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Home My WebLink About200-069 Ima ect Well History File' Cover( e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. .RESCA~ DIGITAL DATA OVERSIZED (Scannable) V Grayscale items: rn Otb er. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: .~ /< OVERSIZED (Non-Scannable) [3 Other: , NOTES: [] Logs of various kinds [] Other Project Proofing .. III IIIIIIIIIIIIII Scanning Preparation BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S! BY: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO Stage 2 BY~ BEVERLY BREN VINCENT SHERYL MARI/~ LOWELL DATE: (SCANNING IS COMPI.ETE AT THIS POINT UNLESS SPEC[AL ATTENTION IS REQUIRED ON AN IND~VIOUAL PAGE BASIS DUE TO QUALI'YY, GRAYSCN_E OR COI.OR IMAGES) ISl ReScanned (individual page [special attention] scanning completed) RESCANNEDBY; BEVERLY B~HERY~. MARIA LOWELL General Notes or Comments about this file: Quality Checked (done) lO/25/02Rev3NOTScan ned.wpd ~ ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Friday, October 02, 2009 3:44 PM To: Saltmarsh, Arthur C (DOA) Cc: Eddy, Andrea (SAIC) Subject: 10-407 Corrections Attachments: PBU 15-42, 11-07-95.pdf Hi Art, ~ ~ t ~' ~~~v'~ ~a~~ ~:r~~~~~% ~'; ~ : .;.. It has recently been discovered that the surface location for the following wellbores should be corrected to match the As-Built. PSD # 195-185, 15-42 (Abandonedl~------ _~ PTD # 200-069 15-42A Abandoned, Extension of 15-42) PTD # 209-073, 15-42B (Current Active ellbore Surface Location should read: 2753' FSL, 3721' FEL, Sec. 22, T11 N, R14E, UM Thanks! Terrie PS - Thanks Andrea! 10/5/2009 STATEOFALASKA f ^ f ;;°; ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ WELL COMPLETION OR RECOMPLETION REPORT AND LQC .. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ~ Abandoned ^ Suspended zoaaczs.~os zonnczs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ~ Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/22/2009 12. Permit to Drill Number 200-069 `' 309-227 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 07/08/2000 13. API Number 50-029-22624-01-00 / 4a. Location of Well (Go ernme tal S n): Surface: 7/ ~~ ~/~~~ ' ' 7. Date T.D. Reached 07/13/2000 14. Well Name and Number: PBU 15-42A ~' 2526 FNL, FEL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 4921' FNL, 445' FEL, SEC. 22, T11N, R14E, UM 8• KB (ft above MSL): 64' Ground (ft MSL): 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4275' FNL, 1590' FWL, SEC. 23, T11 N, R14E, UM 9. Plug Back Depth (MD+~/D) 11630' 8869' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 677524 y- 5958992 Zone- ASP4 10. Total Depth (MD+ND) '13215 8798 16. Property Designation: ADL 028307 TPI: x- 680860 y- 5956675 Zone- ASP4 Total Depth: x- 682878 - 5957371 Zone- ASP4 11. SSSV DeN A(MD+~/D) 17. Land Use Permit: y 18. Directional Survey ^ Yes ~ No Submit el ronic an rin ed information er 20 AA 2. 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (ND): 1900 (Approx.) 21. Logs Obtained (List al! logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR & MEM GR / CCL / CNL Z2. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETfING DEPTH TVD HOLE I14MMOUNT WT'. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD ` PULLED ` 2" 91.5# H-40 SurFace 110' S rf ce 110' 30" 260 sx Arcticse -/" 47# u1f ' rf ' 12-1/ " 442 sx'G', 1260 sx CS III, 250 sx CS I 7" 29# L-80 Surfa 2 9' S rface 1' -1 /2" 210 sx I s'G' 4-1/2" 12.6# L-80 9125' 11590' 164' 8870' 6" 285 sx Class' ' -/ 6x -7/" .#/ .# L- 1' 13 0' 7 4' 7 8' 4-1/" 1 xLA 23. Open to production or inject ion? ^ Yes ~ No 24. Tue~NC RecoR~ If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number); Size ~EPTH SET MD PACKER SET MD 4-1/2", 12.6#, 13Cr80 8788' 8700' MD TVD MD TVD 4-1/2", 12.6#, L-80 9045' - 9126' 9091' ZS. ACID, FRACTURE, CEMENT SQUEEZE', ET0. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED - '3~~js; 11630' SetWhipstock ZF). PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: PROOUCr~or, FoR TEST PERIOD Q~L-BBI: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Cn~cuu~Te~ 24-HouR Rnre• OIL-BBL: GAS-MCF: WATER-BBI: OIL GRAVITY-API ~CORR~: 27. CoRe Dara Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~ None ~:~~ ~" i~~~ ~a'~'1' e: ~ 7~Og ~ ~~ ~ ~ ftE[~ , .~~E4~ ` Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~~~~ ~ ZS. GEOLOCzIC MARKERS ~LIST ALL FORMATIONS AND MARKERS ENCOUNTERED~: Z9. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ~ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test infom-ation per 20 AAC 25.071. Sag River 9241' 826~' None Shublik 9284' 8305' Sadlerochit 9352' 8366' Zone 1 B 9884' 8826' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ /~ / Signed Terrie Hubble Title Drilling Technologist Date ~ PBU 15-42A 200-069 309-227 Prepared ey Namenvumber. Terrie Hubble, 5644628 Wel) Number Permit No. / A POV81 NO. Drilling Engineer: Ron Phillips, 564-5913 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. ITe~ 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITenn 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITea- 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 15-42A, Well History (Pre Rig Sidetrack) Date Summary 6/18/2009 MIRU CTU. MU and RIH w/Baker 2.65" x 12.18' dummy whipstock drift with 2.02" Nozzle. Tag top of 3- 3/16" x 2-7/8" Cross Over at 11661' CTM and POOH. At surface lay down Baker Drift BHA. Freeze protect tubing with 30 bbl of 50/50 meth. Pressure test tree cap to 3,500 psi. Notify Pad Operator of well status. RDMO. Job Comolete. 7/2/2009 T/IA/OA = SSV/600/0 Temp=Sl PPPOT-T (PASS) (Pre CTD) PPPOT-T : RU 2 HP BT onto THA test void 1100 psi, bled to 0 psi. Flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "ET style" (1) LDS @ 5:00 hard to cycle but is moving, some previous damape from aipe wrench. all others were in aood workina condition. 7/12/2009 Pressure test against closed master and wing to 250 low and 5000 psi for 15 mins. Test good. Test aqainst closed swab to 250 low and 5000 psi for 15 mins. Test qood. 8/16/2009 T/I/O = SSV/630/25. Temp = SI. Bleed IAP & OAP to 0 psi (pre CTD prep). No AL or FL attached and ~ welihouse is removed. IA FL near surface. OA FL near surface. Bled IAP from 630 psi to 0+ psi in 4 hr 30 in. Bled ORP from 25 psi to 0+ psi in 2 min. Monitored for 30 min. IAP increased 3 psi. OAP remained unchanged. Final W HPs= SSV/3/0+. Master Valve locked out. Drilling scaffolding is in place. SV / WV / SSV / MV - Closed. IA. OA - OTG. NOVP. 8/17/2009 T/I/O = 2050/55/10. Temp = SI. Bleed IA & OA to 0 psi (pre rig). No AL. IA FL near surface. OA FL near surface. Bled OAP from 10 psi to 0 psi in 1 min. Bled IAP from 55 psi to 0+ psi in 1 hr 15 mins. Monitored for 30 min. TP unchanged, IAP increased 5 psi & OAP increased 3 psi. Final WHPs = 2050/5/3. SV. WV = Closed. SSV. MV = Open. IA & OA = OTG. NOVP. 8/17/2009 T/I/O = 2080/60/20. Temp = SI. WHPs (pre-rig). No AL, no F/L, no W/H. IAP increased 57 psi, OAP increased to 20 psi overniqht. SV, WV - Shut. SSV, MV = Open. IA & OA = OTG. NOVP. 8/17/2009 T/I/0=2100/0/0 Load and kill tbg (pre-ctd) pump 5 bbls 60/40 folllowed by 200 bbls seawater. 8/18/2009 T/I/O=Vac/0/0. Set 4-1/16" CIW H BPV #280 thru tree, pre-Nordic rig. 1-3' ext used, tagged @ 84". No problems. 8/18/2009 Load and kill FP tbq pumped 94 bbls SW (294 total) followed by 30 bbls diesel to freeze protect tbg. Swab closed, wing closed, ssv open, master open, annulus valves open to gauges. Operator notified of well status. FWHP=O/0/0 Page 1 of 1 BP EXPLORATIflN Page 1 ofi 12 Qperations Summary Report Legal Well Name: 15-42 Common Well Name: 15-42 Spud Date: 12/9/1995 Event Name: REENTER+COMPLETE Start: 8/7/2009 End: 8/31/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2009 Rig Name: NORDIC 1 Rig Number: N1 ' Date From - To Hours Task Code NPT Phase Description of Operations 8/20/2009 08:00 - 09:00 1.00 MOB N WAI7 PRE Wait on security to move rig. Another rig camp move was in progress on west dock road. 09:00 - 09:15 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for moving rig from DS 18 to DS 15 with Security, Nordic, SWS and BP personnel. 09:15 - 12:30 3.25 MOB P PRE Move rig to DS 15 with no problems. 6.3 mile derrick up rig move. Position rig in front of DS 15-426. 12:30 - 12:45 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well and setting down. 12:45 - 13:00 0.25 MOB P PRE Back rig over well and set down rig with no problems. Acce t ri at 1300 hrs on DS 15-42B. 13:00 - 15:00 2.00 MOB P PRE Spot tanks and trailers, general rig up. M/U hardline and Tiger tank. 15:00 - 16:30 1.50 BOPSU P PRE N/U BOPE. 16:30 - 21:30 5.00 BOPSU N SFAL PRE Pressure test BOPE. Witness waived by AOGCC inspector Jeff Jones. Unable to get tree valves or Bob swab to hold pressure. Grease crew called out and greased the master, swab, & Bob swab. Trouble shoot valves. Valves holding pressure. Restart BOP test. 21:30 - 00:00 2.50 BOPSU P PRE Pressure test BOPE. Chart tests. 8/21/2009 00:00 - 04:00 4.00 BOPSU P PRE Continue BOP Test. Witness waived by Jeff Jones, AOGCC. Finish Test at 04:00 04:00 - 04:30 0.50 RIGU P PRE Clear rig floor and prep for pulling coil across. 04:30 - 06:00 1.50 RIGU P PRE SAFETY MEETING, re: pulling coil across PU Injector, pull test grapple on reel, remove shipping bar, pull coil across. 06:00 - 10:00 4.00 RIGU P PRE Safery Meeting. Review procedure, hazards and mitigation for stabbing coil and pumping in slack. Stab 2" E-Coil, M/U packoff, reverse circ and fill coil. Pump in slack. reverse circ 2.8 bpm, 4000 psi, 3 times. Cut of 10' of coil. Tested E-Line OK. M/U CTC and pull test 35K. 10:00 - 12:15 2.25 WHIP P WEXIT M/U BHI UQC. Press test CTC and UQC. Press test inner reel valve. Pump slack forward. 12:15 - 12:30 0.25 BOPSU P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for pulling BPV with lubricator. 12:30 - 19:00 6.50 BOPSU P WEXIT Ri u BPV lubricator. Press test lubricator to 1200 si, Pull BPV usin lubricator. } Made 4 attempts, well was on a strong vac, found annular acker rubber in BPV when we recovered the BPV. Rig down lubricator. Clear rig floor. 19:00 - 19:15 025 WHIP P WEXIT SAFETY MEETING, re: PU Whipstock BHA ~ - 19:15 - 20:15 1.00 WHIP P WEXIT PU Whipstock and CoilTrak tools. 20:15 - 22:30 2.25 WHIP P WEXIT Open EDC RIH with Whi stock BHA Stop at 4600' to adjust gooseneck. Continue RIH to 9300' 22:30 - 23:20 0.83 WHIP P WEXIT Log tie-in, -10' correction 23:20 - 00:00 0.67 WHIP P WEXIT RIH to 10600' Printed: 9/1/2009 10:12:56 AM BP EXRLORATI(7N' Page 2 ot 12 Operations Summary R~port Legal Well Name: 15-42 Common Well Name: 15-42 Spud Date; 12/9/1995 Event Name: REENTER+COMPLETE Start: 8/7/2009 End: 8/31/2009 Contractor Name: NORDIC CALISTA Rig Release: 8/31/2009 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 8/21/2009 23:20 - 00:00 0.67 WHIP P WEXIT Log 10600' to 10750' to check depth correction. 8/22/2009 00:00 - 01:15 1.25 WHIP P WEXIT PU Wt is 41.5k# RIH to setting depth Close EDC, Pressure up to 3600 psi, got returns to surface, Did not see a pressure spike indicating the tool sheared. Down on the pumps, stack 1,5k#, PU to 43k#, Tool has not sheared Pressure up to 3400 psi, differential pressure across the tool is 1500 psi Pressure uo to 4000 osi. PU to 46k# and shear cPtting rnri ac_ indicated by a pressure spike and a sharp weight decrease. TOP OF WHIPSTOCK AT 11 630' 90 deg ROHS toolface 01:15 - 03:45 2.50 WHIP P WEXIT Open EDC POH to surface circulating well to milling fluid--2# Biozan 2% KCL doubleslick. 03:45 - 04:45 1.00 WHIP P WEXIT SAFETY MEETING, re: UD Whipstock BHA UD CoilTrak UD Whipstock setting tool 04:45 - 07:30 2.75 WHIP P WEXIT SAFETY MEETING, re: UD CSH in derrick PU 17 stds 1-1/4" CSH in the derrick UD 34 jts 1-1/4" CSH into the pipeshed 07:30 - 07:45 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U window milling BHA. 07:45 - 08:45 1.00 STWHIP P WEXIT M/U BHA #2 window milling BHA with 2.74" HCC window and string mills, Xtreme motor, 2 jts CSH and CoilTrak. BHA OAL = 109.91'. 08:45 - 11:00 2.25 STWHIP P WEXIT RIH with window Milling BHA #2 at 100 fpm. Circ at 0.3 bpm, 800 psi. 11:00 - 11:20 0.33 STWHIP P WEXIT Log GR tie-in at 9400'. -12.5' correction. 11:20 - 12:00 0.67 STWHIP P WEXIT RIH to whi stock. Ta whi stock at 11636'. Up wt = 35K. ~1~~ 12:00 - 15:00 3.00 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2750 free spin, ,C "'2 2750-3000 psi, iK wob, 1/2 fph. 4 stalls total. milled to .r~~t ~ 11637.3' 15:00 - 17:00 2.00 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2650 free spin, 2750-3000 psi, 1 K wob, 1/2 fph. Milled to 11638.1'. 17:00 - 19:30 2.50 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2750 free spin, 2750-3000 psi, 1-2K wob, 1/2 fph. Milled to 11639.9'. 19:30 - 22:00 2.50 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.6 bpm, 2750 free spin, 2750-2900 psi, 0.3k-1.Ok# DHWOB, 1/2 fph. Milled to 11641.9'. 22:00 - 00:00 2.00 STWHIP P WEXIT Mill exited liner. Time mill ahead 1.6 bpm, 28d0 - 2875psi, 1.Ok-1.5k# DHWOB, 4 fph dressing window with string reamer. Drill 10' of rathole at 5 fph. 8/23/2009 00;00 - 02:30 2.50 STWHIP P WEXIT Ream window up & down three times. 11,650' sample shows 70% sand. Start Geo-Vis downhole. RIH through window no pumps. Clean window. WINDOW DEPTHS: 11636' - 11641', not corrected. 02:30 - 05:00 2.50 STWHIP P WEXIT POH 05:00 - 06:45 1.75 DRILL P PROD1 SAFETY MEETING, re: BHA change UD Milling BHA. Mill gauged 2.73" go/2.72" no go, String J Printed: 9/1/2009 10:12:56 AM TREE= t 4-1/8" CIW WELLHEAD = FMC ACTU/~TOR = BA KER C KB. ELEV - 64' BF. ELEV = ~ - _. KOP - _ 1264' Max Angle = 96 ~ 12470' Datum MD = 9987' Datum ND = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" ICtl~t°lt! ~ _ '~.~~~~' '~ ~' ~ L, ~" ~5h~r~ rofil~ ~ 4-1/2" TBG, 12.6#,13~F28t~, .0152 bpf, ID = 3.958" ~~ $7$$' SAFEfY NOTES: SEE GLV ENGR FOR GLM SPECS. 70° @ 9996' AND 90° @ 10179' ~~~4-~f~'" ~NRC}t~~~"~~~ ~T~ Sic~efrac~ 2009~ ~~4-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9126~ TOP OF 4-1/2" LNR 9125~ 7" CSG, 29#, L-80, ID = 6.184" 9299~ ,~ ~ ~~ TOP OF 3-1/2" LNR 9816~ 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~~ 9857. TOP OF 3-3/16" LNR 9857~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 11590~ 3-3/16" LNR, 6.2#, L-80, 11653~ 0076 bpf, ID = 2.80" F'~RFC~FSATIf~N ~U:U~fUtAF2Y €~~ ~o~: ~TV~r~~ oN aa;z~o~ A~~~~~T~c~~ ~: ~~° ~ ~~zaa~ Nc~i~: Refer to ~c~ducfion [7F3 for histc~rica{ perf d~ta SIZE SPF INTERVAL Opt~ISqz DATE 1.56 6 1221~-32480 C3 08i30,'09 1.58 6 1282~1-3317f~ C} U8,'30./{}9 1.56 6 1321~1-1328C7 (~ J&'3~~tt~ 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" 13207' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3283 3181 21 KBG-2 DMY BK 0 08/22/06 3` 5704 5245 32 KBG-2 DMY BK 0 08/22/06 2~ 7284 6559 32 KBG-2 DMY BK 0 01/30/05 1* 8611 7703 28 KBG-2 DMY BK 0 01/30/05 '= GLMS HAV E LOWER P51 RATETHAN NORMAL - $679~ 4-1/2" HES X NIP, ID = 3.813" 8700~ 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" - 8724~ 4-1/2" HES X NIP, ID = 3.813" $7$$' 4-1/2" WLEG ID = 3 958" . , ' " SCOOPGUIDEw/BOWENOVERSHOT, ID=4.00 9045 9091' 7" X 4-1/2" BAKER S-3 PKR 9114~ 4-1/2" HES X NIP, ID = 3.813" 9126~ 4-1/2" TUBING TAIL WLEG ~ ~ ~ ~~; `~ w:~. ~ ~ E~' Tt~p af 2-~~&" liE3er Fl:~tee3 d~playrr~nt sl~ev~ 9816~ 4-1/2"DEPLOYMENTSUB g857~ ~ 3-1/2" X 3-3/16" XO ~ ~9~C~"-1Q965' perfs above 4 1~2" shoe TOE DRILL OUT 11590' .