Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
194-042
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 06/07/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU 05-13 + 05-13A + 05-13B -PTD 177-026 (05-13) -PTD 194-042 (05-13A) -PTD 207-146 (05-13B) -API 50-029-20250-00-00 (05-13) -API 50-029-20250-01-00 (05-13A) -API 50-029-20250-02-00 (05-13B) Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/02/2023 Main Folder Contents: Please include current contact information if different from above. T38881 T38882 T38883 177-026 194-042 207-146 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.10 08:19:20 -08'00' 194-042 T38882 () PTD 194-042 (05-13A) Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN r3 [] [] Other- Pages: DIGITAL DATA ~ Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds [] Other Color items- Pages: Grayscale, halftones, pictures, graphs, charts - Pages: 'Poor Quality Original - Pages: Complete COMMENTS: scanned bY.~eve~ianna TO RE-.SCAN Notes: Vincent Nathan Lowell Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: (fit ~( Q~f~ FILE # ~~, Im ran 1~~G~ To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ! 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 r ~a`~~~~ • STATE OF ALASKA ~~/-off ~~~~~ ALASKA OIL AND GAS CONSERVATION COMIeRSSION FEB 2 0 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska ~lil & Gas Ct;ns~ li4minission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba a~ 1/24/2008 ~ 12. Permit to Drill Number 194-042 - 307-321 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/29/1994 13. API Number 50-029-20250-01-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/7/1994 14. Well Name and Number: PBU 05-13A 3015 FSL, 112 FWL, SEC. 32, T11N, R15E, UM Top of Productive Horizon: 1370' FSL, 3419' FWL, SEC. 29, T11N, R15E, UM 8. KB (ft above MSL): 62.46' ~ Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1680' FSL, 4673' FWL, SEC. 29, T11 N, R15E, UM 9. Plug Back Depth (MD+TVD} 11954 8808 P°ol 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 697176 y- 5949180 Zone- ASP4 10. Total Depth (MD+TVD) 11954 - 8808 16. Property Designation: ADL 028326 ~ TPI: x- 700374 y- 5952901 Zone- ASP4 Total Depth: x- 701619 y- 5953244 Zone- ASP4 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and tinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): CNL/DEN/GR/LWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING. DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 112' Surface 112' 32" 224 sx Arcticset 13-3/8" 72# N-80 Surface 2718' Surface 2718' 17-1/2" 5726 sx PF II 9-518" 47# N-80 Surface 10030' Surface 8064' 12-1/4" 675 sx Class'G' 275 sx PF 7" 29# L-8 4182' 10985' 4058' 8809' 8-1/2" 244 sx Class 'G' *2-7/8" 6.4# L-80 10814' 11952' 8707' 8808' 3-3/4" Uncemented Slotted Liner "Liner a ears to have ulled u hole -200 offsettin the S lotted intervals too. Ori final de the are bein re orted 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD None 4-1/2", 12.6#, L-80 10300' 9925' & 10453' MD TVD MD TVD 4-1/2", 12.6#, L-80 10474' - 10860' 10678 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. p +~ `~(~[~ „~~(~`. ~ ~~ F~U d~ +-~+~+~ DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED c~ 10348' Set Whipstock 10353' P&A with 41 Bbls Class 'G' 26. _ _ ° ' PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FJR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK}: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD 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 ` x!08 l~~~i __ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 17~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 10310' 8264' None Shublik 10364' 8305' Sadlerochit 10433' 8363' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys. 31. I hereby certify that the foregoing is true an_d correct to the best of my knowledge. { Signed Sondra tewma ~ Title Drilling Technologist Date ~ _ (~ '~~ PBU 05-13A 194-042 307-321 Prepared ByNameMumber. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Dolling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRA~: 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. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). 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 TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only I TREE = CNV WELLHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 62.5' BF. ELEV = KOP = 10300' Max Angle = 95 Q 11932' Datum MD = NA Datum ND = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" i--I 2718' Minimum ID = 2.441" @ 10613' TOP OF 2-7/8" LINER TOP OF 7" LNR -SCAB 4182' 7" LNR-SCAB, 26#, L-80, - 9976" 9-5/8" CSG, 47#, N-80, ID = 8.681" 11286' 9-518" MILLOUT WINDOW - 10030' -10080' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10301 7" X 4-1/2" BKR ZXP LNR PKR, ID = 2.992" ~ 10453' TOP OF 4-1/2" TBG 10474' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 10587' I I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10860' PERFORATION SUMMARY REF LOG: AWS CNL ON 07/08!94 ANGLE AT TOP PERF: 40 (d 10785' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SLTD 2 10785 - 11551 C 08/22/94 SLTD 2 10587 - 11720 C 11/09/94 05-13B Post CTD Sidetrack 70° ~ 10994' AND 90° ~ 11049' 1999' 4-1/2 CAMCO SVLN, 9-CR O SSSV NIP, ID = 3.812" ras L~-r MANDRFLs ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04/14/05 2 7384 6210 49 KBG2LS DMY Nff 0 04!14/05 3 9780 7897 48 KBG2LS DMY YJT 0 4182' ~ 9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 9872' ~9-5/8" X 7" ZXP 7" PKR 9925' 7" X 4-1/2" BKR SAB-L-3 HYD PKR 9976' - .v .. ~ 1/2" Liner. TOC 99$6' 3-1 /2" X NIP. ID = 2.813- - 10249` -1/2' X 3-3/16" x-over 10278' 4-1 /2" HES X NIP, ID = 3.813" 0300' 4-1/2" TUBING TAIL WLEG 1 500' 3-3/16 x 2-718 X-over ~., 3-3/16" X 2-75" cirtad & perfect 13095' Mechanical WS : e,~~~~, 10587' 4-1/2" GS DEPLOYMENT SLEEVE 10678' 7" BAKERSABL-3 PKR 10733' 4-1/2" oils X NIP, ID= 3.81" 10860' 4-1/2 TUBING TAIL WLEG ELMD TT NOT LOGGED ' 2-7/8" LNR -SLOTTED, s.5#, 11720' '- // L-80, .0056 bpf, ~ = 2.441" I I~ DATE REV BY COMMENTS DATE REV BY COMMEMS 1977 ORIGINAL COMPLETION 05/03/05 TJP/PJC WAVER SAFETY NOTE 08122/94 SIDETRACKED 12/04/05 DAV/PAG SETTTP 08120198 LAST WORKOVER 12/17/05 EZL/PJC WANER SFTY NOTE DELETED 02/06/02 RN/TP CORRECTIONS 06/24/04 DFR/KAK CORRECTIONS 04/27/05 MGS/TLH GLV GO (04/14/05) PRUDHOE BAY UNfr WELL: 05-13A PERMIT No: 1940420 API No: 50-029-20250-01 SEC 32, T11 N, R15E. 605' FEL & 3599.16' FNL BP Exploration Alaska) • • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2008 00:00 - 01:00 1.00 MOB P PRE 01:00 - 01:15 0.25 MOB P PRE 01:15 - 04:00 2.75 MOB P PRE 04:00 - 14:00 10.00 MOB N WAIT PRE 14:30 - 00:00 I 9.501 MOB I P I I PRE 1/21/2008 00:00 - 04:00 4.00 MOB P PRE 04:00 - 07:00 3.00 MOB P PRE 07:00 - 07:15 0.25 MOB P PRE 07:15 - 10:15 3.00 MOB P PRE 10:15 - 10:30 0.25 MOB P PRE 10:30 - 14:00 I 3.501 MOB P I PRE 14:00 - 14:30 I 0.501 MOB I P I I PRE 14:30 - 18:00 3.50 MOB P PRE 18:00 - 18:45 0.75 MOB P PRE 18:45 - 19:00 0.25 MOB P PRE 19:00 - 19:30 0.50 MOB P PRE 19:30 - 20:00 0.50 MOB P PRE 20:00 - 20:30 0.50 MOB P PRE 20:30 - 20:45 0.25 MOB P PRE 20:45 - 22:45 2.00 MOB P PRE 22:45 - 23:00 0.25 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 1/22/2008 00:00 - 01:30 1.50 MOB P PRE 01:30 - 03:00 1.50 MOB P PRE 03:00 - 03:30 0.50 MOB P PRE 03:30 - 06:00 2.50 MOB P PRE 06:00 - 07:45 1.75 MOB P PRE 07:45 - 08:00 0.25 MOB P PRE Prepare to jack up rig and move off well A-12. Safety Meeting prior to pulling off well. Pull off well and move to side of pad, Weld on guide rollers onto SWS injecterhead support frame to guide injecter into pipe bay. Wait on security, security was busy moving another rig on the spine road to K pad. Wind at 20-40 mph, so unable to lay down derrick. Move to Pad 10. 19:00 -Leak while moving the rig, estimated 1 cup gear oil leaked onto Spine Road near Pump Station 1, from a front drive wheel seal. Spill was reported to x5700 and cleaned up. See Traction incident # 2525892. Continue moving from A-12 to Pad 10. Arrive Pad 10, set rig down and prepare to lay down derrick. SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil stub to reel. Pull coil stub to reel and secure coil. SAFETY MEETING. Review procedure, hazards and mitigation for moving guide arch and placing injector in pipe bay. Place guide arch in pipe shed. Lower injector into pipe bay and remove pipe straightener. Place pipe straightener on rig floor in front of doghouse. Crew change. SAFETY MEETING. Review procedure, hazards and mitigaion for laying down wind walls. Wind at 7-12 mph. Remove chain fall beams in pipe shed. Lower wind walls. Hook up tugger lines to derrick hydraulic cyliunders, scope out cylinders and pin the bottom ends. SAFETY MEETING. Review procedure, hazards and mitigaion for laying down derrick. Scope derrick down. Open pipe shed doors and prepare to lay down derrick. Crew change and safety meeting with new crew. Lay down derrick. Close pipe shed doors. Conduct Safety Meeting to discuss hazards and mitigation for moving rig under power lines. Jack up rig and move to DS 05. Park rig on DS 5 so windwalls on both sides can be accessed. Safety meeting to discuss raising derrick. Open pipe shed roof and raise derrick. Close windwalls. Rig up pipe straightener onto injector. R/U blocks to injector. P/U injector to rig floor. P/U gooseneck from pipeshed and R/U to injector. Install chainfall beams in pipe shed. Prep to back over well. SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. Printetl: 2/13/2008 2:43:22 PM ' ~ • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 1/22/2008 08:00 - 08:30 0.50 MOB P PRE Back rig over well, center rig and set down. ACCEPT RIG AT 0830 HRS, 01/22/2008. 08:30 - 13:30 5.00 BOPSU P PRE N/U BOPE. Rig up cuttings tank and spot trailers. 13:30 - 19:30 6.00 BOPSU P PRE Test BOP. Test witness waived b AOGCC inspector Chuck Sch eve. Rebuild check valve on kill line. Install RA tag on whipstock. 19:30 - 20:45 1.25 RIGU P PRE Safety Meeting for stabbing pipe. P/U injector. R/U internal grapple to coil. Pull test. Pull coil across to injector. 20:45 - 21:00 0.25 RIGU P PRE CT cable is hung up while pulling across. Put CT into horsehead so it can be clamped. Finish pulling CT across. 21:00 - 21:15 0.25 RIGU P PRE Install cable boot. MU injector to riser. 21:15 - 22:00 0.75 RIGU P PRE Safety Meeting to discuss filling reel backwards. Start filling reel backwards. Reverse circulate 97 bbls at 3 bpm rig water for a-line slack management. 22:00 - 22:50 0.83 RIGU P PRE Rig up hydraulic tubing cutter and start cutting back CT to find cable. Cut back 50 ft and cable is found. Dress end of CT for connector. Instal! CT connector. 22:50 - 00:00 1.17 RIGU P PRE Pull test CT connector to 35 Klbs, good. Install cable head. 1/23/2008 00:00 - 01:00 1.00 RIGU P PRE Install X-over and nozzle on BHA. MU injector to wellhead to pump forward. Pump 1 reel volume forward at 2.8 bpm. 01:00 - 01:30 0.50 RIGU N WAIT PRE Wait on BPV crew to finish another job on F Pad. 01:30 - 02:50 1.33 RIGU P PRE P/U BPV crew lubricator and tools thru beaver slide to rig floor. Safety Meeting to discuss hazards and mitigations for pulling BPV. MU BPV lubricator and pressure test to 1,000 psi. Pull BPV 700 si underneath. 02:50 - 03:20 0.50 RIGU P PRE Lay down BPV lubricator and pulling equipment. MU injector to riser. Line up to kill well through CT. 03:20 - 03:50 0.50 KILL P WEXIT Bullhead KCI water to kill well at initial rate of 3 bpm with initial WHP = 740 psi. After 47 bbls awa well not takin fluid WHP = 1,500 psi at 1.7 bpm. (Flo-Pro in well from 1/17 well kill) Shut down and prepare to RIH to circulate gas out. 03:50 - 04:50 1.00 KILL P WEXIT RIH circulate at 0.4 bpm, hold 400 - 500 psi initially while bleeding off gas. 04:50 - 06:00 1.17 KILL P WEXIT Increase rate to 2.6 bpm. At 6,800 ft get some freeze protect fluid back. RIH, 2.5 bpm w/ no retums. Well appears to be on vac. At 9000', start pumping biozan downhole. 06:00 - 06:25 0.42 KILL P WEXIT Getting partial returns w/ 210 psi WHP. Choke partially open, taking returns to tiger tank. RIH to 10,400'. Shut down pumps and close choke. WHP = 160 psi. Fall off to 37 psi. Har~dover to day shift. Printed: 2/73/2008 2:43:22 PM ~~ • BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date ~ From - To ~ Hours I Task Code NPT Phase Description of Operations 1/23/2008 106:25 - 07:30 1.081 KILL I P WEXIT 07:30 - 07:40 I 0.171 KILL I P I I W EXIT 07:40 - 18:00 10.33 KILL N WAIT 18:00 - 21:45 3.75 KILL N WAIT 21:45 - 00:00 I 2.251 KILL N I WAIT WEXIT 1/24/2008 100:00 - 01:00 I 1.001 KILL N I WAIT WEXIT 01:00 - 01:30 0.50 KILL N WAIT W EXIT 01:30 - 02:00 0.50 KILL P WEXIT 02:00 - 03:30 1.50 KILL P WEXIT 03:30 - 03:40 0.17 KILL P WEXIT 03:40 - 04:15 0.58 WHIP P WEXIT 04:15 - 06:55 2.67 WHIP P WEXIT 06:55-07:20 0.42 WHIP P WEXIT 07:20-08:10 0.83 WHIP P WEXIT 08:10 - 10:30 2.33 WHIP P WEXIT 10:30 - 11:30 1.00 ZONISO P WEXIT 11:30 - 13:40 2.17 ZONISO P WEXIT 13:40 - 15:00 1.33 ZONISO P WEXIT 15:00 - 15:30 0.50 ZONISO P WEXIT 15:45-18:35 I 2.83~ZONISO~P ~ WEXIT Circulate thru choke 1.9 bpm at 1050 psi. Bottoms up. Phase 3 called ~ 0715.. Continue to circulate at bottoms up taking clean returns to pits. Safety meeting to dicsuss future operations .Well ops complete kill and circulate at min rate. WOW. Rig operations contiinue monitoring air intakes Circulate bottoms up. Circulate at min rate while WOW. Phase 3 weather. Phase 3 weather. Continue to circulate at min rate while WOW. Phase 2, Level 3 weather. Access roads and pads are closed. Continue to circ at min rate, 0.39/0.36 bpm. WOW. Phase 3, Level 3 weather conditions on roads and pads. Circulate at min rate. WOW. Notification given that emergency equipment was cleared out. Used loader to make sure pad area around rig was clear. Loader also made sure access road to West Dock road was clear to pad. Pad operator gave permission to resume operations. Rig crew made rounds to ensure that everything was okay to resume ops. Close choke, perform infectivity test. Wellbore and pits are full of 2% KCL w/ 2 ppb biozan. 0.5 bpm C~ 1100 psi, 675 psi WHP 1 bpm ®1615 psi, 950 psi WHP 1.5 bpm ~ 2030 psi, 1150 psi WHP 2 bpm ~ 2640 psi, 1440 psi WHP POOH to surface w/ nozzle. S/B injector. L/D nozzle. M/U Whipstock setting BHA #1. Overall BHA length = 81.20'. Stab injector. Test BHI tools, open EDC. RIH w/ WS setting BHA. to 10300' Log tie - in. Correction +22'. Log collars. RIH to setting depth.Place too of WS at 10348'. Close ECD and pressure to 3200 psi to shear. Set down 2K. POH LD WS running tool. PU BHA #2 cementing nozzel. RIH circulating at min rate. Swapping to KCL. Tag correct +23. Swap well to KCL. .5 bpm 1210 psi 1080 Shut in psi, Total 40 bbl injected. Liner vol 26 bbl 1.0 bpm 1780 psi 1460 shut in psi, 1.5 bpm 2238 psi 1780 shut in psi 2.0 bpm 2650 psi 1940 shut in psi PJSM for cementing operation. Flood lines with 5 bbl H2O and PT to 4000 psi. Batch mix 41 bbl 15.8 oob cement. 5 bbl H2O. 30 bbl Bio ands. 2 fpm at 670 psi. After 55 bbl away start bullheadina ~5bbl 2 bpm at 1770 wh, 2527 psi, 317 IA, 543 OA ~ 10 bbl 2 bpm at 2140 wh, 2900 psi, 317 IA, 543 OA After 10 bbl reduce rate to 1.5 bpm ~ 15 bbl 1.5 bpm ~ 2200 wh climed to 2700 and broke back Printed: 2/13/2008 2:43:22 PM • ~ ~~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 05-13 Common Well Name: 05-13 Spud Date: 6/29/1994 Event Name: REENTER+COMPLETE Start: 1/17/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 2/3/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 1/24/2008 15:45 - 18:35 2.83 ZONISO P WEXIT to 2200 psi wh After 19.5 bbl reduce rate to .5 bpm. (~ 20 bbl .5 bpm, 3660 wh, 3200 psi, 340 IA, 550 OA. Sto ed bullheading at 20 bbl. ' La in 21 bbl to while holdin 2200 si WH ressure.~ 1700 hours Pull to 7000' safety. Shut down pump and shutin holding 1900 psi WH. Attem t to s ueeze Pre s off 2700 psi in 8.5 min. IA 251 si, OA 485 si. re resure to 3020 si with .4 additional bbls. IA 250 si,OA 483 si. Bleed off to 2700 in 10 min re ressure to 3000 si with .6 a iti si. 18:35 - 19:45 1.17 ZONISO P WEXIT Wash down to top of whipstock while holding 2000 psi WHP. Zero out MM at 9000'. Pressures and weights indicated cement stringers starting at 9400'. Open choke and take returns out bypass line. Tag pinch point at 10351'. Contaminated cement reached surface at 105 bbls on out MM. 19:45 - 21:45 2.00 ZONISO P WEXIT POOH to surface w/ cement nozzle BHA. 21:45 - 22:00 0.25 ZONISO P WEXIT PJSM. P/U injector. UD cement nozzle BHA #2. M/U swizzle stick. Stab injector. 22:00 - 22:15 0.25 BOPSU P WEXIT Jet stack w/ swizzle stick. 22:15 - 23:15 1.00 STWHIP P WEXIT PJSM. P/U injector. UD swizzle stick. S/B injector. M/U window milling BHA #3. Mill, 2 jts 2-3/8" PH6, DPS. Overall BHA length 112.54' Stab injector. 23:15 - 00:00 0.75 STWHIP P WEXIT RIH w/ window milling BHA. 1/25/2008 00:00 - 01:20 1.33 STWHIP P WEXIT Continue to RIH w/ window milling BHA #3. 