--. 1163~` 3-3(16" F~acker VVhipsicrck P~TC~ 13299' 2-318" ~-80 Lil~er, Cemer~ted & P~~#`r~ ~3338" 12420~ SEf CIBP (7/20/06) TD 13215' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/96 ORIGINAL COMPLEfION 03/18/09 RMH/SV ADPERF (03/13/09) 07/20/00 SIDETRACK 05/19/09 MSE PROPOSED CTD SIDETRACK 02/02/05 MF/GS RWO (DONE BY NORDIC) fl813(7,`Oa TGK ACTUAL CTD S(Q~RAGK 11/04/05 BMcN/TLH DRLG DRAFT CORRECTIONS 07/20/06 CJA/PJC SET CIBP & PERFORATIONS 08/22/06 JCM/PAG GLV GO PRUDHOE BAY UNff WELL' 15-428 PERMfT No: API No: 50-029-22624-02 SEC 22, T11 N, R14E 3689.87' FEL & 4275.04' FNL BP Euploration (Alaska) CJ ~ ~ ~ , ~ ' f d . t f ~:~~~. ~ d ~ F ~ ~ ~ ~ 7 ~ l ~ '~ ~ m.. f ' ~ ~ r ~ . ~ ~ ! Yf : C A g ~ p f~ € ` 4~ ~ ~ ~ k . ke E a~ ~ ~ ~d ( fl z ~ ~ ~~ p F w k ~ q r 1 4 a R ~ ~ p F g`~~ ~~`' ~ ~ ~ (~°-~'¢~ _~ `~ r F . w . G_' ..,~, `~. ~~ t,-~~ 5.~..~..; ~>R . e< ..T~ 4 R. t_A a.). fi. k A..~ ~~~ O~ ~ ~ CO1~T5ERQA7'IO1~T COMNII551O1~T Mr. John McMullen Wells Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: PBU 15-42A Sundry Number: 309-227 ~~'~~~~~ JU~. ;~ ~~ 200~ Dear Mr. McMullen: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 oa'a~ ~ 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 Corrunission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this g day of July, 2009 Encl. ~ p~ STATE OF ALASKA . ~,`~ ALAS~IL AND GAS CONSERVATION COMMIS ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ GP°" ~~~ 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 200-069 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22624-01-00- 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 15-42A - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028307 ~ 64' ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12- ` PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13215 - 8798 ~ 13175 8798 12420' None C sin L n h Size MD TV B rst oll se S ruct ral n r 11 ' 2" 11 ' 11 ' 14 4 Surface 338 ' 9-5/8" 3389' 3280' 6870 476 In rm diate 9299' 7" 92 9' 8318' 160 7 2 Pr i n Liner 2465' 4-1/2" 9125' - 115 0' 8164' - 8 70' 8430 7500 Liner 3392' 3-3/16" x 2-7/8" 9816' - 13208' 8784' - 8798' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9960' - 12335' 8863' - 8804' 4-1/2", 12.6# 13Cr80 & L-SO TO 87~~ ~` 9045' to 9126' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer (2) Packers and SSSV MD (ft): 9091' & 8700' 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: August 27, 2009 ^ Oil ^ Gas ^ Plugged ~ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify tha2 the oregoi is true and correct to the best of my knowledge. Contact Ron Phillips, 564-5913 Printed Name ~h I Title Engineering Team Leader -^'" Prepared By Name/Number Signatur~~~ ~ Phone 564-4711 Date 7 I~U ~ Terrie Hubble, 564-4628 Commission Use OM ~ ~ I -t~ Sundry Number: ~~ ~~ Conditions of approval: Notify Commission so that a representative may witness ' ~ ~~~~~ ~ ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~,~ ~ o~~~~~t 4~1+~~+-~v~O.t~c~J~C`'RS~--- _~,~L°~;_ ~9 ~ ~~l~~ Other: ~~ S~~"`~i.v~-~~'~ ` P ~~~S~~ ~4#~ ~t ~i~IS GOR°~, ~C~~~1ISSIQf~ Anchar~ge Subsequent Form quired: y~ APPROVED BY ~ ~ g A roved B~ COMMISSIONER THE COMMISSION Date ~ Form 10-403 R~~d 06/2006 ' ~... ~~ ,lU~. (~ ~ ?DD9 ; , ; ~ ,r p ~ , t ~ ~ t ~~ 1~ ~_.. Submit In Duplicate .~~~~ ~~% • • To: Tom Maunder Petroleum Engineer h ~ Alaska Oil & Gas Conservation Commission ~`J From: Ron Phillips CTD Engineer Date: June 24, 2009 Re: 15-42A Sundry Approval Sundry approval is requested for well 15-42A. Well 15-42A was a July 2000 CTD sidetrack into Zn lA. It was a toe extension of the parent well (15-42) and followed the structure up. The parent well's perfs were cemented behind the 2-7/8" liner. The well was a fulltime producer for the next 2 years. It was SI for TxIA comunication in the September 2002. It was worked over in early 2005. The well produced full time for a year post the RWO until Jan 2006 when it hit MGOR and began to cycle. The coil service unit set a CIBP over the last set of perfs to reduce uncompetitive gas production in July 2006. In addition to the CIBP, 150' of Zonel perfs were added in what was once the parent well. The adperfs & CIBP operation briefly reduced the well's GOR. However by August 2008 the GORs had climbed back up. In an attempt to prop up the oil rates and reduce the well's GOR, 95' of adperfs were shot on 3/13/09. The initial test showed a GOR reduction. However, the well was back to making over 80,000 GOR within a week. The 15-42A well shows very little healing during shut-in and always comes back at above MGOR. The well has a rapidly declining uptime of 48%. The mechanical condition of the well is splendid. The well passed its CTD screening on 4/17/2009 with the MIT-IA passing to 3000 psi and the MIT-OA passing to 2000 psi. REASON FOR SIDETRACK: The last test had the well making a GOR of over 80k scf / bbl --- which is way above MGOR. The wellwork options have all been exhausted. The well has a declining ontime and shows no ability to recharge. A CST will enable this 4-1/2" Cr TBG wellbore to be more effectively utilized. The proposed plan for 15-42A is to drill a Zn 1 A sidetrack with a Coiled Tubing Drilling rig on or around Aug 27, 2009. The existing perforations below the whipstock setting depth (11630') will be isolated by setting a 3-3/16" packer whipstock. The perforations above 11630' will be isolated by the primary cement job after drilling the well and running liner. All of these perforations are in the same Ivishak Zone 1 reservoir that this lateral will be drilled in. The sidetrack, 15-42B, will exit the existing 3-3/16" liner and drill a 90 deg turn back to the South. The parent well swung North. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. • Pre-Rig Work: 1. C Drift run with dummy 3-3/16" Baker whipstock to ~11650' 2. O MIT-IA to 3000psi Done 04/17/09 3. O MIT-OA to 2000psi Done 04/17/09 4. O PPPOT-T 5. O Function LDS 6. V PT tree (MV, SV, WV). 7. O Blind and bleed lines, remove well house, level pad. • Done 06/18/09 ~ ~~~ ~Qp~Ov0.~ Rig Work: (scheduled to begin on Aug 27, 2009) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Set a 3-3/16" Baker acker WS 90 de ROHS at 11630'. 3. Mi112.8" window and 10' of rat hole. Swap the well to Flo-Pro. 4. Drill Turn/Lateral: 3" OH, 1410' (12 deg/ 100 planned) 5. Run 2-3/8" solid liner leaving TOL at 9700' 6. Pump primary cement leaving TOC at TOL, 11.8 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (~ 1000' ) 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well Ron Phillips CTD Engineer 564-4913 CC: Well File Sondra Stewman/Terrie Hubble 2 TR~ _ ' 4-1 /8" CAN WEL.LHEAD = FMC AeCTUATOR = BAK6~ C KB. E1EV = 64' BF. ~EV = ? KOP = 1264' Max Angle = 99 @ 12321' Datum N~ = 9987' Datum ND = 8800' SS S NOTES: SEE GLV ENGR FOR GLM SPECS. 15-42A 704-1/29CH OMETBG ~0179' • ~ 4-1 /2" HES X NIP, ID = 3.813" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" H 3389~ Minimum ID = 2.375" @ 11653' 3-3/16" X 2-7/8" CROSSOVER ~ ~ 4-1/2" TBG, 12.6#,13CR80, .0152 bpf, ID = 3.958" ~-{ $7$$' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9126' ~ TOP OF 4-1/2" LNR 9125~ ~° csc, 2s#, ~-80, io = s.~sa" 9299' TOP OF 3-1/2" LNR 9816~ 3-1/2" LNR 9.3#, L-80, .0087 bpf, ID = 2.992" 985T TOP OF 3-3/16" LNR 9857' 12.6#, L-80, .0152 bpf, ID = 3.958" Pff2FORATION SUMMARY R~ LOG: MWD/GR ON 07/07-13/00 ANGLE AT TOP P6~F: 63° @ 9960' Note: Refer to Production DB for historical perf data SIZE SPF IMERVAL Opn/Sqz DATE 2" 6 9960 - 9980 O 03/13/09 2" 6 10020 - 10045 O 03/13/09 2" 6 10570 - 10620 O 07/20/O6 2" 6 10750 - 10850 O 07/20/O6 2" 6 10940 - 10965 O 03/13/09 2" 4 11650 - 12210 O 07/18/00 2" 6 12310 - 12335 O 03/13/09 2" 4 12850 - 13170 c 07/18/00 bpf, ID = 2.441" GAS LIFf MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3283 3181 21 KBG-2 DMY BK 0 08/22/06 3' 5704 5245 32 KBG-2 DMY BK 0 OS/22/06 2' 7284 6559 32 KBG-2 DMY BK 0 01/30/OS 1' 8611 7703 2S KBG-2 DMY BK 0 01/30/OS = GLMJ F1AV t LUWtit Y,1 KA 1 t 1 MAN NVKMAL 8679~ 4-1 /2" HES X NIP, ID = 3.813" 8700' 7" X 4-1l2" BAKER S-3 PKR, ID = 3.875" 8724~ 4-1/2" HES X NIP, ID = 3.813" 8788~ 4-1/2" WLEG, ID = 3.958" 9045' SCOOP GUIDE w/BOWBJ OV B~SHOT, ID = 4.00" 9091' 7" X 4-1 /2" BA KER S-3 PKR 9114~ 4-1 /2" HES X NIP, ID = 3.813" 9126' 1~4-1/2" TUBING TAIL WLEG 9816' H4-ii2^o~oYnn~rvrsus 3- TOE DRILL OUT 11590' ~ .0076 bpf, ID = 2.80" TD DATE REV BY COMMENTS DATE REV BY COMMBJTS 01/17/96 ORIGINAL COMPLETION 03/18/09 RMH/SV ADPff2F (03/13/09) 07/20/00 SIDETRACK 05/05/09 MSE ADD INFO 02/02/05 M F/GS RWO (DONE BY NORDIC 11/04/OS BMcWTLH DRLGDRAFTCORRECTIONS 07/20/06 C.JA/PJC SET CIBP & P~2FORATIONS 08l22/06 JCM/PAG GLV GO I SET CIBP (7/20/06) I PRUDHOE BAY UNIT WElL: 15-42A P~ZMfT No: ~`2000690 API No: 50-029-22624-01 SEC 22, T11 N, R14E 3689.87' FEL & 4275.04' FNL BP 6cploration (Alaska) TREE = 4-1 /8" CNV WELLHEAD = FMC AC'fUATOR= BAKERC f<B. E1EV = 64' BF. F1EV = ? KOP = 1264' Max Angle = 99 @ 12321' Datum MD = 9987' Datum ND = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" 15 ~~~ ~ S~99fi AND 0@ 10179GR FOR GLM SPECS. ~ *"'4-1 /2" C HROM E T BG'*" Proposed CTD Sidetrack ~ 4-1 /2" HES X NIP, ID = 3.813" ~ GAS LIFT MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3283 3181 21 KBG-2 DMY BK 0 08/22/O6 3' 5704 5245 32 KBG-2 DMY BK 0 08/22/O6 2* 7284 6559 32 KBG-2 DMY BK 0 01/30/05 1" 8611 7703 28 KBG-2 DMY BK 0 01/30/05 Minimum ID = 2.375" @ 11653' 3-3/16" X 2-7/8" CROSSOVER ~ ~ 4-1/2" TBG, 12.6#,13CR80, .0152 bpf, ID = 3.958" ~~ $7$$' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 7" CSG, 29#, L-80, ID = 6.184" TOP OF 3-1/2" LNR 3- 4-1/2" LNR, 12.6#, .0087 bpf, ID = 2.992" ~• TOP OF 3-3/16" LNR • 0, .0152 bpf, ID = 3.958" 3-3/16" LNR 6.2#, L-80, .0076 bpf, ID = 2.80" '= GLMS HAVE LOWER PSI RATETHAN NORMAL $679~ 4-112" HES X NIP, ID = 3.813" 8700~ 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 8724~ 4-1/2" HES X NIP, ID = 3.813" $788' 4-1/2" WLEG, ID = 3.958" 9045' SCOOP GUIDE w/BOWEN OV ERSHOT, ID = 4.00" 9091~ 7" X 4-1/2" BAKER S-3 PKR 9114~ 4-1 /2" HES X NIP, ID = 3.813" 9126~ 4-1/2" TUBING TAIL WIEG TSGR 9240` I ent sleeve ° 9700~ ~Top of 2-3/8" liner Fluted dep 23 9816~ 4-1/2" DEPL.OYMQVT SUB 9857' ~3-1/2" X 3-3/16" XO ~ 9960'-10965' perfs above 4 1/2" shoe I 11653' I PERFORATION SUMMARY REF LOG: MWD/GR ON 07/07-13/00 ANGLE AT TOP PERF: 63° @ 9960' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9960 - 9980 O 03/13/09 2" 6 10020 - 10045 O 03/13/09 2" 6 10570 - 10620 O 07/20/06 2" 6 10750 - 10850 O 07/20/O6 2" 6 10940 - 10965 O 03/13/09 2" 4 11650 - 12210 O 07/18/00 2" 6 12310 - 12335 O 03/13/09 2" 4 12850 - 13170 c 07/18/00 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" 13207~ TOE DRILL OUT 11590' - 11630~ 3-3/16" Packer Whipstock ~ 2-3/8" L-80 Liner, Cemented & Pert'd 13040~ 12420' SEr CiaP (7i2oios) To H 1 DATE REV BY COMMEMS DATE REV BY COMMENTS 01/17/96 ORIGINAL COMPLETION 03/18/09 RMH/SV ADPERF (03/13/09) 07/20/00 SIDETRACK 05/19/09 MSE PROPOSm CTD SIDETRACK 02/02/05 M F/GS RWO (DONE BY NORDIC) 11/04/05 BMcWTLH DRLG DRAFT CORRECTIONS 07/20/O6 CJA/PJC SET CIBP & PERFORATIONS OS/22/O6 JCNVPAG GLV GO PRUDHOE BAY UNff WELL: 15-426 P9~Mff IVo: API No: 50-029-22624-02 22, T11 N, R14E 3689.87' FE1. 8 4275.04' FNL BP Exploration (Alaska) • • Review of Sundry Application 309-227 BP Exploration (Alaska) Inc. Well PBU 15-42A AOGCC Permit 200-069 Requested Action: BP Exploration (Alaska) Inc. (BPXA) proposes to abandon the existing wellbore to prepare the well for sidetracking. Recommendation: I recommend approval of Sundry Application 309-227 to allow BPXA to perform this operation. Discussion: The current well is a sidetracked well from the mother bore (15-42). That mother bore produced a cumulative amount of 1,444 Mbbls over the four years until it was abandoned and sidetracked into 15-42A. The cumulative oil produced in 15-42A is 1,136 Mbbls, where as the estimated amount of reserves remaining was 660 Mbbls using the trend of most recent decline historical data. (See Appendix A) Beginning in mid 2000, 15-42A showed good production at ~3,000 bopd and had a relatively low GOR at 7.0 Mcf/bbl but had a sharp reduction in oil production and a slow increase in GOR until it hit 316 bopd and a GOR of 34.8 Mcf/bbl in September 2002. In September 2002 it was SI for TxIA communication and only produced four days out of the next twenty-eight months. In February 2005, 15-42A was brought back online and was producing at a high rate of 1,734 bopd but again quick declined to less than 800 bopd in May 2005. In January 2006, 15-42A hit its MGOR and began to be cycled. Since June 2006, 15-42A has been cycled with 15 out of 23 months having less than 20 days of production and 10 months with less than 9 days of production. During this time the GOR kept increasing and as of Apri12009 the GOR was 86 Mcf/bbl with only a production rate of 217 bopd. Appendix B shows the increasing GOR compared to the decreasing oil production. Reading the plan for the abandonment process that was included with the Sundry Application, it is apparent that well 15-42B is to penetrate the Ivishak zone lA which is the same zone that was previously penetrated. 15-42B differs from its predecessors by the direction the well is to be drilled, south, where as the parent well was drilled to the north. Conclusion: • • 15-42A is still a decent producer in bbl of oil but has and had a high GOR. By plugging the current well and sidetracking to a location to the south, away from the gas, seems to be a sound choice for this well. I recommend approving BPXA's request. College Intern AOGCC Aaron Kohring I concur with this statement Reservoir Engineer AOGCC David Roby ~ ? 7 09 •• T ~~~ ~~.~ ~ Appendix A 10000 1000 ~ a 0 a 100 d m ~ O 10 ~ Worldng Forecast Parameters Phase :Oil CaseName Case1 b 0.49724 Di 0290046Ae. qi :1620.57 bbVd ti :12/31/2002 te 02/28/2019 Final Rale 99.6802 bbVd Cum. Prod. 1135.92 Nbbl Cum. Date 04/30/2009 Reserves 660.814 Nbbl Reserves Dffie 02/28/2019 EUR 1796.73 Nbbl Forecast Ended By : Rate DB Forecast Date : Nol Saved ReserveType : None 1 2000 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 DATE Appendix B ~as ~o° 10' 10' 10 10' ~J ~ LUUU U1 UZ Ud u4 uo w v~ w ~• DATE - ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 01, 2009 3:18 PM To: Gary Preble (SAIC) Subject: DS 15-42A (200-069) Gary, I am reviewing the 404 for the perforating operations on this well. An interval 12310 - 12335 is listed on the perf sheet, but this interval is not listed in the operations report. The interval 10020 -10045 is listed twice. Could you reconcile please? Tom Maunder, PE AOGCC ~'~4Jw~~~IC' ~~!k ~3 ~ 6.,V L~~ Maunder, Thomas E (DOA From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Wednesday, April 01, 2009 3:43 PM To: Maunder, Thomas E (DOA) Subject: Emailing: 15-42AWORK SUMMARY CORRECTION.PDF Attachments: 15-42AWORK SUMMARY CORRECTION.PDF ~~. 