01:20 - 01:30 0.17 STWHIP P WEXIT Stop at 10,300'. Up wt 47K, do wt 21 K. Shut down pumps and dry tag at 10321'. P/U to 10310'. Increase pump to 2.6 bpm, 1700 psi. RIH, tag pinch point at 10319.3'. Correct depth to _ pinch point, 10352.6'. +33' correction. __. _._._a Mill 3.80" window thru 7", 29#, L-80 Liner. Start Milling at 10352.6' at 1 fph. Full returns. 01:30 - 02:30 1.00 STWHIP P WEXIT Mill 3.80" window thru 7" liner. 2.6 bpm, 1950 psi, 2K WOB, 1 fph. Milled to 10354.1'. 02:30 - 04:00 1.50 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2200-2700 psi, 2.5-3.5K WOB, 1 fph. Milled to 10355.3'. 04:00 - 06:00 2.00 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2500-2700 psi, 3-3.5K WOB, 1 fph. Milled to 10357.4'. 06:00 - 07:30 1.50 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.5 bpm, 2400-2600 psi, 3-3.7K WOB, 1 fph. Milled to 10357.8'. PT= 305 BBLS. 07:30 - 10:17 2.78 STWHIP P WEXIT Mill 3.80" window thru 7" Liner. 2.6 bpm, 2300-2600 psi, 3-3.7K WOB, 1 fph. Stall at 10358.7. Milled to10360. PT= 305 BBLS. 10:17 - 10:40 0.38 STWHIP P WEXIT Drill formation to 10363'. Printed: 2/13/2008 2:43:22 PM • Well History • Well Date Summary 05-134 12/7/2007 ***WELL S/I ON ARRNAL*** (pre ctd) PULLED 4 1/2" "PXX" PLUG FROM 10,278' MD, GOT CALLED OFF FORA PRIORffY FISHING JOB **** WELL LB= f SHUT IN **** 05-13A 12/10/2007 ***WELL S/I ON ARRNAL*** (pre CTD) DRIFT W/ 2.25" CENT, S-BAILER TO 10,900' SLM, (BAILER IWT) DRIFT W/ 20' DMY WHIPSTOCK (3.68" OD) TO TOP OF LINER @ 10,543' MD CALIPERED CASING W/ PDS 40 ARM W/ GAMMA RAY, FROM LNR TOP @ 10433' SLM TO 9700' SLM ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF CONDffIONS*** 05-13.4 12/31/2007 T/V0=2400/620/390 temp=s/i MIT IA 3000 psi ***PASS*** ; MIT OA 2000 psi ***PASS*** (Pre CTD) Pumped 9.8 bbls crude down IA to reach test pressure. IAP lost 100 psi 1st 15 min, 40 psi 2nd 15 min. Total loss of 140 psi in 30 rrin. Pass. Bleed IAP. Ressured up OA to 2000 psi w/2.6 bbls crude for MIT. OA lost 160 psi in 15 min, lost 20 psi in 2nd 15 min, for a total loss of 180 psi in 30 min. Pass. Bleed OAP. FWP= 2400/660/460 ***Annulus valves open to gages. Tags hung.*** 05-13A 1/12/2008 T= 2300 PSI Set 4" ISA BPS/, pre-rig for Nordic One Did set 4' ISA BPV #511 at 104"... no problems, job complete 05-13A 1/17/2008 T/V0= 2400/640/380. Temp= SI. Bleed IAP & OAP to 0 psi (CTD prep). A/L spool disconnected. IA & OA FL near surface. Hot Oil unit on site, rigged up and ready to begin pumping dow n the TBG. During pump job OAP increased to 510 psi. Bleed IAP from 640 psi to 400 psi in 3 hrs (fluid & gas). Shut-in IA bleed for 30 mins to allow gas to migrate up. Bleed OAPfrom 530 psi to 120 psi in 3.5 hrs (fluid & gas). Continued bleeding IAPfrom 400 psi to 210 psi in 2 hrs. Shift change, night crew will continue bleeding. Flnal WHPs= 0/210/120. 05-13A 1/17/2008 T/V0=2380/560/460 Load & Kill -Spot Flo-Pro (Pre-CTD) -Pumped down Tbg w/5 bbls neat methanol, 295 bbls 100*F 1 % kcl, 45 bbls 60*F 8.5 ppg Flo-Pro, displaced w/75 bbls 1 % kcl & 50 bbls 60/40 methanol. Verify casing valves open to gauges, tag well & notify operator. (DHD still on bcation bleeding IA/OAP). Fnal WHPs=Vac/420/360 05-13A 1/17/2008 T=2300 P.S.I. I./A=600 P.S.I. O/A=500 P.S.I. Pull 4" ISA BPV for Re-Rig. Pulling for Pre-Rig to kill w eIl.Equalized pressure and pulled BPV through tree@ 96"with no problems. 05-134 1/18/2008 T/V0= 0/180/40. Temp= SI. Bleed IAP & OAP to 0 psi (CTD prep). ALP= A/L Spool removed. Initial IA & OA FL's near surface. Bled IAPfrom 180 psi to 15 psi in 6.5 hours (all gas). Bled OAPfrom40 psi to 0 psi in 4 hrs. Monitor BUR w hile rigging down, IAP unchanged, OAP increased to 0+ psi in 30 mins. Flnal WHPs= 0/15/0+. 05-13A 1/18/2008 T/V0= 0/200/155. Temp= SI. ALP= A/L Spool removed. Bleed IAP & OAPto 0 psi (CTD prep). Initial IA & OA FL's near surface. Bled IAPand OAPto 85/10 psi in 7.5 hours (gas/fluid). Returned -71 bbls of fluid during the bleed. Bled gas from the IA & OA for 15 minutes at w hich point fluid came to surface. At the 35 minute rrnrk the annuli started surging fluid and gas to the tank. After bleeding for 90 minutes the TP had increased to 10 psi. Bled TP to 0 psi in - 20 seconds. Open bleed continues on the IA & OA. Shut in bleed and start rigdow n. After rigdow n (30 minutes) TP unchanged, IAP increased 35 psi and OAP increased 15 psi. Flnal WHPs= 0/120/25. 05-13A 1/18/2008 T/V0= 200/0/0 MfrIA PASSED to 3000, MffOA PASSm to 2000 psi. (Pre CTD Rep) Pumped 109 bbls crude to reach test pressure on IA. IA passed MIT on 2nd attempt, IA lost 0 psi in 30 mins. Bled IA back to 500 psi. RU to OA. MR OA to 2000 psi.. Pumped 13 bbls crude to reach test pressure of 2000 psi on OA. OA lost 80 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 100 psi in 30 wins. Bled all pressures back to 0 & rigged down. FWHP=O/0/0 Annulus valves tagged and open to gauges 05-134 1/19/2008 T/V0=20/100/50. SI. Monitor (CTD prep). Tie in crew currently working on well. 05-13.4 1/20/2008 Set 4" FMC ISA BPV. Re-Rig. 500 PSI on tog. 05-13B 1/24/2008 T=700. Pulled 4" FMC IS-A BP./. (Nordic #1) Print Date: 2/19/2008 Page 1 of 1 ~~a~~ 0~ a~~~~~~~~~ ~~o~.~~ COIQSERV~'lIO1Q CODIIK[SSION Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 i F SARAH PALIN, GOVERNOR ~~ /_~ _ 333 W. 7th AVENUE, SUITE 100 `ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 ~~~~ NCU ~' ~ 2007 Re: Prudhoe Bay Field, Prudhoe Bay Oil fool,-PBU-05-13A ~ ~ ~~ Sundry Number: 307-321 `~ Dear McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2007 Encl. Sincerely, • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 `' 1 /as~a ~'il ~ Gas n_ 9 2QQ7 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~Ch or ~ ag~ ^ 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 194-042 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20250-01-00 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: PBIJ 05-13A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028326 62.46' ' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11954 8808 ", 11954 8808 10278 None asin L n h Size MD TVD Burst Colla se' Structural C nd r 12' 20" 112' 112' 153 520 Surface 2718' 13-3/8" 2718' 2718' 4930 2670 Intermediate 10030' 9-5/8" 10030' 8064' 6870 4760 Pr u ti n Liner 6803' 7" 4182' - 10985' 4058' - 8809' 8160 7020 Liner " 1138' 2-7/8" 10814' - 11952' 8707' - 8808' 10570 11160 * Liner a ears to have ulled u hole 200', offsettin the Slotted intervals too. Ori final de the are bein re orted. Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10814' - 11952' 8707' - 8808' 4-1 /2", 12.6# L-80 ~oaoo' & 10474 - ioaso' Packers and SSSV Type: 7" x 4-1/2" Baker'SABL-3' packer; Packers and SSSV MD (ft): 9925'; 7" x 4-112" Baker'ZXP' packer; 7" Baker'SABL-3' packer 10453'; 10678' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 15, 2007 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 1$. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Abby Higbie, 564-5480 iG .7 Terrie Hublilea 564-4628 Signature ~ .~~, ..-- Phone 564-4387 Date rl7/~ ~- ~ ~ ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity "BOP Test ^ Mechanical Integrity Test ^ Location Clearance /~' 0 ~~,¢,~ Other: 354 ~S ~ Qo~ "~'~ST `~ ~~ ~ ~ ~ ~ . ~~~ ~ ~0~`- ~ ~~5, O ~ ~~ Subsequent Form Required: ~„`O~ ~~~ `~- ~~~-v<-~ APPROVED BY 3 ~ ~ A roved B : CO STONER THE COMMISSION Date [ ~ ~ssion Form 10-403 Revised 06/2006 L/ ~ Submit In Duplicate 0R1GI ~~~~~~~~oo~ • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: October 15, 2007 Re: OS-13A Sundry Approval by Sundry approval is requested for well OS-13A. 5-13A was completed as a rotary/CTD combination sidetrack in September 1994. A rotary rig drilled into Z1A and seta 7" liner. CTD then drilled the Z1A production hole section and installed a 1133' slotted liner. The holes in the slotted liner had aluminum plugs inserted to improve well control while R1H. After running the liner to TD, an acid job was pumped to dissolve the aluminum plugs. In October 1994, CT ran in the well to pump an acid job. The CT softly tagged at 11040' and jetted to TD at 11950'. Sticking was noticed at 10930', 10865', and 10807'. After pumping the acid job, the CT started dragging an additional 6000# over string weight at 11230'. At 11100', the weight broke back to normal. A June 1997 LIB detected that the liner had moved with a new liner top at 10587'. In June 1997, a production log identified 9-5/8" production casing leak at 6600' - 6900'. The casing leak was squeezed with Maraseal in Feb 1998 but the job failed. A rig workover to repair the 9-518" casing leak was performed in June 1998. During the workover, a 7" x 4-1/2" liner ZXP packer with a 2.992" ID was installed to prevent future upward movement of the 2-7/8" slotted liner. A 7" scab liner was then installed from 4182' -0 9878' and cemented in place with 156 bbls cement. New 4-1/2" L80 tubing was installed with a new production packer at 9925'. 5-13A produced full time until the gas rate mysteriously increased from 10 mmcfd to 40 mmcfd in late 2002. This rapid increase in gas caused the GOR to increase above marginal and the well has been SI since early 2003 due to uncompetitive GOR. A mechanical problem with the 7" casing or a channel behind 7" is the suspected cause of the high gas production. A log was never run to identify the source of the gas because the slotted liner eliminates any wellwork options. In June 2007, the well passed aMIT-OA to 2000 psi, aMIT-IA to 3000 psi, and aMIT-T to 3000 psi. The PPPOT-T and PPPOT-IC also passed in June 2007. A caliper log of the 4-1/2" production tubing in June 2006 indicated the tubing was in good condition with a maximum penetration of 32%. REASON FOR SIDETRACK: OS-13A currently has very a high GOR therefore receiving very little on-time. The slotted liner completion eliminates any wellwork options. The well currently provides minimal value to the field. Pre-Rig Work: (scheduled to begin December 15, 2007) 1. O MIT-IA, MIT-OA 2. S Pull 4-1/2" PX TT Plug at 10,278 3. S Run 2.25" drift as deep as possible (for kill string in the 2-718" liner}. 4. S Dummy whipstock drift (3.7" x 17') to 10,400' 5. O AC-LDS; AC-PPPOT-IC, T 6. O PT MV, SV, WV 7. O Bleed gas lift and production flowlines down to zero and blind flange 8. O Remove wellhouse, level pad • • • Rig Work: (scheduled to begin on January 15, 2008) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. ~~~ S G ~~C(~~C1`, 2. Set cement retainer with kill string below in ZXP packer bore at 10,453'. ` n 3. Set 4-1/2" x 7" TTWS at 10334' with HS orientation. ~JJ= l~i 4. Down squeeze 20 bbl of 15.8 ppg to isolate the parent well ~, ~Zo X s l 5. Mil 3.8" wm ow at an o rat o e. wap t ewe o o- ro. 6. Drill Lateral: 4.125" OH, 2681' (12 degf100 planned) 7. Run 3-1/2" x 3-3/16" x 2-7/8" solid liner leaving TOL at 9975' 8. Pump primary cement leaving TOC at 9975', 32 bbls of 15.8 ppg liner cmt planned 9. Cleanout liner and MCNL/GR/CCL log 10. Test liner lap to 2000 psi. 11. Perforate liner per asset instructions (1200') 12. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 3. Test separator (1200' of prefs) Sean McLaughlin CTD Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble TREE = CNV WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 62.5' BF. ELEV = KOP = 10300' Max Angle = 95 ®11932' Datum MD = NA Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ~ = 12.347" H 2718' Minimum ID = 2.441" ~ 10613' TOP OF 2-718" LINER TOP OF 7" LNR -SCAB 4182' 05-13A 4-1/2 CAMCO SVLN, 9-CR SSSV N~, ~ = 3.812" GAS LIFT MANDRE3S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04!14/05 2 7384 6210 49 KBG2LS DMY tNT 0 04/14/05 3 9780 7897 48 KBG2LS DMY M 0 9-5/8" X 7" ZXP LNR TOP PKR W/ FN1AC LNR HGR 9872' ~ 9-5/8" X 7" ZXP 7" PKR 7" LNR -SCAB, 26#, L-80, .0383 bpf, ID = 6.276" 9878' 9925' 7" X 4-1/2" BKR SAB-L-3 HYD PKR TOP OF 7" LNR 9878' milled 10278' 4-1l2" HES X NIP, ~ = 3.813" 10278' 4-1/2" PX TTP SET (12/03/05) 9-5/8" MLLOUT WINDOW - 10030' -10080' 4-1/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" ~--~ 10300' I TOP OF 4-1 /2" TBG 1 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" ~ 10587' TOP OF 2-7/8" LNR -SLOTTm 10400' ~ 4-1/2" TBG, 12.8#, L-80, .0152 bpf, ~ = 3.958" ~-~ 10860' PERFORATION SUMMARY REF LOG: AWS CNL ON 07/08/94 A NGLE AT TOP PERF: 40 (d~ 10785' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SLTD 2 10785 - 11551 C 08/22/94 SLID 2 10587 - 11720 C 11/09/94 9-5/8" CSG, 47#, N-80, ~ = 8.681" ~-{ 11 10300' -~a-1n" TUBNVVG TAiI WLEG i 1045$ I 7" X 4-1/2" BKR ZXP LNR PKR, D = 2.992" 14-1/2" GS DEPLOYMENT SLEEVE I '\ \ 10678' -i7" BAKER SABL-3 PKR i \ \ ~ \\ 10733' 4-1/2" OTIS X N6~, D = 3.81" \ \ \ \ \ ~ \\ ~ 10860' 4-1i2 TUBING TAB WLEG \\ ~\ ~ ELMD TT NOT LOGGEO ~~. ~~ ~~ ~ ~~ ~~ ~ ~\\` ~``` 7" LNR, 29#, L-80, .0371 bpf, ~ = 6.184" 10985' ~ ~ 2-7/8" LNR -SLOTTED, 6.5#, L-80, .0056 bpf, ~ = 2.441" ~1,G~5~ , DATE REV BY COMMENTS DATE REV BY COMMENTS 1977 ORIGINAL COMPLETION 05/03/05 TJP/PJC WANER SAFETY NOTE 08/22194 SIDETRACKED 12/04/05 DAV/PAG SETTTP 08/20198 LAST WORKOVER 12/17/05 QL/PJC WAVER SFTY NOTE DELETED 02106!02 RN/TP CORRECTIONS 06!24!04 DFR/KAK CORRECTIONS 04!27/05 MGS/TLH GLV C!O (04/14/05) PRUDHOE BAY UNff WELL: 05-13A PERMR No: 1940420 API No: 50-029-20250-01 SEC 32, T11 N, R15E, 805' FEL 8 3599.16' FNL BP t3cploration (Alaska) TREE = Clw W0.LHEAD= FMC ACTUATOR= BAKERC KB. ELEV = 62.5' BF. 0.EV = KOP = 10300' Max Angle = 95 ~ 11932' Datum MD = NA Datum ND = 8800' SS 13-3/8" CSG, 72*, N-80, ~ = 12.347" 2718' Minimum ID = 2.441" ~ 10613' TOP OF 2-718" LINER TOP OF 7" LNR -SCAB 4182' 7" LNR 05-13B ~ Proposed CTD Sidetrack 9-5/8" CSG, 47#, N-80, ID = 8.681" ~ 11286' 9-5/8" MILLOUT WINDOW - 10030' -10080' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 10300' nf~atable cen~~n[ reta~rer 10453' 7" X 4-1/2" BKR ZXP LNR PKR, ID = 2.992" 10453' TOP OF 4-1/2" TBG 10474' 2-7/R" I NR R 5!t t_-Atl OnSA hef_ ID= 2.441" --~OSAT 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: AWS CNL ON 07/08/94 ANGLE AT TOP PERF: 40 ~ 10785' Note: Refer to Production DB for historical p ert data S¢E SPF INTERVAL Opn/Sqz DATE SLTD 2 10785 - 11551 C 08/22/94 SLTD 2 10587 - 11720 C 11/09/94 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" -~ 2-7/8" LNR -SLOTTED, 6.5~, L-80, .0056 bpf, D = 2.441" { 1 NOTES: 70° ~ 10994' AND 90° ~ 11049' 1999' 4-1/2 CAMCO SVLN, 9-CR O SSSV NP, ID = 3.812" (,AS LET MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3874 3809 32 MMG DMY RK 0 04/14/05 2 7384 6210 49 KBG2LS DMY INT 0 04/14/05 3 9780 7897 48 KBG2LS DMY AVT 0 9-5/8" X 7" ZXP LNR TOP PKR W/ HMC LNR HGR 9872' ~ 9-5/8" X 7" ZXP 7" PKR 9925' 7" X 4-1/2" BKR SAB-L-3 HYD PKR 9975' Top of 3-112" !.finer ~ OC 9985' 3-1%2" XN NIP. ID = 2.75" 10278' 4-1 /2" HES X NIP, ID = 3.813" 1030Q' 4-1/2" TUBING TAIL WLEG 11500' 3-3 ~ ' ;ver 3-3/16" X 2-7/8" cmted 10334' Mechanical Whipstock 106781 7" BAKER SABL-3 PKR 10733' 4-1 /2" OTIS X NIP, ID = 10860' 4-1/2 TUBING TAIL WLE 0.MD TT NOT LOGGED DATE REV BY COMMEMS DATE REV BY COMMEMS 1977 ORIGINAL COMPLETION 05/03/05 TJP/PJC WANFRSAFETY NOTE 08/22/94 SIDETRACKED 12/04!05 DAV/PAG SETTTP 08120/98 LAST WORKOVER 12/17/05 E3UPJC WANER SFTY NOTE DELETED 02/06/02 RN/TP CORRECTIONS 06/24/04 DFR/KAK CORRECTIONS 04/27/05 MGS/TLH GLV GO (04/14/05) 13015' PRUDHOE BAY UNIT W0.L: 05-13A PERMfT No: 1940420 API No: 50-029-20250-01 SEC 32, T11 N, R15E, 605' F0. & 3599.16' FNL BP Exploration (Alaska) ~ Oil AND ~:~T¿g~S~:A~ON COMMIION RlECE:!VF!"1 REPORT OF SUNDRY WELL OPERATIONS JA 0"",,, StimulateD tbJn., /!JIJ~' Waiver D Time Extension all & Gas ,.. f.,(]f)~ c: Re-enter Suspended Well D An'" 0Ir;¡'" ,,,,- 5. Permit to Drill Number:"i¡j{ 194-0420 o 6. API Number: 50-029-20250-01-00 9, Well Name and Number: 1, Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2, Operator BP Exploration (Alaska), Inc. Name: P.O, Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3, Address: 62.46 KB 8, Property Designation: ADL-028326 11. Present Well Condition Summary: Total Depth measured 11954 feet true vertical 8807.69 feet Effective Depth measured 11954 feet true vertical 8807.69 feet Casing Length Size Conductor 80 20" 94# H-40 Surface 2687 13-3/8" 72# N-80 Production 10000 9-5/8" 47# N-80 Liner 6803 T' 29# L-80 Liner 1133 2-7/8" 6.5# L-80 Perforation depth: Closed Measured depth: 10785 - 11551 True Vertical depth: 8685,7 - 8821.32 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12, Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13, Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Class: Development I;?' Stratigraphic 0 MD 32 - 112 31 - 2718 30 - 10030 4182 - 10985 10587 - 11720 Closed 10587 - 11720 8514.47 - 8818.07 4-1/2" 12.6# 4-1/2" 12.6# Exploratory Service 05-13A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) 10278 PX None TVD 32 - 112 31 - 2717.92 30 - 8063.94 4057.77 - 8808.95 8514.47 - 8818.07 Burst 1530 4930 6870 8160 10570 Collapse 520 2670 4760 7020 11160 <;;;,«(' i4, \i\..\i~\~¡fJ, "",vlI',,U't, C._·, L-80 L-80 21 - 10300 10474 - 10860 4182 9872 9925 10453 10678 7" Baker ZXP Packer 7" Baker ZXP Packer 4-1/2" Baker SABL-3 Packer 4-1/2" Baker ZXP Packer 4-1/2" Baker SABL-3 Packer \~BOMS 8Ft ,IAN ] ¡ 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN SHUT-IN 15. Well Class after oroposed work: Exploratory Development I;?' Service 0 16. Well Status after proposed work: Oil I;?' Gas 0 WAG GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Form 10-404 Revised 04/2004 ORIGIN L Date 1/9/2006 Submit Original Only "" e e 05-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTI~ITYDA TE I . SUMMARY 12/3/2005 *** CONTINUE FROM 12-02-05*** STAND BY FOR LRS, LRS ON LOCATION TO LOAD TUBING AND IA WI 270 CRUDE SET 4-1/2" PX PLUG IN X NIPPLE @ 10278' MD PLUG TESTED GOOD ***WELL LEFT SHUT IN*** FLUIDS PUMPED BBLS 5 MeOH 288 Crude 293 TOTAL 05-13A (PTD #1940420) Internal Waiver Cancellation - Trouble Well e e Kqî I VIZ4D~ .. .. .. Subject: OS~13A (PTD #1940420)Intet11al Waiver Cancellation - Trouble Well d From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BPi:com> . . . .. . . Date: Fri, 16Pec 2005 19:14:43 -0900 To:"AOGCq-,'" onAub~rt (E-mailyi <Wi jimJegg@ad·.. .;us,;;.('NSU,ADW W <NSUADWVV;jl· .·ßSûpervisor@~P. .. "GPB, ~S lISIISTP'~ehMgr" <GP " "GPB, F$l DS;Ops Lead" <GPBESl eel' ¡'NSÛ, A!'W W~ll Integrity'~fig ADW WI Tee,' <NSüADWWITech "Mielke,R~~ê' \!-<'<robert.mielke@BP. .' J,128~ubert@admilI.staté:äk.us>, :.::::..: . ":::::;:: ..: erations Snpe' 'sor" .. >, "Rossberg,'R ..' '.' n" <Rossb,eR$" BP.eom>, "Kurz1¡ ().. ·~;<john.kutZ@I3 ad@BP.cq,m> !~. '..:: . ..' . SUADWWellInt' rityEngineef@BP.eom>, , . m>, "Dean, James "<J ames.Dean@:pIl,eom>, . ,'.£0:& H..'" . > . ". ....;.. . " .. :#,,/,0,0,'0)\\(> All, An internal waiver was issued for TxlA communication on well 05-13A (PTO #1940420) on 04/27/05. The well no longer meets waiver requirements as it now has TxlAxOA communication. Therefore the waiver is cancelled. The well is currently secured. Although it is uneconomic for repair at this time, the well will be evaluated for a rig sidetrack. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, )lnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 {t(;'~~~f,~Æ::ir.! c 1 of 1 12/21/20054:32 PM 05-13A (PTD #1940420) Classified as Problem Well ') Subject: 05-13A (PTD #1940420) Classified as Problem Well From: "Anders, Joe L" <anders22@BP.com> Date: Tue, 05 Apr 2005 20:40:01 -0800 T~:: "Dean,"James A" <deanja@BP~c()m>,"GPB,FSl DSOps Lead".. . <GPBFSIDSOpsLead@BP.com>, "Rossberg, R Steven" <Ross~eR8@BP.com:>;."NSU,ADW Well: Operations Supervisor" <NSUADWW ellOperationsSuperVisor@BP·.com>;"GPB,:Wells.Opt Eng" , <qPBW ellsOptEng@BP~com>, .tAOGCC!imRegg.(E-mail)..<jitn~r¢gg@adn1in.state.ak.us>.. . ".. . "AOGÇC Winton Aubert (E-mail)..<winton_aribert@admin.state;ak.us>~·~·NSU.~ADW WL &<. .. C01npletion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>~~"G~B, FSl DS5 . . . Opératòr" <<:iPBFSll?S50per~tor@B~~cçm:>, .'~GPB, FS 1/SIP/STPArea:ry.Jgr'» . .. <GPBFSITL@BP.com>, "GPB;Opsl\.1gr"<(}PBOpsMgr@BP.com:?-: ,; ,': . . , .. :. . CC: "NSU,· .APWWeU Integrity Engineer" <NSUADWWellIntegrityJingineêr@BP ~com>; ·~'Reeves, D~nala F"<ReevesPf@B~ .com>,· "Mì~lke"RobertL.":<tpbert.mìe1ke@BP.c()m:>::' . ) All, Well 05-13A (PTD #1940420) has sustained casing pressure on the IA and is classified as a Problem well. TIO's on 04/04/05 were 2360/2120/600. The plan forward for this well is as follows: 1. SL: Run DGL V's 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «05-13A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Wark: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWell!ntegrityEngineer@bp.com SCJ,NNED JUL O? 2005 Content-Description: 05-13A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/10/2005 8:07 AM ) TREE = W8..LHEAD = A GfUA TOR = KB. ELEV = BF. ELEV = KOp·= . Max Angle = ·ÖäiumiVib";· DatumTVD = CWV FIVC BA KER C 62.5' u... ...Ú)300ï 95 @ 11932' u................Nii:.. 8800' SS I 13-3/8"CSG, 72#, N-80, ID=12.347" H 2718' ~ Minimum ID = 2.441" @ 10613' TOP OF 2-718" LINER TOP OF 7" LNR -SCAB H 4182' 17" LNR -SCAB, 26#, L-80, .0383 bpf, ID = 6.276" H 9878' 1 1 TOP OF 7" LNR 1--19878'milled 1 4-1/2"TBG, 12.6#, L-80,.0152 bpf, ID =3.958" H 10300' ITOPOF4-1/2"TBG H 10474' 1 2-7/8" LNR,6.5#, L-80,.0058bpf,ID=2.441" H 10587' I ITOPOF2-7/8"LNR-SLOlTED H 10400' ~ 14-112"lBG,12.6#, L-80, .0152 bpf,ID=3.958" H 10860' 1 PffiFORATION SUrv1VIARY REF LOG: AWS CNL ON 07/08194 ANGLE AT TOP ÆRF: 40 @ 10785' Note: Refer to Production DB for histori::al perf data SIZE SPF INTERV AL Opn/Sqz D6.1E SL TD 2 10785 - 11551 0 08122/94 SL TD 2 10587 - 11720 C 11/09/94 / 9-5/8"CSG,47#,N-80,ID=8.681" I., 11286' 1 05-13A fa SAFETY NOTES: 70° @ 10994' AND 90° @ 11049' 1999' 1- 4-1/2 CAMCO SVLN, 9-CR SSSV NP, D = 3.812" ~ GAS LIFT Mð.NDR8..S ST MD TVD DEV lYÆ VLV LATCH PORT D6.1E 1 3874 3809 32 rv1VIG RK 2 7384 6210 49 KBG2LS INT 3 9780 7897 48 KBG2LS INT L ~ z- 4182' 1- 9-5/8" X 7" ZXP LNR TOP A<R W/ HIVC LNR HGR 9872' 1-19-5/8" X 7" ZXP 7" A<R 1 9925' I.,T'X4-1/2" BKRSAB-L-3 HYDPKR 1 10278' 1-14-1/2" HES X NIP, ID = 3.813" 1 9-5/8" MIL LOur WINDOW - 10030'-10080' 10300' 1-14-1/2" TUBING TAIL WLEG 1 1 10453' 1-17" X 4-1/2" BKR ZXP LNR PKR, ID = 2.992" 1 1058T 1"4-1/2" GS DER.OYMENTSLEEVE 1 10678' I--iT' BAKERSABL-3 PKR 1 1 10733' 1--14-1/2" OTIS X NIP, ID = 3.81" 1 10860' H4-1/2 TUBING TAIL WLEG 1 1-1 ELMD TT NOT LOGGED 1 .............. .............. ~ ....... ..................... .................... ...... - ............. .............. .................... ............. ...... ............ .............. .............. ~ .................... .............. IT' LNR. 29#, L-BO, .0371 bpI, ID = 6.184" 1--1 10985' I ", ~ 2-718" LNR-SLOTTED, 6.5#, ., 11720' L-80, .0056 bpf, ID = 2.441" D6. TE REV BY COM~NTS 10/10/03 JADI1LP MJL llPLE CORREGfIONS 06124/04 DFRlKAK CORREGfIONS PRUDt-KJEBA Y UNT \NELL: 05-13A PE~rr No: 1940420 AR No: 5O-029-2û250-01 SEL 32, T11 N, R15E, 605' ÆL & 3599.16' FNl DATE 1977 08/22/94 06/20/98 02/06/02 06/12/03 08/18/03 REV BY COrv1VlENTS ORIGINAL COM PLETION SIDETRACKED LAST WORKOVER RN'TP CORREGfIONS C1v10ITLP KB 8.. EVA llON CORRECllON C1v10ITLP D6. TUM MD CORRELllON 8: :& z Z I I BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 M C:LORI~IFILM. DOC E PL W ATE IA L U N D ER TH I$ M A R K E'~~~ /'"~--, STATE OF ALASKA ~ ALASKA;,'-,~ AND GAS CONSERVATION C ,,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate I--] Pull Tubing [--I Alter Casing [~ Repair Well [--I Other [] Plugging I--I Perforate 2. Name of Operator 15. ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: 6. [~ Development I--I Exploratory 7. [--I Stratigraphic I--IService 4. Location of well at surface 8. Datum Elevation (DF or KB) KBE = 62.46' Unit or Property Name Prudhoe Bay Unit Well Number 3015' NSL, 112' EWL, SEC. 32, T11N, R15E, UM At top of productive interval 1367' NSL, 1883' WEL, SEC. 29, T11N, R15E, UM At effective depth 1677' NSL, 607' WEL, SEC. 29, T11 N, R15E, UM At total depth 1677' NSL, 607' WEL, SEC. 29, T11 N, R15E, UM 05-13A 9. Permit Number / Approval No. 94-42 10. APl Number 50-029-20250-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11954 feet true vertical 8597 feet Effective depth: measured 11954 feet true vertical 8597 feet Casing Length Structural Conductor Surface Intermediate Production Liner Liner Scab Liner Perforation depth: measured true vertical Size Plugs (measured) Junk (measured) Fish - Nature Unknown (Confirmed 11/19/94) Cemented MD TVD 112' 20" 224 sx Arcticset 2687' 13-3/8" 5726 sx Permafrost II 112' 112' 2718' 2718' 9998' 9-5/8" 675 sx Class 'G', 275 sx Permafrost 10030' 1107' 7" 244 sx Class 'G' 9878' - 10985' 11140' 2-7/8" UncementeO S,ott~~ E i V E d0813,, _ 11953, 5696' 7" 760 sx Class 'G' 4182' - 9878' Slotted Liner: 11001'- 11952' AUC 2. 7 1998 Slotted Liner: 8816' - 9597' ~asl(a Oil & Gas Cons. Commission ~nch0ra0e Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 10300'; 4-1/2 , 12.6~, L-80 from 10474' - 10860' 8064' 7962'-8808' 8706'-9021' 4058'-7962' Packers and SSSV (type and measured depth) Camco BaI-O SSSV nipple at 1999'; Baker S-3 Packer at 9925'; 7" x 4-1/2" Baker ZXP Liner Packer w/Custom Unique Overshot at 10453'; Baker SABL-3 packer at 10678' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure O,qiG NAL 14. Prior to well operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 5. Attachments I16. Status of well classifications as: [--I Copies of Logs and Surveys run I [] Oil [] Gas I--I Suspended [] Daily Report of Well Operations Y(~i~ ? i~. '_,~and correct to the best of my knowledge 7. I hereby certif rego Signed ~,~~.,~ James .~-a~-.~ Title Senior Drillin~l En~lineer Prepared By Name/Number: Service Date ~/~-~"'" Terrie Hubble, 564-4628 ~S~ ~'n ~)uplicat~ Form 10-404 Rev. 06/15/88 Progress Report Facility PB DS 05 Well 05-13A Page 1 Rig Doyon 16 Date 21 July 98 Date/Time 04 Jun 98 03:00-06:00 06:00-06:30 06:30-15:00 15:00-17:45 17:45-18:15 18:15-00:00 05 Jun 98 00:00-01:00 01:00-04:00 04:00-06:00 06:00-06:30 06:30-17:00 17:00-18:00 18:00-21:00 21:00-21:30 21:30-00:00 06 Jun 98 00:00-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-16:00 16:00-22:30 22:30-01:00 07 Jun 98 01:00-06:00 06:00-06:30 06:30-15:00 15:00-21:30 21:30-00:00 08 Jun 98 00:00-03:00 03:00-06:00 06:00-06:30 06:30-08:30 08:30-14:30 14:30-19:00 19:00-23:30 23:30-06:00 09 Jun 98 06:00-06:30 06:30-09:30 09:30-10:00 10:00-14:00 14:00-15:00 15:00-16:00 16:00-17:00 17:00-18:45 18:45-19:30 19:30-22:00 22:00-02:00 10 Jun 98 02:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-11:00 11:00-11:30 11:30-15:00 15:00-18:00 Duration 3hr 1/2hr 8-1/2 hr 2-3/4 hr 1/2 hr 5-3/4 hr lhr 3hr 2hr 1/2 hr 10-1/2 hr lhr 3hr 1/2 hr 2-1/2 hr 6hr 1/2 hr 2-1/2 hr 1/2 hr 6-1/2 hr 6-1/2 hr 2-1/2 hr 5hr 1/2 hr 8-1/2 hr 6-1/2 hr 2-1/2 hr 3hr 3hr 1/2 hr 2hr 6hr 4-1/2 hr 4-1/2 hr 6-1/2 hr 1/2 hr 3hr 1/2 hr 4hr lhr lhr lhr 1-3/4 hr 3/4 hr 2-1/2 hr 4hr 4hr 1/2 hr 1/2 hr 2hr 2hr 1/2 hr 3-1/2 hr 3hr Activity Rig moved 25.00 % Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Held safety meeting Circulated closed in well at 10500.0 ft Circulated closed in well at 10500.0 ft Circulated closed in well at 10500.0 ft Monitor wellbore pressures Held safety meeting Monitor wellbore pressures Functioned Hydraulic master valve Circulated closed in well at 10500.0 ft Flow check Rigged down Xmas tree integral components Installed BOP stack Held safety meeting Tested BOP stack Removed Hanger plug Worked stuck pipe at 10500.0 ft Conducted electric cable operations Worked stuck pipe at 10500.0 ft Conducted slickline operations on Slickline equipment - Retrival run Held safety meeting Conducted slickline operations on Slickline equipment - Retrival run Conducted electric cable operations Worked stuck pipe at 10319.0 ft Laid down 2200.0 ft of Tubing Installed Slip & seal assembly Held safety meeting Installed Seal assembly Flow check Monitor wellbore pressures Laid down 10283.0 ft of Tubing R.I.H. to 2000.0 ft Held safety meeting R.I.H. to 3000.0 ft Tested Kelly cocks R.I.H. to 6758.0 ft Milled Casing at 6758.0 ft Circulated at 9660.0 ft Milled Casing at 9660.0 ft R.I.H. to 8000.0 ft Serviced Block line R.I.H. to 9878.0 ft Reverse circulated at 9878.0 ft Pulled out of hole to 9878.0 ft Held safety meeting Circulated at 3600.0 ft Pulled out of hole to 0.0 ft R.I.H. to 4515.0 ft Tested Casing - Via annulus Pulled out of hole to 0.0 ft R.I.H. to 5000.0 ft Progress Report Facility PB DS 05 Well 05-13A Rig Doyon 16 Page 2 Date 21 July 98 Date/Time 11 Jun98 12 Jun 98 13 Jun 98 14 Jun 98 18:00-18:30 18:30-21:00 21:00-21:45 21:45-23:30 23:30-04:00 04:00-04:45 04:45-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-13:30 13:30-18:00 18:00-18:30 18:30-20:30 20:30-21:15 21:15-21:45 21:45-03:00 03:00-04:30 04:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-11:30 11:30-21:00 21:00-21:30 21:30-03:30 03:30-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-12:30 12:30-16:30 16:30-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:15 09:15-10:00 10:00-10:30 10:30-11:30 11:30-14:00 14:00-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-22:00 22:00-04:00 Duration 1/2 hr 2-1/2 hr 3/4 hr 1-3/4 hr 4-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 4-1/2 hr 1/2 hr 2hr 4-1/2 hr 1/2 hr 2hr 3/4 hr 1/2 hr 5-1/4 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3hr 9-1/2 hr 1/2 hr 6hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr lhr 5hr 4hr 1-1/2 hr 1/2 hr 3hr 1/2 hr 5hr lhr 2hr 1/2 hr 1/2 hr 1-1/2 hr 3/4 hr 3/4 hr 1/2 hr lhr 2-1/2 hr 4hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 6hr Activity Held safety meeting R.I.H. to 9878.0 ft Functioned Other sub-surface equipment Circulated at 9838.0 ft Pulled out of hole to 80.0 ft Pulled BHA Made up BHA no. 4 Held safety meeting R.I.H. to 9877.0 ft Milled Liner at 9883.0 ft Circulated at 9877.0 ft Pulled out of hole to 2000.0 ft Held safety meeting Pulled out of hole to 0.0 ft Serviced Block line Pulled BHA Ran Liner to 2584.0 ft (7in OD) Serviced Casing handling equipment Ran Liner to 3500.0 ft (7in OD) Held safety meeting Ran Liner to 5695.0 ft (7in OD) Circulated at 5695.0 ft Ran Drillpipe in stands to 8000.0 ft Laid down 5695.0 ft of Liner Made up BHA no. 5 Singled in drill pipe to 5200.0 ft R.I.H. to 9885.0 ft Reamed to 9890.0 ft Circulated at 9890.0 ft Held safety meeting Circulated at 9890.0 ft Pulled out of hole to 0.0 ft Tested All functions Ran Liner to 0.0 ft (7in OD) Held safety meeting Ran Liner to 1400.0 ft (7in OD) Circulated at 1400.0 ft Ran Liner to 5600.0 ft (7in OD) Rigged up sub-surface equipment - Liner hanger Ran Liner in stands to 8000.0 ft Held safety meeting Ran Drillpipe in stands to 9878.0 ft Circulated at 9878.0 ft Mixed and pumped slurry - 156.000 bbl Displaced slurry - 288.000 bbl Functioned Liner hanger Reverse circulated at 4182.0 ft Pulled Drillpipe in stands to 4182.0 ft R.I.H. to 6000.0 ft Held safety meeting R.I.H. to 6564.0 ft Serviced Block line R.I.H. to 9635.0 ft Drilled cement to 9890.0 ft Progress Report Facility PB DS 05 Well 05-13A Rig Doyon 16 Page 3 Date 21 July 98 Date/Time 15 Jun 98 16 Jun 98 17 Jun 98 18 Jun 98 19 Jun 98 04:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-14:30 14:30-15:30 15:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-01:00 01:00-03:00 03:00-05:30 05:30-06:00 06:00-06:30 06:30-13:30 13:30-18:00 18:00-18:30 18:30-20:00 20:00-01:30 01:30-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-11:30 11:30-17:00 17:00-18:00 18:00-18:30 18:30-22:00 22:00-23:00 23:00-06:00 06:00-06:30 06:30-09:00 09:00-18:00 18:00-18:30 18:30-19:15 19:15-20:15 20:15-23:45 23:45-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-11:00 11:00-14:00 14:00-16:30 16:30-18:00 18:00-18:30 18:30-21:30 21:30-22:00 Duration lhr lhr 1/2 hr 1-1/2 hr 2-1/2 hr 4hr lhr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 5hr 2hr 2-1/2 hr 1/2 hr 1/2 hr 7hr 4-1/2 hr 1/2 hr 1-1/2 hr 5-1/2 hr lhr 1/2 hr 2hr lhr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 5-1/2 hr lhr 1/2 hr 3-1/2 hr lhr 7hr 1/2 hr 2-1/2 hr 9hr 1/2 hr 3/4 hr lhr 3-1/2 hr 6-1/4 hr 1/2 hr 1-1/2 hr 2hr lhr 3hr 2-1/2 hr 1-1/2 hr 1/2 hr 3hr 1/2 hr Activity Tested Liner - Via annulus and string Washed to 9890.0 ft Held safety meeting Washed to 10317.0 ft Circulated at 10317.0 ft Pulled out of hole to 4181.0 ft Circulated at 4181.0 ft Pulled out of hole to 0.0 ft Removed Rig services Held safety meeting Made up BHA no. 7 R.I.H. to 10317.0 ft Reamed to 10540.0 ft Circulated at 10540.0 ft Pulled out of hole to 9500.0 ft Held safety meeting Pulled out of hole to 0.0 ft R.I.H. to 10317.0 ft Held safety meeting Circulated at 10500.0 ft Pulled out of hole to 200.0 ft Laid down fish Made up BHA no. 9 R.I.H. to 6600.0 ft Serviced Block line Held safety meeting R.I.H. to 10450.0 ft Tested Liner - Via annulus and string Washed over string at 10494.0 ft Circulated at 10494.0 ft Pulled out of hole to 0.0 ft R.I.H. to 2000.0 ft Held safety meeting R.I.H. to 10450.0 ft Functioned Liner hanger Pulled out of hole to 4000.0 ft Held safety meeting Laid down 3381.0 ft of 3-1/2in OD drill pipe Ran Tubing to 7400.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 8300.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 10300.0 ft (4-1/2in OD) Reverse circulated at 10300.0 ft Held safety meeting Installed Tubing hanger Functioned Production packer Installed Hanger plug Rigged down All functions Installed Xmas tree Displace treatment Held safety meeting Installed Hanger plug Rig moved 5.00 % 0 I=t I I__1... I IM G WELL LOG TRANSMITTAL To: State of Alaska July 30, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 05-13A RE: AK-MW-40055 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.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. JUi_ ,.,~, '-"" Am0rafle 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Inc. Company PERMIT DATA 9/+-0/+2 ~225 / 9/+ - 042 .~/,3, P 9/+ -042 9/+-0/~2 9/+-0/+2 ~',HP /---~CC Indi vi dua'i We'i 'i G; ,ca'l Mater'ia'ls Inventory T DATA_PLUS T i0196-1i08a OH/ZDL/CN/GR R COMP DATE: 08/22/94. R 06/25-08/22/94 ~-~D~,F WELL REPT R MD VISUAL LITHOLOGY _r~F~RVEY R 10022-11116 9/+-o/+2 94-042 ~6~,/CCL. 9/+-0/+2 .