15-42AWORK iMARY CORRECTI01 Tom, The perf attachment was correct but the work summary was wrong. I have changed it on the summary that is attached. Thanks The message is ready to be sent with the following file or link attachments: 15-42AWORK SUMMARY CORRECTION.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «15-42AWORK SUMMARY CORRECTION.PDF » STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~ION REPORT OF SUNDRY WELL OPERATIONS, 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ r 7S ;gpg, ~II(trmirc. E Of? Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension U~£~tffr a¢ ~ + ~4 Change Approved Program ~ Operat. Shutdown ~ Perforate 0 ~ Re-enter Suspended Well 2.Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to DriII Number: Name: Development ~ Exploratory Zoo-osso - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22624-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64 KB ~ PBU 15-42A 8. Property Designation:. 10. Field/Pool(s): ADLO-028307 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13215 - feet Plugs (measured) 12420' 7/20/06 true vertical 8798.48 - feet Junk (measured) None Effective Depth measured 13175 feet true vertical 8798 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 Surface 3358 9-5/8" 47# L-80 31 - 3389 31 - 3280 6870 4760 Production 9269 7" 29# L-80 30 - 9299 30 - 8318 8160 7020 Liner 2465 4-1 /2" 12.6# L-80 9125 - 11590 8164 - 8870 8430 7500 Liner 41 3-1/2" 9.3# L-80 9816 - 9857 8811 - 8868 8520 7660 Liner 1796 3-3/16" 6.2# L-80 9857 - 11653 8811 - 8868 8520 7660 Liner 1554 2-7/8" 6.5# L-80 11653 - 13207 8868 - 8798 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# 13CR-80 28 - 8788 4-1/2" 12.6# L-80 9045 - 9126 Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER S-3 PKR 8700' 7"X4-1/2" BAKER S-3 PKR 9091' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 525 41620 0 1407 Subsequent to operation: 476 35743 0 1773 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ' " Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG T GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 3/20/2009 rune iv-~ruw RCV Cu v~+icwv gg au~m~t Vflglnal vnry 15-42A 200-069 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15-42A 7/18/00 PER 11,650. 12,210. 8,867.97 8,816.9 15-42A 7/18/00 PER 12,850. 13,170. 8,801.12 8,797.85 15-42A 10/21/04 BPS 9,400. 13,170. 8,408.84 8,797.85 15-42A 1/31/05 BPP 9,400. 13,170. 8,408.84 8,797.85 15-42A 7/17/06 BPS 12,420. 13,170. 8,792.66 8,797.85 15-42A 7/19/06 APF 10,570. 10,620. 8,876.54 8,876.14 15-42A 7/19/06 APF 10,750. 10,850. 8,873.98 8,873.89 15-42A 3/12/09 APF 10,940. 10,965. 8,873.2 8,872.76 15-42A 3/12/09 APF 12,310. 12,335. 8,807.83 8,803.85 15-42A 3/13/09 APF 9,960. ~e/' 9,980. 8,863.39 8,871.82 15-42A 3/13/09 APF 10,020. 10,045. 8,883.74 8,887.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r~ LJ 15-42A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3111/2009]**** CTU 9 -1.75 CT **** Log /Add Perfs ""'`*" MiRU -Knock WHP down - fMU/R!Htyith PDS GRICCL Tag at 12453 -log up at 50 fpm to 8600', pooh. ;DATA good. MU pert gun. l*"job continued on WSR 03-12-09** 3112/2009**continued from WSR 03-11-09** Scope; adperfs, RIH w! 25' x 2', 6SPF 2006 PJ perf gun and pert int 12310' -12335' Tag cibp and tie in, pu to shoot depth, Edropped two ea 1/2" balls and did not see any good indication of frying, pooh.- 'Gun # 1 all shots fired -recover two 112" balls. MU/RIH gun # 2 and perf int 10940 -10965 -good surface indication gun fired - POH- LD gun # 2. All shots !fired, Trim 100' of pipe..MU & RIH wf gun # 3. **continued on WSR 03-12-09** 3/13l2009Continued from INSR 03-12-09 CTU 9 1.75" pipe, Continue RIHw/ 8NA # 3. sat dawn high @ 12300 mechanical and 12,138 electronic, attempt to tag again and ;pumped down backside attempting to flush away debris. Tag same depth. Pooh. lck guns..OK -Confer with CT Scheduler dec€ssion not to re log -continue to use CIBP at MCNL depth of 12423'. RIH with Gun # 3 - 25' of 2"-6SPF-PJ 2006 HMX - taa CIBP a# 12449 ctm up - PUH to pert depth and pert ftom 10020 - 14045 -Good surface indication gun fired.POH LD gun #3 all shots fired - `MUIRIH w !Gun # 4 - 20' 2"-6SPF-PJ 2006 HMX .tag C18P @ 12460. tie into 12,422' and pull up and shoot pert interval ~ 8960-9980. good indication of ;firing. pooh. All sho#s fired. ""*job complete** rig down continued on WSR 03-14- ;09 _...... -.--..._....._.. _...__ ............._. , ...,............_.._..........._.................................._ .......v............._....._.. _...__...__ _...._. _...._._. _........._....,......_.._._... _............___.. ~... 3113/2009jHeat 1% kCl for Coil. {Add perfs). Heated upright # 73084 to 120* for coil, 3114/2009 ~ Contnued~~from 1NSR 02-18-09.. finish rig down. *"" job comple'te~ ""* ~ ~ ~"~ ~ ~~~~~~~~ ~ ~~ FLUIDS PUMPED BBLS 50 1 %KCL W/6% SAFELUBE 153 60140 METH 37 1 %KCL 240 Total `DA good. MU pert gun. **job ontinued on WSR 03-12-09** i 3/12/2009""contin d from WSR 03-11-09** Scope; adperf .RIH w/ 25' x 2', 6SPF 2006 z PJ perf gu and pert int 10020 - 10045_Tag cib and tie in, pu to shoot depth, j 'dropped two a 1/2" balls and did not see an good indication of firing. pooh.- ,Gun # 1 all sh s fired -recover two 1/2" ba . MU/RIH gun # 2 and perf int _, _ _ _ y ~ 10940 - 10965 - ood surface indication n - POH- LD gun # 2. All shots ~'~~' t~ " ~ ~~ ~ ;fired, Trim 100' of ipe..MU & RIH w/ gu # 3. "`continued on WSR 03-12-09** /~ _~,.~ ~ F ,. :_ ':_~~L..o.:~~~z~~~ fit; 3/13/2009;Continued from WSR 03- -0 j !down high @ 12300 mecha 'i pumped down backside atte "ck guns..OK -Confer with CIBP at MCNL depth of 42; HMX - taa CIBP at 124 ctm 1 I VVY.! - VVVU JUI 1~ MU/RIH w /Gun # a 12,422' and pull Miring. pooh. All c `.09 -- -b - Z`TU 9 1.75" pipe. Continue RIHw/ BHA # 3. sat and 12,138 electronic, attempt to tag again an3 ng to flush away debris. Tag same depth. Pooh. heduler decission not to re log -continue to use H with Gun # 3 - 25' of 2"-6SPF-PJ 2006 - UH to perf depth and, perf from 10020 - ed.POH LD gun #3 all shots fired - 06 HMX .tag CIBP @ 12460. tie into erv 9960-9980. good indication of lete riq down continued on WSR 03-14- 3/13/2009; Heat 1 % kc for Coil. (Add perfs). Heated upri t # 73084 to 120" for coil. 3/14/2009~Continue from WSR 02-13 09.. finish rig down. *"job complete *"" FLUIDS PUMPED BBLS 50 1 %KCL 6% SAFELUBE 153 60/40 TH 37 1 % K L 240 Total c maicauon gun - 20' 2"-6SPF-PJ and shoot erf int s fired. ""job comp • LL LAG - -- , ~. -- - - -- :~ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/men Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petratechnical beta Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 J l 7 / /~ ~ and ProActive Diagnost~ Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907] 245-8952 1) Coil Flag 11-Mar`09 15-42A E~ 50-029-2262401 2) Jewelry Log 11-Mar09 15.42A EDE ~ 5@=F}~9~2'62~401 1 ! t__.~ Signed : ~ ~° ~~ .~ ~ '~~ Oate ~~- :.~ Print Name: PROACTIVE DU\GNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-98952 EawAIL: r~'a~7..5:3~~~7?!t~'s"i"~":G`:~IL' ~'3~?3 WEBSITE r~~ ;li,~ ::33s"'Jv~~,a",3's'~3 C:\Documents and Settv~gs\OwneclDesktap\Transmit_BP.doac . RECEIVED ALASKA Oil AND ~~T~g~S~l:::~ON COM Mil ON SEP 2 7 2006 REPORT OF SUNDRY WELL OPERA TION80ì1 & Gas Cons. Commission 1. Operations Perfonned: OtherŒJ CIBP AbandonD Repair WellD Plu: PerforationsD Stimulate 0 Alter Casing 0 Pull TubingD Perforate New PaolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD ...... ...... 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StråtigraPhicO ServiceD 50-029-22624-01-00 7. KB Elevation (ft): 9. Well Name and Number: 64.00 15-42A 8. Property Designation: 10. Field/Pool(s): ADL-028307 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 13215 feet true vertical 8798.0 feet Plugs (measured) CIBP set @ 12420 (07/17/2006) Effective Depth measured 13175 feet Junk (measured) None true vertical 8798.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 - 112 32.0 - 112.0 1490 470 SURFACE 3358 9-5/8" 47# L-80 31 - 3389 31.0 - 3280.0 6870 4760 PRODUCTION 9269 7" 29# L-80 30 - 9299 30.0 - 8318.0 8160 7020 LINER 2465 4-1/2" 12.6# L-80 9125 - 11590 8164.0 - 8870.0 8430 7500 LINER 41 3-1/2" 9.3# L-80 9816 - 9857 8784.0 - 8811.0 10160 10530 LINER 1796 3-3/16 6.2# L-80 9857 - 11653 8811.0 - 8868.0 8520 7660 LINER 1554 2-7/8" 6.5# L-80 11653 - 13207 8868.0 - 8798.0 10570 11160 Perforation depth: Measured depth: 10570-10620,10750-10850,11650-12210,12850-13170 ~~t:·! . :¿ True vertical depth: 8877-8876,8874-8874,8868-8817,8801-8798 'fjç~",¡.. ..."".' . Tubin: (size, :rade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 28 - 8788 4-1/2" 12.6# L-80 @ 9045 - 9126 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 8700 " . . 7" Baker S-3 Packer @ 9091 4-1/2" HEX X Nipple @ 2009 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT 0 3 2006 Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubin: Pressure Prior to well operation: 586 26935 27 --- 1460 Subsequent to operation: 824 10,919 49 --- 1090 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A9J:~ ~~~ Phone 564-5174 Date 9/22/06 fOrm 10-404 Revise r<lbll\iAL . . 15-42A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/25/2006 TIO = 22801990/20. Temp = SI. WHPs & IA FL (post TIFL). No AL. TBGP unchanged, lAP increased 10 psi, OAP unchanged, IA FL dropped 35' to 5545' overnight. 08/24/2006 T/I/O = 22801980/20. Temp = SI. WHPs & IA FL (post TIFL). No change in pressures overnight. IA FL @ 5510' (between sta #4 & #3). 08/23/2006 T/I/O = 228012300/20. Temp = S/I. No AL. TIFL - PASSED. (Post-DGLV, PW Day 11). IA FL @ 5704' (STA#4 DMY) (101 bbLs). Bled IA from 2300 psi to 980 psi in 1.25 hrs. IA FL rose 146' to 5558' during bleed. Monitored for 1 hr, no change in lAP, or IA FL. Final WHPs = 2280/980/20. 08/22/2006 ( gl maint- prob well) SET DGL V'S IN ST A'S 4 & 3 PULLED EMPTY c-SUB *** WELL LEFT SI *** 08/21/2006 *** WELL SI ON ARRIVAL, MASTER CLOSED, SSV DUMPED **** (gl maint- prob well) SET 4 1/2" SS C-SUB @ 5843' SLM PULLED S/O FROM ST A #3--- 5684' SLM & LGL V FOM STA #4--- 3263' SLM 08/15/2006 T/l/0=SSV/1720/20. Temp=SI. WHP's post-TIFL (eval high lAP). Could not obtain TBGP master valve was flagged and SSV was closed, DSO not available. lAP increased 130 psi from 1590 psi to 1720 psi. No change in OAP 08/14/2006 T/l/0=2360/1590/20. Temp=SI. WHP's post-TIFL (eval high lAP). lAP increased 240 psi. OAP increased 20 psi. 08/13/2006 T/I/O=2360/135010. Temp=SI. WHPs post-TIFL. TBGP increased 10 psi, lAP increased 150 psi. No change in OAP over night. 08/12/2006 T/I/O=2350/235010, Temp=SI. Perform TIFL (FAILED on BUR) (high lAP). No AIL. InitiallA FL @ 5704' STA# 3 (100 bbls). Bled lAP from 2350 psi to 1200 psi in 45 min. IA FL remained unchanged. Monitor pressures for 1 hr, TBGP remained unchanged, lAP remained unchanged OAP remained unchanged, IA FL remained @ 5704'. FWHP=2350/120010. 07/19/2006 CTU #9 w/1.75" CT. RIH wI gun run #4. tie into CIBP, perf 10750'-775', POOH. Cut pipe, do injector maint., MU and RIH with gun run #5. Tie into CIBP, PUH and perf 10,595' - 10,620'. POOH. MU and RIH with gun run #6. Tie into CIBP, PUH and perf 10,570' -10,595'. POOH. Freeze protect well to 2500' with 50/50 meth water down backside while POOH. RD CTU and notify pad operator of well status. **** Continued on 07/20/06 WSR **** Note: Guns were 2.0" - 6 SPF - 60 deg - PJ2006 HMX - 6.5 gm - .23" Ent Hole - 19.0" Penetration 07/18/2006 CTU #9 w/1. 75" CT. MU new WFD MHA with SLB firing head and 25' of perf guns for gun run #2. RIH, tie into CIBP, perf 10,800-825', and POOH. MU gun run #3, RIH, tie into CIBP, perf 10,775-800', and POOH. MU gun run #4, RIH. Page 1 . . 15-42A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/17/2006 CTU #9 w/1. 75" CT. MU and RIH with WFD MHA with PDS MEM GR/CCL to 12600' CTM. Log interval 12600' to 10200'. Paint flags at 12400' and 10750' and POOH. Tied into SWS MCNL 7/16/00; good data with -24' correction. RIH and set CIBP at 12,420'. POOH. MU 25' of perf. guns to WFD MHA for run #1. RIH and tag CIBP and correct depth to 12418.8' .(bottom shot) POOH to 10850' and perforate interval from 10850'-10825'. POOH to surface. 07/16/2006 MEM GR/CCL/ CIBPI ADPERF. CTU #9. Move on to pad and wait for Rig 27E to clear equip from in front of well #42. Spot unit and rig up, perform weekly BOP test. 07/15/2006 *** Well Flowing on arrival *** Drift wI 2.25: cent. & sample bailer to 9910' slm, ( no sample) Notify DSO of well status, returned to prod. FLUIDS PUMPED BBLS 48 50/50 Methanol Water 1342 1 % KCL Water with 0.6% Safe Lube 1390 TOTAL Page 2 TREE : 4-1/8" CrN ~ NOTES: SEE GLV ENGR FOR GLM SPECS. WELLHEAD: FMC 15-42A , ACTUATOR: BAKERC 70·@ 9996' AND 90· @ 10179' ***4-1/2" CHROM E TOO*** KB. ELEV : 64' BF. ELEV : ? KOP= 1264' Max Angle = 99 @ 12321' Datum MD = 9987' I 2009' -14-1/2" HES X NIP, ID = 3.813" I Datum TVO = 8800' SS I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 3389' ~ ~ GAS LIFT MANDRELS L ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 4 3283 3181 21 KBG-2 OMY BK 0 08/22/06 3' 5704 5245 32 KBG-2 DMY BK 0 08/22/06 Minimum ID = 2.375" @ 11653' 2' 7284 6559 32 KBG-2 DMY BK 0 01/30/05 l' 8611 7703 28 KBG-2 DMY BK 0 01/30/05 3-3/16" X 2-7/8" CROSSOVER . = GLM SHAVE LOWER PSI RATE THAN NORM AL 'Z. I..,..." 8679' -14-1/2" HES X NIP, ID= 3.813" I ""-'" 8700' 1- 7" X 4-1/2" BAKER S-3 A<R, ID = 3.875" I . 1 8724' 1- 4-1/2" HES X NIP, ID = 3.813" I 14-1/2" TBG, 12.6#,13CR80, .0152 bpf, ID = 3.958" I 8788' 8788' 1- 4-1/2" WLEG, ID: 3.958" 1 9045' 1- SCOOP GUIDE w /BOWEN OVERSHOT, 10 = 4.00" 8 ~ -17" X 4-1/2" BAKERS-3 A<R I ""-'> 9091' . 1 9114' 14-1/2" HES X NIP, ID: 3.813" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9126' I 9126' -14-1/2" TUBING TAIL WLEG I I TOP OF 4-112" LNR I 9125' .. . 7" CSG, 29#, L-80, ID = 6.184" I 9299' 1---4 ... TOPOF 3-1/2" LNR H 9816' I I I I 9816' 1-14-1/2" DEA..OYMENT SUB I ---- I 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I 985T 1---- _ 1-13-1/2" X 3-3/16" XO I ~- I 9857' TOPOF 3-3/16" LNR I 9857' ~ ~~ SIDETRACK WINDOW 11590' 14-1/2" LNR. 12.6#, L-80, .0152 bpf, ID = 3.958" I 11590' I ÆRFORA TION SUMMARY REF LOG: MWD/GR ON 07/07-13/00 11653' 113-3/16" X 2-7/8" XO, ID = 2.375" I ANGLE AT TOP ÆRF: 90 @ 10570' Note: Refer to Production DB for historical perf data 12420' 1-1 SET CIBP ~12r;¡IQê) I SIZE SPF INTERV AL Opn/Sqz DATE r 2" 6 10570 - 10620 0 07/20/06 o'/.I?