~dWL 9/+-042 .~SGAC/SROP 9/+-042 ~oGAC/SROP 9a-0~2 ~/SSTVD L 10221-11085 L 10196-11066 L 9750-10995 L 10538-10998 L 9000-11100 LWD/TVD L 8000-8800 LWD/MD L 10196-11085 *-/ZDL/'CN/GR/CAL/RB L 10196- i 1 ocs LOGY VISUAL D SPERRY oUN ~--~ge: i I ~e: 06/08/'96 RUN DATE_RECVD 1 08/11/9/+ 10/11/9a. 10/11/9/+ 0872679~. 10/"1 1/"9/+ I 08/06/9/+ 1 08/06/9/+ 1 o8/15/9/+ I 08/15/9/+ 1-6 08/26/9~. 1-6 08/26/9/+ 1 08/06/94. 1 08/06/9/+ 08/26/9a. Ar'e dr'y ditch samp'les required? yes no And received? yes no Was the wel"l cored? yes j~~nalysis & description recei ~" V~C~'~~O Ar'e ~¢e'l 1 tests requi r'ed'-~ yes ~ R~e~ei v~? yes ne We i '1 i' s i' n comp 1 i' a nce lni ti'al COMMENTS To: ComPanY: Phone: f~×: Fr°m: L~fry J this ~ p~': 1' Comments:: Pe/:. 6uk.,~:~erjatio.a I am faxlng a list of wells for which we currently r&qfl~i[,~ii da~; pjeaS~'let uS knoTM as to When Wh refieive thes~ data:: ' British ~trOleum.~ .Inc.. (Al~ka) company C, ontact: DaVid D~uglas Haas C..°ntac~ d~ie: 12/b5~9~1 Ph, p~ne Number: 907~584.592~ -~mmontS: ~ J', g2'04~-~; '_ "~DIU '4~~3 ' J "B-~ ,'-': '; ' J DISITAL O~TA &'LIS V~RIFICATION'LI~IN0 RECEIVED MAY 2 5 1995 Oil & G~s Coos. Commission Anchorage ALASKA OiL AND GAS CONSERVATION CQ,,,MISSION WELL COMPLETION OR R£COMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEhDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 94-42 3. Address 3. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 $0- 029-20250-01 4. Location of well at surface .9. Unit or Lease Name 3015' NSL, 112' EWL, SEC. 32, T11N, R15E Prudhoe Bay Unit At Top Producing Interval ~~~?~t ~~! 10. Well Number 1367'NSL, 1883'WEi., SEC. 29, T11N, R15E.'~~~ .! ~ 5-13Aprudhoe 11, Field and Pool At Total Depth Bay Field/Prudhoe Bay Pool 1677' NSL, 607' WEL, SEC. 29, T11N, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 62.46' I ADL 28326 12. Date Spudded :13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. o! Completions 6/29/94 7/7/94 8/22/94I N/A teet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey p0. Depth where SSSV set ]21. Thickness of Permafrost 11954' MD/8597' TVD 11954' MD/TVD YEs [] NO []I 2099' feet MD! 1900' (Approx.) 22. Type Electric or Other Logs Run CNL/DEN/GR/L WD 23. CASING, LINER AND CEMENTING RECORD SETRNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO]TOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 112' 32" 224 sx Arcticset 13-3/8" 72# N-80 Surface 2718' 17-1/2" 5726 sx PF II 9-5/8" 47# N-80 Surface 10030' 12-1/4" 675 sx "G"/275 sx PF 7" 29# L-80 9878' 10985' 8-1/2" 244 sx Class "G" 2-7/8" 6.4# L-80 11001' 11952' 3-3/4" Uncernented slotted liner 24. Pertorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None - Slotted Liner MD TVD 4-1/2", L-80 10860' 10678' 11001'-11952' 8816'-9597' TVD :)6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/27/94 I Gas Lift Date of Test Hours Tested PRODUCTION FOR OlL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing !Casing Pressure 2ALCULATED ~)IL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence ol oil, gas or water. Submit core chips. OCT 1 1 1994, A!aska Oil & Gas Conn. Commission Anch0r Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOL~ MARKr- .., 'I .-~MATION TESTS NAME , Include interval tested, pressure data, all fluids recovered and gravily, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 10297' 8264' Shublik 10346' 8305' Sadlerochit 10415' 8363' RECEIVED A,, 31. LIST OF ATTACHMENTS ~ul~or~ ~ ~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _ Title Dr/fling Engineer Suoervisor Date JO-I/v'(~ V INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-site combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 ..' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL: DS 5-13A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: DAILY OP ERAT I O../'~x?\ PAGE: 1 ACCEPT: 06/24/94 06:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 06/25/94 (1) TD:11286 PB:10687 06/26/94 (2) TD:11286 PB:10687 06/27/94 (3) TD:10260 PB:10260 TESTING BOPE MW: 8.5 Seawater MOVED RIG F/ DS 5-10A TO 5-13A. ACCEPTED RIG @1800 HRS 06/24/94. RU LUBRICATOR, PULLED BPV, RD LUBRICATOR. RU TO KILL WELL. CIRCULATED DOWN ANNULUS, RECOVERED 130 BBLS DIESEL F/ TUBING. CIRCULATED DOWN TUBING UNTIL CLEAN SEAWATER RETURNS. SAW ONLY CONTAMINATED SEAWATER F/ ANNULUS, REQUIRED FULL CBU TO CLEAN UP WELL. MONITORED WELL, WELL DEAD AND IN BALANCE. RD HOSES, SET BPV, ND TREE. NU BOPE. RU AND BEGAN TESTING BOPE. LD COMPLETION MW: 8.5 Seawater FINISHED TESTING BOPE. RU LUBRICATOR AND PULLED BPV. RD LUBRICATOR. RU TUBING TOOLS, CONTROL LINE AND CI LINE SPOOLS, MU LANDING JOINT. PULLED HANGER TO RIG FLOOR. HAD TO RE-LAND HANGER TO PLUG OFF CI PORT ON TUBING HEAD; ALSO, AIR BOOT ON FLOWLINE LEAKED, REPLACED AND TESTED SAME. PULLED HANGER TO RIG FLOOR AND RU TO CIRCULATE. CBU. LD 3 1/2" L-80 COMPLETION. SHUT DOWN F/ 1.5 HRS F/ SPILL RESPONSE. POH F/ SECTION MILL MW: 8.5 Seawater FINISHED LD 3 1/2" COMPLETION. RECOVERED 327 JTS TUBING, SSSV, 7 GLM'S, 335 CONTROL LINE CLAMPS. CONTROL LINE SPLIT AS IT WAS SPOOLED UP, APPEARED TO BE EMBRITTLED. RD TOOLS AND CLEARED/CLEANED UP FLOOR. RU TO FINISH BOP TEST. TESTED LOWER PIPE RAMS, BLIND RAMS, SAFETY VALVES, DART VALVE, KELLY VALVES. TEST PLUG LEAKED, HAD TO RILDS TO SEAT. BLED DOWN 13 3/8" ANNULUS. ARCTIC PACK IN RETURNS F/ ANNULUS, HAD TO BLEED THRU 2" LINE TO KEEP FROM PLUGGING W/ ARCTIC PACK. BOLDS, LEFT 4 IN. PLACED 20000 FT-# LH TORQUE ON PACKOFF, NO MOVEMENT. BACKED OUT 4 LDS AND PULLED PACKOFF TO FLOOR W/ 30K# STRAIGHT PULL. MU NEW PACKOFF AND INSTALLED SAME; TOOK 2 ATTEMPTS TO GET PACKOFF TO SEAT FULLY. RILDS AND TESTED. MU BAKER BRIDGE PLUG AND RIH PU DP. SLIPPED AND CUT DRILLING LINE. CONTINUED RIH W/ BRIDGE PLUG. SET SAME @10260' AND RELEASED RUNNING TOOL. TESTED CASING. SOLID TEST. DISPLACED WELL TO MILLING FLUID, SPOTTED 18 PPG PILL ON BOTTOM. POH F/ SECTION MILL. RECEIVED. OCT 1 i '199a~ /.,:ia ska 0i~ & Gas Con.~. Commission Anchor.~ ,, WELL : DS 5-13A ~ ~, OPERATION: RIG : NABORS 2ES PAGE: 2 06/28/94 (4) TD:10260 PB:10260 06/29/94 (5) TD:10030 PB:10030 06/30/94 (6) TD:10030 PB:10030 07/01/94 ( 7) TD:10038' ( o) POH W/ SECTION MILL MW: 8.5 Seawater FINISHED POH F/ SECTION MILL. MU BHA #1 AND RIH TO 10021'. PU KELLY AND POSITIONED MILL @10030'- MADE CUT OUT AND MILLED 50' WINDOW F/ 10030-10080'. 95% METAL RECOVERY, HARD CEMENT IN RETURNS. CBU. CEMENT AND SHALE IN RETURNS. POH. HOLE CLEAN. CHANGING DOOR SEAL ON BLIND RM MW: 8.5 Seawater POH. LD BHA #1, MILL 85% WORN. MU 4 1/2" MULE SHOE AND RIH. WASHED THRU SECTION AND INTO STUMP TO 10180'. CIRCULATED AND CONDITIONED MUD; RU BJ AND BATCH MIXED PLUG. TESTED LINES. POH 10 STANDS, CIRCULATED DP VOLUME. HESITATION SQUEEZED CEMENT, STAGED UP TO 1800 PSI AND HELD F/ 1 HR. SQUEEZED 1 BBL. PUMPED DRY JOB AND POH. SLIPPED DRILLING LINE. POH. LD MULESHOE AND CLEARED FLOOR. FLUSHED OUT BOP STACK, PWR, OPENED DOORS AND FLUSHED OUT SAME. SET TEST PLUG. TESTED BOPE. DOOR SEALS ON BLINDS LEAKED. CHANGING OUT DOOR SEALS. WORKING TORQ INTO DP MW: 8.5 Seawater COMPLETE BOPE TEST, R/D TEST EQ. INSTALL WEAR RING. M/U 8 1/2" BIT AND STEERABLE DRILLING ASSEMBLY, ORIENT MOTOR, TEST MWD. RIH WITH 8 1/2" BIT TO 9812'. KELLY UP AND WASH DOWN FROM 9812' TO TOC @9865', CLEAN OUT CMT FROM 9865-10032'. START SIDETRACK OF WELL @10032', TIME DRILL TO 10038. DRILLSTRING PACKOFF AND PRESSURED UP, ATTEMPTED TO MOVE DRILL STRING, NO GO. JAR ON DRILLPIPE, WORK DRILL PIPE UP HOLE 4', CONTINUE TO JAR AND WORK DRILL PIPE, NO MOVEMENT. WORK LEFT HAND TORQ INTO DRILL PIPE. PERFORM BLIND BACKOFF, STRING WT WHEN PIPE PARTED, PUMP DRY JOB, SET BACK KELLY. POH,' CHECK EVERY CONNECTION, RECOVERED 3767' DRILLPIPE, LAY DOWN BACKED OFF JT OF DRILL PIPE. M/U SCREW-IN-SUB, RIH TO TOF @3767', SCREW INTO DRILL STRING. RU ATLAS, M/U 480 GR STRING SHOT, RIH, TIE-IN, WORK LH TORQUE IN DRILL PIPE. CHECK TIE-IN FOR STRING. WORK ON DRAWWORKS MW: 9.8 VIS: 59 FIRE STRING SHOT @ 9859' WLM, P/U ON DRILL PIPE TO CONFIRM STRING FREE. POH WITH WIRELINE, R/D ATLAS WIRELINE UNIT. CIRC BTTMS UP. POH, CHECK EACH CONNECTION FOR OVER TORQUE, RECOVERED JARS & BUMPER SUB. M/U FISHING BHA #1 WITH SCREW-IN-SUB, RIH. SLIP AND CUT DRLG LINE. RIH, P/U 52 JTS 4 1/2" 3-135 DRILL PIPE. SCREW INTO TOF @9855' DPM, TORQ UP SCREWW-IN-SUB, JAR ON FISH, WORK PIPE, WORK TORQ INTO PIPE AND SLUMP ON STRING, PRESSURE UP ON DRILL STRING TO ESTABLISH CIRC, ATTEMPT TO BREAK DOWN FORMATION WITH 3500 PSI ON DRILL PIPE ANNULUS, NO PIPE MOVEMENT.' IN-PUT SHAFT COUPLING ON DRAWWORKS BROKE, REPAIRING SAME. RECEIVED WELL : DS 5-13A '~ % OPERATION: RIG : NABORS 2ES PAGE: 3 07/02/94 ( 8) TD: 10038' ( 0) 07/03/94 (9) TD:10155' ( 117) 07/04/94 (10) TD:10654' ( 499) 07/05/94 (11) TD:10826' ( 172) RIH W/ CLEAN OUT ASSY MW: 9.8 VIS: 56 REPAIR IN-PUT SHAFT COUPLING ON DRAWWORKS. CONTINUE TO JAR ON FISH, FISH FREE, ATTEMPT TO CIRC, DRILL STRING PLUGGED. STAND BACK KELLY, POH 10 STANDS, NORMAL DRAG, DROP BALL FOR PUMP OUT SUB. MIX AND PUMP DRY JOB. POH WET. STAND BACK DRILL COLLARS, STRING PLUGGED FROM BIT 80' UP INTO DRILL STRING WITH CMT AND FORMATION CUTTINGS, LAY DOWN FISH, RECOVER MWD TOOL, LAY DOWN FISHING TOOLS, CLEAR FLOOR. M/U 8 1/2" BIT AND CLEAN OUT ASSEMBLY, RIH. SLIP AND CUT DRLG LINE. RIH TO 9935', KELLY UP, WASH DOWN TO TOP OF SECTION. SIDETRACK WELL MW:10.2 VIS: 60 WASH DOWN F/ 9948' TO TOP OF SECTION @10030'. WORK PIPE AND WT UP MUD TO 10.0 PPG, BTMS UP CMT CUTTINS AND SHALE. WASH DOWN TO CLEAN OUT SECTION, TAG FIRM PLUG @10040'. CIRC BTTMS UP, CIRC UNTIL HOLE CLEANS UP. POH, LD S-135 DRILL PIPE AND 6 1/4" DRILL COLLARS. M/U 8 1/2" BIT AND STEERABLE DRILLING ASSEMBLY TO KICKOFF WELL, TEST MWD TOOL. RIH W/ BHA #5. ORIENT MWD TOOL, ATTEMPT TO SIDETRACK WELL @10040', SLIDE TO 10049'. HOLE PACKING OFF AND TIGHT HOLE, PULL 375K TO FREE UP PIPE. PULL UP INTO CASED HOLE, CIRC BTSM UP, RETURNS SHOW 80% SHALE. CIRC AND WT UP MUD TO 10.2 PPG TO CONTROL SLOUGHING SHALE. SIDETRACK WELL, SLIDE F/ 10042-10155'. POH TO CHANGE BHA MW:10.2 VIS: 52 DRILL AND SURVEY 8 1/2" OPEN HOLE, ROTARY DRILL FIRST 10' OF EACH KELLY. SLIDE REMAINING 20', REAM EACH CONNECTION TO INSURE ADEQUATE HOLE CLEANING, DRILLED FROM 10155-10654', START OF BUILD SECTION FORMATION TOPS FROM GEOLOGRAPH: SHUBLIK @ 10347' MD, ZONE #4 @ 10416' MD, ZONE #3 @10575' MD. CIRC BTTMS UP, MIX AND PUMP HI/LOW VIS SWEEP TO CLEAN HOLE. POH TO CHANGE BHA. POH FOR BHA CHANGE MW:10.2 VIS: 63 POH TO CHANGE BHA, LAY DOWN HWDP. MU BHA #6 AND BIT 92, RIH, TEST MWD AND MUD MOTOR. RIH W/ BHA #6. SLIP AND CUT DRLG LINE. RIH, LAY DOWN 21 JTS DRILLPIPE WITH DAMAGED TOOL FACES FROM BAD SAVER-SUB. MAKE MADD PASS FROM 10630-10654'. DRILL AND SURVEY 8 1/2" OPEN HOLE FROM 10654-10826', CANNOT GET BUILD RATE WITH CURRENT BHA, TRIP FOR 2 1/4 DEGREE MUD MOTOR. CIRC BTTMS UP, PUMP HI/LOW VIS SWEEP TO CLEAN UP HOLE. POH FOR BHA CHANGE, NORMAL DRAG OFF BTM, OPEN HOLE IN GOOD CONDITION. l:.~!?_z~t~ 0ii & G-~s Con~. Commission WELL : DS 5-13A .''\ OPERATION: RIG : NABORS 2ES PAGE: 4 07/06/94 (12) TD:10919' ( 93) 07/07/94 (13) TD:10949' ( 30) 07/08/94 (14) TD:llll2' ( 163) 07/09/94 (15) TD:llll2' ( 0) RIH W/ BHA #8 MW:10.2 VIS: 60 POH TO CHANGE BHA. CHANGE BHA, BIT & PU 2.25 DEGREE MUD-MOTOR, SERVICE MWD, RIH, TEST MWD. RIH W/ BHA 97. KELLY UP, WASH DOWN F/ 10787-10826', BENCHMARK SURVEY @10795'. DRILL AND SURVEY F/ 10826-10919'. CIRC BTTMS UP, PUMP HI/LOW VIS SWEEP TO CLEAN HOLE, DROP SS, PUMP PILL. POH TO CHANGE BHA. CHANGE BHA, PU BIT, 3 DEGREE MUD-MOTOR, & NMLC, SERVICE MWD, RIH, TEST MWD. RIH W/ BHA #8. SLIP AND CUT DRLG LINE. RIH W/ BHA 98. RIH W/BIT #9 MW:10.2 VIS: 63 RIH W/BHA #8. KELLY UP CHK SPOT W/SS, ORIENT MUD MOTOR SLIDE F/10920 T/10949. PR SLOWED, ADDED LUBETEX T/MUD T/REDUCE DRAG. CBU, MIX & PUMP DRY JOB. POOH F/BHA CHANGE. STND BCK BHA, BREAK OFF BIT/STAB SLEEVE ON MUD MOTOR. TEST BOPE 250/5000. REPAIRED BLIND RAM DOOR SEAL. RETEST OK. CHK LINE VALVE FAILED REPLACE/RETEST 250/5000 OK* PULL TEST PLUG, INSTALL WEAR RING. MU 8.5 BIT #5. RIH W/BHA/TEST MWD & ORIENT MUD MOTOR. RIH W/BHA #9. *NOTE: BOPE TEST WITNESS WAS WAIVED BY AOGCC REP: JOHN SPAULDING. RIH W/ DP LOGGING TOOLS MW:10.2 VIS: 61 RIH W/ BHA #9. DRILL AND SURVEY F/ 10949-11112'. CIRC BTTMS UP, MIX AND PUMP DRY JOB. POH. RU ATLAS WIRELINE, MU DP CONVEYED LOGGING TOOLS. RIH W/ CNL/GR DP CONVEYED LOGGING TOOLS ON DRILL PIPE. SHORT TRIPPED TO WINDOW MW:10.2 VIS: 74 RIH WITH OPEN HOLE LOGGING TOOLS TO 9903'. MU SIDE SUB, RIH WITH E-LINE TO WET CONNECT, RIH 7 LOG OPEN HOLE SECTION FROM 10030-11109' WITH CNL/DEN/GR. POH TO SIDE SUB, POH WITH E-LINE, RD ATLAS FROM DERRICK. SLIP AND CUT DRLG LINE. POH WITH LOGGING TOOLS ON DRILL PIPE. LAY DOWN DRILL PIPE LOGGING TOOLS. RIH WITH 8 1/2" BIT FOR WIPER TRIP. KELLY UP, WASH AND REAM THRU TIGHT HOLE FROM 10940-11103'. CIRC BTTMS UP, MIX AND PUMP HI/LOW VIS SWEEP UNTIL HOLE CLEANS UP. MAKE SHORT TRIP TO WINDOW SECTION @10030'. RECEIVED WELL : DS 5-13A OPERATION: RIG : NABORS 2ES PAGE: 5 07/10/94 (16) TD: 11112 PB: 0 07/11/94 (17) TD:llll2 PB: 0 07/12/94 (18) TD:llll2 PB:10986 07/13/94 (19) TD:llll2 PB:10986 POH, LAY DOWN BAKER RUNNING TL MW: 8.5 Seawater CIRC BTTMS UP, MIX, SPOT 16 BBL 18 PPG PILL ON BTTM IN OPEN HOLE SECTION. POH, DROP DRILL PIPE DRIFT FOR LINER JOB, LAY DOWN BHA. RU CSG TONGS, RIH WITH 26 JTS 7" 29# L-80 NSCC CSG, MU BAKER 7" LINER HANGER. CIRC CSG VOL, RD CSG TOOLS. RIH WITH 7" LINER ON DRILL PIPE TO 9 5/8" WINDOW @10030'. CIRC DRILL PIPE AND CSG VOL. RIH WITH 7" LINER ON DRILL PIPE TO 10985'. CIRC AND COND HOLE FOR CMT, RECIPROCATE PIPE 30', BATCH MIX CMT. PUMP 5 BBLS KCL H20, TEST CMT LINES. DRILL PIPE WIPER PLUG, DISPLACE PLUGS TO · LANDING COLLAR WITH MUD USING RIG PUMPS. BUMP PLUG, SET LINER HANGER, PRESSURE UP TO SET LINER TOP PACKER, ROTATE AND RELEASE FROM LINER HANGER. REVERSE OFF LINER TOP. CIRC, SLIP AND CUT DRLG LINE. POH, LAY DOWN 45 JTS DRILL PIPE & BAKER RUNNING TOOL. POH W/ 3 1/2" MULE SHOE MW: 8.5 Seawater RIH W/ 6" BIT TO CLEAN OUT 7" LINER, TAG CMT @10866'. DRILL OUT CMT IN 7" LINER FORM 10866-10902', TOP OF LANDING COLLAR. TEST 7" LINER AND LINER TOP. DRILL UP 7" LANDING COLLAR, 7" FLOAT COLLAR AND 7" FLOAT SHOE, CLEAN OUT OPEN HOLE TO 11085'. CIRC BTTMS UP, UNTIL HOLE CLEANS UP. POH WITH 6" BIT. MU 3 1/2" MULE SHOE, RIH TO SET KICK OFF PLUG. CIRC DRILL PIPE VOL, BATCH MIX CMT. PUMP 5 BBLS H20, TEST CMT LINES. POH WITH 3 1/2" MULE SHOE. RIG UP TO RUN 4 1/2" TBG MW: 8.5 Seawater POH W/ 3 1/2" MULE SHOE, LAY DOWN 24 JTS DRILL PIPE. MU 6" BIT AND 7" SCRAPER, RIH WITH DRILL COLLARS. RIH TO LINER TOP @9821'. CIRC, WOC RIH TO 10671', PU KELLY WASH DOWN TO TOP OF CMT @10~54'. DRILL UP FIRM CMT F~OM 10854-10986'. PUMP HI VIS SWEEP AND KCL H20 SPACER, CHANGE WELL OVER TO SEAWATER. POH, STAND BACK 64 STDS DRILL PIPE IN DERRICK, LAY DOWN 105 JTS DRILL PIPE AND BHA. CLEAR FLOOR, PULL WEAR RING. RU NABORS CSG CREW TO RUN 4 1/2" TBG. DROP SETTING BALL TO SET PACKR MW: 8.5 Seawater RIH W/ 4 1/2" COMPLETION EQ AND TBG. MU CONTROL LINE TO TRSV. RIH W/ 4 1/2" TBG AND CONTROL LINE. MU TBG HGR AND LANDING JT, LAND TBG, TBG HGR DID NOT SEAT PROPERLY IN TBG SPOOL BOWL, PU TBG STRING AND PULL TBG HGR TO RIG FLOOR. MU REBUILT TBG HGR AND LANDING JT, LAND TBG RILDS, SET BPV. ND BOPE, NU ADAPTER FLANGE AND TREE, TEST ADAPTER FLANGE. RU HI-PRESSURE LUBRICATOR, PULL BPV, INSTALL TREE TESTER, TEST TREE, OK, PULL TREE TESTER AND RD LUBRICATOR. CIR DOWWNANNULUS WITH INHIBITED SEAWATER. DROP SETTING BALL TO SET PACKER. SIGNATURE: (drilling superintendent) DATE: RECEIVED OCT I 1 1904 /~:,:-~ka Oil & Gas Con~. Commission Anchor~ ~e 5-13A DESCRIPTION OF WORK COMPLETED COILED TUBING WELLBORE EXTENSION DRILLING 8/9/94: MIRU 2" CTU & PT BOP's. PT tools, then RIH w/CT nozzle. 8/10/94: Tagged hard cement bottom at 10986' MD. POOH w/CT. MU & RIH w/BHA consisting of a 3.75" TSD bit & 350 Mud Motor. Milled cement to 10993' MD & circulated 27 bbls of 2# biozan. POOH w/mill. MU & RIH w/BHA, consisting of 3.75" PDC bit, D-287 motor w/2.5 degree housing, 1/8" pad, & Monels. Tagged at 10983' MD & could not pass liner shoe w/bent motor. POOH w/BHA. RIH w/Reamer & dressed off cement from 10983' to 10992' MD while circulating 1.54t biozan. POOH w/reamer. 8/11/94: MU & RIH w/BHA, consisting of 3.75" PDC bit, D-287 motor w/2.5 degree housing, 1/8" pad, & Monels. Drilled from 10988' to 11030' MD, w/occasional motor stalls & stops for orienting tools. Lost MWD signal below 11023' MD. Took MWD survey at 10992' MD showing 67.6 degree angle. Survey at 10996' MD showed 71.6 degrees. POOH w/BHA. RIH w/multi-shot survey, & surveyed off bottom up to 10970' MD. Survey at 11024' MD showed 85.2 degree angle. POOH w/survey tools. 8/12/94: MU & RIH w/BHA consisting of 3.75" PDC bit, D-287 motor w/l.0 degree bend, 1/16" wear Pad, & Monels. Attempted to get to TD, but could not pass 10991' MD. Took survey at 10985' MD showing 67.4 degree angle. POOH w/BHA. Noted injector damaged pipe at 2000'; rigged down CTU to replace pipe. 8/13/94: MIRU 2" CTU & PT equipment. RIH w/TTL & tagged PBTD at 11042' MD uncorrected. POOH w/TTL. MU & was deploying BHA consisting of 3.75" PDC bit, D-287 motor w/2.5 degree bend, Monels, & GR. Hook got loose from lifting eye & BHA dropped down wellbore. RIH w/roller stem & tagged fish at 2040' MD (at SSSV); POOH. RIH w/Alligator grab tool; could not grab fish. POOH w/grab tool. RIH w/redressed grab; could not grab fish; POOH. RIH w/flipper dog & latched top of fish. Jarred fish loose. 