/~ÞOG 2" 6 10750 - 10850 0 07/20/06 13-3116" LNR, 6.2#, L-80, 11653' I 2" 4 11650 -12210 0 07/18/00 2" 4 12850 - 13170 0 07/18/00 .0076 bpf, ID = 2.80" I PBTD I 13175' ~ I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" I 13207' I TD I 13215' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 01/17/96 ORIGINAL COM PLETION WELL: 15-42A 07/20/00 SIDETRACK ÆRMrr No: "2000690 02/02/05 M F/GS RWO (DONE BY NORDIC) API No: 50-029-22624-01 11/04/05 BMcNlTLH DRLG DRAFT CORRECTIONS SEC 22, T11 N, R14E 3689.87' FEL & 4275.04' FNL 07/20/06 CJA/PJC SET CIBP & ÆRFORA TIONS 08/22/06 JCM'PA G GLV C/O BP Exploration (Alaska) . . WELL LOG TRANSMITTAL RE:C;E:I\/E:[) ProActive Diagnostic Services, Inc. AUG 2 9 ZUUG I\Iaska Oil & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and lor Tubing Inspection[Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 J EDE Disk 2) 3J 4) 5) 6) 7) D.S. 15-42A 5-Jul-06 Coil Flag SCANNED AUG 3 0 2006 Print Name: tpk_ _CJ'l (Y1)~ IJLf> ~L./Llc..e1l\ Date: trl~)Ov / Û¿~ Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: POSANCHORAGE{â1MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM Qro-00~ :¢- /4015 I C:IDocumenfs and SeUingslPDS Anchorage· MPLIDcskfopITran..mif_Original.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc , STATE OF ALASKA ') Re~~,v- .. ALASKJ.. )IL AND GAS CONSERVATION C<J...MISSION \.IE:: ~o REPORT OF SUNDRY WELL OPERATIONS MAR 0'3 2005 Alaska Oil & Gas Cons. Cnmmitslon Anchorage 0 Other 0 Time Extension 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 028307 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 64' 13215 8798 13175 8798 110' 3389' 92991 2465' 3392' 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 200-069 6. API Number: 50-029-22624-01-00 99519-6612 9. Well Name and Number: PBU 15-42A 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst 20" 110' 110' 1490 9-5/8" 3389' 3280' 6870 7" 9299' 8318' 8160 Collapse 470 4760 7020 4-1/2" 3-3/16" x 2-7/8" 9125' - 11590' 8164' - 8870' 9816' - 13208' 8784' - 8798' SCANNED MAR 0 4 2.005 8430 7500 11650' - 13170' 8868' - 8798' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4-1/2", 12.6# 13Cr80 & L-80 Surface to 8788' & 9045' to 9126' 9091' & 8700' 2009' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker 'S-3' packer (2/Ea) 4-1/2" 'X' Nipple Treatment description including volumes used and final pressure: RBDMS BFl MAR 0 3 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure 10,366 4 20,059 -0- 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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 Scott Kolstad, 564-5347 N/A Oil-Bbl Prior to well operation: 438 Subsequent to operation: 1,010 14. Attachments: 0 Copies ot Logs and Surveys run 181 Daily Report ot Well Operations 181 Well Schematic Diagram 13. Printed Name Terrie Hubble Signatur~i f. ~~ Form 10-404 Revised 04/2004 Tubino Pressure 1 ,400 1,787 Title Technical Assistant Phone Date 03/UL/O"S Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 \C'.l.r:,~. ,i\ \ n 0\. . -; t~ :\. . \ I." " -- ') ) Well: Field: API: Permit: 15-42A Rig Workover Prudhoe Bay Unit 50-029-22624-01-00 200-069 Accept: Spud: Release: Rig: 01/26/05 N/A 02/01/05 Nordic #2 PRE-RIG WORK 1 0/19/04 PULL PX PRONG AT 9083' SLM. PULLED PX PLUG BODY AT 9086' SLM. DRIFTED WI 33/8" DUMMY GUN TO 9350' SLM. (TARGET 9250') 10/21/04 SET 4-112" HALLIBURTON FAS DRILL PLUG AT 9247'. FIRED 12' OF STRING SHOT ACCROSS INTERVAL 9037' -9049' IN PREPARATION FOR CHEMICAL CUT. CUT 4-1/2" 12.6 #/FT TUBING WITH 3-5/8" CHEMICAL CUTTER AT 9048'. GOOD INDICATIONS OF FIRING AT SURFACE. AFTER STABBING OFF WELL, PART OF TOOL STRING MISSING. FROM TOP DOWN, MISSING PARTS CONSIST OF (CATALYST SUB) 1-1/2" 00 X 2- 1/2 LENGTH + 2-1/4" 00 X 1-11" LENGTH + (SEVERING HEAD) 3-5/8" 00 X 8" LENGTH + (CENTRALIZER) 20- 1/2" + (BULLNOSE) 2" FOR A TOTAL OF 34.5". 1 0/26/04 RAN 3.5 LIB SAT DOWN AT 9034' SLM. REC SMALL MARK OF DEEP CUT, CLOSE TO CENTER OFLlB. RAN D-CENT WI 3.5 LIB SAT DOWN AT 9034' SLM. REC. CUT TBG ON LOW SIDE. TWO HALF MOON C-CUTTER CLOSE TO CENTER. 1 0/27/04 RAN 3 1/4 PUMP BAILER WI 3.61 FINGER GRAB BOTTOM, SAT DOWN AT 9068' SLM. FELL DOWN TO 9105' SLM. RIH WID-CENTRALIZER, 3.5 LIB, SAT DOWN AT 9105' SLM. FELL THRU. RIH WI 3" PUMP BAILER SAT DOWN AT 9105' SLM. FELL THRU SAT DOWN AT 9254' SLM. RDMO. 11/02104 TAGGED UP AT 9112' SLM, WI 3.75" LIB (LIB SHOWS POSSIBLE TBG TAIL STUB). TAGGED TOP OF FISH WI 3.50" LIB AT 9245' SLM. FISHED 1/2 OF FISH (CHEM CUTTER). 11/03/04 ATTEMPTED TO SPEAR CHEM CUTTER FISH SEVERAL TIMES WITHOUT SUCCESS. RAN LIB SAT DOWN AT 9245' SLM, LIB SHOWS 1/2 MOON. RAN PUMP BAILER WI SNORKEL TO 9245' SLM, MIT & NO MARKS. RAN VARIOUS SPEARS UNABLE TO LATCH. TAGGED TOP OF FISH W/3.5" TAPERED LIB AT 9241' SLM. MADE SEVERAL MORE RUNS WITH SPEAR. RUN HYD BAILER. 11/04/04 RUN HYDROSTATIC BAILER. RUN SPEAR, LIB, POCKET PUNCH. BOX TAP, MAGNET, BLIND BOX. RAN HYDROSTATIC BAILER W/3.58" FINGER BASKET. RECOVERED ONLY SOME FINES. 11/05/04 RAN NUMEROUS FISHING ASSEMBLIES ATTEMPTING TO RETRIEVE CHEM CUTTER HEAD. RIH BOX TAP GRABBED & PULLED FISH UP TO 9103' SLM. SHEARED GR. RUNNING IN W/4 1/2 GS. 11/06/04 RETRIVED FISH. ') ) BPEXPLORATION Operations Summary Repørt , Paget of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-42A 15-42A WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/24/2005 Rig Release: 2/1/2005 Rig Number: Spud Date: 12/9/1995 End: Date . From - To Hours Task ' Code NPT Phase Description of Operations 1/25/2005 16:00 -18:15 2.25 MOB P PRE Continue rig down operations on Y-06. 18:15 - 18:35 0.33 MOB P PRE Safety meeting prior to laying over derrick. 18:35 - 21 :45 3.17 MOB P PRE Scope down derrick. Lay derrick down into pipe shed. Held post well pad inspection with pad operator. No problems found. 21:45-22:15 0.50 MOB P PRE Safety meeting with crew about pending rig move. Discuss SWS/Nordic premove checklist and action items. 22:15 - 22:40 0.42 MOB P PRE Safety meeting with tool service and security about rig move. 22:40 - 00:00 1.33 MOB P PRE Begin rig move from Y pad to DS 15 on the EOA. 1/26/2005 00:00 - 13:00 13.00 MOB P PRE Continue move from Y pad to DS 15. The rig was at the Frontier corner as of 04:30. 13:00 - 13:20 0.33 MOB P PRE PJSM to raise derrick. 13:20 - 16:00 2.67 MOB P PRE Raise Derrick. 16:00 - 16:30 0.50 MOB P PRE PJSM to move over well. 16:30 - 17:00 0.50 MOB P PRE Move rig over well. 17:00 - 18:00 1.00 MOB P PRE Accept rig at 17:00. Begin rigging up. 18:00 - 18:30 0.50 RIGU P PRE PJSM about plan forward. Finish MIRU, Pull BPV, Circ out well, test BOP trolly. 18:30 - 20:30 2.00 RIGU P PRE Continue with RU. 20:30 - 20:45 0.25 RIGU P PRE Pick up valve crew lubricator. 20:45 - 20:55 0.17 RIGU P PRE PJSM Re: Pulling BPV. 20:55 - 21 :30 0.58 RIGU P PRE Pull BPV 21 :30 - 00:00 2.50 RIGU P PRE Slide in cuttings box. Position tiger tank. Rig up and PT hardline to tiger tank. Move BOP trolly to middle of pad. Blow first vac truck of 120 degf 2% KCL into pits. Position 2nd vac truck near pits. 1/27/2005 00:00 - 02:30 2.50 RIGU P PRE Continue to rig up hardline to tiger tank. Drill site maintenance had to wait for a pump to PT with, then had a couple of leaking chick's. Had to change those out. Final PT to 4000 psi passed ok. 02:30 - 03: 15 0.75 BOPSURP DECOMP Come on line with 160 degree KCL. Pump down the lA, taking returns of diesel freeze protect fluid from the tubing. Displace out 40 bbls of freeze protect. Initial pump pressure 340 psi at 2.5 bpm. SD pumps, rig up to pump down the tubing. Circulate down the tubing taking returns from the IA to the tiger tank. Pump pressure 790 psi at 4 bpm. 03:15 - 03:40 0.42 BOPSUF P DECOMP Hold risk ascessment meeting with hands involved in test of 13-5/8" BOP trolley. Discuss anticipated hazards of this new piece of equipment. Discuss mitigations to hazards. 03:40 - 06:00 2.33 BOPSUR P DECOMP Continue pumping to circ out well, while assembling BOP stack on new trolley. 06:00 - 06:20 0.33 BOPSUP P DECOMP Hold TL and PJSM. Review plan forward for building 13-5/8" BOP stack on new BOP Skid and functioning of the trolley. Also discuss SIMOPS for ND production tree. Discuss frostbite hazards. Current temp is -33F with 4mph winds. 06:20 - 09:15 2.92 BOPSUFP DECOMP Set TWC with T-bar and test from beneath to 500 psi. ND production tree and adapter. Build 13-5/8" stack on skid/trolly. Shutdown operations on nippling up stack on trolley system due to cold weather conditions. Did test stack moveability without the 13.8k annular on the stack and it was no problem moving the stack back and forth. ND BOP componets and will proceed with normal NU procedures without the use of the skid Printed: 2/7/2005 9:39:13 AM ) ) , BP EXPLORATION, Operé1ti()n.sS~mmary Report' Page 2 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-42A 15-42A WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/24/2005 Rig Release: 2/1/2005 Rig Number: Spud Date: 12/9/1995 End: 'Date From -To Hours Task Code NPT Phase Description of Operations 1/27/2005 06:20 - 09:15 2.92 BOPSUF P DECOMP system. (plan is to use the skid/trolley when we ND the 13-5/8" stack once the well work is finished) Alert AOGCC of pending bop test. 09: 15 - 11 :30 2.25 BOPSUP P DECOMP ND 4-1/16" 5K production tree to the tbghead. Install 4-1/2" NSCT XO to check tbg hanger threads. Made up 8-1/2 rds which is just right. Remove XO. Check LDS. 11 :30 - 18:00 6.50 BOPSUR P DECOMP NU 13-5/8" BOP stack choke/kill/control lines. 18:00 - 18:30 0.50 BOPSUR P DECOMP Pre tour safety meeting. 18:30 - 00:00 5.50 BOPSUR P DECOMP Resum~ NU of the 13-5/8" stack, choke/kill manifold, riser and control lines. 1/28/2005 00:00 - 04:30 4.50 BOPSUP P DECOMP Pack about 20 softball sized gel balls down around the leaking 7" packoffs. Perform weekly BOP test. Gel is working to seal off leaking 7" packoffs. Witness of BOP test waived by AOGCC, Jeff Jones. 04:30 - 05:30 1.00 BOPSUP P DECOMP Pull TWC. 05:30 - 06:00 0.50 PULL P DECOMP Rigging up 5" DP pups to use as landing joint to pull tubing. 06:00 - 06:30 0.50 PULL P DECOMP Hold PJSM with oncoming crews. Review procedures for pulling tbg hanger to surfae. Spot SWS e-line surface equipment (if needed for another chem cut). 06:30 - 10:10 3.67 PULL P DECOMP Measure in hole with 5"DP and 4-1/2" NSCT XO to top of hanger. Make-up 9rds. Backout LDS. Clear floor. Pull tbg hanger to floor without problems up wt 92k. Release SWS e-line crew. Backout hanger. RU Camco spooler hyd control lines. Tool service NORM hanger and tree. Will send in for reconditioning. UD hanger and pulling equipment. R/U to pull tbg. 10:10 - 16:30 6.33 PULL P DECOMP Pull and I/d 4-1/2" L-80 BTM tbg to SSSV. Recovered 53 of 55 SS bands. Have 107jts I/d. 16:30 - 17:15 0.75 PULL P DECOMP With crane lift Nabors's Eckels tongs and remove Camco spooler. 17:15 - 18:00 0.75 PULL P DECOMP Continue pulling 4-1/2" tbg. 18:00 - 18:10 0.17 PULL P DECOMP PJSM for pulling tubing. 18:10 - 22:15 4.08 PULL P DECOMP Continue pulling 4-1/2" tubing completion. Bleeding OA to 0 while pulling pipe. 22:15 - 23:15 1.00 PULL P DECOMP Recovered cut tubing to surface. Cut looks in good shape. Minimum OD of pipe at stub is 4-7/16". Cut appears to be circular and just as needed to run completion. We recovered 213 joints, 3 GLM, and stub. Stub was in first full joint below bottom GLM. Stub was 20.95' long. The stub sticking up downhole should be 20.88' long. Layout pipe from pipe shed. 23: 15 - 23:35 0.33 PULL P DECOMP Safety meeting prior to pulling 7" casing packoffs. 23:35 - 00:00 0.42 PULL P DECOMP Check OA, no pressure. Pull old 7" casing packoffs to rig floor. Took 19 klbs overpull to get them free. Recovered all seals, etc. 1/29/2005 00:00 - 01 :30 1.50 PULL P DECOMP Run new 7" casing packoffs. Rllockdown screws. PT to 5000 psi. Passed ok. 01 :30 - 01 :50 0.33 CLEAN P DECOMP PJSM with slickliners and rig crews prior to running slickline. Discuss SIMOPS with bringing in tubing. Hazards and mitigations to hazards. 01 :50 - 03:00 1.17 CLEAN P DECOMP PU SWS 7" lubricator and close in bag. Rig up slickliners upper and lower sheaves, and manual packoff. Rig up junk basket with 6.07" gauge ring. 03:00 - 06:00 3.00 CLEAN P DECOMP Run slickline junkbasket and gauge ring. A little tight at 5000'. Printed: 2/7/2005 9:39: 13 AM ') ) , BPEXPLORATION , , ,Opéré1ti:ons Summary: Report ,Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-42A 15-42A WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/24/2005 Rig Release: 2/1/2005 Rig Number: Spud Date: 12/9/1995 End: Date From - To Hours Task Code NPT Phase Description of Operations 1/29/2005 03:00 - 06:00 3.00 CLEAN P DECOMP RIH. Tagged up hard 2 x at 9046. POOH slick. Recovered 1-1/2 SS bands. Reran GB recovered 1-2/3 SS bans and small pieces of misc crud. Rerun GB 3rd time. Same time have been loading tbg in shed. 06:00 - 14:30 8.50 CLEAN P DECOMP Make 3 cleanout runs with junk basket. Last 1 empty. Got 2 missing control line clamps, and other debris. Attempt to run scoop guide, could not get it to set. POOH, marks on bottom of scoop guide indicate it was hitting top of tubing stub. Run LIB. 14:30 - 16:00 1.50 CLEAN N SFAL DECOMP Hydraulics failed on SL unit. Wait on repairs. 16:00 - 16:45 0.75 CLEAN P DECOMP LIB confirms good clean cut, no damage to tubing stub. 16:45 - 18:00 1.25 CLEAN P DECOMP Grind inside of scoop guide to a sharper edge. RIH with scoop guide again. 18:00 - 19:45 1.75 RUNCOMP RUNCMP Tag up on top of tubing stub with scoop guide. Set down 10 times. Clean PU, indicating it is not setting. Get a little rougher with it. Set down 20 times. Got good overpull to max slickline pull of 1800 Ibs. Looks set. Jar off of it, and POOH. 19:45 - 22:00 2.25 RUNCOMP RUNCMP Back on surface, scoop guide left in hole as expected. Rig up 3.80" drift BHA to run thru it and confirm it is set properly. RIH. Made it thru scoop guide slick. Tagged up at TTP at 9119'. POOH. 22:00 - 22:30 0.50 RUNCOMP RUNCMP Rig down slickliners. 22:30 - 00:00 1.50 BOPSUP P RUNCMP Pressure test lower set of rams. Passed ok on low and high tests. 1/30/2005 00:00 - 00:20 0.33 RUNCOMP RUNCMP Bring Nabors casing crew eq. to rig floor to prepare to run crome tubing. 00:20 - 01 :00 0.67 RUNCOMP RUNCMP PJSM prior to running tubing. Discuss hazards/mitigations. Prepare floor valve with right crossover for V AM top tubing. 01 :00 - 06:00 5.00 RUNCOMP RUNCMP Run 4-1/2" VAM top 13 crome completion as per proceedure. All pin connections below Baker packer were Baker locked. All connections above packer were lubed with Jet Lube Seal Guard Thread Compound. On joint 65 of 204 at 05:00 06:00 - 06:15 0.25 RUNCOMP RUNCMP PJSM with oncoming crews and casinghand. 06:15 - 15:00 8.75 RUNCOI\IP RUNCMP Continue running 4-1/2" tbg. Total of 204jts of 4-1/2" 12.6# 13Cr-80 VamTop and jewelry. Torqued to +/-4400fVlbs using Torque-Turn and "Soft" dies in tongs. 15:00 - 16:00 1.00 RUNCOMP RUNCMP MU FMC tbg hanger (NSCT top thds) and landing joint. RIH and land tbg. RILDS 16:00 - 18:00 2.00 RUNCOrvP RUNCMP MU circulation lines to annulus and tbg. Mix corrosion inhibitor. (Hold PJSM for picking Nabors tongs oft rig floor using crane) 18:00 - 19:00 1.00 RUNCOrvP RUNCMP Crew change, and finish rigging up to circulate. 19:00 - 21 :00 2.00 RUNCOrvP RUNCMP Circulate 290 bbls of clean 2% KCL at 100 degf down the tubing, taking returns from the annulus to the tiger tank. Pumping at 3 bpm, 300 psi as per the Baker packer hand. 21 :00 - 22:00 1.00 RUNCOrvP RUNCMP Circulate 160 bbls of clean 2% KCL with 2 drums Corexit corrosion inhibiter down the backside at 3 bpm, 370 psi. 22:00 - 22:30 0.50 RUNCOrvP RUNCMP Drop ball and rod. Wait 15 minutes. Pressure up to 4000 psi to set packer. 22:30 - 23:30 1.00 RUNCOrvP RUNCMP Hold pressure on tubing for 1/2 hour. Initial tubing pressure = 4000 psi Printed: 2/7/2005 9:39: 13 AM ') ) BPEXPLORATION Operâtions,SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/30/2005 1/31/2005 15-42A 15-42A WORKOVER NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 22:30 - 23:30 1.00 RUNCOMP RUNCMP 23:30 - 00:00 0.50 RUNCOMP RUNCMP 00:00 - 00:10 00: 10 - 00:30 0.17 RUNCOMP 0.33 RUNCOMP RUNCMP RUNCMP 00:30 - 01 :00 0.50 BOPSUR P RUNCMP 01 :00 - 01 :20 0.33 BOPSUP P RUNCMP 01 :20 - 06:00 4.67 BOPSUPP RUNCMP 06:00 - 06:15 0.25 BOPSUR P RUNCMP 06: 15 - 08:30 2.25 BOPSURP RUNCMP 08:30 - 08:45 0.25 BOPSUP P RUNCMP 08:30 - 12:00 3.50 BOPSUF P RUNCMP 12:00 - 16:30 4.50 WHSUR P RUNCMP 16:30 - 18:00 18:00 - 18:50 1.50 WHSUR P 0.83 RIGD P RUNCMP POST 18:50 - 19:00 19:00 - 19:45 0.17 RIGD P 0.75 RIGD P POST POST Page4 of 5 Start: 1/24/2005 Rig Release: 2/1/2005 Rig Number: Spud Date: 12/9/1995 End: Final tubing pressure = 3933 psi. Good pressure test of tubing. Bleed tubing pressure to 1500 psi, pressure up IA to 3500 psi, and hold for 1.2 hour. Initial; TP = 1800 psi, lAP = 3500 psi. Final; TP = 1800 psi, lAP = 3475 psi. Good pressure test.of IA. Continue with IA pressure test. Passed ok. Bleed tubing pressure down to shear DCK valve in upper GL station. Did not shear the first time. Pressure up tubing to repeat. It sheared the 2nd time. Pump 2 bbls to confirm good communication. Pumped at 1 bpm, 120 psi. Good communication thru DCK valve. Rig down the landing joint. Dry rod in a TWC. Pressure test from below to 500 psi. Passed ok ND riser and 13-5/8" hydril. Crew change. Review plan forward. Continue to prep BOP for lifting onto new BOP Trolley/Skid system. (Loader operator is having some stomach discomfort and was taken to the Deadhorse medic. Will report on his condition after he arrives back to rig. Bladder infection. Given medication and allowed to return to work). Attach lifing cap onto remaining stack: single gate/mudcross/single gate PJSM review Operation Procedures and Risk Assessments for BOP Carrier System. Open cellar doors and level area around wellhead. Position BOP skid next to wellhead with trolley in forward position and locked. (Note: position it 30" from wellhead center to first cross I-beam on skid and in-line with rig's center line) Attach rig's bridge crane to stack lifting cap and position over trolley. Lower onto trolley guide pin and secure with special studs. Unlock trolley and move stack back to rear position and lock. Unable to close cellar door on drillers side. Trolley forward/lock and rotate stack from a 1 hole position to square position. Trolley back to rear position and lock. Now able to close door. Simple, smooth operation. Nipple up adaptor and original re-conditioned 4-1/8" 5K production tree. FMC test void between adaptor and hanger to 5k. Test tree to 5K Same time removing off drillers side stair case in preparation for Endicott wells. Spot Little Red and pre-heat diesel to 60f R/U lubricator and pull TWC RU to freeze protect well with diesel. Continuing to do crane work to change out landings for moving rig in at Endicott. Help PJSM with hand working outside. Ambient temperature -35 degf, WC--55 degf. Discuss hazards of working in cold. Take plenty of warm up breaks, don't expose your fingers to cold, keep your gloves on, etc. Told them to take plenty of time, and not get in a hurry. Safety meeting with Little Red about pumping diesel. Pump 75 bbls of diesel down the IA. Pump at 3 bpm, 1150 psi. Printed: 2/7/2005 9:39: 13 AM ) ) Page 50ts BP EXPLORATION 'OpérätionsS uml11ary" Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-42A 15-42A WORKOVER NORDIC CALISTA NORDIC 2 Date From- To Hours Task Code NPT Phase 1/31/2005 POST POST 19:00 - 19:45 0.75 RIGD P 19:45 - 20:45 1.00 RIGD P 20:45 - 21 :30 0.75 RIGD N 21 :30 - 22:30 1.00 RIGD P WAIT POST POST 22:30 - 00:00 1.50 RIGD P 2/1/2005 00:00 - 01:30 1.50 RIGD P 01 :30 - 06:00 4.50 RIGD P POST POST POST 06:00 - 06:15 0.25 RIGD P POST 06:15 - 07:30 1.25 RIGD P POST 07:30 - 08:30 1.00 RIGD P POST 08:30 - 11 :45 3.25 RIGD P POST 11 :45 - 12:00 0.25 RIGD P POST 12:00 - 12:30 0.50 RIGD P POST 12:30 - 13:10 0.67 RIGD P POST 13:10 - 14:00 0.83 RIGD P POST 14:00 - 14:30 0.50 RIGD P POST 14:30 - 14:31 0.02 RIGD P POST Start: 1/24/2005 Rig Release: 2/1/2005 Rig Number: Spud Date: 12/9/1995 End: Description of Operations Hook up jumper hose to let well U-tube IA to tubing. Wait for 1 hour for U-tubing to occur. Valve crew busy on 4ES. Waiting for them to arrive to set BPV. Continue to let well U-tube. Rig up lubricator, set BPV. Test BPV from the bottom to 500 psi. It held fine. RD lubricator. Suck back diesel from tree to Little Red. RD Little Red. Begin to clean pits with Vac truck. Continue with crane work replacing ram on elevator system. Continue with rig down, continue working with crane to remove bad elevator ram. Release rig at 01 :30. Continue with rig repairs and rig down. Finally got old ram out. Work to install new elevator ram. Position injector to lower derrick. Air up tires to move off well. Hook up bridle lines to scope in derrick. Ambient temperature -35 degf, WC = -54 degf. PJSM review on going work and associated hazards from frostbite. Finsih work on elevator lift. Scope down derrick. Prep to pull of well. Air up tires. Move off well. Hold Safety meeting with crane operator Re: current weather conditions. It is marginal for doing the full stack BOP trolley test. Discuss using crane for only lifting the 2 single gates and trolley to stow them on the lowboy. The crane operator is comfortable with that lift. Hold PJSM with full rig team and crane operator. Discuss making a lift of the single gates and trolley. Everybody is comfortable with the lift. Center the BOP single gates and flow cross on the BOP trolley. Lift complete assembly onto the lowboy. Current winds are 24 mph, gusting to 38 mph. Lift went perfectly. The single gates on the trolley hang perfectly straight. There is no tilt to the trolley at all. It should be the same with the hydril on top. Good job to tool pusher Ron Holmes for designing this trolley, and GBR for building it. Weather conditions were just declaired phase 2. We will continue to clean up on pad and reevaluation the move when ready. The rig is ready to move. Weather conditions are not suitable for moving the rig due to blowing snow reducing visibility, and snow drifting on the road. We will begin standby waiting on weather. Further telex entries carried on Endicott 1-27 MR. Printed: 2/7/2005 9:39: 13 AM ') ) Well: Field: API: Permit: 15-42A Rig Workover Prudhoe Bay Unit 50-029-22624-01-00 200-069 Accept: Spud: Release: Rig: 01/26/05 N/A 02/01/05 Nordic #2 POST RIG WORK 02106/05 PULL BALL & ROD AT 8692' SLM. PULL 1" DMY GLV AT STA# 3 AT 5687' SLM, & DCK VLV AT STA# 4 AT 3267' SLM. SET GENERIC GLV AT STA# 4 AT 3267' SLM & ORIFICE GLV AT STA# 3 AT 5687' SLM. PULL RHC FROM 8703' SLM. DRIFT WI 3.625 TO FAS DRILL PLUG AT 9261' SLM. 02115/05 MU/RIH WI BAKER 3.75" WASH OVER SHOE. TAG FASDRIL PLUG AT 9271' CTM-UP. MILL TO 9276'. 02116/05 MILLING FASDRIL PLUG FROM 9276'.9277'. BIT STUCK. SWAP FLUIDS TO DIESEL. POPPED FREE ON 6TH JAR LICK. POOH. RE-CHECK INJECTIVTY. PERFORM WEEKLY BOP TEST. MILUPUSH FASDRIL PLUG WI 3.75" FIVE BLADE MILL FROM 9271'- LINER TOP AT 9816'. CHASE FINAL SWEEP OUT OF HOLE. PERFORM INJECTIVITY TEST. MUIRIH WI 3 118" VENTURI. 02117/05 RUN VENTURI FROM 9250' TO LINER TOP AT 9816'. MAKE REPEAT PASSES ABOVE LINER TOP. POOH. PERFORM INJ TEST. RECOVERED 1 CUP OF METAL SHAVINGSISMALL COMPOSITE SHREDS/PIECES. MUIRIH WI 2.5" - 3 BLADE JUNK MILL. CLEAN OUT TO 11,653'. POOH. MUIRIH WI 2.2" - 3 BLADE MILL. RUN TO 13,065'. COIL STACKING OUT DUE TO HOLE DEVIATION. NO INDICATION OF MOTOR WORK OR TAG ON BOTTOM. POOH. 02118/05 COMPLETE POOH. RDMO. JOB COMPLETE. TREE = FMC WELLHEAD = CrN ACTUA TOFr;----SAKÊ'R ¿ 'KB.'ä.E\i';" ,.. ",.", "é4' . ..,....,., ""'..n. . "".. ..".... BF. ELEV = _? 'KÕP';" ,', ""'1264' .. .""... .. .... . . . .... .... ..... . ""..,,,.. Max Angle = 99 @ 12321' bâtüm MD ';" "',, """,, '9987; 'OatlJ'rii l\ib ..~..... ... 8800" '88' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1--1 3389' ) 15-42A FROM DRLG - DRAFT 51 )V NOTES: GLMS HAVE LOWER PSI RATE THAN NORMAL. CHECK W / ACE/FE. TIGHT SPOT @ 9100' (06/07/97); OBSTRUCTION@ 9120' (11/22/97); 70° @ 9996' AND 90° @ 10179' Need to review post workover r--J Minimum ID = 2.375" @ 11653' 3-3/16" X 2-7/8" CROSSOVER ---~ 86'79' 'X', N~PPI.e, W" I 3".8..1, 3" !O" -//,t8l,. ~ . 8700' 1--1 Bak¡1r 4 112 x l 83 packer 1.//1 8723' I., X' Nipple wi 3.813" ID ~- /,....-l. .~/ :8: 9045' - Scoop Guìde wi Bowen overshot attached to tubing r,;tub wi spìral qrapple 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1--1 I TOP OF 4-1/2" LNR 1--1 7" CSG, 29#, L-80, 10 = 6.184" 1--1 I TOP OF 3-1/2" LNR 1-1 I I 2009' I-I 4-1/2" "X" NIPPLE, ID::: ~'L8B" ~ I ST MD L -1* 8G11 2* 7284 3* b'704 4 32H3 lV 0 DEV GAS LIFT MANDRELS TYÆ VLV LATCH PORT DMY BK 0 DMY BK 0 DMY BK 0 DKC BEK-2 DATE 01/29/05 01/29/05 01/29/05 01129/05 @ tZ 8'--1 .J &--i 8788' 1-1 4-1/2", 12,6#, 13Cr-80 I TUBING w IWLEG 9091' 1-1 7" X 4-1/2" BAKER S-3 PKR I . . 9114' 1-1 4-1/2" HES X NIP, 10 = 3.813" I 9114' 1--1 TIP (10/12/02) I 9126' 91251 9299' 9816' I " 1 91261 1-1 4-1/2" TUBING TAIL WLEG I ! ..i~1 I ,J.lI. l 9,242' ¡----" ~-.k--'I I I I I 1-1 Ha!!ìburton FAS Drill compoßít I I brid¡:;e plug Dr~"d ~ qZIZCDS 9816' 1--1 4-1/2" DEPLOY MENT SUB 3-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" 1--1 9857' ~ I TOP OF 3-3/16" LNR 1--1 9857' ~ 9857' 1--1 3-1/2" X 3-3/16" XO 1 I 4-1/2" LNR. 12.6#, L-BO, .0152 bpf, ID = 3.95B" H 11590' J ~ ÆRFORA TION SUMMARY REF LOG: I'v1WD/GR ON 07/07-13/00 ANGLEATTOPÆRF: 93 @ 11650' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11650-12210 0 07/18/00 2" 4 12850 - 13170 0 07/18/00 DATE 01/17/96 07/20/00 02/10102 1 0/04102 06/13/03 03/19/04 COMMENTS ORIGINAL COM PLETION SIDETRACK RN/TP CORRECTIONS SDF/KK GL V CIO CMO/TLP MAX ANGLE CORRECTION JLA/TLH CORRECTION (TIP 10/12/02) REV BY SIDETRACK WINDOW 11590' 116531 1--1 3-3/16" X 2-7/8" XO I 3-3/16" LNR, 6.2#, L-80, --1 11653' I _? bpf, 10 = 2.80" I TOP OF 2-7/8" LNR Ii 11653' I 2-7/8" LNR, 6.5#, L-80, .00579 bpf, ID = 2.441" 1--1 13207' I TO 1--1 13215. I PRUDHOE BA Y UNIT WELL: 15-42A ÆRMIT No: 2000690 API No: 50-029-22624-01 SEC 22, T11 N, R14E 3689.87' FEL & 4275.04' FNL DA TE REV BY COMMENTS 02/01/05 MF/GS RIG WORKOVER BP Exploration (Alaska) Re: DS15-42 Permit to Drill Subject: Re: DS15-42 Permit to Drill Date: Mon, 22 May 2000 13:54:51 -0900 From: "Danny T Kara" <DKARA~ppco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us> CC: "Lamar L Gantt" <LGANTT~ppco.com>, "Paul C Rauf" <PRAUF~ppco.com> Blair, We would appreciate approval of the Prudhoe DS15-42A Permit to Drill by this Thursday, May 25. Thanks for your efforts. Dan Kara 263-4837 Blair Wondzell <blair wondzell@admin.state.ak.us> on 05/22/2000 08:31:27 AM To: Danny T Kara/AAI/ARC0@Arco cc: Lamar L Gantt/AAI/ARCO@Arco, Paul C Rauf/AAI/ARCO@Arco Subject: Re: DS15-42 Permit to Drill Dan, Will do. Blair Danny T Kara wrote: > Blair, > We are again requesting an accelerated approval. Please review Prudhoe well > 15-42A as soon as reasonable possible. We are experiencing some prep work > problems in both wells 7-34 and 15-45. Well 15-42 is the only option at this > time in the event the problems are not quickly resolved. The CTD rig should be > ready to move later this week and 15-42 also needs work completed prior to the > rig moving on location. > As stated in the last E-mail sent to you, we will do a leak-off-test. > Thanks for your assistance. > Dan Kara > Phillips Alaska, Inc > 263-4837 1 of 1 5/23/00 9:37 AM BP Amoco Baker Hughes INTEQ Survey Report L, nTEQ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft Latitude: 70 17 35.236 N 676296.98 ft Longitude: 148 34 21.213 W North Reference: True Grid Convergence: 1.34 dog Well: 15-42 Slot Name: 42 15-42 Well Position: +N/-S 125.33 ft Northing: 5958991.50 ft Latitude: 70 17 36.468 N +FJ-W 1230.42 ft Eastiag: 677524.05 ff Longitude: 148 33 45.354 W Position Uncertainty: 0.00 ft Wellpath: 15-42A Drilled From: 15-42 500292262401 Tie-on Depth: 11590.00 ft Current Datum: 59 ' 42 5/30/1996 16:49 Height 63.72 ft Above System Datum: Mean Sea Level Magnetic Data: 1/22/2001 Declination: 26.84 dog Field Strength: 57483 nT Mag Dip Angle: 80.79 dog Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff dog 0.00 0.00 0.00 26.86 Survey: MWD Start Date: 7/13/2000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation :~::?