8/14/94: PU fish to 1870' MD, where fish hung up & sheared off. POOH w/fishing tools. MIRU 3/16" line crane. RIH w/GS & latched fish at 1890' MD. Jarred fish through collars & POOH w/fish. 8/15/94: MIRU CTU. MU & RIH w/BHA consisting of 3.75" PDC bit, D-287 motor w/2.5 degree housing, 1/8" pad, & Monels. RIH to 10890' MD & attempted to orient tools. BHA stuck at casing collar; had to hydraulically disconnect. POOH & MU 3" GS fishing assembly. RIH & latched fish at 10941' MD. Jarred fish loose & POOH w/fish. 8/16/94: MU & RIH w/TTL & nozzle, to tag PBTD at 11041' MD. POOH w/1-1'L. RIH w/BHA consisting of 3.75" PDC bit, D-287 motor w/2.5 degree housing, 1/16" pad, Monels, & Jars. Redrilled hole from 11026' MD, w/several wiper passes through shoe. Drilled to 11051' MD. MWD surveys showed 76.1 degree angle at 11010' MD, 80.1 degrees at 11017' MD, 83.1 degrees at 11027' MD; projected 91 degrees at 11051' MD. POOH w/BHA. RIH w/BHA consisting of new 3.75" PDC bit, D-287 motor w/0.5 degree housing, & GR. Logged GR from 10910' to 10970' MD, then drilled hole from 11050' to 11069' MD. Could not get WOB. PU to shoe & oriented tools. RIH & drilled to 11075' MD at 3 - 5 fph ROP. 8/17/94: Drilled to 11081' MD. Survey at 11049' MD showed 91.2 degree angle. Hung up at 11080' MD. Pumped FIo-Pro w/Lube Tex to try to free BHA; still hung up. Switched to circulating Crude & got. free. Attempted to start drilling again & briefly got hung up again at 11080' MD. Circulated 200 bbls of Mud to recondition the hole until returns cleaned up. POOH w/BHA. RIH w/BHA consisting of 3.75" PDC bit, D-287 motor w/0.5 degree adjustable bent housing, 1/16" wear pad, & Monels (no GR). Drilled horizontal hole from 11080'to 11484'MDat10-70fph ROP. RECEIVED cont. OCT 11 ~' ~'"~ OiJ & Gas Con,~. Commission Anchor:, 5- 1 3 A '~~'~ DESCRIPTION OF WORK COMPLETED COILED TUBING WELLBORE EXTENSION DRILLING 8/18/94: Drilled from 11484' to 11520' MD at 60 - 100 fph ROP. Survey at 11487' MD showed 88.4 degree angle. BHA stuck at 11520' MD; pumped Crude to free up & POOH w/BHA. RIH w/BHA consisting of 3.75" PDC bit, D-287 motor w/0.75 degree adjustable bent housing, 1/16" wear pad, & Monels. Drilled from 11520' to 11537' MD at 70 fph ROP. 8/19/94: Drilled from 11537' to 11663' MD. Got stuck at 11498' & 11549' MD on short trips; pumped Crude to free both times. Reconditioned mud. Started drilling at 11663' & stuck at 11533' on short trip. Circulated Crude to pull free. Made wiper passes w/80 bbls high viscosity Xanvis pill. 8/20/94: Drilled from 11663' to 11925' MD at 25 - 70 fph ROP. high-vis sweep. Tried to POOH & stuck pipe. Circulated FIo-Pro to displace Crude CCH. Unable to get WOB at 11925' MD. Circulated Circulated Crude to pull out of sticky hole w/BHA. 8/21/94: RIH w/multi-shot & GR tools. Could not locate TT; POOH. RIH w/TTL, multi-shot & GR tools. Displaced FIo-Pro w/Crude, & logged openhole from 11954' to 10925' MD. Displaced Crude w/Seawater & POOH w/logging tools. 8~22/94: RIH w/CT cOnveyed 2-7/8" pre-perforated liner assembly, consisting of Baker Float Shoe, followed by Float Collar, followed by 34 joints of 2-7/8", 6.4#, L-80, FL4S with 2-3/8" spf (w/aluminum plugs), followed by 6 joints of 2-7/8", 6.4#, L-80, FL4S, followed by a 2-7/8", 6.4#, L-80, FL4S Pup, followed by a 4-1/2" 'G' Deployment Sub. Landed liner on bottom at 11954' MD. Total liner assembly is 1141' long & set at 10813' - 11954' MD. Pumped 200 bbls 2% KCl Water while RIH w/liner, followed by 20 bbls Lithium Hypochlorite. Displaced Lithium Hypochlorite w/2% KCl Water & let soak 2 hours. Displaced Lithium Hypochlorite from liner w/215 bbls 2% KCl Water; lost 15 to 28% of fluids to formation. Pumped 15 bbls of 15% HCl, followed by 40 bbls 2% KCl Water flush, to dissolve aluminum plugs in pre-perforated liner. Displaced wellbore w/Crude. POOH w/CT. Rigged down. Placed well on initial production & obtained valid welltests. Initial test rates are 1000 - 1300 BOPD, 40 - 65 BWPD, 2200 - 3500 MscFD, at 700 - 850 ftp, w/choke still restricted at 40 degrees. RECEIVED Gas Cons. A~ch0r; ~e SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 PRUDHOE BAY DRILLING PBU/5-13A 500292025001 NORTH SLOPE COMPUTATION DATE: 7/11/94 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 10022 8058.96 7996.46 10283 8252.94 8190.44 10314 8278.17 8215.67 10346 8304.56 8242.06 10376 8329.72 8267.22 DATE OF SURVEY: 070894 MWD SURVEY JOB NUMBER: AK-MW-40055 KELLY BUSHING ELEV. = 62.50 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 48 0 N 57.00 E .00 3532.52N 3061.81E 35 47 N 71.40 E 5.94 3610.01N 3216.14E 35 12 N 73.90 E 5.07 3615.38N 3233.32E 33 42 N 72.40 E 5.39 3620.62N 3250.64E 32 17 N 70.50 E 5.80 3625.82N 3266.13E VERT. SECT. 3677.58 3843.83 3861.71 3879.71 3895.91 10406 8355.23 8292.73 10438 8382.75 8320.25 10469 8409.62 8347.12 10500 8436.78 8374.28 10530 8463.38 8400~88 31 12 N 71.20 E 3.87 3630.99N 3281.04E 30 6 N 71.80 E 3.57 3636.17N 3296.51E 29 47 N 69.50 E 3.83 3641.30N 3311.11E 27 47 N 73.50 E 8.96 3646.05N 3325.26E 27 17 N 73.20 E 1.73 3650.02N 3338.55E 3911.53 3927.70 3943.01 3957.81 3971.61 10560 8490.19 8427.69 10590 8517.21 8454.71 10627 8550.68 8488.18 10658 8578.68 8516.18 10689 8606.26 8543.76 26 0 N 72.50 E 4.46 3653.99N 3351.41E 25 30 N 76.40 E 5.89 3657.49N 3363.96E 25 0 N 75.60 E 1.64 3661.30N 3379.27E 25 47 N 75.90 E 2.61 3664.58N 3392.16E 28 30 N 77.20 E 8.92 3667.86N 3405.92E 3984.99 3997.97 4013.73 4027.01 4041.14 10721 8633.92 8571.42 10752 8659.66 8597.16 10778 8680.33 8617.83 10814 8707.50 8645.00 10845 8729.47 8666.97 31 53 N 79.60 E 11.27 35 47 N 80.20 E 12.63 38 47 N 81.20 E 11.77 43 12 N 82.20 E 12.36 46 30 N 83.30 E 10.94 3671.08N 3421.68E 4057.23 3674.10N 3438.68E 4074.49 3676.64N 3454.23E 4090.24 3680.04N 3477.59E 4113.82 3682.79N 3499.28E 4135.64 10877 8750.78 8688.28 10908 8769.99 8707.49 10940 8787.99 8725.49 10971 8803.11 8740.61 11003 8816.20 8753.70 50 0 53 24 58 5 63 30 68 11 N 80.80 E 12.39 N 80.80 E 10.97 N 79.50 E 15.07 N 78.80 E 17.53 N 79.30 E 14.76 3686.11N 3522.91E 4159.47 3690.00N 3546.92E 4183.78 3694.53N 3572.98E 4210.22 3699.63N 3599.54E 4237.27 3705.17N 3628.20E 4266.46 11033 8826.14 11063 8833.67 11116 8844.87 8763.64 73 5 3710 3715 8771.17 77 48 ~/3726 8782.37 77 48 ON THE METHOD 3~q ~ HORIZONTAL DISPLACEMENT = 5276.26 FEET AT NORTH 45 DEG. 3 MIN. EAST AT MD = 11116 N 79.80 E 16.41 N 78.10 E 16.60 N 78.10 E .00 THE CALCULATION PROCEDURES ARE BASED THREE-DIMENSION MINIMUM CURVATURE VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 79.04 DEG. .30N 3656.03E .87N 3684.52E 55N~/3735.21E USE 4294.76 4323.79 4375.58 RECEIVED OCT 11 19',]q ~ .... ,.~ Oil & G~$ Con~. Commission Anchor: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PBU/5-13A 500292025001 NORTH SLOPE COMPUTATION DATE: 7/11/94 DATE OF SURVEY: 070894 JOB NUMBER: AK-MW-40055 KELLY BUSHING ELEV. = 62.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10022 8058.96 7996.46 11022 8822.94 8760.44 11116 8844.87 8782.37 3532.52 N 3061.81 E 1963.54 3708.51 N 3646.19 E 2199.56 236.02 3726.55 N 3735.21 E 2271.13 71.56 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PBU/5-13A 500292025001 NORTH SLOPE COMPUTATION DATE: 7/11/94 DATE OF SURVEY: 070894 JOB NUMBER: AK-MW-40055 KELLY BUSHING ELEV. = 62.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 10022 8058.96 7996.46 10028 8062.50 8000.00 10167 8162.50 8100.00 10294 8262.50 8200.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3532.52 N 3061.81 E 1963.54 3534.94 N 3065.29 E 1965.51 1.97 3582.69 N 3150.01 E 2005.11 39.60 3612.14 N 3222.67 E 2032.27 27.16 10414 8362.50 8300.00 10529 8462.50 8400.00 10640 8562.50 8500.00 10755 8662.50 8600;00 10895 8762.50 8700.00 3632.41 N 3285.20 E 2052.00 19.73 3649.89 N 3338.12 E 2066.51 14.51 3662.68 N 3384.61 E 2077.55 11.04 3674.45 N 3440.83 E 2093.08 15.54 3688.45 N 3537.35 E 2133.24 40.16 11116 8844.87 8782.37 3726.55 N 3735.21 E 2271.13 137.88 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES LOGGING SYSTEMS Anchorage, Alaska FINAL END OF WELL LOGS and DATA INC 2ES 50-01 Alaska PREPARED FOR: ARCO Alaska, Inc. PREPARED BY: John Patton Sperry-Sun Drilling Services Logging Systems Anchorage, Alaska · ' i( ) The following information was derived from in house evaluations of well cuttings caught at the Nabors 2ES rig site during the drilling of well 5-13A. The lithological evaluation was performed for the Horizontal / Slimhole section. The Engineer and Sample Catcher on location performed their duties on a twelve hour tour basis. The method of lag calculations used for depth tagging the samples were derived from borehole and surface equipment geometry. This calculation was checked by use of u-circulated calcium carbide pills. Sample evaluations were performed by John Patton, Sperry-Sun Drilling Services' Geologist / Logging Engineer, inhouse at our Anchorage lab. John was able to give an interpretive analysis of lithology by utilizing FE/MWD data recorded from the wellsite. ARCO AI;ska, Inc. Date: Subject: From/Location: Telephone: To/Location: August 24, 1994 ARCO Open Hole Finals Karla Zuspan/ATO-1529 (907) 263-4310 Distribution P.O. Box 100360, ~'~orage, AK Transmittal #: 94095 99510,~ ~, ~ Well Log Date Tool Type Run, Scale Contractor"' Number (M-D-Y) '" 05-10A 6-21'94 MWD,MD: SGR 1-10,2" & Sperry Sun 5" 05-10A 6-21-94 MWD,TVD: SGR 1-10,2" & Sperry ~un '" ~ 5" " 5-13A 7-8-94 MwD, MD: 1-6,2" & 5" Sperry Sun 3- SGRC/SROP 5-13A 7-8.94 MWD, TVD: 1-6,2" & 5" Sperry Sun 1.,-,- SGRC/SROP , ,, 11-23A 7-06-94 MWD, ME): 1-10,2" & Sperry Sun ROP/SG R 5" 11-23A 7-06-94 MWD, TVD: 1-10, 2" & Sperry Sun ROP/SGR 5" Number of Records: 6 Karla Zusi~n Distribution: Central Files Phillips ^NO-8 Geology BPX Exxon State of Alaska Mobil D & M PB Well Files Please ack~,~vledge re~/e?j;){ by signing and returning a copy of transmittal. 'Date RECEIVED AUG 2 f 1994 ~aska 0il & Gas Cons, Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIcMleldCompany ARCO Alaska, Inc. P.O. Box 100360, ~lorage, AK Date' August 24, 1994 Transmittal #: 94093 Subject: ARCO Open Hole Finals From/Location- Telephone: To/Location- Karla Zuspan/ATO- 1529 (907) 263-4310 ~..~~ Distribution Well Log Date Tool Type Run, ScaleContractor Number (M-D-Y) 5-13A 7-18-94 MD Visual 1 Sperry-Sun Lithology Number of Records: I Karla Zuspan Distribution: Central Files ANO-8 Geology Exxon Mobil PB Well Files Phillips BPX State of Alaska D&M returning a C. Ol~y ~f~r~l~iJ,tal. Please ac,~edge/~/by signing and ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany 6OO W. irdert'K:d~l Abl:x)d Roed ,ad'l~~, ,AK 99618-1199 ATTN: Sherfie Well NO. 8858 ~)~,,~ Company: Alaska Oil 8: Gas Cons Comm tp~&~,~,~ Attn: Larry Grant , '~/~,/~O/1.~ ~/~ I 3001 Porcupine Drive ? Anchorage, AK 99501 '/o/~,~ O~ Field- Prudhoe Bay · 'e ~q~,~,/o0 ' Log Description BL RR Sepia RF Sepia Mylar D.S. 5-13A GAMMA RAY-CCL (7-23-94) 1 1 D.S. 5-13A JEWELRY LOG (7-25-94) 1 1 D.S. 12-7A IBP SETTING RECORD (7-25-94) 1 1 D.S. 9-7 IBP SETTING RECORD (-23-94) 1 1 D.S. 16-13 ~ IBP SETTING RECORD (-23-94) 1 1 SlGI~ Pledse sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: 8/11/94 Date: Subject- From/Location' Telephone: To/Location: August 10, 1994 Transmittal #: ARCO Open hole Magnetic tape(s) Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution 94O77 Well 'Log Datei Tape Type i Run, i Number (M-D-Y) Footage i 5-03A 7-27-94 CDR/CDN 1,10801- ~ ! 9845 i 5-13A 7-8-94 i ZDL/CN/GR 1,10196- 11083 Contmctor Atlas Number of R&cords: 2 Karla Zuspan Distribution: Bob ©canas Phillips BPX Exxon State of Alaska Please ackn. eCledge_r~c~t by signing and returning a copy of transmittal. Date: ., EMORANDI. TO: State ( laska Alaska Oil and Ga Conservation Commission DATE: August 9, 1994 THRU: Blair Wondzell, ~ P. I. Supervisor FILE NO: ae9hhibd.doc FROM: Doug Amos ~(.._~ SUBJECT: Petroleum Inspector BOPE Test Dowell CTU #2 Arco PBU DS5-13A Prudhoe Oil Pool PTD No. 94-42 Tuesday. Auaust 9, 1994: I traveled to Arco' s PBU DS5-13& well to witness the BOPE test on Dowell CTU #2. As the attached AOGCC BOPE Test Report indicates there were 2 failures. The Kill Line Flex Hose and the Pressure Transducer, which provided the digital signal to the chart recorder in the CTU, used to record the test results. The 12 hour test time can be attributed to the process of finding the slow leak which plag.~ed each component BOP equipment. The leaks were finally isolated and necessary repairs made. After the repairs were made the test continued without failures. I found the C TU equipment and location in good condition. Summary: I witnessed the BOPE test at Arco's PBU DS5-13a well on Dowell CTU #2. Test time 12 hours, 2 failures, 12 valves tested. Attachment AE9HHFIBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Ddg Contractor: Dowell CTU Rig No. 2 PTD # 94-42 Operator: Arco Alaska Inc. Rep.: .. . Well Name: PBU DS5-13 Rig Rep.: Casing Size: 7" Set @ 11,264 Location: Sec. 32 T. Test: Initial X Weekly Other DATE: 8/9/94 Rig Ph.# 659-521 Gary Goodrich Dave Duer 11N R. 15E Meridian Umiat Test MISC. INSPECTIONS: FLOOR SAFETY VALVES: Ouan. Pressure P/F Location Gen.: X Well Sign X Upper Kelly / IBOP N/A N/A N/A Housekeeping: X (Gen) Drl. Rig X Lower Kelly / IBOP N/A N/A N/A Reserve Pit N/A Ball Type N/A N/A N/A Inside BOP N/A N/A N/A BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams 2 Choke Ln. Valves HCR Valves 1 Kill Line Valves 2 Check Valve N/A Test Pressure Test 250/2,500 Pressure 250 / 4, 000 250 / 4, 000 251/4,000 ?5214,000 253 / 4, 000 254/4,000 255/4,000 N/A P/F P P P P/P P P ,p/p MUD SYSTEM: Visual Alarm Trip Tank N/A N/A Pit Level Indicators N/A N/A Flow Indicator OK OK Meth Gas Detector N/A N/A H2S Gas Detector N/A N/A CHOKE MANIFOLD: No. ValVes 9 No. Flanges 16 Manual Chokes 2 Hydraulic Chokes N/A ,,,, 250 / 4, 000 Functioned N/A PIF P P N/A ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2 ~ 2,000 1,860I P minutes 13 sec. minutes 45 sec. Yes Remote: Yes Psig. Number of Failures: 2 ,Test Time: 12.0 Hours. Number of valves tested 12 Repair or Replacement of Failed Equipment radii be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276'7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours Please contact the P. I. Supervisor at 279-1433 REMARKS: We.experienced a constant bleed down of pressure on all compoents tested. After searchin~ for the leaks we found the main cause to be pin holes in kill line taxable hose and a leak in the pressure transducer providinc, i.. pressure information t° the. ditial pressure recording divice in the CTU used to record the test information. The transducer and the kill line flex hose was replaced and the test continued with no more falTures. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: ~)~ ~ FI-021L (Rev. 7/19) AE9HHIBD.XLS ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, orage, AK July 29, 1994 Transmittal #: ARCO Open Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94067 99510,d~ ~ Well Log Date Tool Type Run, Scale Contractor Number (M-D-Y) 05-13A 07-08-94 ~.~.Z'~)'ensilog 1, 2"&5" Atlas 05-13A 07-08-94 f.....-~STVD 1, 1"&2" Atlas 05-13A 07-08-94~.~¢hole Prof 1, 2"&5" Atlas 05'~13A 07-08-94 i z..--'~CNL/GR 1, 2"&5" Atlas 11-23A 06-30-94 ~...~'S~TVD 1, 2"&5" Atlas 11-23A 06-30-94 ~.-~B~A/GR 1, 2"&5" Atlas 11-23A 06-30-94 ~--'D~FL/GR/SP 1, 2"&5" Atlas 11-23A 06-30-94 CNL/GR 1, 2"&5" Atlas Number of Records: 8 John E. DeGrey Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil D & M PB Well Files Please ackno~_ e r'e~~~t by signing and returning a copy~C?l~i,ttal. . --el By: ~,/'~ Date: ~. '~QC 0 ~' CL) ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompeny MEMORANDU TO: David John _~n, Chairm..am~~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 29, 1994 THRU: Blair Wondzell ~ FILE NO: ,?~,,~?~ P. I. Supervisor~~ FROM: Bobby Foste~ 2~-~' SUBJECT: Petroleum In~p'ector AMEIF3BD.doc BOPE Test- Nabors 2ES ARCO - PBU - DS 5-13A PTD # 94-42 Prudhoe Bay Field Wednesday, June 29, 1994: I traveled this date to ARCO's DS5-13A being redrilled by Nabors rig 2ES and witnessed the BOPE Test. As the attached AOGCC BOPE Test Report shows there were 2 failures. The hinge pin seals leaked on the blind rams - these are to be replaced with in 2 days and the AOGCC inspector notified. The other failure was the manual choke line valve leaked. The valve was cycled, Washed out and retested OK. The rig was very clean and all the equipment seemed to be in good working order. The location was clean and there was good access to all areas of the rig. Summary: BOPE test on Nabors 2ES on ARCO's DS5-13A - 3 hours test time - 2 failures - 1 failure repaired - 1 to be repaired and the inspector notified. Attachment: AEMIF3BD.XLS Note: I was notified late on this date that the hinge pin seals had been replaced and were tested OK. STATE OF ALASKA OIL AND GA8 CONSERVATION COMMISSION BOPE Test Report OPERATION: Orlg: X-fiD Workover: ...... DATE: 6/2g/94 Ddg Contractor: .... NABO~ ............ Rig No..~ES. PTD # . .g4-42 Rig Ph.# ' 659,~_6 ...:' Operator: .... ...~.. _ ARCO Rep.: ' ' ' GENE BECK . : . ,11111 illl i1,1, ii. i; i[ i . i . - ' - ~_.. · .......... :. *. .... . · Well Name: DSS-f3A Rig Rep.: DAVE HEBERT Casing Size:: ' 95~ ' ...... ~set~" -: fO,030 ..... Location: Sec. '32' 'T.' flN R. "15E 'Meridian Test: "initial Weekly '~ .... ~e~ ' "' ' ..... '- - .................... Test .... i MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F Location Gen.: OK Well Sign OK Upper Kelly / IBOP Housekeeping:.'. OK' (Gen) Dd. Rig ~ Lower Kelly I laoP Reserve Pit .~.A Ball Type Inside BOP BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blhld Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quart. Pressure P/F ii..f i"l .'-500/5',~0 i '..P"'.' i '. ! ' N/A! ~IUD SYSTEM: V'~ual Alarm TdpTank OK Pit Level Indicators OK YES Flow Indicator .10K" ' YES' Meth Gas Detector -4' - YES H2S Gas Detector NOTE~ 500~',000 I .... 5oo/s, ooo . I P _.! I ! CHOKE MANIFOLD: No. Valves No, Flanges Manual Chokes . Hydraulic Chokes Test Pressure P/F 141 :vs, ooo.. I.P :~ 3f4 -' FunctiOned i-1 _! Funcl~ned ! ACCUMULATOR SYSTEM: System Pressure 3,000 .1._ P Pressure After Closure ~ ' :.f'600 ' I'P ~' 200 psi Attained After Closure .. '.. minutes :30,-, sec. System Pressure Attained "'1' minutes 4f sec. Blind Switch Covers: Masteri ....YEs RemOte!` YES Nitgn. Btl's: ~ . 4 ~ 2100' i~~ ........ , ~ , . L .,,,,,, ,., ,,, , _ , , ,, ~ , , ,i, Pl~ig' Number of Failures: .2_ ,TestTime: 3.0 HOurs. Number of valves tested _18' Repair or Replacement of Failed iEquipment wiflbe made within . . 2 , ,, 'days' Notify the Inspector and follOW with written or Faxed verification to the AOGCC Commission Office at: Fax No.,276-7542 inspector North Slope Pager No. 659-3607 or 3687 tf your call is not retumed by the inspector within 12 hours please contact the P ! Supervisor at 279-1433 "*,~ ' ' ~ ~ . ~'~.i~ .... i '.i ' . -~' . ....... I Ill I Il I . Il I Illl..! I I ]ill] I I ]llll] . Hill.. Ill] II. ] II ! . I !lll. I. ]Bill_ _ ! ] ! ] IIlll~]._. I.] I1 Iii] I Il Ill REMARKS: _~. ~ehinge pin seals !ee_ked ..on the bl!~_ rams ~ to be repaired end the inspector n ,.~ed _ . ~manua!~_~oke.,.,r.meva~v..e...f.~l~d,~c~, washedout'~retes~OK,'.' ..i'..' _ ii-...'.ii i'.:.'iii i': i..-.'..... ' · · .: .... ' The upper and lower kelly valve was tested 2 clays ~usly- did not retest " · - ' ...........· .~ - ' ....~: ' ' '. ; ": '. : . ' ..... : · ' . · · · ... ' . ~-' . , .. L" ;: . . ' .' :.. : ~ ." ":- .' * --- Distribution: orig-Weli File c - Oper,/Rig c- Database c - Tdp Rpt File c - Inspector "'STATE'WIT~SS REQUIRED? YES X NO .,,,u, ,i , . , . . ::. : : 24 HOUR NOTICE GIVEN YES X NO Waived By: .BOBBY D. FOSTER FI-021L (Rev. 7/19) AEMIF3BD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 24, 1994 Terry Jordan, Drlg Engr Spvr ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit DS 5-13A Revised ARCO Alaska Inc 94-42 3015'NSL, 5168'WEL, Sec 32, T11N, R15E, UM 1667'NSL, 454'WEL, Sec 29, T11N, R15E, UM Dear Mr Jordan: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original apProved permit dated March 31, 1994 are in effect for this revision. David W JohnSon Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/O encl Dept of Environmental Conservation - w/o encl ~.~ printed on recycled paper b y C. E). BP EXPLORATION ARCO Alaska, Inc. To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Date: June 22, 1994 Attention: David Johnston Subject: 5-13A Change of Bottom Hole Location (Permit #94-42) Enclosed is a revised permit application to change the bottom hole location for well 5-13A. This will replace the permit to drill that was approved on March 31, 1994, permit #94-42. The well is anticipated to be spudded within a few days, your early approval would be appreciated. Yours Sincerely, Terry Jordan Drilling Engineering Supervisor MS RECEIVED JUN 2 2 1994 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA~T"~ - ALASKA (J~L AND GAS CONSERVATION CO~/~MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill I-] Redrill EIIlb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A!a~ka, Inc. KBE = 64' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool p, O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28326 4. Location of well at surface 7. Unit or property. Name 11. Type Bond(,ee 20 Mc 2~.o2~')" 3015'NSL, 5168' WEL, SEC. 32, T11N, R15E Prudhoe Bay Unit At top of productive interval !8. Well number Number 1479'NSL, 1426' WEL, SEC. 29, T11N, R15E 5-13A U-650610 At total depth 9. 'Approximate spud date Amount 1667' NSL, 454' WEL, SEC. 29, T11N, R15E 6/23/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MDand WD) property line ADL 28325-454 feet No close approach feet 2560 12181' MD/8837' TVD feet 16. To be completed for deviated wells 17. AntiCipated pressure (~e ~o ^^c 25.o3~ (e)(~)) Kickoff depth ~o,~,~o feet Maximum hole an~ile o~ o Maximum surface 3330 pslg At total depth (TVD) 8800'/4390 pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" .29# 13CR NSCC 2104' 9080' 7428' 11184' 8837' 180.sx C/ass "G" 3-3/4" 2-3/8" ~ 6.2# L-80 NSCC 1100' 11500' 8812' 12181' 7380' Uncernented ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. d U N 2 2 1994 Present well condition summary Total depth: measured 11304 feet Plugs (measured) Alaska 0il & I~a$ Cons. Commission true vertical 8945 feet Anchorage Effective depth: measured 11199 feet Junk (measured) true vertical 8870 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 112' 20" 224 sx 112' 112' S u rface 2718' 13-3/8" 5726 sx 2718' 2718' Intermediate P rod uction 11286' 9-5/8" 950 sx 11286' 8932' Liner ... 528' 7" 180 sx "G" 11264' 8916' Perforation depth: measured 11060'-11080; 11082'-11092', 11113'-11116', 11116'-11157', 11157'-11162'(allsqueeZed) true vertical 8770'-8784', 8785'-8793', 8808'-8810', 8810'-8839't 8839'-8843' (all squeezed) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drillincj fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that_the foregoing is true and correct to the best of my knowledge Signed ~'~~ TitleDrillingEngineerSupervisor Date ~-~'.Z-? ~' Commission Use Only Permit Number IAPI number IApproval date ISee cover letter ~'~-~.,?_, J50-~?- .7__~ 2_5'~-~! I ~-2-Y-'~c/r Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg-- l-lYrequired es J~ No Hydrogen sulfide measures [] Yes [] No Directional survey requ~reo [] Yes [] No Required working pressure for DOPE I-'I2M; 1-13M; c~r5M; r-llOM; I-I15M; Other: Original Signed By by order of _Approved by David W,. Johnston Commissioner [ne commmsion Date Form 10-401 Rev. 12-1-85 Submit in trii cate I Well Name: II S 5- 3^ I Redrill Plan Summary I Type of Redrill (producer or injector): I Producer I £C£! V£D I Surface Location: 1 3015 FSL 5168 FEL S32 T11N R15E um Target Location: 1479 FSL 1426 FEL S29 T11N R15E UM Bottom Hole Location: 1667 FSL 0454 FEL S29 T11N R15E UM ~a~,~.~,' COns. c~,~._. I ' '"ullOi'agp, .... I AFENumber: 14J0260 I I Rig: I Nabors2ES I I Estimated Start Date: 1 6/22/94 I I Operating da;ys to complete: 128 112181' I IxvI : 18775 ss I I KBE: 62.5 I Well Design (conventional, slimhole, etc.): I Sidetrack Objective: The pdmary objective of the DS 5-13 sidetrack is to drain the current reserves by drilling a new horizontal wellbore to a location northeast of the current BHL. The expected LOC is 66 feet. The post sidetrack rate is expected to be 2600 BOPD at 2000 GOR. Offsets to 5-13 indicate that the Romeo is highly productive in this area, however, 5-13's production was never as high as the offsets due to well damage. 5-13 is currently shut-in due to a gas channel (current GOR=26,000). If 5-13 were produced, the GOR would continue to rise due to channeling, thus the 5-13 GOR would not be competative even after GHX-2. A squeeze in September, 93 was not successful. Squeezing the channel is complicated by the presence of a scab liner. It is unlikely that any series of squeezes and stimulations would result in more than 600 BOPD. A horizontal wellbore will increase the productivity, provide standoff from the GOC and eliminate any well damage problems. The intermediate section will be drilled with the rig and the 1000 foot horizontal section will be drill underbalanced with the coiled tubing unit. CTU drilling will minimize well damage and provide additional data regarding the benefits of CTU drilling. CTU underbalanced drilling was successful on 2-16, which has sustained an initial rate over 2000 BOPD at a Iow GOR since it was brought on line 2 months ago. Mud Program: Special design considerations After dressing off the kickoff plug we will displace to Flopro system (Xanvis) and drill to 7" shoe depth with @ 10.00 ppg to 10.20 ppg. 6" hole will be drilled with the same system with @ 9.2 ppg to 9.4 ppg. Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.00 14 47 22 31 6.5 0 7 tO tO tO tO tO tO tO tO tO TD' 9.4 11 44 18 22 6 0 2.5 Directional'. [ KOP: [ 10060'MD I Maximum Hole Angle: 1 90 Close Approach Well: NONE Casin /Tubin ' ram- Hole Siz~ Csg/ Wt/Ft° Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5 7" 29# L-80 nscc 1223 9900/8084 11123/8827 3-3/4" 2-3/8" per. ln. L-80 nscc 1114 11000/8827 12114/8837 N/A 4.5" 9.3 L-80 nscc 9000 Surface 9000/7380 7" csg n/a 12.6g L-80 nscc 120 11100/8827 11135/8827 Cement Calculations: I Liner Size: ]7" I Basis:] 50~o open hole ex':ess, 80' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: @ 180 sxs of Class G Blend @ 1.18 ft3/sx I Liner Size: 1 2-3/8" (Perforated Liner) ] · · · Basis:I Total Cement Volume: N/A in this case.sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. RECEIVED dUN 22 1994 Alaska Oil & Gas Cons. Commission Anchorage Anadrill Schlumberger Alaska District 1111 East 80~h Avenue Anchorage, AK 99518 (907) 349-45L1 Fax 34g-,~487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING GROUP Nell ......... : DS 05-13A Field ........ : PRUDHOE BAY DRILL SITE 5 Computation..: MINIMUM CURVATURE Units ........ : FEET Surface Lat,.: 70.26532897 N Surface Long.: 148.40563055 W LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 3015 FSL 5168 FEL S32 TllN R15E U~! 697[76.17 5949L80.16 Tie-in/KOP...: 1281 FSL 2070 FEL S29 Tll~ R15E U~! 700167.16 5952807.33 Target ....... : 1479 ~SL 1426 FEL S29 T11~ R15E U~! 700805.00 5953522.00 BHL .......... : 5667 FSL 454 FEL S29 Tll~ RISE ~4 701772.00 5~53235.60 PROPOSED 9~ELL PROFILE STATION IDENT I FI CAT I ON 5~EAS INCLN DIRECTIO~ VERT-DEPTHS SECT RELATIVE-COORDiNATES DEPT}{ ANGLE AZIMUTH BKB SUB-S D[ST FROM-THE-WELLHEAD Prepared ..... : 06/22/94 ~ Section at...: 79.04 KB elevations: 62.50 ft ~ ~4agnetic Dcln: 29.994 E c~ Scale Factor: 0,99994417.~, ~ Convergence. +1 5007706 ~) ~7 STATE- PLEASE TOOL DL/ X Y FACE 100 TIE- IN KIN~K SAG RIVER 10060 48,00 10100 45.69 10200 39.96 10273 35.81 10298 34.44 10300 34.31 SMUBLIK 10345 31.77 10400 28.77 TSAD Z4/43 / IVISHAK 10415 27,97 10500 23.44 56.60 8084 8022 3703 ~ 3547.78 N 3085.t3 E 700167.16 5952807.33 164R <TIE 57.50 8111 8049 3730 3563.65 N 3109.62 E 70019!.21 5952823.84 164R 6.00 ~0 12 8185 8122 379~ 3598 91 N 3167.69 E 7002~8 34 5952860 59 162R 6 62.47 8243 8~80 3837 3620,53 N 320~.09 E 700287.16 5952883.24 160R 6 00 63.36 8263 8200 3850 3626.93 N 3219.61 E 700299.51 5952889.97 159R 6.00 63.45 8264 8202 3851 3627.53 N 3220.79 E 700300.67 5952890,59 159R 6.00 65,29 8303 8240 3875 3638.25 N 3243.11 E 700322.70 5952901.89 158R 6.00 67.89 8350 8287 3902 3649.20 ~ 3268.34 E 700347.63 5952913.50 155R 6.00 68.67 8363 8300 3909 3651.77 ~ 3274.79 E 700354.02 5952916.2~ 155R 74.19 8439 8377 3946 3663.69 N 3309.81 E 700388.71 5952929.07 150R 6.'00 ZONE 4A/X-rAY E~D OF ~/Z00 CURVE ZONE 3 BUILD 14 10503 23.27 74.45 8443 8380 3947 3664.05 N 3311.09 E 700389.98 5952929.47 149R 6,00 10556 20.59 79.04 8492 8429 3967 3668.62 N 3330.31 E 700409.08 5952934.54 6,00 ~0568 · 20.59 .... 79.04 ' 8503" '8440 ..... 397'1 3669.'4'0 N-"3'334.32'-E '""~'00413'.'06'5952935';'42 " 0.'00 10632 20.59 79.04 8562 8500 3993 3673,66 N 3356.34 E 7~0434.96 5952940.26 HS 0.00 (Anadr[l (c.~94 05[~AP3 B~.,J2 9:~8 19.1 DS 05-13A (P3) 06/22/94 Page STATION I DEb?TI FI CAT I ON zo~z 2/~c ZONE 2 B/TD2~GO ZONE 2A/ROMEO PROPOSED WELL PROFILE ME~S INCLN DIRECTION VERT-DEPTMS SECT RELATIVE:COORDINATES STATE-PLANE TOOL DL/ DEPTH ANGLE AZIPH3TH BKB SUB-S DIST FRO~-TME-WELLH~d) X Y FACE 100 10632 20.64 79.04 8563 8500 3993 3673.~8 lq 3356.45 E 700435.07 5952940.29 HS 14.00 10700 30.15 79.04 8624 8561 4023 3679.22 l{ 3385.04 E 700463.50 5952946.57 HS 14.00 10710 31.57 79.04 8633 8570 4028 3680.20 N 3390.12 E 700468.56 5952947.68 ~S I4.00 10800 44.15 79.04 8703 8641 4083 3690.67 ~.~ 3444.19 E 700522.33 5952959.56 ~S 14.00 10867 53.56 79.04 8748 8685 4133 3700.27 N ~493.81 E 70057[.68 5952970.46 HS 14.00 PGOC 10885 55.99 10900 58.15 ZO}~ 1B/LOWER R~,~EO 10934 62.87 11000 72.15 111~0 86.15 11123 89.42 11123 89.42 12114 89.42 12114 89.42 ....... TARGET ....... END 1~/100 CURVE BSAD/~AVIK TD 79.04 8758 8695 4148 3702.96 N 3507.71 E 700585.50 5952973.52 HS 14.00 79.04 8766 8703 4160 3705.43 N 3520.46 E 700598.18 5952976.32 HS 14.0( 79.04 8783 8720 4190 3711.01 t~ 3549.26 E 700626.83 5952982.6% HS 14.00 79.04 8808 8745 4251 3722.63 N 3609.33 E 700686.57 5952995.84 ~S 14.00 79.04 8827 8764 4349 3741.25 ~I 3705.51 E 700782.22 5953016.97 HS 14.00 79.04 8827 8765 4372 3745.68 N 3728.41 E .700805.0~ 5953022.00 79.04 8827 8765 4372 3745~68 N 3728.41 E 700805.0~ 5953022.00 79.04 8837 8775 5363 3933.90 N 4700.73 E 701772.00 5953235.60 79.04 8837 8775 5363 3933.90 l{ 4700.73 E 701772.00 5953235.60 14.00 14.00 0.00 0.00 l PFiU'I~HOE BAY D.RT'L_L NG" '6ROU,P..' _ i i i i ii ii i _ i iii i i i ii i i iiii , , , , Maeker I~ntific~tio~ ~ 8KB SECIN INCLN A) TIE-IN t0060 B084 3703 48.00 Bt END OF B/JO0 CURVE 10556 B492 3967 20.59 CI BUILD 14/lOO 10632 8562 3993 20.59 8J ....... TARGET ....... 11J23 8827 4372 89,42 E] END 14/JO0 CURVE 11J23 8827 4372 89.42 F) TD 12J14 8837 5363 89.42 __ mil i ilnll i iIm I IIIII DS 05-i3A (P3) VERTICAL SECTION VIEN Section ~t' 79.04 TVD Scale.' 1 inch = 200 feet Dep Scale.' i inch: 200 feet Drawn ..... ' 06/22/9~ B 3500 3700 3BOO 3900 4000 4100 4200 4300 4400 4500 4B00 4700 4800 4900 5000 5!DO 5200 5300 54D0 Sect ion Departure Anadr'i 11 Schluf~ber'ger' DS.--05-13A (P3) PLAN VlEU J I II I J Illl I I I Ill I I ...... PROD-HOE --BAY"' DRILLING--GRO'O'P --- I I I J I I I~l Il It _ I I I I lJ Il II, IJt~l , Il Il Il []1 CLOSURE: ...... 6130 feet at Azimuth 50,08 )ECLINATIaN. 29.994 E ~CALE ' J iach: 300 feet ,brker ]dentilicat]o~ NB N/S E/N il END OF 6/100 CURVE t05'~' 3669 33~ :] BUILD 14/]0~ f0632 3674 3356 ~) ....... fARGEI ...... t1123 3746 '3728 ~) END ~4/~00 CURVE J1123, 3746 3728 :) fO 12~i4 3934 470t i "-- ,.__/ .......... i /' ~ .- ..... j - / i / ~ / ; ~ .., i I ~ .... ' _ i i J I I 3750 2850 2600 2751] 2§00 3050 320~) 3350, 3500 3050 3800 3950 4 lO0 4~50 4400 4558, 4700 4850 5001], EASt -> -- m~ I.II ' ~ ....... I -- I Jill I Illll Il Ii -- I I ~aflri]l [cig] ~15i3),1~ Bt.52:10:0!] ~W li IT Z PRUDHOC 'BAY DRILLING ROUP ,~ ~,~o~/,oo~,v~ ,o~,~ ~,,~ ,,~, ~o.,, VERTICAL SECTION VIEW Cl BUILD ~4/,00 ~063e 85$~ 3993 B) ....... TARGET ....... 1~1~3 88~7 437~ 89.4~ E} ENO ~4/~80 CurVE ~1~3 8827 4372 8~.4~ Section at: 79.04 F) TO ~2~4 8837 5363 8g,~2 TVD Scale.' ~ ~nch : ~200 feet <KB> o ...... Dep Scale · 1 inch = ~200 feet Onawn ' 06/22/94 ~ i 6oo .................... ! ..................................................... ~nadr~ ]] Sch]umOerger ....................................................... J200 . . ~800 ............................................................................. = .......................................... I ........ : .......... t , I : 3000~- ~ ............ ~ : ,. 3~0 ~ ' - ........ 4800 ~% ~ ' ~ ,,, ,, , , - ' ' RECEIVED 5400- - * ............................. ¢ ..... ',,t JUN2 2 19~4 ,~ .... ~,, - _ , .... 6000 ............. ,, i Aias~ a-u,-~ u~s Cons. C0mmissi~ ",, J A~chorage 6500 ................................................ -~ :-- ...................... ....... .., ............. 7200 ............... ' ', I .... -~r~- ~ ..... ~ ........... ~ ...... ~ ..... ~ ..... 7800 ................................. '....................... ~ J ....... ...... ~ooo ...... ' ~' .- [' ~.,...,.~ ............. ~ .... :%~..;.--' .......... ,, ! I- .. t .. 1 ..... gGO0 0 EO0 i200 18o0 2400 30oo 3600 4~00 4800 5400 6000 6600 7200 7800 Sect ~on II I III I JA,~fi~J)] [~]~ ~ R~ ~ 5fr ~ ~ ~1 ' ..... . ,,,,,, JUN-Z~-i~4 il:JZ PNU~ HNHUNILL IU MMD bNUINbbN5 I..- .... ,, '"--PR-[J"'[~'FIC~E__,.. ,, , BAY ............. .... DRI_LING GROUP ....,,, ........... .. iHim I II I ............ , ............... IIII I A) fiE-~N 10060 35'8 3085 O) ........ TAR6ET ....... ~1123 3746 3728 ...... E) END 14/~00 CURVE II~23 3746 3728 CLOSURE · 6~30 feet at AZ'~mUth 50.08 BEOLINAflON ' 29.994 E ~SCALE . · ] inch : 800 feet DRAWN ' 06/22/94 ...... ~nadri ] ] Sc~]umberger / 5200-- , ~ - ............................ ~ ...... . .......... : 4800 ~ ' - 4400 ................................................................ . 4000" ' , . ' .¢ ~50 FT 'ARGET R~ ]IUS / FAULT LINE ....... $,,, ,, , ~800 ........ i ~ '- ' ..................... 2~00- _ , ..... t ........ 2000 ......... - : i .......... : ., ~ ........................... ...... ~ : ~ dU~ ~ 2 1~[4 " 800 ~' , ...... , / An~horaDe . ~ / ~" 0 ...... ~ I ...... ~ ...... ~ ! ..... "' 400 0 ~00 8oo 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 ~-' WEST ' EAST -> DS 5-13A Redrill 6/22/94 SUMMARY I. Pre-rig work: J . . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. PROCEDURE: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut the 3-1/2" tubing near 10650' MD. Freeze protect and set a BPV. Intermediate casing pack-off failed the test and it wil be replaced. Move in drilling rig. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and test tree plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 3-1/2" tubing. ( Please inspected for NORM prior to handling or shipping off the location ) P/U bridge plug and RIH to @ 10360' MD. Set bridge plug. POOH. P/U section mill and RIH to top of bridge plug and spot a 18 ppg pill on bottom and prior to cutting a 45' section in the 9-5/8" casing ( starting from about 1006'0'MD) 9-5/8 packoff will have to be replaced. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target with 90° hole angle at 8765'ss as per the attached directional plan. ( NOTE: In order to {~¢¢orrlmodate CTU we will drill to target r 90°] DIus additional ~ 200' of horizontal } Obtain GR / Neutron / Density formation evaluation logs via drill pipe after TD in 8.5" hole is reached starting from the top of the Sag River to TD. Run a 7" 29 # L-80 liner assembly ( packer and hanger will be an L-80 ) from the bottom in the 8-1/2" hole and up to 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 60 % open- hole enlargement plus the 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. ( Note: if the caliper information is available you may use it by adding 20% to it ) P/U 6" bit and clean out 7" liner plus please drill @ 15' of new 6" hole to accommodate CTU drill out. Run @ 3-4 joints of 4.5" 12.6# liner to bottom and space it inside of 7" liner so that additional zone of interest is not covered ( this depth will be reconfirmed after open hole logs are ran ) Run the 4-1/2" L-80 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Install a BPV and test plug. Remove BOP'S. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production RECEIVED JUN 2 2 1994 Alaska 0il & Gas Cons. Commission Anchorage Page 4 · CONSERVATION COMMISSION WALTER J, HIC, KEL, GOVERNOR ALASKA OIL AND GAS / 3004 PORCUPINE DRIVE March 31, 1994 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 5-13A ARCO Alaska, Inc. Permit No. 94-42 Sur. Loc. 30t5'NSL, 5168'WEL, Sec. 32, TllN, R15E, UM Btmnhole Loc. 2827'NSL, 266'WEL, Sec. 29, TllN, R15E, UM Dear Mr. Jordan: 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. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redri,l E]llb. Type of well. Exploratoryl-I Stratigraphic Test [] Development O,, [] Re-Entry [] DeepenElI Service I"! Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. KBE = 64' feet Prudhoe Bay Field/Prudhoe 3. Address 6. PrOperty Designation Bay Pool P. O. Box 196612. Anchoraae. Al~.eka 99519-6612 ADL 28326 4. Location of well at surfaCe 7. Unit or property Name 11. Type Bond(-. 2o Mc 25.02s) 3015' NSL, 5168' WEL, SEC. 32, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 2196' NSL, 1010' WEL, SEC. 29, T11N, R15E 5-13A U-630610 At total depth 9. Approximate spud date Amount 2827' NSL, 266' WEL, SEC. 29, T11N, R15E 5/15/94 $200,000.00 !12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL 28325-266' feet No close approach feet 2560 12658' MD/8817' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (~ee ~o AAC 25.035 (e)(2)) Kickoff depth 10440 feet Maximum hole angle eoo Maximum surface 3330 psig At total depth (TVD) ~00'/4390 pslg 18. Casing program Setting Depth ..... s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" 7" 29# 13CR NSCC 1384' 10300' 8269' 12658' 8827' 180 sx Class "G" 3-3/4" 2;~/8" 6.2# 13CR NSCC 1100' 11500' 8812' 12658' 8817' Uncemented ...... EIVL~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 5 994 Total depth: measured 11304 feet Plugs (measured) true vertical 8945 feet /~t~ska (~[l & Gas Cons. Commission Anchorage Effective depth: measured 11199 feet Junk (measured) true vertical 8870 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 112' 20" 224 sx 112' 112' S u rface 2718' 13-3/8" 5726 sx 2718' 2718' Intermediate Production 11286' 9-5/8" 950 sx 11286' 8932' Liner 528' 7" 180 sx "G" 11264' 8916' Perforation depth: measured 11060'-11080', 11082'-11092', 11113'-11116', 11116'-11157', 11157'-11162'(allsqueezed) true vertical 8770'-8784', 8785'-8793', 8808'-8810', 8810'-8839't 8839'-8843' (ali squeezed) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] .Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report• 20 AAC 25.050 requirementsl-I 21. I hereby certify tha~,~h.,e~,l~rue and correct to the best of my knowledge Signed Title Drilling Engineer Supervisor Date ~'-/V- ~ ~ Commission Use Only Permit Number IAPI number . IApproval date _ ISee cover letter 15°-o'z-?I ,~.,-~.~/.... ,~;~'~/4. Ifor other requirements Conditior~s of approval Samples required [] Yes ~ No Mud log required [] Yes ~ No Hydrogen sulfide measures !-I Yes ~il No Directional survey requ~reo ~] Yes [] No Required working pressure for BOPE 1-12M; 1"I3M; I~I5M; I-I10M; I-I15M; Other: by order of Approved by Commissioner ~ne commission Date ,,~J~/,/'~ (f :orm 10-401 Rev. 12-1-85 Submit in trip IWell Name: IDS 5-13A Redrill Plan Summary Type of Redriil (producer or injector): [ Producer RECEIVED MAR ] 5 1994 Alaska Oil & Gas Cons. Commission Anchorage Surface Location: 3015 FSL 5168 FEL S32 T11N R15E UM Target Location: 2196 FSL 1010 FEL S29 TllN R15E UM Bottom Hole Location: 2827 FSL 0266 FEL S29 T11N R15E UM ArE Number: I I ]Estimated Start Date: I 5/15/94 112658' I Iyw: [ Well Design (conventional, slimhole, etc.): I Rig: I Nabors 2Es [ Operating days to complete: 1 25 18755 ss [ [KBE: 164 I Sidetrack Objective: The primary objective of the DS 5-13 sidetrack is to drain the current reserves by drilling a new horizontal wellbore to a location no~heast of the current BHL. The expected LOC is 66 feet. The post sidetrack rate is expected to be 2600 BOPD at 2000 GOR. Offsets to 5-13 indicate that the Romeo is highly productive in this area, however, 5-13's production was never as high as the offsets due to well damage. 5-13 is currently shut-in due to a gas channel (current GOR=26,000). If 5-13 were produced, the GOR would continue to rise due to channeling, thus the 5,13 GOR would not be competative even after GHX-2. A squeeze in September, 93 was not successful. Squeezing the channel is complicated by the presence of a scab liner. It is unlikely that any series of squeezes and stimulations would result in more than 600 BOPD. A horizontal wellbore will increase the productivity, provide standoff from the GOC and eliminate any well damage problems. The intermediate section will be drilled with the rig and the 1000 foot horizontal section will be drill underbalanced with the coiled tubing unit. CTU drilling will minimize well damage and provide additional data regarding the benefits of CTU drilling. CTU underbalanced drilling was successful on 2-16, which has sustained an initial rate over 2000 BOPD at a Iow GOR since it was brought on line 2 months ago. Mud Program: ISpecial design considerations After dressing off the kickoff plug we will displace to Flopro system (Xanvis) and drill to 7" shoe depth with @ 10.00 ppg to 10.20 ppg. 6" hole will be drilled with the same system with @ 9.2 ppg to 9.4 ppg. Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 10.00 14 47 22 31 6.5 0 7 to to to to to to to to to TD' 9.4 11 44 18 22 6 0 2.5 Directional: IKOP: 1 10440' MD I Maximum a°le Angle: i Close Approach Well: NONE Casin bin:ram- Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tb§ O.D. MDfFVD MDfFVD 8.5 7" 29# 13cr nscc 1384 10300/8269 11684/8827 3-3/4" 2-3/8" per. ln. 13cr nscc 1100 11500/8812 12658/8817 N/A 4.5" 9.3 L-80 nscc 10000 Surface 10000/8065 Cement Calculations: I Liner Size: 17" I Basis:[ 50¢o open hole ex~ess, 80' shoe joint, 150' liner lap and 150' excess above linei' with DP. Total Cement Volume: 180 @ 180 sxs of Class G Blend @ 1.18 ft3/sx I Liner Size: 1 2-3/8" (Perforated Liner) I Basis:I · . . Total Cement Volume: N/A in this case. sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum pOtential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Gas Cons. commission Anchorage - DS 5-13A AFE INFORMA ., )N SUMMARY PROCEDURE: le . . . . el . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut the 3-1/2" tubing near 10650' MD. Freeze protect and set a BPV. Test intermediate casing pack-off to 5000 psi. Move in drilling rig. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. Pull BPV. Circulate diesel freeze protection cap from well and recover for future use. Install a BPV and test tree plug. Remove the production tree. Install BOP's and test to 5000 psi. Remove the test plug and BPV. Pull and lay down the 3-1/2" tubing. Spot a 18 ppg pill on bottom and cut a 50' section in the 9-5/8" casing starting from about 10440'MD. Spot a balanced cement kick-off plug (180 cubic feet minimum) through open- ended drillpipe from 100' below the base of the section to 200' above the top of the section. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to the target with 90° hole angle at 8765'SS as per the attached directional plan. Obtain Direction / GR / Resistivity / Neutron / Density formation evaluation logs while drilling starting from the top of the Sag River Fm. Run a 7" 2~) # 13cr liner assembly to bottom in the 8-1/2" hole and up to 100" above the top of sand followed with 7" 29# L-80. Space the liner hanger (L-80) and top isolation packer (L-80) about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 60 % open- hole enlargement plus the 80' shoe volume, 150' lap volume and 150' excess on top of the liner with drillpipe in the hole. Pull the wash string up just above the hanger and circulate out Xanvis mud above the slotted liner with filtered seawater. Pull out of the hole and lay down the wash string. Retest 9-5/8" wellhead packoff and replace as needed. Run the 4-1/2" L-80 completion string assembly. Space out and circulate with corrosion inhibitor before setting the tubing packer. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production ~.~ 1 5 1994 Gas Cons. Commissio~ Anchorage PRUBHOE' BA' >'' 'D'RZ_LTNG GROUP C) STAPT 6/100 CIJRVE¢2 t1229 8788 5608 53.85 .......... D) ENO OF 6/~00 CURVE¢2 ~684 ~27 6047 9u..g E} TARGET 11684 ~27 6047 90.59 SeCtiOn at: 49.62 F) TD ~2658 88~7 702~ 90.¢_=a TVD Scale '. ~ ~nch = ]200 <KB> o ,,, Dep Sca~e · ~ ~ncm = ~200 feel ', J Drawn ' 02/28/94 i ' , 600 ....... i i i ....... I ~ ~ ~ ~naCj ]] Sch]umbenger 1 , , , . .~ _ . 1200 ~ ~ , ~ ', !~00 ........... . ' ] ' , , i Z~00 .............. i ~ ' I I : i ' ' I '-. I , . - , ........................ 54oo .... F ...... i ~-. ............... ' ........... ~ ................................................ 5000- , .. ~ . , ~ i i '. I { ,,KELEIV .......... '' i MAR 1 5 1994 5600-- ~ ~ ~ '. ......... i .... , I ~ ~ % ~, k~ 7200 j ~ ~ ,, j A.~S ~., ',._ , An :h~rag¢ ~ ' t ' ' i J! *'~ ~ I ~ ', ~ , %~ .......... , ...... , 78oo- ~- *A~,' .... '-. J ................. . . _ ........ , ; ; :: ~vv ., ~ ~,~, ~-.-.. ~ ....... ~, ====================== SOOO~ . ; · ~ · -- . ... , j ' c , ~ ~ ~ i '-" -"', , " .... '" [ ~ ~ ; i I ~ ; ~ : -~800 -600 0 600 ]200 ~g00 2~00 3000 2500 a200 zS0~ 540~ 6000 6600 7200 Section Departure PRUDHOE BAY DRILLING i i , , Narker IdP. nlificalion MD Bt'.;~SE[fN [liCLN A] TI£-IN tO,Hr) 8]37 4~29 4?.52 B] [1,~ OF ~/]00 CURY[~I 10785 8533 52J~ 63.85 C) 51ARI 6/i00 E~tVE,f2 11229 8ZEB 5603 5].85 B) [ND ~ 6/]00 OJRVE~2 t168,i 8327 5847 g0.59 E) 1 &RISE f 11684 8827 60,17 90.59 GROUP DS 05- 3A VERTICAL SECTION Section at: TVD Scale' Dep Scale.' Drawn .... · 49.62 ~ inch = 300 teet ] inch: 300 faet 02/28/94 , ~- ~'~'~ ~,:,.~.. ,,,~,~[%.~.r ...... ~ "'; ,--- --"'~ ..... - ~ ~-~ ................. -' ~ ' ' ~ - ..... ' ..... ~ .......................................................................................................... ' ........... ;E~F 5., .,.-¥,~ - ~41~ ........... ~ ....................... : .~ ~_ / .... : ....... 5~ ......... : .... '_ . . i ~."~ -. ¢~ .... ,-~ 7 ': - ..... I .. .... ] ................ 2~_ -~ ....................... · , >,.-~ ........................................... I ................ =: ::=== :::==:=:=::::::X ...... ..... ~ , ,, ., ,, , : _ ~ ........................................ ~ ............. , I , , -O .......... r _ _ .. . . . . ....... , · ' . ; ........~ ............................. ] .................................. ' ~ I MA~ 1 5 ~994 ~ . 9450 ........................ ' i-. · ~.~; ,~-~ ~-~ ;:~om~ ;si~ ........... j ....................... Anchora, le i I ....... 9600 ..... ~ I ' - ' ,1500 ~65~ ,16D0 495~ 5 ]00 5250 5400 5550 5700 5850 6CJ)O 6 ~ 50 65D0 645~ 6600 5750 ~900 7050 7200 Sec[ion Departure Ir'lq] 091]~;'1 I];.57 4.54 I;I I) "'"'"'"" ~. OIL AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. Abandon x Suspend ~ Alter casing ~ Repair well Cha.nge approved program ~ 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2267' SNL, 100' EWL, SEC. 32, T11N, R15E, UM At toP of productive interval 1446'NSL, 1815' WEL, SEC. 29, T11N, RISE, UM At effective depth Operation Shutdown __ Re-enter suspended well Plugging x,, Time extension ~ Slimulate Pull tubing~ Variance Perforate Other X Plugback for redrlll 5. Type of Well: 6. Datum elevation (DF or KB) 69 feet Development X Exploratory Stratigraphic ~ Service RECEIVED 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 5-13 9. Permit number 77-26 10. APl number 50- 029-20250 1 !~ Field/Pool ?Prudhoe Bay Field~Oil Pool At total depth 1746' NSL, 1318' WEL, SEC. 29, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical MAR 2 4 1994 Alaska Oil & Gas Cons. Commission Anchorage 11304 feet Plugs(measured) 8945 feet Effective depth: measured true vertical 11176 feet Junk (measured) 8853 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size -Cemented Measured depth True vertical depth 112' 20" 224 sx 112' 112' 2718' 13-3/8" 5726 sx 2718' 2718' 11286' 9-5/8" 528' 7" measured 950 sx 11286' 8932' 180 sx CIG 11264' 11060;11080', 11082;11092', 1:1113;11116', 11116;11157,, 11157;11162' (all squeezed) true vertical 8770'-8784', 8785'-8793', 8808'-8810', 8810'-8839', 8839'-8843' (all squeezed) Tubing (size, grade, and measured depth) 3-1/2" 13 Cr-80 Fox ~ 10794' Packers and SSSV (type and measured depth) Baker 'SB-3A' Packer @ 10691'; Otis 'FMX' SSSV ~ 2198' 13. Attachments Description summary of proposal 14. Estimated date for commencing operation 4/15/94 16. ff proposal was verbally approved Name of approver Date approved Detailed operations program ~ BOP sketch 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby certify that the~regoing is true and correct to the best of my knowledge. Si~lned %- Title Drillir~l En~lineer Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required lO- Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner Date.~''/V'"? l"t J Approval No.,~ y----O ~7 WELL PERMIT CHECKLIST COMP ANY /~,_,~ INIT CLASS UNIT# PRO~RAM: exp [] dev~ redrll~ serv [] ADMINISTRATION 1. 2. 3. 4. 5. 6. '7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Y Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary.. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval.. Can permit be approved before 15-day wait ....... ENGINEERIN~ GEOLOGY 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMTvol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMTwill cover all known productive horizons ....... Y 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ .~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. N 22. Adequate wellbore separation proposed ......... N 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... .~ N 26. BOPE press rating adequate; test to ~(~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. Y 30. Permit can be issued w/o hydrogen sulfide measures .... 31. Data presented on potential overpressure zones ..... Y / N --/~ ,p n y progress ~ ;o [exploratory only] GEOLOGY: ENgINEERINg: COMMISSION: Cosments/Ins~cuctions: Z 0 HOW/jo - A:~FORMS%cheldist rev 03/94 WELL PERMIT CHECKLIST ADMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore Plat included ........ N · 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait. ' N UNIT# PROGRAM: exp [] dev.~ redrll.~ serv [] 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 surf csg to next string .... lS. 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 abndnmnt been approved.~~/~~-~---- 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~6)~O psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/. 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y/ N 33. Seabed condition survey (if off-shore) ......... 7 N ' 34. Contact name/phone for weekly progress reports .... / Y N [explorator~onl~] GEOLOGY: Ccmmmnts/Instructions: .O 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. Tape~Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-40055 A. SHERRITT N. SCALES D.S. 5-13A 500292025001 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 25-JUL-96 MWD RUN 2 A. SHERRITT N. SCALES MWD RUN 3 A. SHERRITT N. SCALES MWD RUN 4 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: A. SHERRITT N. SCALES WELL CASING RECORD MWD RUN 5 A. SHERRITT N. SCALES 32 liN 15E MWD RUN 6 A. SHERRITT N. SCALES 3015 5168 62.50 61.00 RECEIVED JUL 0 199S Alaska Oil & Gas Cons. Commission An orage OPEN HOLE CASING DRILLERS 1ST STRING' 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 13.375 2718.0 9.625 10022.0 8.500 11116.0 ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1-6 WERE DIRECTIONAL WITH GAMMA RAY (NGP / SGP~). SURVEYS FROM 10908' MD TO 11063' MD HAVE CORRECTED AZIMUTHS DUE TO INSUFFICIENT MONEL SPACING IN THE BHA (19.1' TO DIRECTIONAL PROBE FROM MUD MOTOR). FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9948.0 $ BASELINE CURVE FOR SHIFTS: GR (WALS, CURVE SHIFT DATA .(MEASURED DEPTH) BASELINE DEPTH 10207.0 10210.5 10215.5 10231.0 10233.5 10236.5 10246.5 10251.0 10258.0 10262.5 10265.0 10270.5 "1-0284.5 10286.0 10289.5 10312.0 10323.0' 10326.5 10359.0 10365.0 10371.0 10373.0 10379.5 10383.0 10387.5 10395.5 10398.0 10406.0 10430.5 10433.5 10442.5 10455.0 10476.5 10493.5 10501.0 10533.5 10585.5 %0739.5 10743.0 10748.5 10751.5 10757.0 10759.0 10767.0 STOP DEPTH 11080.0 OPEN HOLE, 08-JUL-94) ......... EQUIVALENT UNSHIFTED DEPTH ......... GR 10188.5 10195.0 10200.5 10214.0 10215.5 10218.0 10229.0 10233.5 10240.5 10244.5 10246.0 10252.0 10267.5 10269.5 10271.5 10296.5 10307.0 10309.5 10341.0 10346.0 10352.0 10354.5 10361.0 10363.5 10368.0 10377.5 10379.5 10388.0 10412.0 10415.0 10423.5 10434.0 10458.0 10472.5 10481.5 10513.5 10563.5 10723.0 10725.5 10729.5 10732.5 10739.5 10741.5 10745.0 10769.5 10774.5 10782.0 10790.0 10801.0 10809.0 10831.0 10836.5 10875.0 10901.5 10921.0 10930.0 10932.0 10955.0 10957.5 10986.5 10992.5 10995.5 11001.5 11025.'5 11032 .O 11037:5 11044.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: 10747.0 10753.0 10765.0 10772.0 10779.0 10787.0 10809.0 10815.5 10856.5 10879.5 10902.0 10910.5 10913.0 10939.5 10941.5 10967.0 10973.0 10977.0 10985.0 11010.5 11016.5 11022.5 11029.5 BIT RUN NO MERGE TOP MERGE BASE 1 9949.0 10041.0 2 10041.0 10654.0 3' 10654.0 10826.0 4 10826.0 10919.0 5 10919.0 10948.0 6 10949.0 11113.0 MERGED MAIN PASS. ROP WAS SHIFTED WITH GR. CN WN FN COUN STAT / ??SHIFT. OUT $ : ARCO ALASKA, INC. : D.S. 5-13A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code. Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod ~1 GR MWD 68 1 2 ROP MWD 68 * DATA RECORD (TYPE# 0) Total Data Records: 29 AAPI 4 FPHR 4 1014 BYTES * 90 310 01 90 810 01 Tape.File Start Depth = 11130.000000 Tape File End Depth = 9948.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7096 datums Tape Subfile: 2 186 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape'Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2~ RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: ~5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9948.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9974.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 02-JUL-94 MSC 1.32 NGP 5.74 MEMORY 10041.0 9949.0 10041.0 0 .0 .0 TOOL NUMBER NGP 023 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 2718.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BIO POLYMER 9.80 65.0 12.2 30000 5.4 .000 .000 .000 .000 .0 108.3 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR 'FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 1 · CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-13A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves-. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 I AAPI 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 810 01 i * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 10045.000000 Tape File End Depth = 9948.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 586 datums 66 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: 15000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9974.0 $ LOG HEADER DATA DATE LOGGED:. SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10587.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: · MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) EWR FREQUENCY (HZ). REMARKS: MWD RUN 2. 04-JUL-94 MSC 1.32 NGP 5.74 MEMORY 10653.0 10041.0 10653.0 0 .0 .0 TOOL NUMBER NGP 069 8.500 2718.0 BIO POLYMER 10.20 52.0 10.5 30000 4.3 .000 .000 .000 .000 .0 137.5 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-13A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 810 01 i * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 17 Tape File Start Depth = 10655.000000 Tape File End Depth = 9970.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 11210 datums Tape Subfile: 4 80 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10580.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10777.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 05-JUL-94 MSC 1.32 NGP 5.74 MEMORY 10826.0 10653.0 10826.0 0 .0 .0 TOOL NUMBER NGP 023 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 10022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BIO POLYMER 10.20 68.0 9.9 30000 4.5 .000 .000 .000 .000 .0 124.9 .0 .0 NEUTRON TOOL MATRIX: · MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 3. CN WN FN COUN STAT * FORMAT RECORD : ARCO ALASKA, INC. : D.S. 5-13A : PRUDHOE BAY : NORTH SLOPE : ALASKA (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 i 1014 BYTES * Tape File Start Depth = 10830.000000 Tape File End Depth = 10575.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2120 datums Tape Subfile: 5 70 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10774.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10869.0 06-JUL-94 MSC 1.32 NGP 5.74 MEMORY 10919.0 10826.0 10919.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 023 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.500 10022.0 BIO POLYMER 10.30 72.0 10.0 30000 3.5 .000 .000 .000 .000 .0 124.9 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 4. CN WN' FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-13A : P-RUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR MWD 68 1 AAPI 2' ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 4 90 810 01 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10925.000000 Tape File End Depth = 10770.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation Code decoding summary: Rep Code: 68 12144 datums Tape Subfile: 6 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10858.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10887.0 06-JUL-94 MSC 1.32 NGP 5.74 MEMORY 10948.0 10919.0 10948.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 023 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 10022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX cIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BIO POLYMER 10.20 61.0 9.8 30000 3.5 .000 .000 .000 .000 .0 127.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 5. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 5-13A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves'. Name Tool Code Samples Units GR MWD 68 1 AAPI ROP MWD 68 1 FPHR * DATA RECORD (TYPE# 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 90 310 01 1 4 4 90 810 01 1 8 1014 BYTES * Tape File Start Depth = 10950.000000 Tape File End Depth = 10850.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code.decoding summary: Rep Code: 68 2724 datums Tape Subfile'. 7 66 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10870.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11066.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 08-JUL-94 MSC 1.32 NGP 5.74 MEMORY 11113.0 10948.0 11113.0 0 .0 .0 TOOL NUMBER NGP 023 BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 10022.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: BIO POLYMER 10.20 59.0 10.0 29000 10.6 .000 .000 .000 .000 .0 129.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 REMARKS: MWD RUN 6. CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 5-13A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 FPHR 4 4 90 310 01 4 4 90 810 01 1 8 * DATA RECORD (TYPE# 0) Total Data Records: 1014 BYTES * Tape File Start Depth = 11130.000000 Tape File End Depth = 10860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13768 datums Tape Subfile: 8 70 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 9 is type:-LIS 7/25 O1 **** REEL TRAILER **** 96/ 7/25 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 25 JLY 96 4=49p Elapsed execution time = 4.12 seconds. SYSTEM RETURN CODE = 0 0 ALASKA INC t)ate. Run 1' 08 - ,July - 1994 ZDL/CNIOR Pipe Conveyed 0196 1083 AIl,AS Atlas Wireline Services Tape Subfile .2 is.type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: - FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6241.00 BRAD ESARY SEE REMARKS D.S. 5 - 13A 500292025001 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 14-JUL-94 RUN 2 RUN 3 32 liN 15E 2265 112 62.50 30.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: ZDL/CN/GR. 9.625 10030.0 11112.0 CIRCULATION STOPPED AT 20:00, 07-JUL-94. LOGS WITNESSED BY: N. SCALES & R. KALISH. ** PIPE CONVEYED LOGGING OPERATION. ORIGINAL KB NOT USED. RELATIVE BEARING (RB) IS 180 DEGREES WITH Z DENSITY PAD DOWN. TOOL SET DOWN HIGH ON MAIN PASS. SPLICED BOTTOM OF REPEAT PASS TO BOTTOM OF MAIN PASS AT 10970'. SPLICING DONE IN THE FIELD. AFTER-LOG CALIPER VERIFICATION DONE IN CASING. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX CALIPER CORRECTED CHISM FILTERING ACTIVE NO CASING CORRECTIONS · SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; cased hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFTDATA depth shifted and clipped curves; .5000 BASELINE DEPTH 10236.5 10241.0 10246.0 10254.5 10270.0 10286.0 10289.0 10289.5 10293.5 10323.0 10342.0 10370.0 10379.0 10389.0 10406.5 10410.5 10417.5 10420.0 10428.0 10430.0 10438.0 10439.0 10442.0 10455.0 10466.0 10476.0 10476.5 10482.0 10484.0 10490.5 10493.0 10493.5 10496.0 10498.5 10499.0 10501.0 10503.5 10517.5 10525.5 10528.5 10533.5 START DEPTH STOP DEPTH 10196.0 11056.0 10224.0 11083.0 10228.0 11061.0 GR (MEASURED DEPTH) RHOB 10236.5 10287.0 10289.0 10293.0 10323.0 10370.0 10379.5 10407.0 10410.5 10417.5 10419.5 10428.0 10439.0 10441.5 10454.0 10476.5 10481.5 10490.0 10492.5 10498.5 10501.5 10504.0 10516.5 10533.0 all runs merged; no EQUIVALENT UNSHIFTED DEPTH ......... NPHI 10241.0 10245.5 10253.5 10269.0 10285.5 10289.5 10323.0 10342.0 10379.5 10390.0 10406.5 10420.0 10428.0 10430.5 10438.0 10441.5 10455.0 10466.0 10476.0 10484.0 10492.5 10494.5 10497.5 10517.0 10526.0 10528.5 10541.0 10546.5 10557.0 10585.0 10599.5 10679.5 10702.5 10712.5 10724.5 10731.5 10735.5 10736.0 10738.5 10743.0 10748.0 10751.0 10753.0 10770.0 10777.5 10778.5 10782.0 10797.0 10800.5 10809.0 10811.0 10818.0 10831.0 10849.5 10876.0 10878.0 10893.5 10901.5 10902.0 10920.5 10921.0 10924.0 10926.5 10929.0 10932.0 10932.5 10950.5 10956.0 10963.0 10973.0 10987.0 10991.5 10992.0 10995.5 11004.0 11009.0 11012.0 11025.5 11045.0 $ MERGED DATA SOURCE PBU TOOL CODE GR GR SDN 10547.0 10557.0 10585.0 10702.5 10731.0 10736.0 10739.5 10746.5 10750.5 10753.0 10770.0 10778.0 10800.5 10809.0 10831.5 10875.5 10901.5 10920.5 10924.5 10932.5 10950.5 10956.5 10963.5 10991.5 11025.0 11044.5 RUN NO. 1 1 1 10541.0 10547.0 10585.0 10599.0 10679.5 10713.0 10724.5 10736.0 10744.0 10751.0 10753.5 10779.0 10783.0 10797.0 10810.5 10818.5 10850.0 10878.5 10893.0 10902.0 10921.0 10925.5 10928.0 10932.0 10961.0 10971.5 10987.0 10991.5 10995.0 11003.5 11008.0 11011.0 PASS NO. 3 1 3 MERGE TOP 10196.0 10970.0 10224.0 MERGE BASE 10970.0 11056.0 10970.0 SDN 2435 2435 $ REMARKS: I I 10970.0 11083.0 i 3 10228.0 10970.0 i I 10970.0 11061.0 MAIN PASS. DRHO, PEF, CALl, RB1, MTEM, TEND, & TENS WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT $ : ARCO ALASKA INC. : D.S. 5 - 13A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape.depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SDN 68 1 GAPI 2 RHOB SDN 68 1 G/C3 3 DRHO SDN 68 i G/C3 4 PEF SDN 68 i BN/E 5 CALl SDN 68 i IN 6 RB1 SDN 68 i DEG 7 MTEM SDN 68 1 DEGF 8 TEND SDN 68 I LB 9 TENS SDN 68 i LB 10 NPHI 2435 68 I PU-S 11 FUCT 2435 68 i CPS 12 NUCT 2435 68 i CPS 4 4 65 475 05 6 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records:' 98 Tape File Start Depth = 11110.000000 Tape File End Depth = 10182.000000 Tape File Level SPacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24142 datums Tape Subfile: 2 298 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: I TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10191.0 ZDL 10222.5 2435 10204.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: STOP DEPTH 11057.0 11083.5 11066.0 TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MODL GR KNJT CN ZDL KNJT TEMP PCM RB $ SWIVEL SUB CABLEHEAD TENSION MODAL SUB GAMMA RAY KNUCKLE JOINT COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR ORIENTATION SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 08-JUL-94 FSYS REV. J001 VER. 1.1 2000 07-JUL-94 1411 08-JUL-94 11112.0 11101.0 10196.0 11085.0 1200.0 TOOL NUMBER 3944NA 3974XA 3517XA 1309XA 3921NA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3975XA 8.500 10030.0 .0 BIO POLYMER 10.20 61.0 10.3 3.5 168.8 RESISTI.VITY .(OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 5 - 13A : PRUDHOE BAY : NORTH SLOPE : ALASKA .131 56.0 .047 , 168.8 .189 56.0 .000 .0 .312 56.0 .000 .0 THERMAL SANDSTONE 2.65 .000 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR ZDL 68 1 GAPI 2 ZDEN ZDL 68 1 G/C3 3 ZCOR ZDL 68 1 G/C3 4 PE ZDL 68 1 BN/E 5 CAL ZDL 68 1 IN 6 HRD1 ZDL 68 1 CPS 7 HRD2 ZDL 68 1 CPS 8 SFT2 ZDL 68 1 CPS 9 SHR ZDL 68 1 10 RB ZDL 68 1 DEG 11 TEMP ZDL 68 1 DEGF 12 CHT ZDL 68 I LB 13 TTEN ZDL 68 i LB 14 SPD ZDL 68 1 F/MN 15 CNC 2435 68 1 PU-S 16 CNCF 2435 68 1 PU-S 17 CN 2435 68 1 PU-L 18 LSN 2435 68 I CPS 19 SSN 2435 68 1 CPS 4 4 68 996 67 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 15 242 69 1 4 4 14 587 33 1 4 4 78 812 61 1 4 4 37 715 66 1 4 4 06 777 14 5 4 4 42 007 86 5 4 4 80 407 86 5 4 4 80 407 86 5 4 4 14 871 86 5 4 4 98'211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 310 Tape File Start Depth = 11110.000000 Tape File End Depth = 10182.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 74261 datums Tape Subfile: 3 390 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10732.0 10764.0 10746.0 ZDL 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT MODL GR KNJT CN ZDL KNJT TEMP PCM RB $ SWIVEL SUB CABLEHEAD TENSION MODAL SUB GAMMA RAY KNUCKLE JOINT COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR ORIENTATION SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 11057.0 11083.5 11066.0 08-JUL-94 FSYS REV. J001 VER. 1.1 2000 07-JUL-94 1305 08-JUL-94 11112.0 11101.0 10196.0 11085.0 1200.0 TOOL NUMBER 3944NA 3974XA 3517XA 1309XA 3921NA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3975XA 8.500 10030.0 .0 BIO POLYMER 10.20 61.0 10.3 3.5 168.8 .131 56.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 5- 13A : PRUDHOE BAY : NORTH SLOPE : ALASKA · 047 · 189 .000 ·312 .000 THERMAL SANDSTONE 2.65 .000 .0 168·8 56.0 .0 56·0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR ZDL 68 1 GAPI 2 ZDEN ZDL 68 1 G/C3 3 ZCOR ZDL 68 1 G/C3 4 PE ZDL 68 1 BN/E 5 CAL ZDL 68 1 IN 6 HRD1 ZDL 68 1 CPS 7 HRD2 ZDL 68 1 CPS 8 SFT2 ZDL 68 1 CPS 9 SHR ZDL 68 1 10 RB ZDL 68 1 DEG 11 TEMP ZDL 68 1 DEGF 12 CHT ZDL 68 1 LB 13 TTEN ZDL 68 1 LB 14 SPD ZDL 68 1 F/MN 15 CNC 2435 68 1 PU-S 16 CNCF 2435 68 1 PU-S 17 CN 2435 68 1 PU-L 18 LSN 2435 68 1 CPS 19 SSN 2435 68 1 CPS 4 4 68 996 67 0 4 4 52 443 33 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 15 242 69 1 4 4 14 587 33 1 4 4 78 812 61 1 4 4 37 715 66 1 4 4 06 777 14 5 4 4 42 007 86 5 4 4 80 407 86 5 4 4 80 407 86 5 4 4 14 871 86 5 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 76 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 121 Tape File Start Depth = 11092.000000 Tape File End Depth = 10732.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 52963 datums Tape Subfile: 4 199 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS 01 **** REEL TRAILER **** 94/ 7/15 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 15 JLY 94 2:30p Elapsed execution time = 14.28 seconds. SYSTEM RETURN CODE = 0