~:~::~:~11590.00, }::8869.64~i~:: Kick-off:: :: ~ ~::Point: : :?:/~ :; ! : ~ :}~/~ :~:: :~?:~:: : ~!;i: i: ~ 113215.00 8798.44 Projected to TD Survey 11590.00 91.23 103.39 8869.64 8805.92 -2931.60 4877.94 5956176.11 682469.55 0.00 -411.40 11623.00 91.20 102.80 8868.94 8805.22 -2939.07 4910.08 5956169.39 682501.85 1.79 -403.55 11652.00 93.10 97.10 8867.85 8804.13 -2944.08 4938.61 5956165.06 682530.49 20.70 -395.13 11683.00 94.60 92.90 8865,76 8802.04 -2946.77 4969.41 5956163.09 682561.34 14.36 -383.61 11714.00 95.20 89.80 8863.12 8799.40 -2947.50 5000.29 5956163.10 682592,22 10.15 -370.31 11743.00 96.10 85.60 8860.26 8796.54 -2946.34 5029.12 5956164.93 682621.02 14.74 -3 56.26 11772.00 95.20 81.70 8857.40 8793.68 -2943.15 5057.79 5956168.80 682649.61 13.74 -340.45 11808.00 96.10 76.00 8853.86 8790.14 -2936.23 5092.93 5956176.55 682684.56 15.95 -318.40 11830.00 96.70 74.10 8851.40 8787.68 -2930.59 5114.05 5956182.69 682705.55 9.01 -303.83 11860.00 97.10 72.00 8847.80 8784.08 -2921.91 5142.53 5956192.04 682733.82 7.08 -283.21 11896.00 97.00 66.90 8843.38 8779.66 -2909.37 5175.98 5956205.36 682768.95 14.06 -256,92 11929.00 96.40 64.10 8839.53 8775.81 -2895.78 5205.80 5958219.65 682796.44 8,62 -231.32 11961.00 95.80 61.50 8836.13 8772.41 -2881.24 5234.09 5956234.86 682824.39 8.29 -205.56 11988.00 95.90 58.40 8833.37 8769.65 -2867.79 5257.34 5958248.85 682647.31 11.43 -183.06 12015.00 96.70 53.50 8830.41 8766.69 -2852.77 5279.57 5956264.39 682869.17 18.28 -159.62 12043.00 95.60 50.50 8827.41 8763.69 -2835.63 5301.50 5956282.04 682890.70 11.35 -134.42 12070.00 94.30 46.90 8825.08 8761.36 -2817.68 5321.71 5956300.26 682910.47 14.13 -109.45 12104.00 93.20 42.50 8822.85 8759.13 -2793.77 5345.57 5956324.93 682933.75 13.31 -77.17 BP Amoco Baker Hughes INTEQ Su~ey Repo~ ~r~Q Survey DLS VS deg/lOOft ft 12139.00 92.70 37.20 8821.05 8757.33 -2766.94 5367.95 5956352.27 682955.50 15.19 12172.00 93.30 34.90 8819.32 8755.60 -2740.30 5387.35 5956379.36 682974.26 7.19 12199.00 94.00 29.70 8817.60 8753.88 -2717.53 5401.74 5956402.46 682988.11 19.39 12231.00 93.00 25.00 8815.65 8751.93 -2689.17 5416.41 5956431.16 683002.10 14.99 12262.00 94.90 20.60 8813.51 8749.79 -2660.67 5428.39 5956459.94 683013,41 15.43 12291.00 97.30 18.00 6810.43 8746.71 -2633.46 5437.92 5956487.36 683022.29 12.16 12321.00 99.40 14.70 8806.07 8742.35 -2604.98 5446.28 5956516.03 683029.97 12.94 12352.00 98.80 11.10 8801.17 8737.45 -2575.15 5453.11 5956546.01 683036.10 11.63 12418.00 95.70 3.20 8792.83 8729.11 -2510.25 5461.24 5956611.08 683042.69 12.77 12459.00 92.60 1.80 8789.86 8726.14 -2469.40 5463.02 5956651.96 683043.51 8.29 12491.00 91.60 359.40 8788.69 8724.97 -2437.43 5463.35 5956883.93 683043.09 8.12 12523.00 90.00 356.69 8768.24 8724.52 -2405.45 5462.26 5956715.87 683041.24 9.83 12554.00 89.60 354.60 8768.35 8724.63 -2374.54 5459.91 5956746.71 683038.16 6.68 12588.00 91.00 352.00 8768.17 8724.45 -2340.78 5455.94 5956780.37 683033,40 8.68 12624.00 89.20 347.90 8768.11 8724.39 -2305.34 5449.68 5956815.65 683026.28 12.44 12646.00 68.90 343.80 8768.47 8724.75 -2264.02 5444.29 5956836.84 683020.40 18.68 12676.00 87.60 339.90 8789.39 8725.67 -2255.53 5434.95 5956865.09 683010.39 13.70 12710.00 85.50 335.00 8791.44 8727.72 -2224.20 5421.94 5956896.11 682996.65 15.65 12736.00 85.30 330.40 8793.52 8729.80 -2201.17 5410.05 5956918.64 682984.23 17.65 12768.00 84.70 326.80 8796.31 8732.59 -2173.97 5393.45 5956945.65 682966.98 11.36 12796.00 86.30 329.30 8798.51 8734.79 -2150.28 5378.68 5956968.97 682951.66 10.58 12825.00 87.20 331.80 8800.15 8736.43 -2125.07 5364.45 5956993.84 682938.84 9.15 12859.00 89.00 335.80 8801.28 8737.56 -2094.59 5349.45 5957023.96 682921.12 12.89 12892.00 90.20 338.80 8801.51 8737.79 -2064.15 5336.71 5957054.08 682907.68 9.79 12922.00 90.10 341.90 8801.43 8737.71 -2035.90 5326.63 5957082.09 682896.93 10.34 12948.00 91.00 346.10 8801.18 8737.46 -2010.92 5319.46 5957106.89 682889.17 16.52 12983.00 92.80 350.00 8800.02 8736.30 -1976.70 5312.22 5957140.93 682681.13 12.27 13013.00 92.20 352.50 8798.71 8734.99 -1 947.08 5307.68 5957170.43 682875.87 8.56 13041.00 90.50 353.90 8798.06 8734.34 -1919.29 5304.35 5957198.13 682871.90 7.86 13071.00 91.00 356.80 8797.66 8733.94 -1689.39 5301.92 5957227.g6 682868.76 9.81 13103.00 89.90 0.50 8797.41 8733.69 -1857.41 5301.16 5957259.92 682867.25 12.06 13142.00 89.70 6.50 8797.55 8733.83 -1818.50 5303.54 5957298.87 682868.71 15.39 13171.00 89.20 9.90 8797.83 8734.11 -1789.80 5307.68 5957327.65 682872.17 11.85 13215.00 89.20 9.90 8798.44 8734.72 -1746.46 5315.24 5957371.16 682878.71 0.00 -43.12 -10.59 16.22 48.15 78.99 107.57 136.75 166.45 228.03 265.27 293.95 321.98 348.49 376.82 405.60 422.19 443.39 465.46 480.63 497.40 511.85 527.91 548.33 569.73 590.38 609.43 636.68 681.05 684.34 709.92 738.11 773.90 801.37 643.45 REFERENCE INFORMATION CO,ordinate (NIE Ref~ce: Wetlhead~ 15~42, ~ue North vertical ('i~ D} Re er~ce: Fie~d · Mean See Level Secfl~l (VS) Relerence: S~ol. Wee, ff.)lEast(*) 400 800 1000 1/22/2001 1:31 PM 05/11/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1135 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay & Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD ~ o o-0~'~ B-29A 21204 SCMT 04113/01 D.S. 15-45A 20392 MCNL 09/08/00 D.S. 15-42A 20307 MCNL 07/16/00 D.S. 5-22A 20477 MCNL t11t6/00 D.S. 4-41A 21029 MCNL 01/07101 OWDW,SW 21149 RST 03/14/01 NK-12B 21130 OH EDIT IMP & DIN (PDC) 02/24/01 NK-12B 21130 MD VISION RES 02/24/01 NK-12B 21130 TVDVISION RES 02124/01 NK-12B 21130 MD VISION DIN 02/24/01 NK-12B 21130 TVD VISION DIN 02/24/01 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: RECEIVED I A¥ 15 2001 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-rN: Sherrie Received ~ ~ ~~,.~ ! Permit to Drill 2000690 MD 13215 TVD DATA SUBMITTAL COMPLIANCE REPORT 919/2002 Well Name/No. PRUDHOE BAY UNIT 15-42A Operator BP EXPLORATION (ALASKA) INC 8798 Completion Dat 7/19/2000 ~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22624-01-00 UIC N REQUIRED INFORMATION Mud Log N.._Qo Sample N._9o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital T?_~Media Fmt Log Log Run Name Scale Media No Interval Start Stop 10281 FINAL 8980 (data taken from Logs Portion of Master Well Data Maint) 13118 OH / Dataset CH Received Number Comments CH 9/14/2001 10281 .... '~980-13118 digital data Open 12/2112001 10593 / Case 9/12/2001 10281"'"~"'8980-13118 . Case 5/11/2001 10036 ~,~'~80-13118 2/14/2001 Dir Survey Digital Data 2/14/2001 Dir Survey Paper Copy OH 8/4/2000 BHI 11520-13215 ch 5/15/2001 8980-13118 BL, Sepia · ch 5/15/2001 10036~/8980-13118 Digital Data Ver LIS Verification Directional Survey Directional Survey UTM SRVY RPT Memory CNL GR/CCL/PTF 10036 1 11624 13215 8980 13118 8980 13118 FINAL FINAL 11520 13215 FINAL 8980 13118 FINAL 8980 13118 Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y~) Chips Re ce ived ?...~-Y-/'I~-- Analysis R~.n~.ivP. d? Daily History Received? Formation Tops N Comments: Permit to Drill 2000690 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. PRUDHOE BAY UNIT 15-42A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-22624-01-00 MD 13215 TVD 8798 Completion Dat 7/19/2000 Compliance Reviewed By: ..................... Completion Statu 1-OIL Current Status 1-OIL UIC N 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: 15-42A Pmdhoe Bay Unit : Contains the following: 1 LDWG format disk 1 listing 1 set films ( 2 fihns: GR MWD - ND and TVD) 1 set prints (2 p.'ints: GR lVBYD - MD and TVD) IiLAC:16292 Sent By: IuHana Craiciu Date: Date: Dec 19, 2001 PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN~at~alt~,~~.t;~,~~ OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9t~ Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 09/12/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1435 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 J-17A / ~c)---'Oc~ c:~ 21388 SCMT 08129101 2 K-07C /~c~_/O~_ 20034 MCNL 12110199 I I 1 S-20A c.,~ ~ -/-/--~.~,t 21348 MCNL 071J 8/0J X-15Lt (REDO) ~0/:O~ ~ 21330 MCNL 06/11101 1 ~.S. 15~2A (REDO~-~ 20307 MCNL 071t6100 NK-07A (REDO~/~~ 21341 MGR 04126101 1 I, ..... ,,. .... ,, . ,-- ,, 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: RECEIVED SEP 1 4 2001 AJaska 0il & Gas Cons. C0mmis~i0n Anch~age Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie TATE OF ALASKA ALASrv-~ OIL AND GAS CONSERVATION COMM,oSION Extension WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [~ Gas E] Suspended D Abandoned E] service D 2. Name of Operatori~~~ 7. Permit Number BP Exploration (Alaska), Inc. ~ 200-069 3. Address 8. APl Number P. O. Box 196612, Anchorage, AK 99519-6612 50-029-22624-01 . 4. Location of well at surface 9. Unit or Lease Name 2526' FNL, 3719' FEL, Sec. 22, T11N, R14E, UM (asp's 677523, 5958991) ~ ,' ;~;';~.~L~'! iS:..".i ~ Prudhoe Bay Unit At Top Producing Interval i i),"~ TE ~ 10. Well Number 4925' FNL, 445' FEL, SEC 22, T11 N, R14E, UM (asp's 680859, 5956674) ~ .................. ~ 15-42A At Total Depth ~' 11. Field and Pool 4279' FNL, 3689' FEL, SEC 23, T11 N, R14E, UM (asp's 682878, 5957369) ~ ........................ ..... ~ Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. RKB 64 feetI ADL 28307 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 July 8, 2000 July 13, 2000 July,.~,r~, 2000/od~Ii 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 13215' MD / 8798' TVD 13175' MD / 8798' TVD YES [~] No [--~I 2225' feetMD 1900'(approx) 22. Type Electric or Other Logs Run MWD GR & MEM GR/CCL/CNL 23. CASING, LINER AND CEMENTING RECORD SE-I-rING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 110 30" 260 Sx AS 9-5/8" 47# L-80 Surface 3389' 12-1/4" 442 Sx G, 1260 Sx CS III, & 250 Sx CS I 7" 29# L-80 Surface 9299' 8-1/2" 210 Sx Glass G 4-1/2" 12.6# L-80 9125' 11590' 6" 285 Sx Class G 3-3/16"/2-7/8" 9.3#/6.2# L-80 9816' 13208' 4-1/8" 28 bbls 15.8 ppg LARC 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) 4-1/2" 9126' 9091' 11650'- 12210' MD; 8868'-8817'TVD; @ 4SPF 12850' - 13170' MD; 8801' - 8798' TVD; @ 4 SPF 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.) July 30, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/30/2000 2.6 Test Pedod >I 1484 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') Press. -454 psi 24-Hour Rate > 6116 9076 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved May 24, 2000 (Permit ~200-069) ORIGINAL ' Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top of Sag River Sand Top of Shublik Top of Sadlerochit Top of Zone 1 B GEOLOGIC MARKERS MEAS. DEPTH 9241' 9284' 9357 9884' TRUE VERT. DEPTH 8267' 8305' 8366' 8826' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of 15-42A CT Extension Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~C'~'~:J~ ~~& ¢ Title CeritT,b~r,.q '' . ' Lamar L. Gantt ~.. ~ ~ Date INSTRUCTIONS Prepared by Paul Rau! 263-4990. 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. . ..... - ....... ,~;~"~ .... Item 28: If no cores taken, indicate "none". Form 10-407 15-42A DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 5/24/2000: 6/05/2000: 6/06/2000: 6/15/2000: 7/25/2000 - 7/28/2000: 7/04/2000 - 7/07/2000: 7/08/2000: 7/09/2000: 7/10~2000: 7/11/2000: 7/12/2000: 7/13/2000: 7/14/2000: 7/15/2000: 7/16/2000: MITIA to 3000 psi - passed. MITOA to 2000 psi - passed. MIRU CTD & PT'd equip. Stabbed onto well. Loaded well. RIH & tagged BTM @ 11490' MD. Milled 6' on CIBP (milled out & pushed to BTM on 6/05/1998). POOH. RIH & milled ahead through landing collar, float collar, float shoe, & OH to 11612' MD. Reamed / backreamed interval multiple times. POOH. FP'd well. RD CTU. RIH w/Venturi Junk Basket & recovered big pieces of cast iron. GLV C/O w/Slickline Unit. MIRU Nabors 3S. Rig accepted 1800 hrs. NU BOPE. Performed E-line coil conversion & rig maintenance. MIRU CTU#4. Tested BOPE. RIH & tagged BTM @ 11612'. Drilled to 11618' & POOH. RIH w/bi-centered bit & swapped to FIo Pro. Performed LOT to EMW of 9.55 ppg. Drilled to 12250' & POOH. ~ RIH & drilled to 12499' - became stuck. Upper disconnect inadvertantly released. POOH. RIH w/fishing BHA but could not get past 12162'. POOH. RIH & latched fish. Pumped Crude & jarred. POOH w/fish - 100% recovery. RIH to BTM. POOH. RIH & drilled to 12557'. Drilled to TD @ 13215'. Conditioned OH f/Liner. Continued conditioning OH f/Liner & POOH. MU 3-3/16" & 2-7/8" Liner. RIH w/3-3/16" TCII & 2-7/8" FL4S Liner & landed it @ 13208'. TOL = 9816'. PBTD = 13175'. Pumped 28 bbls of 15.8 ppg LARC to cement liner in place & to isolate the pre-existing perforations located @: 10130' - 10235' MD (Zone 1 B) 10280' - 10655' MD (Zone lB) 10715' - 10900' MD (Zone 1 B) 10940' - 11045' MD (Zone 1 B) 11085' - 11215' MD (Zone 1 B) 11305'- 11495' MD (Zone lB) Full returns during entire job. Launched dart & bumped plug. Unstung f/Liner. Contaminated Cement w/Biozan & cleaned contaminated Cement from the wellbore. POOH w/CT. WOC. PT'd BOPE (AOGCC rep witnessed). RIH w/Mem GR/CCL/CNL & logged well. POOH w/logging tools. Pumped new mud. Sidetrack Summary Page I 15-42A DESCRIPTION OF WORK COMPLETED COILED TUBING EXTENSION DRILLING OPERATIONS SUMMARY Date Event Summary 7/17/2000 - 7/19/2000: 7/20/2000: Evaluated logs. PT'd liner lap to 2500 psi. RIH & cleaned out to 13175' MD. POOH. RIH w/ perforating guns & shot 880' of Initial perforations f/: 11650' - 12210' MD (Zone 1 B) 12850' - 13170' MD (Zone 1 B) Used 2" carriers & shot all Perfs @ 4 SPF, overbalanced press & random orientation. POOH w/guns. ASF. Displaced well to Crude. Begin RD. 3S rig released 2200 hrs. RDMOL CTU. Opened choke & placed well on initial production. Well test. Sidetrack Summary Page 2 BP Exploration Alaska, Inc. WELLPA TH DETAILS 15-42A 500292262401 Parent Wellpath: 15-42 Tie on MD: 11590.00 Vertical Section Origin: Slot. (0.00,0.00) Vertical Section Angle: 26.86 ° Rig: Nabors 3S Depth Reference: 15-42 63.72ft REFERENCE INFORMATION Co-ordinate (N/E)Reference: Wellhead: 15-42, Tree North Vertical (TVD) Reference: Field - Mean Sea Level Section (VS) Reference: Slot - (0.00.0.00) Measured Depth Reference: 15-42 63.7 above Mean Sea Level Calculation Method: Minimum Curvature ANNOTATIONS No. TVD MD Annotation I 8807.35 11520.00 Tle-lnPolnt 8734.56 13215.00 ProJected to TD TARGET DETAILS TVD N/S E/W Target None 8400 .................. [ i .... i ................. i ...... i ....... i ...... i ........... i LEGEND 15-42 (15-42) 15-42 (Plan #215-42&) 15-42A T 1 Wellpa~: (15-42/15-42A) . M All Angles Relative[ Created By: BriJ Pomls Date: 8/2/2(X}0 To True North I Contact Informr~tlon: Tmc North' 0 00/ J B~ker HLigI'le8 INTEQ: (90'/) ?.67-6600 , -1500 ....... ...................... i ...................................................................... i ..... i[ 115-42i (Plan #2 15-42A) i I Projected to -2ooo... -2500 ...... i i / ~i i i ! [ : West(-)/East(+) [500ft/in] t ~ ~ ~ /~ ~ ~ ~ i ...... ~. [ 1'~2(e~.2~5~)1 ............] ~ ~ ~' , ~ , i , ..... , .._: : ~ ~ , ~ , , ~ ~ ~ ~ i : ~ ' ~ t .............. ~, ; ~ ~ t ...... ~ ......... ~ · ~ : 8800 .... -800 -600 -400 -200 0 200 400 600 800 1000 Ve~ical Section at 26.86~ [200~n] Exploration Alaska, "~ [ ~ HUGHES ~"~- UTM Survey Report Field: Prudhoe Bay Unit North Slope USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Ellipsoid: Clarke - 1866 North Reference: True Sys Datum: Mean Sea Level Geomagnetic Model: Wmm_2000 Site: Drillsite 15 Site Position: Northing: 5960055.00 ft Latitude: 70 17 46.977 N From: Map Easting: 676795.70 ff Longitude: 148 34 5.866 W Position Uncertainty: 0.0 ft Magnetic Declination: 27.11 deg Water Depth: 0.0 ft Grid Convergence: 1.34 deg Well: 15-42 WellPosition: +N/-S -1081.1 ft Northing: 5958990.60 ft Latitude: 70 17 36.342 N From Slot: +E/-W 702.3 ft Easting: 677523.10 ft Longitude: 148 33 45.401 W Position Uncertainty: 0.0 ft Wellpath: 15-42A Drilled From: 15-42 ...... 500292262401 Tie-onDepth: 11590.0 ft Vertical Section: +N/-S 0.0 ft V.Section Direction: 26.86 deg :': '":' From: Well +E/-W 0.0 ft Measured Depth Reference: 15-42 63.7 ft Above System Datum: Mean Sea Level Survey: MWD Start Date: 7/13~2000 . . Measured While Ddlling ~-~h3~;.;3. ~ -~:.:,~.,, ~:" ~. :-.::~ ~.~.:~,.. =,.,~::.,~ Company: Baker Hughes INTEQ Engineer: Tool: Survey: MWD 11520.0 91.38 102.81 8807.3 -2915.7 4809.8 5956188.21 682399.74 70 17 7,639 N 148 3125.292W 11590.0 91.23 103.39 8805.8 -2931.5 4877,9 5956173.95 682468.26 70 17 7.482 N 148 31 23.307W 11623.0 91.20 102.80 8805.1 -2939.0 4910.1 5956167.23 682500.56 70 17 7,409 N 148 3122,371 W 11652,0 93.10 97.10 8804.0 -2944.0 4938,6 5956162.89 682529.20 70 17 7,359 N 148 3121,540W 11683.0 94.60 92.90 8801.9 -2946.7 4969.4 5956160,91 682560.06 70 17 7,332 N 148 3120.642W 11714.0 95,20 89.80 8799.2 -2947.4 5000,3 5956160.91 682590.94 70 17 7.325 N 148 31 19.743W 11743.0 96.10 85.60 8796.4 -2946.3 5029.1 5956162.74 682619,73 70 17 7,336 N 148 31 18.903W 11772.0 95.20 81.70 8793,5 -2943.1 5057.8 5956166,60 682648.33 70 17 7,367 N 148 31 18.067W 11808.0 96.10 76.00 8790.0 -2936,2 5092,9 5956174.34 682683.29 70 17 7.435 N 148 31 17.043W 11830,0 96.70 74.10 8787.5 -2930.5 5114.0 5956180.48 682704,27 70 17 7,490 N 148 31 16.428W 11860.0 97.10 72.00 8783.9 -2921.8 5142.5 5956189.82 682732,55 70 17 7,575 N 148 31 15,598W 11896.0 97.00 66.90 8779.5 -2909.3 5176.0 5956203.14 682765.69 70 17 7.698 N 148 31 14.623W 11929,0 96.40 64,10 8775.6 -2895.7 5205.8 5956217.42 682795.18 70 17 7,832 N 148 31 13.754W 11961.0 95.80 61,50 8772.2 -2881.2 5234.1 5956232.62 682823.13 70 17 7.975 N 148 31 12,929 W 11988.0 95.90 58.40 8769.5 -2867.7 5257.3 5956246.61 682846.06 70 17 8.107 N 148 31 12.251 W 12015.0 96.70 53.50 8766,5 -2852.7 5279,6 5956262.15 682867.93 70 17 8.254 N 148 31 11.603W 12043.0 95.60 50.50 8763,5 -2835.6 5301.5 5956279.79 682889.46 70 17 8.423 N 148 31 10,964W 12070,0 94,30 46,90 8761.2 -2817.8 5321.7 5956298,01 682909.24 70 17 8,597 N 148 31 10,375W 12104.0 93.20 42.50 8759,0 -2793.7 5345.6 5956322.67 682932.53 70 17 8.834 N 148 31 9.679W 12139.0 92.70 37.20 8757.2 -2766.9 5367,9 5956350.02 682954.28 70 17 9,098 N 148 31 9.026 W 12172.0 93.30 34.90 8755.4 -2740.2 5387.3 5956377,10 682973.05 70 17 9,359 N 148 31 8.460W 12199.0 94.00 29.70 8753.7 -2717.5 5401,7 5956400.20 682986.91 70 17 9,583 N 148 31 8.040W 12231.0 93.00 25.00 8751.8 -2689.1 5416.4 5956428,90 683000.91 70 17 9.862 N 148 31 7,612W 12262.0 94.90 20.60 8749.6 -2660.6 5428.4 5956457.67 683012.22 70 1710.142 N 148 31 7.262W 12291.0 97.30 18.00 8746.5 -2633.4 5437.9 5956485.10 683021.11 70 1710.410N 148 31 6,984W np Exploration Alaska, In-,-. BAKER ' " ~ --- HUGHES UTM Survey Report S~e~: MWD 12321.0 99.40 14.70 8742.2 -2604.9 5~6.3 5956513.76 683028.80 70 1710.690 N 148 31 6.740W 12~2.0 98.80 11.10 8737.3 -2575.1 5~3.1 59565~.74 683034.93 70 1710.983 N 148 31 6.540 W 12418.0 95.70 3.20 8728.9 -2510.2 5461.2 5956608.82 683041.54 70 1711.621 N 148 31 6.301 W 12459.0 92.60 1.80 8726.0 -2469.3 5463.0 5956649.70 683042.36 70 1712.023 N 148 31 6.248W 12491.0 91.60 359.40 8724.8 -2~7.4 5463.3 5956681.67 683041.95 70 1712.~8 N 148 31 6.237W 12523.0 90.00 356.69 8724.4 -2405.4 5462.3 5956713.61 683040.11 70 1712.652 N 148 31 6.268W 12554.0 89.60 ~.60 8724.5 -2374.5 5~9.9 59567~.46 683037.04 70 1712.956 N 148 31 6.336W 12588.0 91.00 ~2.00 8724.3 -2~0.7 5~5.9 5956778.12 683032.28 70 1713.288 N 148 31 6.451 W 12624.0 89.20 ~7.90 8724.2 -2305.3 ~9.7 5956813.40 683025.17 70 1713.637N 148 31 6.6~W 12646.0 88.90 ~.80 8724.6 -2283.9 5~.3 59568~.59 683019.30 70 1713.847 N 1~ 31 6.789W 12676.0 87.60 ~9.90 8725.5 -2255.5 5~4.9 5956862.86 683009.30 70 1714.127 N 148 31 7.060W 12710.0 85.50 ~.00 8727.6 -2224.1 5421.9 5956893.88 682995.56 70 1714.~5 N 148 31 7.~8W 12736.0 85.30 ~0.40 8729.6 -2201.1 5410.0 5956916.62 682983.14 70 1714.662 N 148 31 7.784W 12768.0 84.70 326.80 8732.4 -2173.9 5393.4 59569~.42 682965.90 70 1714.930 N 148 31 8.267W 12796.0 86.30 329.30 87~.6 -2150.2 5378.7 5956966.76 682950.59 70 1715.163 N 148 31 8.697W 12825.0 87.20 ~1.80 8736.3 -2125.0 5364.4 5956991.63 682935.~ 70 1715.411 N 148 31 9.111 W 12859.0 89.00 ~5.80 8737.4 -2094.5 5~9.4 5957021.75 682920.06 70 1715.711 N 148 31 9.547W 12892.0 90.20 ~8.80 8737.6 -2064.1 5~6.7 5957051.88 682906.62 70 1716.010 N 148 31 9.917W 12922.0 90.10 341.90 8737.6 -2035.8 5326.6 5957079.89 682895.87 70 1716.288 N 148 31 10.210W 12948.0 91.00 ~6.10 8737.3 -2010.8 5319.5 5957104.70 682888.13 70 1716.534 N 148 31 10.418W 12983.0 92.80 350.00 8736.1 -1976.6 5312.2 5957138.74 682880.09 70 1716.871 N 148 31 10.628W 13013.0 92.20 352.50 87~.8 -1947.0 5307.7 5957168.24 682874.84 70 1717.162 N 148 31 10.760W 13041.0 90.50 353.90 87~.2 -1919.2 5304.3 5957195.95 682870.87 70 1717.~5 N 148 31 10.856W 13071.0 91.00 ~6.80 87~.8 -1889.3 5301.9 5957225.78 682867.74 70 1717.729 N 148 31 10.926W 13103.0 89.90 0.50 87~.5 -1857.3 5301.2 5957257.74 682866.24 70 1718.044 N 148 31 10.947W 13142.0 89.70 6.50 8733.7 -1818.4 5303.5 5957296.69 682867.71 70 1718.427 N 148 31 10.877W 13171.0 89.20 9.90 87~.9 -1789.7 5307.7 5957325.48 682871.17 70 1718.709 N 148 31 10.756W 13215.0 89.20 9.90 87~.6 -1746.4 5315.2 5957368.98 682877.72 70 1719.135 N 1~ 31 10.534W ALASKA OIL AND GAS CONSERVATION COPlMISSION l/ TONY KNOWLE& GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lamar L. Gantt Coil Tubing Drilling Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Prudhoe Bay Unit 15-42A Phillips Alaska, Inc. Permit No: 200-069 Sur Loc: 2526'FNL, 3719'FEL, Sec. 22, T11N, R14E, UM Btmhole Loc. 4155'FNL, 3540'FEL, Sec. 23, T11N, R14E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~_ d/_ 7-/~ day of May, 2000 dlf/Enclosurcs cc~ Department of Fish & Game. Habitat Section xv/o encl. Dcparlmcnt of Environmental Conservation w/o encl. ALASKA OIL AND GAS CONSERVATION COMMISSION [..,1AY 0 5 200 _ l PERMIT TO DRILL .ala~a Oil a Gas Cons. Con, mission 20 AAC 25.005 g..n.~ ~.~: la. Type of work: DrillD Redrillr~ I lb. Type of well. Exploratory [~ StratigraphicTestr~ Developmer;t0~'[~-'~ Re-entry D Deepen DI Service D Development Gas D Single Zone [~1 Multiple Zone D (EXTENSION) 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 64 feet 3. Address 6. Property Designation/./.~4 Z ~..-~¢z,. Prudhoe Bay Field P.O. Box 100360 Anchorage, AK 99510-0360 ~ADL 28307--/~ Prudhoe Bay Oil Pool 4. Location of well at sudace ~/' ,,/' ~/' 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 2526' FNL, 3719' FEL, Sec. 22, T11N, R14E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 4795' FNL, 647' FEL, SEC. 22, T11N, R14E, UM 15-42A #U-630610 At total depth 9. Approximate spud date Amount 4155' FNL, 3540' FEL, Sec 23, T11N, R14E, UM June 1,2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number o! acres in property 15. Proposed depth (MD and 'FVD) ADL 28308, 1128' @ TD feetI No Close Approach feet 2560 13308 MD / 8769 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 11590' MD Maximum hole angle 95° Maximum surface 2450 psig At total depth (TVD) 3300 psi~ @ 8864' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD /include stage data) 3-3/4" 3-3/16" 6.2 L-80 TCll 1600' 10000' 8880' 11600' 8869' 11 bbls 3-3/4" 2-7/8" 6.4 L-80 FL4S 1708' 11600' 8869' 13308' 8769' 12 bbl s 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 11590 feet Plugs (measured) Tagged PBTD @ 11500' MD on 6/05/1998. true vertical 8870 feet Effective Depth: measured 11500 feet Junk (measured) CIBP pushed to BTM @ 11500' MD. true vertical 8872 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 110' 20" 260 Sx AS 110' 110' Surface 3325' 9-5/8" 442 Sx G, 1260 Sx CS III, & 250 Sx CS I 3389' 3280' Production 9235' 7" 210 Sx Glass G 9299' 8318' Liner 2465' 4-1/2" 285 Sx Class G0F IGIN L11590' 8870' Perforation depth: measured 10130' - 10235'; 10280' - 10655'. 10715'- 10900'; 10940' - 11045'; 11085' - 11215'; 11305' - 11495'. true vertical 8892~ - 8891', 8886' - 8875'; 8874' - 8874'; 8873' - 8872'; 8873' - 8877'; 8877' - 8872', 20. Attachments Filing fee [~] Property Plat [~] BOP Sketch [~] Diverter Sketch [~ Drilling program Ddlling fluid program Time vs depth plot r-] Refraction analysis D Seabed report ~] 20 AAC 25,050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledg~ Questions? Call Dan Kara @ 263-4837. Signed ~ ~ ~ Title: Coil Tubing Ddlling Supervisor Date ~_amar L. Gantt Prepared b)/ Paul Rauf 263-4990 Commission Use Only Permit Number I APl number v' Approval date ISee cover letter '2--~E:P --- O(.O~I 50- ~ Z..q- ~ Z. ~-- ~) / Ifor other require, ments Conditions of approval Samples re~ ri Yes .]~ No Mud log required,_,/ ['~ Yes .J~[" No Hydrogen suffide measures .~Yes D No Directional survey required..~ Yes D No Required working pressure for BOPE ~2M; E~] 3M; [--1 5M; D 10M;[~] r~ 3500 psi for CTU Other:. by order of , Approved by Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate DS 15-42A CT Sidetrack and Completion Intended Procedure Objective: Drill an extension from the existing wellbore to reach new target. A P&A will not be required. Existing perforations to be isolated with cement behind CT installed liner. Intended Procedure: Attempt to mill through landing collar, float collar and float shoe with service CTU. If unsuccessful, install mechanical whipstock at -11480' (above landing collar) and mill window in 4-1/2" liner with service CTU. Since perforations are open a leak-off test will not be performed as it will not be meaningful. Directionally drill a 3-3/4" well to access Zone 1 reserves. Run 3-3/16" blank liner across perforated interval, crossover to 2-7/8" in openhole. Cement in place. Run memory CNL, perforate -1500 fi, place on production. NOTE: Drill cuttings will be disposed of at GNI and drilling mud will be disposed at GNI or Pad 3. May 5, 2000 DS 15-42A Potential Drilling Hazards POST ON RIG H2S production is not anticipated from this well. Continue to ensure all H2S monitoring equipment is operational. BHP: 3300 psi @ 8800' ss (7.2 ppg EMW), BHT 200 °F (estimated pressure). No over-pressured zones are anticipated. Maximum anticipated WHP w! full column of gas: 2450 psi. High perm intervals are expected across the Sadlerochit. No major faults are anticipated. The well will be drilled with 8.5 ppg mud. May 4, 2000 HORIZONTAE TENSION DS 15-42A : OPOSED CT ~ ~SSSVN @ 2225' 9-5/8" Shoe @ 3389' 4-1/2", 12,6#, L-80 Production Tubing to Surface 7" x 4-1/2" Baker S~3 Packer @ 9091' 4-1/2" HEX Nipple @ 9114' 4-1/2" TT/4-1/2" @ 9126' 7" Shoe @ 9299' 4-1/2" Liner 3-3/16"X2-7/8"XO Top of 3-3/16" TCII Liner ~ 10000' (above existin9 perforations/ Existing 4-1/2" Perfs Isolated Behind 3-3/16" w/Cement 2-7/8" FL4S 6,4# Liner Cemented & Perf'c~ ~ 3-3/4" Open hole \ \ \ ~ TD @ 13308' 4-1/2" Shoe @ 11590' PCR 5/s/2oo0 ARCO Plan.xlt 8200 t 6300t 8500 1 _ 87O0- 8800 - 8900' , , 800 , , 700 l F e d : Prudhoe Boy Locot on : North S ope, A osko ] Eosf (feet) -> 3o,oo, 32,o0 ,3,,o0 ,36,oo ,36,oo , ?o , ?0 , ,4,oo , ? , ? ,6o.oo ,5? , ?o , ?o ,58,oo 4:~...,. ,,? ° 2 ................ ;,<'~/o~ 4¢/ 600 500 400 300 200 1 oo 0 1 oo 200 300 400 500 600 700 Verticol Section (feet) -> Azimuth 27.00 with reference 0.00 N, 0.00 E from 15-42 , , 8OO TD 60?0 62100 i , , , , 9OO IOO0 1400 . - 1600 - -1800 - -2000 .2200 .2400 · '2600 , , , , , 1100 1200 1300 2000 Prepared by BHI 05/04/2000 Proposal Calculations ~G~ Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: ~; ]};~"'Alaska~ Inc. Vertical Sect. Plane: 27.000 TRUE Job No: 0 Field: Prudhoe Bay~ Alaska Mag. Declination: 27.190 AFE No: 0 Well: 15-42A Version#1 Grid Correction: 1.340 API No: 50-029-22624-01 Rig: Nabors 3S Total Correction: 25.850 BHI Rep: 0 Surface Location Dip: 80.720 Job Start Date: 00-Jan-00 X: 677523.1 RKB Height: 63.720 Job End Date: 00-Jan-00 Y: 5958990.6 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn ,~'"' Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (ft) Lat. (Y) De[~. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 11520.00 91.38 102.81 8807.35 -2915.66 4809.78 5956188.51 682399.50 0.00 -414.28 104.00 0.00 0.00 Tie-in Point 11544.00 91.23 103.39 8806.80 -2921.10 4833.15 5956183.62 682422.98 2.50 -408.52 0.00 -0.62 2.42 11545.00 91.23 103.39 8806.78 -2921.33 4834.12 5956183.41 682423.96 0.00 -408.28 0.00 0.00 0.00 11570.00 91.23 103.39 8806.24 -2927.12 4858.43 5956178.20 682448.40 0.00 -402.40 0.00 0.00 0.00 11590.00 91.23 103.39 8805.81! -2931.75 4877.88 5956174.02 682467.96 0.00 -397.70 -83.00 0.00' 0.00 Kick-off Point 11595.00 91.32 102.53 8805.70 -2932.87 4882.76 5956173.02 682472.85 17.39 -396.48 -83.00 !.80 -17.2~3 11600.00 91.41 101.66 8805.58 -2933.92 4887.64 5956172.08 682477.76 17.39 -395.20 -83.00 1.80 -17.4~3 11620.00 91.78 98.20 8805.02 -2937.37 4907.33 5956169.10 682497.53 17.39 -389.33 -84.00 1.85 -17.3~3 11645.00 92.23 93.87 8804.15 -2939.99 4932.17 5956167.05 682522.42 17.39 -380.39 -84.00 1.80 -17.32 11670.00 92.66 89.54 8803.08 -2940.74 4957.13 5956166.90 682547.39 17.39 -369.72 -84.00 1.72 -17.32 11695.00 93.08 85.21 8801.83 -2939.59 4982.07 5956168.62 682572.29' 17.39 -357.381 -84.00 1.68 -17.32 11700.00 93.16 84.34 8801.56 -2939.14 4987.04 5956169.19 682577.25 17.39 -354.72 -84.00 1.60 -17.40 11720.00 93.48 80.87 8800.40 -2936.57 5006.84 5956172.23 682596.98 17.39 -343.45 -84.00 !.60 -17.35 11745.00 93.87 76.53 8798.79 -2931.68 5031.30 5956177.68 682621.32 17.39 -327.99 -85.00 1.56 -17.36 11770.00 94.23 72.18 8797.03 -2924.96 5055.31 5956184.97 682645.16 17.39 -311.10 -85.00 1.44 -17.40 11795.00 94.56 67.84 8795.11 -2916.44 5078.73 5956194.03 682668.37 17.39 -292.87 -85.00 1.32 -17.36 !1800.00 94.63 66.97 8794.71 ~2914.53 5083.33 5956196.05 682672.93 17.39 -289.08 -85.00 !.40 -17.40 11820.00 94.87 63.48 8793.05 -2906.18 510!.42 5956204.82 682690.82 17.39 -273.42 -86.00 1.20 -17.45 11840.00 95.10 60.00 8791.32 -2896.74 5118.97 5956214.66' 682708.14 17.39 -257.05 -91.00 1.15 -17.40 1 11845.00 95.09 59.69 8790.87 -2894.24 5123.27 5956217.26 682712.39 6.10 -252.87 -91.00 -0.20 -6.20 11870.00 95.06 58.16 8788.66 -2881.39 5144.60 5956230.61 682733.41 6.10 -231.74 -91.00 -0.12 -6.12 11895.00 95.02 56.63 8786.46 -2867.97 5165.58 5956244.51 682754.06 6.10 -210.26 -91.00 -0.16 -6.12 11900.00 95.01 56.33 8786.03 -2865.22 5169.73 5956247.36 682758.15 6.10 -205.92 -91.00 -0.20 -6.00 11920.00 94.98 55.11 8784.28 -2854.00 5186.20 5956258.96 682774.35 6.10 -188.45 -91.00 -0.15 -6.10 11945.00 94.93 53.58 8782.12 -2839.48 5206.43 5956273.95 682794.23 6.10 -166.33 -91.00 -0.20 -6.12 11970.00 94.88 52.05 8779.98 -2824.43 5226.27 5956289.47 682813.72 6.10 -143.90 -91.00 -0.20 -6.12 11995.00 94.83 50.52 8777.87 -2808.85 5245.71 5956305.50 682832.78 6.10 -121.20 -92.00 -0.20 -6.12 12000.00 94.82 50.21 8777.45 -2805.67 5249.55 5956308.76 682836.54 6.10 -116.62 -92.00 -0.20 -6.20 12020.00 94.78 48.99 8775.77 -2792.75 5264.72 5956322.03 682851.41 6.10 -98.22 -92.00 -0.20 -6.1~3 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)?vV(-) N(+)/S(-) E(+)/~V(-) Severity Section Comments (des) (des) (ft) Lat. (Y) De[~. (X) Lat. (Y) De[~. (X) (°/100ft) (Wellhead) (°/100ft) (°/100ft) 12045.00 94.72 47.46 8773.70 -2776.15 5283.30 5956339.06 682869.60 6.10 -75.00 -92.00 -0.24 -6.12 12070.00 94.65 45.93 8771.66 -2759.06 5301.44 5956356.57 682887.32 6.10 -51.54 -92.00 -0.28 -6.12 12095.00 94.59 44.41 8769.65 -2741.50 5319.11 5956374.54 682904.58 6.10 -27.87 -92.00 -0.24 -6.08 12100.00 94.58 44.10 8769.25 -2737.93 5322.59 5956378.19 682907.97 6.10 -23.11 -92.00 -0.20 -6.20 12120.00 94.52 42.88 8767.66 -2723.46 5336.31 5956392.97 682921.35 6.10 -3.99 -92.00 -0.30 -6.10 12145.00 94.45 41.35 8765.71 -2704.98 5353.02 5956411.84 682937.62 6.10 20.07 -92.00 -0.28 -6.12 12170.00 94.37 39.82 8763.79 -2686.05 5369.24 5956431.15 682953.39 6.10 44.30 -92.00 -0.32 -6.12 12195.00 94.29 38.30 8761.90 -2666.69 5384.94 5956450.86 682968.64 6.10 68.67 -93.00 -0.32 -6.08 12200.00 94.28 37.99 8761.52 -2662.77 5388.02 5956454.86 682971.63 6.10 73.57 -93.00 -0.20 -6.20 12220.00 94.21 36.77 8760.04 -2646.92 5400.13 5956470.98 682983.36 6.10 93.19 -93.00 -0.35 -6.10 12245.00 94.13 35.24 8758.22 -2626.75 5414.79 5956491.49 682997.54 6.10 117.81 -93.00 -0.32 -6.12 12270.00 94.04 33.72 8756.44 -2606.20 5428.91 5956512.37 683011.17 6.10 142.53 -93.00 -0.36 -6.08 12295.00 93.95 32.19 8754.70 -2585.27 5442.47 5956533.60 683024.25 6.10 167.34 -93.00 -0.36~ -6.12 12300.00 93.93 31.89 8754.36 -2581.04 5445.12 5956537.89 683026.79 6.10 172.31 -93.00 -0.40 -6.00 12320.00 93.86 30.67 8753.00 -2563.99 5455.48 5956555.18 683036.75 6.10 192.20 -93.00 -0.35 -6.1~3 12345.00 93.76 29.14 8751.34 -2542.37 5467.92 5956577.09 683048.68 6.10 217.12 -93.00 -0.40 -6.12 12370.00 93.66 27.62 8749.72 -2520.42 5479.78 5956599.30 683060.02 6.10' 242.06 -93.00 -0.40 -6.08 12395.00 93.56 26.10 8748.15' -2498.16 5491.05 5956621.82 683070.76 6.10 267.01 -93.00 -0.40 -6.08, 12400.00 93.54 25.79 8747.84 -2493.67 5493.23 5956626.36 683072.84 6.10 272.00: -93.00 -0.40 -6.20 12420.00 93.46 24.57 8746.61 -2475.61 5501.73 5956644.61 683080.91 6.10 291.95 -93.00 -0.40 -6.10 12445.00 93.35 23.05 8745.13 -2452.78 5511.80 5956667.67 683090.45 6.10 316.86 -94.00 -0.44 -6.08 12470.00 93.24 21.53 8743.69 -2429.68 5521.27 5956690.98 683099.37 6.10 341.74 -94.00 -0.44 -6.08 12495.00 93.13 20.00 8742.30 -2406.35 5530.12 5956714.52 683107.67 6.10 366.55 -94.00 -0.44 -6.12 12500.00 93.11 19.70 8742.03 -2401.65 5531.81 5956719.25 683109.25 6.10 371.50 -94.00 -0.40 -6.00 12520.00 93.02 18.48 8740.96 -2382.78 5538.34 5956738.27 683115.34 6.10 391.29 -94.00 -0.45 -6.10 12545.00 92.91 16.96 8739.67 -2359.00 5545.94 5956762.22 683122.38 6.10 415.92 -94.00 -0.44 -6.08 12570.00 92.79 15.44 8738.42 -2335.02 5552.91 5956786.35 683128.78 6.10 440.45 -94.00 -0.48 -6.08 12595.00 92.67 13.92 8737.23 -2310.86 5559.24 5956810.65 683134.54 6.10 464.85 -94.00 -0.48 -6.08 12600.00 92.65 13.61 8737.00 -2306.01 5560.42 5956815.53 683135.62 6.10 469.71 -94.00 -0.40 -6.20 12620.00 92.55 12.40 8736.09 -2286.55 5564.92 5956835.09 683139.66 6.10 489.09 -94.00 -0.50 -6.05 12645.00 92.43 10.88 8735.01 -2262.08 5569.96 5956859.66 683144.12 6.10 513.18 -94.00 -0.48 -6.08 12645.23 92.43 10.86 8735.00 -2261.86 5570.00 5956859.89 683144.16 6.10 513.40 -88.00 0.00 -8.70 2 12670.00 92.45 9.35 8733.95 -2237.49 5574.34 5956884.35! 683147.93 6.09 537.08 -88.00 0.08 -6.10 12695.00 92.48 7.83 8732.87 -2212.80 5578.07 5956909.12 683151.08 6.09 560.77 -89.00 0.12 -6.08 12700.00 92.48 7.53 8732.65 -2207.85 5578.74 5956914.09 683151.63 6.09 565.49 -89.00 0.00 -6.00 12720.00 92.50 6.31 8731.78 -2188.01 5581.15 5956933.97 683153.57 6.09 584.25 -89.00 0.10 -6.10 12745.00 92.53 4.78 8730.69 -2163.15 5583.56 5956958.88 683155.40 6.09 607.50 -89.00 0.12 -6.12 12770.00 92.55 3.26 8729.58 -2138.24 5585.31 5956983.82 683156.57 6.09 630.49 -89.00 0.08 -6.08 12795.00 92.571 1.74 8728.46 -2113.29 5586.40 5957008.79 683157.08 6.09 653.22 -89.00 0.08 -6.08 12800.00 92.57 1.43 8728.24 -2108.30 5586.54 5957013.79 683157.10 6.09 657.73 -89.00 0.00 -6.20 12820.00 92.58 0.22 8727.34 -2088.32 5586.83 5957033.76 683156.92 6.09 675.66 -89.00 0.05~ -6.05 12845.00 92.60 358.69 8726.21 -2063.35 5586.59 5957058.72 683156.10 6.09 697.80 -89.00 0.08 -6.12 12870.00 92.61 357.17 8725.07 -2038.39 5585.69 5957083.65 683154.61 6.09 719.63 -89.00 0.04 -6.08 12895.00 92.62 355.65 8723.93 -2013.47 5584.13 5957108.53 683152.46 6.09 741.13 -89.00, 0.04 -6.08 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (de~) (de~) (~) Lat. (Y) DeF. (X) Lat. (Y) DeF. (X) (°/100ft) (Wellhead (°/100~) (°/100ft) 12900.00 92.63 355.34 8723.70 -2008.49 5583.73 5957113.50 683151.96 6.09 745.39 -89.00 0.20 -6.20 12920.00 92.63 354.12 8722.79 -1988.59 5581.90 5957133.34 683149.66 6.09 762.28 -89.00 0.00 -6.10 12945.00 92.64 352.60 8721.64 -1963.79 5579.01 5957158.07 683146.19 6.09 783.07 -89.00 0.04 -6.08 12970.00 92.65 351.08 8720.48 -1939.07 5575.47 5957182.70 683142.07 6.09 803.49 -89.00 0.04 -6.08 12995.00 92.65 349.55 8719.33 -1914.45 5571.27 5957207.21 683137.29 6.09 823.51 -89.00 0.00 -6.12 13000.00 92.65 349.25 8719.09 -1909.54 5570.35 5957212.10 683136.26 6.09 827.47 -89.00 0.00 -6.00 13020.00 92.65 348.03 8718.17 -1889.95 5566.41 5957231.58 683131.87 6.09 843.14 -89.00 0.00 -6.10 13045.00 92.66 346.51 8717.01 -1865.60 5560.91 5957255.81 683125.80 6.09 862.34 -90.00 0.04 -6.08 13070.00 92.65 344.98 8715.85 -1841.39 5554.76 5957279.86 683119.08 6.09 881.12 -90.00 -0.04 -6.12 13095.00 92.65 343.46 8714.69 -1817.36 5547.97 5957303.72 683111.73 6.09 899.45 -90.00 0.00 -6.08 13100.00 92.65 343.16 8714.46 -1812.58 5546.54 5957308.47 683110.19 6.09 903.06 -90.00 0.00 -6.00 13120.00 92.65 341.94 8713.54 -1793.52 5540.55 5957327.38 683103.75 6.09 917.32 -90.00 0.00 -6.10 13145.00 92.64 340.42 8712.39 -1769.88 5532.49 5957350.82 683095.14 6.09 934.72 -90.00 -0.04 -6.08 13170.00 92.63! 338.89 8711.24 -1746.47 5523.80 5957374.03 683085.91 6.09 951.64 -90.00 -0.04 -6.12 13195.00 92.62 337.37 8710.09 -1723.29 5514.50 5957396.98 683076.07 6.09 968.07 -90.00 -0.04 -6.08 13200.00 92.62 337.06 8709.86 -1718.69 5512.57 5957401.53 683074.03 6.09 971.29 -90.00 0.00 -6.20 13220.00 92.61 335.85 8708.95 -1700.37 5504.59 5957419.66 683065.62 6.09 983.99 -90.00 -0.05 -6.05 13245.00 92.59 334.32! 8707.82 -1677.72 5494.07 5957442.05 683054.58 6.09 999.39 -90.00 -0.08 -6.12 13270.00 92.58 332.80' 8706.69 -1655.36 5482.95 5957464.15 683042.94 6.09 1014.27 -90.00 -0.04 -6.08 13295.00 92.56 331.28 8705.57 -1633.30 5471.24 5957485.92 683030.72 6.09 1028.61 -90.00 -0.08 -6.08 13300.00 92.55 330.97 8705.35 -1628.93 5468.83 5957490.24 683028.20 6.09 1031.41 -90.00 -0.20 -6.20 13307.83 92.55 330.50 8705.00 -1622.10 5465.00 5957496.97 683024.22 6.09 1035.76 0.00 0.00 -6.00 TD 888V Tub~og Ca$~og Cas~n9 iBP Peri, Peri Per 15-42 APl 500292262400 SSSV Type Annular F~u,a 6 8 D~esel/8 5 Seawater Reference Log Last Tag -asr Tag Date' Depth Anno[ations Depth Comment Bay 5-4;2 An§ie~TS: 26 dog ~9352 Angle~TE 91de9~11590 ~ev Reason: Picture General Notes Date Note Other (plugs, equip., etc.) · JEWELRY Depth TVD Type Description Casing Strings - All Size Weight Grade Top Btm Feet Description 4.50£ 1260 _-8c 9125 11590 2465 L~ner 7.00£ 2900 L-8£ 9 9299 9299 Casing 2.625 47.00 1-80 9 3389 3389 Casing Tubing Strings - Ail Size Weight Grade Top Btm Feet Description 4~500 12.80 L-80 0 9128 9126 Tubiog Gas Lift Mandrels/Velves Stn MD TVD Man Man V Mfr VType VOD Latch Port TRO Mfr Type 3999 3811 CAMCO;BG2LSMOICAMCO DM 1 O ~T 0.0O0 2 8950 6277 CAMCO;BG2LSMO ~AMCO DM~ 10 ~T 0000 3 9022 887I CAMCO~ESgLSMO~CAMCD DMY 1.6 ~T 6660 Zone StatusFeetSPF Date Type Comment 0 375 4* 1/17/96 IPERF C 105 4 1/17/96 IPERF 3813 9 090 3813 0000 Date V]v 11/22/97 (2) 2/24197 (3) C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I =~ I -'- 7" Riser I' '1 .~ Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold I Man (3.5") Cutters or Combination CuttedBlinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold Hanger Upper Annulus Lower Annulus CASH ADVANCE DRAFT 102 ~ DOLLARS Issued by' JOO WELL PERMIT CHECKLIST COMPANY C,:::) WELL NAME /~':- ~¢"Z,~ PROGRAM: exp FIELD & POOL (",.~ C/~")/L~') INIT CLASS -"~'-'V" /" ~/___--)//~ GEOL AREA - ! ~ ,. ADMINISTRATION 2. Lease number appropriate.¢~. ,.5,,~,. 3. Unique well name and number .................. 4. Well located in a defined pool .................. (~Y).,..¢., N 5. Well located proper distance from drilling unit boundary .... (,.~?N 6. Well located proper distance from other wells .......... (.,~, !N 7. Sufficient acreage available in drilling unit ............ ( >Y.,. )N ~. If deviated, is wellbore plat included ............... ~,,,N Operator only affected party ................... ~N 101 Operator has appropriate bond in force ............. ~ N 11. Permit can be issued without conservation order ........ ( ~ )N 12. Permit can be issued without administrative approval ...... ( ~v / DATE ~':~.. ~O 13. Can permit be approved before 15-day wait ........... dev V'/redrll v,/' serv wellbore seg ann. disposal para req UNIT# (~//~...~'("b ON/OFF SHORE _(~"~/-1_ ENGINEERING DATE 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 ~-,~q~) psig. 27. Choke manifold complies w/APl RP-53 (May-84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ...... Y N } ...~ 32. DATE 33. ~- ~?, ~ 34. Seismic analysis of shallow gas zones ............. ,/W'~,.-/ Y N Seabed condition survey (if off-shore) ............. ,,.//'-~ Y N Contact name/phone for weekly progress reports [exploratory only]/~/,/~ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate fr~r; or cause~waste... Y N to surfa/ce; // / ~ (C) will not('~al i e~fthe well used for disposal; Y N (D) will not ~,na'-~rmation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: . -- Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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 APPENDIX,' .. No special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 01/12/18 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 01/12/18 48494 01 1.75" NaviGamma - Gan~na Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: glen.las ~Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM.UNIT Data Type # - STRT. FT STOP. FT STEP. FT NULL COMP WELL FLD LOC CNTY STAT SRVC TOOL DATE API CWLS log ASCII Standard -VERSION 1.20 One line per frame Information 11624.0000: Starting Depth 13215.0000: Ending Depth 0.5000: Level Spacing -999.2500: Absent Value COMPANY: PHILLIPS Alaska, Inc. WELL: 15-42A FIELD: Prudhoe Bay Unit LOCATION: 2526' FNL, 3719' FEL COL~_Y: North Slope STATE: Alaska SERVICE COMPANY: Baker Hughes INTEQ TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray LOG DATE: 13-Jul-00 API NYUMBER: 500292262401 -Parameter Information Block #MAIEM.UNIT Value Description # -- SECT. 22 : 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 63.72 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 63.72 : 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 (2 (3 (4 (5 (6 (7 (8) Ail depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRAX) presented is realtime data. Well 15-42A was drilled as an extensiom to well 15-42. Well 15-42A was drilled to TD at 13215' MD (8735' SSTVD). The interval from 13180' MD (8734' SSTVD) to 13215' MD (8735' SSTVD) was not logged due to sensor to bit offset. The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve supplied by BPX (SWS, 16-07-2000). A Magnetic Declination correction of 26.84 degrees has been applied to the Directional Surveys. MAIEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 2 27.20 ft. 33.10 ft. 3 27.20 ft. 33.10 ft. 6 27.20 ft. 33.10 ft. 7 27.20 ft. 33.10 ft. CURVE SHIFT DATA BASELINE, MEASURED, 11665.5, 11682.0, 11704.8, 11727.7, 11732.2, 11772.6, 11797.6, 11819.4, 11845.0, 11869.8, 11872.9, 11886.6, 11890.2, 11895.1, 11900.2, 11903.6, 11904.8 11906.8 11908.0 11915.0 11928.6 11933.5 11937.7 11946.9 11953 2 11955 8 11989 7 11993 6 12027 5 12035 2 12038 7 12041.7 12046.0, 12050.3, 12055.1, 12072.6, 12074.8, 12079.1, 12082.8, 12087 0, 12093 6, 12103 7, 12113 2, 12116 1, 12123 6, 12127 5, 12140.3, 12147.6, 12150.6, 12153.3, 12163.6, 12167.3, 11665.3, 11684.4, 11706.0, 11730.1, 11734.4, 11774.4, 11798.6, 11821.1 11847.0 11869.4 11872.0 11890.7 11893.9 11898.4 11904.1 11906.8 11908.4 11909.9 11911.7 11919.6 11928.6 11932.6 11944 2 11950 7 11956 6 11958 9 11993 4 11997 7 12031 8 12038.3 12043.1 12045.8 12049.0 12055.6 12059.6 12075.9 12079.3 12083.2 12085.4 12088.9 12097.0 12108.1 12115.9 12118.5 12125.4 12130.5 12142 9 12148 8 12152 6 12155 1 12164 8 12168 1 DISPLACEMENT -0.196289 2.36133 1.18066 2.36133 2.16504 1.77148 0.983398 1.77051 1.96777 -0.393555 -0.984375 4.13184 3.73828 3.3457 3.93555 3.14844 3.54199 3.14844 3.73926 4.52539 0 -0.983398 6 49316 3 73828 3 34473 3 14844 3 73828 4 13184 4 32812 3 14844 4 3291 4.13281 2.95117 5.3125 4.52637 3.3457 4.52539 4.13184 2.55762 1.96777 3.3457 4.3291 2.75488 2.36133 1.77051 2.95117 2 55762 1 18066 1 96777 1 77051 1 18066 0 787109 12204.8 12211.7 12228.0 12242.2 12255.0 12258.5 12264.0 12284.6 12294.7 12339 9 12341 1 12342 5 12347 6 12362 2 12366 7 12371 7 12379 3 12404 4 12658 4 12672 0 12682.2 12781.5, 12786.4, 12790.2, 12817.9, 12825.1, 12855.3, 12869.5, 12979.2, 12994.9, 12996.9, EOZ END 12207.9 12213.4 12225.0 12242.6 12253 6 12257 7 12263 4 12283 3 12295 1 12339 2 12340 7 12342 9 12347 2 12361 4 12370 1 12374 2 12381 7 12404 0 12659.2 12670.4 12679.3 12777.2 12782.1 12786.8, 12812.4, 12821.0, 12851.2, 12865.0, 12971.9, 12986.4, 12989.4, 3.14844 1.77148 -2.95117 0.393555 -1.37695 -0.787109 -0.59082 -1.37793 0.393555 -0.787109 -0.393555 0.393555 -0.393555 -0.787109 3.34473 2.55859 2.36133 -0.393555 0.787109 -1 57422 -2 95215 -4 3291 -4 3291 -3 3457 -5 50879 -4 13184 -4 13281 -4 52539 -7.28027 -8.46191 -7.47656 BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 155 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MAIEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska, Inc. WN 15-42A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1o The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 16-Jul-00. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAX11 0.0 2 ROP ROPS11 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: 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 Size 68 1 API 4 68 1 F/HR 4 Total Data Records: 38 Tape File Start Depth = 11624.000000 Tape File End Depth = 13215.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 47 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 Length 4 4 8 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN Phillips Alaska, Inc. WN 15-42A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!1!11!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM __-- ...... 1 GRAX GRAX 2 ROPS ROPS * 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: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MW-D Code Samples Units 68 1 API 68 1 F/HR Total Data Records: 38 ODEP 0.0 0.0 Size Length 4 4 4 4 8 Tape File Start Depth = 11624.000000 Tape File End Depth = 13215.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 47 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/12/18 48494 01 **** REEL TRAILER **** MWD 01/12/18 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH 11624 11624 11700 11800 11900 12000 12100 12200 12300 12400 12500 12600 12700 12800 12900 13000 13100 13200 13215 GR ROP 0000 -962.1429 63.9155 5000 50.2312 65.7622 0000 69.5732 64.6559 0000 54.8009 60.7102 0000 82.4197 102.1287 0000 39.2574 75.4986 0000 78.2165 60.8937 0000 36.9738 67.3389 0000 29.6831 73.5024 0000 31.2682 94.4880 0000 49.2088 60.9191 0000 39.3139 107.9227 0000 39.7902 92.4826 0000 37.6259 88.0731 0000 32.3527 46.9849 0000 86.4261 96.3549 0000 33.5830 90.5060 .0000 -999.2500 71.7990 .0000 -999.2500 -999.2500 Tape File Start Depth = 11624.000000 Tape File End Depth = 13215.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 11624.0000 11624.5000 11700.0000 11800.0000 11900.0000 12000.0000 12100.0000 12200.0000 12300.0000 12400.0000 12500.0000 12600.0000 12700.0000 12800.0000 12900.0000 13000.0000 13100.0000 13200.0000 13215.0000 GRAX -999 2500 50 3120 63 8290 53 9850 57 2890 43 2820 78 1260 36 5620 29 5800 31 2500 59 2330 47 5070 41 0400 39.4880 34.1860 105.1010 34.0140 -999.2500 -999.2500 ROPS 63 65 69 6O 7 127 52 67 76 94 8O 109 94 84 98 69 88 68 60 853O 6200 8830 5720 1360 4180 2590 3030 6950 4880 2510 9650 4880 8820 0170 3250 9970 3840 8820 Tape File Start Depth = 11624.000000 Tape File End Depth = 13215.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS