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Home My WebLink About203-063 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available .in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dQ3 - 0 ~ '3 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed II 111111111 II III III RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. & o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Dale lfl1//0~ o Other:: BY: ~ 151 .k11f BY: ~ Dale ~ / Df,¡¿ f ~ ' () 1/1 11111111111 1111I 151 tl1f Project Proofing BY: Date: Scanning Preparation Production Scanning Stage 1 Page Count from Scanned File: -1L (Counl does include oove, sheel) Page Count Matches Number in Scanning Preparation: L YES BY: ~ Date: '+/1/ / ofo 11/111111111111111I NO 151 vwp NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: 151 III 111/111/111 II III Scanning is complete at this point unless rescanning is required. ReScanned 1/11111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 111111111111 111111I 10/6/2005 Well History File Cover Page. doc ~chlumherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll ~..~. u ~ > ~~ N0.5011 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/18/08 11-34 12071901 USIT G~ _ 10/17/08 ~..~ VVW( 1 vv 1 V-219 12103700 USIT 11/21/08 1 1 0-12 12113022 INJECTION PROFILE '~j 12/05/08 1 1 R-11A 12096929 USIT 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG (A - / ~} ~ a 12/06/08 1 1 F-19 AWJI-00011 MEM LDL 12/08/08 1 1 18-296 AWJI-00010 MEM LDL ~ b 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE f 4~ .--(T 12/04/08 1 1 18-14B ~ 12005233 MCNL - 09/21/08 1 1 18-066 12083417 MCNL 10/28/08 1 1 18-14C 12066551 MCNL ~ 10/06/08 1 1 05-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 ~ L - ~ ~ ~ f °~ ~ tM T -t ~ - ~ ~ al Fecc er•Irnrn~en CI1/~C ~G /~CIIYT o _-_. _ __ _._.__.___.--.__..~. ~.-.-...~~..~..... r~v.• •v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: r~ LJ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth Received by: ., S , k . ngFra ~ .i~~ t STATE OF ALASKA ,z ? ~~ ~~ 5''O~ t ALASK~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , _;; 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 9/27/2008 12. Permit to Drill Number 203-063 , 308-356 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/26/20x4 13. API Number 50-029-21614-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Rea ~GL/ ~~ Il 2/2 /2004 14. Well Name and Number: PBU 18-148 ' 4351 NSL, 4609 WEL, SEC. 19, T11 N, R15E, UM Top of Productive Horizon: 884' NSL, 3644' WEL, SEC. 19, T11N, R15E, UM 8. KB (ft above MSL): 46.4" Ground (ft MSL): 15. Field /Pool(s): ~ Prudhoe Bay Field / Prudhoe Bay Total Depth: 1496' NSL, 380' WEL, SEC. 24, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12201 - 8748 - Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 692104 y- 5960948 Zone- ASP4 10. Total Depth (MD+TVD) 12270 _ 8746 ' 16. Property Designation: ADL 028307 TPI: x- 693171 y- 5957508 Zone- ASP4 Total Depth: x- 691452 y- 5958076 Zone- ASP4 11. SSSV Depth (MD+TVD) 2213' 2213' 17. Land Use Permit: 18. Directional Survey ®Yes ^ No mi I i 'n inf 2 . 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permaftost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES 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 1 2. -4 rf 11 1 4" 1 4" 4 7- / " 29.7# rf 7 7 -7/ " x ' -1/2" 1 L- 7 LinerTiebadc 1 1 x x I ' ,~ ~ ~ ~~ ~ , - / ,~ ~ 1 ~ 4- /4" 23. Open to production or inject ion? ^Yes ®No 24. Tuewc 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 3-1/2", 9.3#, 13Cr80 / 9Cr 9118' ~ 9062' MD TVD MD TVD _ ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~ ~~ }(y DEPTH INTERVAL MD AMOUNT ~ KIND OF MATERIAL USED 10170' Set Whi stock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N!A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR FZA7E• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+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 O Form 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE ~a~ ~` ~,y ~a~~~" ~~ `~F/~ ~ ~ gnDG /ro 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Base CGL 9599' 8463' None 23S6 9759' 8555' 22TS 9792' 8571' 21 TS 9931' 8625' Zone 1 B 10147' 8672' TDF 10448' 8729' Base Sadlerochit 11609' 8755' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. l Si d '~ ~/~ / gne / Title Drilling Technologist Date Terrie Rubble PBU 18-146 203-063 308-356 Prepared ay lvame/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRAt.: 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only 18-14BL1 -change of completion flan ~ Page 1 of 2 Hubble, Terrie L ~~~'-~ ~ ~'~- `~Q Off. From: Maunder, Thomas E (DOA) [tom.maunder@alaska.gov] Sent: Monday, October 06, 2008 10:09 AM To: Hubble, Terrie L Subject: DS 18-146L1 (208-132) Terrie, We have received the sundry to abandon 18-14B and the PTD for 18-14C. After much discussion over here, it will also be necessary to submit a 407 abandoning 18-14BL1. All that is needed is the form 407 with a copy of this message attached. For anyone interested, all the drilling information can be found in the 18-14 C (208-151) well file. Thanks for you attention to this matter. The 407 will put all the proper paperwork in place. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Friday, October 03, 2008 2:38 PM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Tom, I put the following statement in the sundry regarding the reserves in the drainage area as I though it addressed the reserve accessibility issue. The low remaining reserves in 18-14B would be accessible with a future side track from 18-14C, 18-03B, or 18-24B. Here is a little more information on the parent well. 18-14B has little remaining value to the field and would not sustain production on its own. The sidetrack was first planned with a solid cemented liner. 18-14B is a horizontal well low in Z1 A and has low perm. The team decided to take the risk and plan a slotted liner completion. The intention (hope) was to use the flow from 18-14BL1 to pull a little more liquid from 18-14B before it was plugged. If/when the 18-148 well goes to excessively high GOR it would be plugged. The prize was to save ~$700k in completion costs and attempt to keep 18- 14B online. When another wellbore becomes available the 18-14B drainage area will be evaluated for redevelopment. Regards, sean From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, October 03, 2008 12:34 PM To: Maunder, Thomas E (DOA); McLaughlin, Sean M Cc: McMullen, John C; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Sean, I am reviewing the permit application for DS 18-14C. I have included copies of our messages that describe why the changes were necessary. One item still missing is highlighted in our message of yesterday (below). I would appreciate a statement addressing the now not accessible reserves. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 10/30/2008 18-14BL1 -change of completion flan • Page 2 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, October 02, 2008 11:34 AM To: 'McLaughlin, Sean M' Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor; Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: 18-146L1 -change of completion plan Sean, Thanks for the information. You are correct that this newly drilled well segment will become 18-14C. I have spoken to my colleagues and unfortunately it will be necessary to submit a new permit application. This is necessary due to the data system we employ. It is not possible to just "over write" information. It will also be necessary to submit a 407 abandoning the lost portion of 18-14B. It is not necessary to halt operations. The new app ica ions ou a su mi a as soon posse e. ease inc u e a discussion of what has happened to require the new permit. There should also be a discussion regarding the reserves that will no longer be accessible due to the plugging of 18-146. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Thursday, October 02, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor Subject: 18-14BL1 -change of completion plan Tom, Nordic 1 is currently drilling 18-14BL1. This lateral was planned to be completed with a slotted liner. Unfortunately last night the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent well bore. Our planned 18-146L1 would then become 18-14C. Would this require a change to the current permit (208-132) or a new permit? Regards, Sean «18-146L1.jpg» «18-14C.jpg» Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 10/30/2008 • i 18-14B, Well History (Pre Rig Sidetrack) Date Summary 8/22/2008 T/I/O = 2500/200Nac MIT IA PASSED to 3000 psi (Pre CTD) Pumped 6.4 bbls of crude into the IA to reach test pressure. MIT IA lost 100 psi in the 1st 15 min and 40 psi in the 2nd 15 min for a total loss of 140 psi in the 30 min test. Bled IA down. Final WHP's = 2500/50Nac. Valve positions at time of departure: Swab closed /Wing flagged, tagged and closed /SSV open /Master open / IA tagged and open / OA open. 8/31/2008 WELL S/I ON ARRIVAL. DRIFTED TO 10011' SLM, W/ 2.50" CENTRALIZER/SAMPLE BAILER, STOPPED DUE TO DEVIATION, SAMPLE BAILER EMPTY. RAN PDS 24 EXTENDED ARM CALIPER FROM 9936' SLM TO SURFACE, GOOD DATA..., WELL LEFT SHUT IN, DSO NOTIFIED. 9/18/2008 MIRU. MU Baker MHA and 2.70" dummy whipstock drift. 9/19/2008 Drift tubing with 2.70" dummy whipstock. Taq C~ 10011'. Attempt to work through tag area multiple, times. Consistent, hard tag C~3 10011' ctmd. POOH. Discuss options with town engineer. MU and RIH with 2-1/8" motor and 2.72" mill. While RIH with motor, develop leak at flanged connection between swab valve and p-sub; pull to surface and replace ring gasket at flange. RBIH with 2-1/8" motor and 2.72" parabolic diamond speed mill. Dry tag obstruction at 10021' ctmd. Mill through tag depth with no_ significant motor work. Attempt to RIH without milling, dry tag at 10060' ctmd. Mill through tag depth with no significant motor work. Attempt to RIH without milling, dry tag at 10247' ctmd. Mill through tag depth with no significant motor work. RIH dry to 10953' ctmd. POOH back reaming through tight spots. OOH. MU Baker 2.70" dummy whipstock drift. 9/20/2008 MU and RIH with 2.70" dummy whipstock drift. Drift to 10950' ctmd. POOH. At surface, pump 1.25" OD drift ball through CT to investigate cement chunk that was found in toolstring on earlier run. Recover an additional piece of cement in nozzle, ahead of drift ball. Pickle pump iron, reel iron and CT with 5 bbls 12% HCI acid to remove any residual cement. Overflush acid out of line. Recover additional cement piece after flushing coil. Decide to rig down and inspect all treating iron. Recover additional 1.5 cups of cement pieces from treating iron. Pumped coil volume and found no additional cement pieces. 9/21/2008 MU and RIH with SWS CNL logging BHA. Load well with 1% XS KCL and perform MCNL/GR/CCL passes at 60 fpm from 10950' ctmd - 8950' ctmd. POOH and confirm good data. Freeze protect wellbore to 2500' with 50/50 methanol/water. Leave flowline not freeze protected; FB to freeze protect tomorrow. Notify drill site operator of well status. RDMO. Job complete. 9/22/2008 T/I/0=340/220/0 Temp=S/I Freeze protect F/L. (Post coil) Pumped 8 bbls neat meth & 56 bbls crude down flowline. FWHP's=250/220/0 Annulus casing valves open to gauges upon departure and DSO notified of the following, Swab,Wing=S/I / Master,lA,OA=open. 9/22/2008 T/I/O=SSV/220/0 Temp=S1 Freeze Protect Flow Line with 5 bbls neat methanol and 56 bbls crude post coil work. FWHP's=SSV/220/0 AT DEPARTURE VALVES in following positions -and operator notified of positions and result of job. Wing closed, Swab closed, SSV closed, Master open, IA open, OA open - Well SL 9/23/2008 T/I/0=0/200/0. Set 4" CIW H BPV. Pre Nordic 1. 9/24/2008 T/IA/OA= BPV/200/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre CTD) PPPOT-T RU 2 HP BT onto THA test void, 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bled void to 0 psi, RD test equipment, did not cycled LDS "ET style" all were in good visual condition. PPPOT-IC RU 2 HP BT onto IC test void, 100 psi to 0 psi, flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3450/ 15 minutes, 3450/ 30 minutes. Bled void to 0 psi, RD test equipment, did not cycled LDS "ET style" all were in good visual condition. Page 1 of 1 • • BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: ~Z~ ~~ ~ Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/25/2008 22:00 - 22:15 0.25 MOB P PRE 22:15 - 22:30 0.25 MOB P PRE 22:30 -00:00 1.50 MOB P PRE 9/26/2008 00:00 - 05:00 5.00 MOB P PRE 05:00 - 11:00 6.00 MOB N WAIT PRE 11:00 - 11:30 0.50 MOB P PRE 11:30 - 11:45 0.25 MOB P PRE 11:45 - 12:00 0.25 MOB P PRE 12:00 - 16:00 I 4.00 MOB I P I PRE 16:00 - 18:30 2.50 MOB P PRE 18:30 - 18:45 ~ 0.25 ~ MOB ~ P ~ ~ PRE 18:45 - 19:40 0.92 MOB P PRE 19:40 - 00:00 4.33 BOPSU P PRE 9/27/2008 00:00 - 01:00 1.00 BOPSU P PRE 01:00 - 01:30 0.50 MOB P PRE 01:30 - 01:45 0.25 MOB P PRE 01:45 - 02:45 1.00 RIGU P PRE 02:45 - 04:40 1.92 RIGU P PRE 04:40 - 04:50 0.17 RIGU P PRE 04:50 - 05:50 1.00 RIGU P PRE 05:50 - 07:00 I 1.171 RIGU P I PRE 07:00-08:45 1.75 WHIP P WEXIT 08:45 - 09:00 0.25 WHIP P WEXIT 09:00 - 10:45 1.75 WHIP P WEXIT Prepare to move rig off of well. Jack up and warm up tires. SAFETY MEETING. Review procedure, hazards and mitigation for moving rig to DS 18-146L1. Move rig to DS 18-148L1. Move Nordic 1 rig on Oxbow road to West Dock road to DS18 While moving rig past Doyon 14 rig. The rear tire went thru the pad near a wet area with thin [2-aft] gravel on the pad. Jacked rig out using rig mats and plywood. Move rig to DS 18-146L1 and position rig in front of well. SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over the well. Back rig over well and center over well. Set down rig. ACCEPT RIG AT 12.00 HRS 09/26/20~~ ON nc +n_1agL1 Position trailer and tanks, rig up hardline to Tiger Tank. N/U BOP Stack. Position injector head. M/U and pull test CT internal grapple. Pull CT stub to reel. Prep for BOP test and reel swap. SAFETY MEETING. PJSM for swapping reels. Hazards discussed were overhead loads, communication and falling objects when the reel door is opened. Lower 2" a-free work string down onto trailer and secure. Hook up to 2" a-line reel and lift into reel house. Test BOP. Test is witnessed by AOGCC official Lou Grimaldi. Also test pit level indicators and all gas alarms. Pit level sensor for pit 1 failed. Continue BOP test. Load BPV lubricator and pulling equipment to rig floor. SAFETY MEETING. PJSM for pulling BPV. Pull BPV. Well is on slight vac. Load out BPV equipment. Inspect injector chains, replace failed bearings. Fill well with 6 bbls while waiting. SAFETY MEETING. PJSM for pulling CT across pipe shed roof. Crew positions and procedure was discussed. Install grapple in CT end. Pull test. Pull CT across pipe shed and into injector. Cut off grapple and install cable boot. M/U CT riser, line up to pump backwards to fill reel. Pump 20 bbls fresh water followed by 2# biozan to fill reel. Reverse circ at 3.0 bpm, 4200 psi, 5 times to pump slack into coil. Cut off 105' of coil, found E-Line at 60'. M/U Kendle CTC. Pull test. M/U CoilTrak UOC and test E-Line, OK. SAFETY MEETING. Review procedure, hazards and mitigation for M/U Baker whipstock and CoilTrak BHA. M/U Baker Monobore 3-1/2" Retrievable Whipstock to CoilTrak tools. Install 2 SWS PIP tags into Whipstock tray 5.35' from top of tray. BHA OAL = 66.69'. 5`~ '-'r'p' $. • BP EXPLORATION Paget of 12 Operations Summary Report Legal Well Name: 18-14 Common Well Name: 18-14 Spud Date: 10/22/1986 Event Name: REENTER+COMPLETE Start: 9/18/2008 End: 10/9/2008 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/27/2008 10:45 - 13:15 2.50 WHIP P WEXIT RIH with BHA #1, BOT 3-1/2" Monobore RWS Whipstock setting BHA. Check CoilTrak tools at surface. Open EDC. Circ at 0.1 bpm, 600 psi. 13:15 - 13:45 0.50 WHIP P WEXIT Log GR tie-in with GEO log. -16' CTD. 13:45 - 14:10 0.42 WHIP P WEXIT RIH and position top of Whipstock at 10710' with a 90 LOHS TF. Close EDC. Press up and set Whipstock with #10J setting tool at 4200 psi. 14:10 - 16:00 1.83 WHIP P WEXIT POH with setting tools while Circ well to 2# Biozan. 16:00 - 16:30 0.50 WHIP P WEXIT La out Whi stock runnin tools. _ - 1.7:15 0.75 STWHIP P WEXIT M/U 2.74" window milling BHA #2 with 2.74" HCC diamond window mill and string reamer, motor, 2 jts CSH and CoilTrak. BHA OAL = 99.26'. 17:15 - 19:25 2.17 STWHIP P WEXIT RIH with milling BHA #2. circ at 0.2 bpm, 1200 psi. I, 1 G 19:25 - 21:00 1.58 STWHIP P WEXIT flag whipstock with min pump rate and correct -15 ft to 10,710 "1 Pick up and bring pump up. Up weight is 34 Klbs. Free spin is 3120 psi at 1.50 / 1.48 bpm. Ease down and tag whipstock to start milling. Stall at 10,708.8 ft, then steady progress after that. TOW = 10,708.8 ft. 21:00 - 00:00 3.00 STWHIP P WEXIT Mill at 10,709.8 ft ~ 1.44 / 1.44 bpm 3040 psi. DWOB = 1.40 Klbs. 22:00 - 10,710.8 ft 1.43 / 1.43 bpm ®3130 psi. DWOB = 2.39 Klbs. 23:00 - 10,710.85 ft 1.51 / 1.52 bpm @ 3,220 psi. DWOB = 1.84 Klbs. 9/28/2008 00:00 - 04:00 4.00 STWHIP P WEXIT Continue milling window. 00:00 - 10,711.62 ft 1.52 / 1.52 bpm ~ 3170 psi. DWOB = 1.83 Klbs. 01:00 - 10,712.50 ft 1.51 / 1.51 bpm ~ 3060 psi. DWOB = 1.61 Klbs. 02:00 - 10,712.90 ft 1.50 / 1.50 bpm ~ 3030 psi. DWOB = 1.76 Klbs. 03:00 - 10,713.70 ft 1.50 / 1.50 bpm ~ 3100 psi. DWOB = 1.90 Klbs. Stall at this depth, then loss of DWOB and motor work. Likely window exit at 10,713.7 ft. 04:00 - 05:40 1.67 STWHIP P WEXIT Continue milling 1 ft/hr until string reamer exits. Drill 10 ft of rathole to 10,725 ft at 10 - 15 fUhr. Trace of formation in 10,714 sample. 05:40 - 06:20 0.67 STWHIP P WEXIT Perform 3 up and down passes through window at slow speed. Dry run through window shows no weight bobbles. 06:20 - 08:45 2.42 STWHIP P WEXIT POOH with window milling BHA. 08:45 - 09:00 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for changing BHA's. 09:00 - 09:45 0.75 STWHIP P WEXIT L/O milling BHA. Mills gauged at 2.73" go/1.72" no-go. 09:45 - 10:15 0.50 STWHIP P WEXIT C/O CT pack-off and repair hyd hose. 10:15 - 11:00 0.75 DRILL P PROD1 M/U CoilTrak Turn/RES BHA #3. HYC BC Bit #1, 1.9 deg Xtreme motor, CoilTrak with RES. BHA OAL = 67.76'. 11:00 - 13:00 2.00 DRILL P PROD1 RIH with CoilTrak Turn/Res BHA #3. Circ at 0.1 bpm. 13:00 - 13:30 0.50 DRILL P PROD1 Log GR tie-in from 10350-10400'. -17' CTD. 13:30 - 14:45 f .25 DRILL P PROD1 Drill Z1 A left turn section. 1.6 bpm, 3650-4200 psi, 88 deg rrmiea: iuiauizuuo i i:m:ya nm vr~Lhr~,u = rn ACTUATOR = BAKER ;B. ELEV = 47 3F. ELEV = SOP = 45C Aax Angle = 97 @ 1221 )alum MD = 91 ~ )alum TV D = 8800' ~ DRLG DRAFT 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I~ 3452' TOP OF 5-1/2"" SCAB LNER I~ 3530' Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" ~ 8509' 7-518" CSG, 29.7#, L-80, ID = 6.875" ~ 8700' PERFORATION SUMMARY REF LOG: MCNL Log CCL/GR/CNL 06-OCT-08 A NGLE AT TOP PERF: 89 ~ 10860' Note: Refer to Roductbn DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 1.56" 6 10860-10890 O 10!07/08 1.56" 6 10920-10990 O 10/07/08 1.56" 6 10080-11130 O 10/07/08 1.56" 6 11280-12080 O 10107/08 1.56" 6 12470-12490 O 10/07/08 1.56" 6 12530-12610 O 10/07/08 1.56" 6 12700-12859 O 10/07/08 18-14C 3-1 /2" TBG, 9.3#, 13-CR .0087 bpf, ID = 2.992" 11 9118' ~i TOP OF EZSV 9596' 10590' Liner Top Packer Note: LTP did NOT set i-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ~ = 4.767" 3-1/2" LNR, 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" I 9086' H3-1/2" HES X NIP, ~ = 2.813" 9106' --13-1/7' HES XN N~, ID = 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413' 5-1/2" BKR LNR TOP TIEBACK, ID = 4.24" 9419' 5-1 /2" X 3-117' BKR ZXP LTP, ID = 3.410" MLLOUT WBJDOW (18-14B~ 9568' - 9581' 10593' ' 3/8" TOP OF LINER Depbyment Sleeve 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 12904 TD 12867 PBTD 10710' TOP 3 112" WHIPSTOCK 12201' PBTD DATE REV BY COMMENTS GATE REV BY COMMENTS 11/08/86 ORIGINAL COMPLETION 09/24!04 KDCITLH TRSSSV CORRECTION 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSB/PJC GLV C/O 04/01/95 CTD (2-7/8" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWC/PJC TRSSSV LOCKED OPEN (02/28/C 03/16/04 JBM/KAK GLV CIO 05/30/08 DAV/PJC TRSSV CORRECTION (02/21/08 09/18/04 G.B/TLP GLV C/O 10108108 Nordic 1 CTD SidPtrark (1R-1dC1 O NOTES: ORIGINAL WELLBORE NOT ~""'~ ON DIAGRAM. 3-112" CHROME TBG. 2213' 3-1/2" CAMCO TRM-4E TRSSSV, ID = 2.812" LOCKED OPEN (02/28/08) GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/0 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/0 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/0 3530' ~ 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1 /2" BKR ZXP LTP, ID = 4.910" 3543' 7-5/8" X 5-112" FLEX LOCK HGR, ID = 4.820 8509' BKR C-2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-1/7' BKR H PKR, ID = 4.812" 8522' 5-1/2" HMC LNR HGR, ID = 4.938" 13-1 /2" HES X NIP, ID = 2.813" I 5-1 /2"X3-1 /7' BKR S-3 PERM PKR, ID = 2.770" PRUDHOE BAY UNff WELL: 18-14C PERMIT No: 82081320 API No: 50-029-21614-03 3) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL BP Exploration IAlaskal L~ ~., ~ ~~ ~ ~I ~ ~~ ~~-~4~~ ALASKA OIL A1~TD GA-S CO1~T5ERQATIOI~T CODiI-II55IO1~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. • SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 PO Box 196612 .;~(:~L~,v~ s~!~'; ~~ ~ ~~~~ Anchorage, AK 99519-6612 , Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-14 Sundry Number: 308-356 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commssion an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of October, 2008 Encl. STATE OF ALASKA ~0~ D8 OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL ~ '~ ~~ ,10 20 AAC 25.280 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension. ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: BP Ex location (Alaska) Inc. 4. Current Well Class: ®Development - ^ Exploratory 5. Permit To Drill Number 203-0tS3 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 ^ Service ^ Stratigraphic 6. API Number: 50-029-21614-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? ^ Yes ®No 8. Well Name and Number: PBU 18-14B 9. Property Designation: ADL 028307 - 10. KB Elevation (ft): 46.4' ~ 11. Field /Pool(s): Prudhoe Bay Field / Prudhoe Ba Pool f 2• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): 12270 - Total Depth TVD (ft): 8746 - Effective Depth MD (ft): 12201 - Effective Depth TVD (ft): 8748 - Plugs (measured): None Junk (measured): None i i Perforation Depth MD (ft): 10880' -12190' Perforation Depth TVD (ft): 8750' - 8748' Tubing Size: 3-1/2", 9.3# Tubing Grade: 13Cr80 / 9Cr Tubing MD (ft): 9118' Packers and SSSV Type: 5-1/2" x 3-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 9062' 13. Attachments: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed O erations Pro ram 14. Well Class after proposed work: ^ Exploratory ®Development ^ Service 15. Estimated Date for Commencin O rations: Current) In Pro ress 16. Well Status after proposed work: ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: 10/2/2008 Commission Re resentative: Tom Maunder ^ WAG ^ GINJ ^ WINJ ^ WDSPL 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLauchlin, 564-4387 Printed Name Jo ul Title En ineerin Team Leader ~~ Signature Phone 564-4711 Dat~ 08 Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. Subsequent Form Required: ~ APPROVED BY / /~ l A roved B COMMISSIONER THE COMMISSION Date / 6 Form 10-403 Revised`06/2006 Submit In Duplicate ~ ~ ~ A ~ ~~ ~~ z~oe ~~ • To: Tom Maunder Petroleum Engineer ~.Jp Alaska Oil & Gas Conservation Commission 1~.! From: Sean McLaughlin CTD Engineer Date: October 02, 2008 Re: DS 18-14B Sundry Approval CC: Well File Terrie Hubble 18-14B was initially planned as a coil sidetrack in February 2004, but the tubing retrievable SSSV broke and we were unable to fish the flapper. After coil rigged down, the well was completed as a rig sidetrack in March 2004, kicking out of the 5- 1/2" liner and completed with 3-1/2" chrome tubing. The 5-1/2" scab liner was cemented across the cretaceous during a previous rig sidetrack in February 1995. The well has had chronic SSSV problems and the tubing-retrievable valve is currently locked open. After approximately 6 months of full-time production, the well was swapped to the HP production header and saw an immediate 300 bopd drop in oil rate. Although the gas rate also dropped for some time, it was back on trend within 2 months. The well sustained full-time production for another year and then began to see erratic test rates. Finally, the well was not able to overcome the 1100 psi backpressure and ceased to produce liquids. The well was still sustaining low rate liquid production 2 months after swapping to low pressure. 18-14B produces very little gas and was a good candidate to add a lateral leg because it poses low GOR risk to the new leg. A coil sidetrack was planned on 18-14B because this low rate low gas producer poses very little GOR risk to the new penetration. The production from the parent well would likely not remain competitive on its own for much longer and this provided a good data-gathering opportunity for how to produce Z1 A low-perm wells as well as multi- laterals. REASON FOR SUNDRY: The 18-14BL1 lateral was planned to be completed with a slotted liner. Unfortunately the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. There would be no remedial options if a slotted liner completion was run. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent well bore. The low remaining reserves in 18-14B would be accessible with a future side track from 18- 14C, 18-03B, or 18-24B. Pre-Rig Work Summary: • 1. F MIT-IA Passed 8/22/08 2. S Run Caliper deep as possible Done 8/31108 3. C Drift with dummy 2.7" x 15' whipstock to 10900' (90deg incl) Done 4. C MGR/CCUCNL log from 9000' to 10900'. Done 5. W Set BPV Done 6. W PT MV, SV, WV Done 7. O Blind and bleed lines, remove well house, level pad Done Rig Sidetrack Operations: 1. MIRU Nordic Rig 1 Done 2. NU 7-1/16" CT Drilling BOPE and test. Pull BPV. Done 3. Set 3-1/2" retrievable whipstock 90 LOHS with top at 10,710'. Done 4. Mill 2.74" window through 3'/z" liner. Done 5. Drill turn section with 2.70" x 3.0" bicenter bit to 11350'. Done 6. Drill lateral section to 12,800'. In Progress 7. Run and cement a 2-3/8" L-80 liner string, abandoning perfs in parent wellbore (8 bbls) -~- 8. Make a cleanout run with mill and motor. 9. Make a logging run with a MGR/CCUCNL fogging tool. 10 . Perforate well. 11 . Circulate well to brine. FP well to 2000' with diesel. 12 . Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 13 . RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well THEE = 7-1116" F WELLHEAD = FMC ACTUATOR = ~ BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = _ 94 @ 11865' Datum MD = 159' 9 Datum TV D = _ 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~ 18 -14 B ~'~DY1 ~ ON DIAGRAM. 3A1 /2"~CHROME BG. ITOPOFS-1/2"" SCAB LNERI Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 5-1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD / GR ON 03/01 /04 ANGLE AT TOP PEFtF: 88 @ 10880' Note: Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10880 - 11610 O 03/04/04 2" 6 11860 - 12190 O 03/04/04 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" H 9118' TOP OF EZSV ~ 5-1/2" LNR, 17#, NT-80 NSCC, .0232 bpf, ID = 4.767" ~-I 10312' 2213, I 3-112" CANTO TRM-4E TRSSSV, ID = 2.812" LOCKm OPEN (02/28/08) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/07 2 5751 5606 39 KBG2-9 DMY INT 0 09/18/04 1 8322 7510 39 KBG2-9 DMY INT 0 03/11/04 3530' 7' BKR LNR TIEBACK SLV, ID = 5.750" 3537' 7-5/8" X 5-1/2" BKR ZXP LTP, ID = 4.910" 354$' 7-5/8" X 5-112" FLEX LOCK HGR, ID = 4.820 $rjQ9' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-1/2" BKR H PKR ID = 4.812" 8522' S-1/2" HMC LNR HGR, ID = 4.938" 9041' H 3-1 /2" HES X NIP, ID = 2.813" 9062' H 5-1/2" X 3-1/2" BKR S-3 PERM PKR, ID = 2.770" 9086' 3-1 /2" HES X NIP, ID = 2.813" 9106' H3-1/2" HES XN NIP, ID = 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413 5-1/2" BKR LNR TOPTI~ACK, ID = 4.24" 9419' 5-1/2" X 3-1/2" BKR ZXP LTP, ID = 3.410" MILLOUT WINDOW (18-148) 9568' - 9581' I I ~ ~ ~ ~ ~ ~ 3-1 /2" LNR 9.2#, L-80 IBT-M, .0087 bpf, ID = 2.992" 12201' H PBTD I 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 11/08/86 ORIGINAL COMPLETION 09/24/04 KDC/TLH TRSSSV CORRECTION WELL: 18-146 02125/95 RIG SIDETRACK (18-14A) 06/24!07 KSB/PJC GLV GO PERMIT No: `2030630 04/01195 CTD (2-718" SLTD LNR) 06/25/07 ?/ PJC TBG /LNR CORRECTIONS API No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02/28/0 8) SEC 19, T11 N, R15E, 4350' FSL & 4613' FEL 03/16/04 JBM/KAK GLV GO 05/30/08 DAV/PJC TRSSV CORRECTION (02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) I TREE= 7-1116" FMC WELLHEAD = FMC ACTUATOR = BAKER C KB. ELEV = 47.7' BF. ELEV = KOP = 4500' Max Angle = 94 @ 11865' Datum MD = 9159' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" 18 -14 C ~ ON DIAGRAM. N3 1 /2" CHROME TBG. Proposed CTD Sidetrack 2213' 3-1/2"CAMCOTRM-4ETRSSSV,ID=2.812" LOCKED OPEN (02/28/08) GAS LIFT MANDRELS 3452, , ST MD TVD DEV TYPE VLV LTCH PORT DATE 3 3240 3240 1 KBG2-9 DMY INT 0 06/24/07 2 1 5751 8322 5606 7510 39 39 KBG2-9 KBG2-9 DMY DMY INT INT 0 0 09/18/04 03/11/04 TOP OF 5-1/2"" SCAB LNER Minimum ID = 2.750" @ 9086' 3-1 /2" HES X NIPPLE 5-1/2" SCAB LNR, 15.5#, L-80 BTC, ?bpf, ID = 4.950" 8509' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 8700' PERFORATION SUMMARY REF LOG: SPERRY-SUN MWD / GR ON 03/01/04 ANGLEAT TOP PERF: 88 @ 10880' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10880 - 11610 O 03/04/04 2" 6 11860 - 12190 O 03/04/04 3-1/2" TBG, 9.3#, 13-CR, .0087 bpf, ID = 2.992" TOP OFEZSV 9~' MILLOUT WWDOW (18-14B) 9568' -9581' ' ' ~ 10600' 2 3/8" TOP OF LINER, TOC ! ~ ' , i 4 A~ TlIP Z ~ / )" 1A/1-JIDCT(1(`LC 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, 1p=1.995" f-{ 12800' (5-1 /2" LNR, 17#, NT 80 NSCC, .0232 bpf, ID = 4.767" 3-1/2" LNR, 9.2#, L-80 ~T-M, .0087 bpf, ID=2.992" 10312' 12269' 12201' -~ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 11/08/86 ORIGINAL COMPLETION 09/24/04 KDClfLH TRSSSV CORRECTION WELL: 18-14C 02/25/95 RIG SIDETRACK (18-14A) 06/24/07 KSB/PJC GLV GO PFRMfT No: 81030630 04/01/95 CTD (2-718" SLTD LNR) 06/25107 ?1 PJC TBG /LNR CORRECTIONS AR No: 50-029-21614-02 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/08/08 SWGPJC TRSSSV LOCKED OPEN (02/28/0 8) SEC 19, T11N, R15E, 4350' FSL & 4613' FEL 03/16/04 JBMlKAK GLV GO 05/30/08 DAV/PJC TRSSV CORRECTION (02/21/08 09/18/04 GJB/TLP GLV GO BP Exploration (Alaska) 9118' 7' BKR LNR TIEBACK SLV, ID = 5.750" 7-5/8" X 5-1/2" BKR ZXP LTP, ID = 4.910" 7-5/8" X 5-1 /2" FLEX LOCK HGR, ID = 4.820 8509' BKR G2 TIEBACK SLV, ID =? 8517' 7-5/8" X 5-112" BKR H PKR, ID = 4.812" 8522' S-1/2" HMC LNR HGR, ID = 4.938" 9041' ~ 3-1 /2" HES X NIP, ID = 2.813" 9062' 5-1/2" X 3-112" BKR S-3 PERM PKR, ID = 2.770" 9086' 3-112" HES X NIP, ID = 2.813" 9106' 3-1/2" HES XN NIP, ~= 2.750" 9118' 3-1/2" WLEG, ID = 2.992" 9413' 5-1/2" BKR LNR TOP TIEBACK, ~ = 4.24" 941 5-1/2" X3-1/2" BKR ZXP LTP. 10= 3.410" 18-14BL1 -change of completion plan Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) ~~ ^ ~ ~` ~ ~0~~ ~ ~~ Sent: Thursday, October 02, 2008 11:34 AM To; 'McLaughlin, Sean M' Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor; Davies, Stephen F (DOA); Saitmarsh, Arthur C (DOA) Subject: RE: 18-14BL1 -change of completion plan Sean, Thanks for the information. You are correct that this newly drilled well segment will become 18-14C. 1 have spoken to my colleagues and unfortunately it will be necessary to submit a new permit application. This is ,• necessary due to the data system we employ. It is not possible to just `over write' information. It will also be necessary to submit a 407 abandoning the lost portion of 18-14B. It is not necessary to halt operations. The new application should be submitted as soon as possible. Please include a discussion of what has happened to require the new permit. There should also be a discussion regarding the reserves that will no longer be accessible due to the plugging of 18-14B. Call or message with any questions. Tom Maunder, PE AOGCC From: McLaughlin, Sean M [mailto:Sean.McLaughlin@bp.com] Sent: Thursday, October 02, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: McMullen, John C; NSU, ADW Drlg Nordic 1 Supervisor Subject: 18-14BL1 -change of completion plan Tom, Nordic 1 is currently drilling 18-146L1. This lateral was planned to be completed with a slotted liner. Unfortunately last night the wellbore crossed a fault and clean Z1 B sand was encountered. Both of these events significantly increase the chance of the well going to gas very quickly. The plan forward is to change the lateral to a solid cemented completion so the conduits to gas can be isolated. The cemented option would plug the parent well bore. Our planned 18-14BL1 would then become 18-14C. Would this require a change to the current permit (208-132) or a new permit? Regards, Sean «18-14BL1.jpg» «18-14C.lpg" Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 10/3/2008 • • ~--- MICROFILMED 03/0112008 DO NOT PLACE ;_,., s~ ~, ,~` ~~ :.~ ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc J I ~prd Àðú~ DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 5i~ :¿far¡4 À ~~ '-( API No. 50-029-21614-02-00 Permit to Drill 2030630 1~^1.ð M D .:J.í!2&t Well Name/No. PRUDHOE BAY UNIT 18-14B Operator BP EXPLORATION (ALASKA) INC ~7'Í' TVD ..i+4& Completion Date 3/11/2004"---- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional surv~ (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OHI . Scale Media No Start Stop CH Received Comments 9471 12220 Open 4/16/2004 EWR4, GR, ROP 4/16/2004 DSN 12547 9546 12270 3/25/2004 9546 12270 3/25/2004 MWD 9546 12270 3/25/2004 9546 12270 3/25/2004 MWD Sample Set Sent Received Number Comments DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES Well Log Information: Electr Dataset Number Name 12547 Induction/Resistivity LIS Verification Directional Survey Directional Survey Directional Survey Directional Survey D Pdf ED D Pdf Rpt Rpt L....- Well CoreslSamples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y I~ Daily History Received? QN Q/N . Chips Received? Analysis Received? - Y/N Formation Tops ~ Comments: ¡ij Date: J>~<p Compliance Reviewed By: · e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 1'31 ¡i RE: MWD Formation Evaluation Logs 18-14B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 18~14B: LAS Data & Digital Log Images: 50-029-21614-02 :lJ3~Ow3 1 CD Rom @IíQ~QJ~D 9'\9"21 I Olo 18-14B (PTD #2030630) Classified as Problem Well All, Z03-063 Well 18-14B (PTD #i~) has been found to have sustained casing pressure on the IA. The TIO's on 09/11/04 were 2380/2270/0. A TIFL Failed on 9/11/04. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GLV c/o 3. DHD: Re-TIFL A wellbore schematic has been included for reference. «18-14B.pdf» The well has been classified as a Problem well and may be produced until evaluation is complete. Please call if you have any questions. Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 Content-Description: 18-14B.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 9/22/2004 12:58 PM TREE = INELLHEA D = AClUATOR= KB. ELBI = BF. ELBI - KOP= IVI3x A ng Ie = Datum M) = Datum lVD= 7-1/16" FMC FMC BAKER C 47.7' 18-148 4500' 94@11865' 9159' 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I I TOP OF SCAB LNER I 3530' Minimum ID = 2.750" @ 9086' 3-112" HES X NIPPLE BOTTOM OF SCAB LNER 7-5/8" CSG, 29.7#, L-80, ID= 6.875" ÆRFORA 1l0N SlIvIMð.RY REF LOG: SPERRY -SUN WID / GR ON 03/01/04 ANGLE AT TOP PERF: 88@ 10880' Note: Refer to Production DB for historical perf data SIZE SF-F INlERVAL OpnlSqz IY\TE 2" 6 10880 - 11610 0 03/04/04 2" 6 11860 -12190 0 03/04/04 3-1/2"TBG, 9.3#, 13-CR, .0087 bpf, ID- 2.992" I 5-1/2" LNR, 17#, L-80, ID = 4.767" I I I I I I I ~ I 2-7/8" LNR, 6.5#, L-80, 10 = 2.387" H 10970' SAFETY NOTES: ORIGNAL W B.LBORE NOT SHOWN ON DIAGRAM. 3-112" CHROMETBG 2213' H3-1/2" HES SCSS RETRlEVABLEVLV, 10- 2.812" I GAS LFT Mð.NDRELS ST M) TVD DEV TYPE VLV LTŒI FORr DATE 3 3240 3240 1 KBG2-9 DOrÆ INT 16 03/16/04 2 5751 5606 39 KBG2-9 SO INT 20 03/16/04 1 8322 7509 39 KBG2-9 [)IIY INT 0 03/11/04 3537' 7-5/8" X 5-1/2" BKR ZXP LNR TOP A<R 8517' 7 -5/8" X 5-112" BKR H A<R, ID = 4.812" 9041' 9062' 9086' 9106' 9118' 5-1/2" X 3-112" BKRZXP LNR TOPPKR 3-1/2" I-ESX NP, ID=2.813" 3-1/2" HESX NP, ID=2.750" 3-1/2" WLEG, ID - 2.992" 9419' MlLLOUT WINDOW 9568' - 9581' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, 10 - 2.992" DATE REV BY COfvTv1ENTS 11/08/86 ORIGINAL COMPLETION 02/25/95 RIG SIDETRACK (18-14A) 04/01/95 CTO 2-7/8"SLTDLf'R 03/13/04 DAV/KA RIG SIDETRACK (18-14A) 03/16/04 JBfliVKAK GL V C/O IY\ TE REV BY COfvTv18'JTS FRUŒlOE BA Y UNIT W8.L 18-14B PERMIT No: 2030630 A PI No: 50-029-21614-02 SEe 19, T11 N, R15E, 4350' FSL & 4613' ÆL BPExploration (Alaska) e e WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 12, 2004 À()')-\J~ > RE: MWDFonnationEvaluationLogs 18-14B, AK-MW-2916013 1 LDWG fonnatted Disc with verification listing. ilPI#: 50-029-21614-02 t\ \).. f"l 7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: J JJ~ 1N~ S@lOO._~ {)UJ yt a I as Cons. n . . 1a. Well Status: r8I Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Clas"nChorag'b 20AAC 25,105 20AAC 25.110 r8I Development Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/11/2004 203-063 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/26/2004 50- 029-21614-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/29/2004 PBU 18-14B 4351' NSL, 4609' WEL, SEC. 19, T11N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 884' NSL, 3644' WEL, SEC. 19, T11 N, R15E, UM 46.4' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1496' NSL, 380' WEL, SEC. 24, T11 N, R14E, UM 12201 + 8748 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692104 y- 5960948 Zone- ASP4 12270 + 8746 Ft ADL 028307 TPI: x- 693171 y- 5957508 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 691452 y- 5958076 Zone- ASP4 2213' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey r8I Yes ONo NIA MSL 1900' (Approx.) 21. Logs Run: MWD, GR, RES 122. CASING, LINER AND CEMENTING RECORD i('~ ~~f~g~ . ::it:"TTIN$.DE¡PTtI MÖ $ETTINi;! 1f$f'TI-IT\fI) HOLE '·.i.,. ·.'.....,i..'·' W'T'.PER fT. ...··"...·,GlV\.oe .,., TOP.," I BoTTOM Top BOttOM SIZE 16" 62.5# H-40 Surface 115' Surface 115' 24" 1540 # Poleset 10-314" 45.5# J-55 I L-80 Surface 3452' Surface 3452' 13-112" 5"'200 sx CS III, 400 sx CS II 7-5/8" 29.7# L-80 Surface 8700' Surface 7806' 9-7/8" 300 sx Class 'G' 5-112" 15.5# L-80 3530' 8509' 3530' 7656' Liner Tieback 131 sx Class 'G', 286 sx Class 'G' 5-1/2" 17# NT -80 8415' 9568' 7661' 8443' 6-3/4" :>26 sx Class 'G' 3-1/2" 9.2# L-80 9413' 12269' 8338' 8746' 4-3/4" ")20 sx Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24. i i' '';'' 'i ,"i· .. Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 3-1/2",9.3#, 13Cr80 19Cr 9118' 9062' MD TVD MD TVD 10880' - 11610' 8750' - 8755' 25. Ahlr'i CEMENT 11860' - 12190' 8754' - 8748' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3240' Freeze Protect with 145 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 1, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO 4/6/2004 6.2 TEST PERIOD .. 270 934 3 53.71 3,459 Flow Tubing Casing Pressure CALCULATED .. Oil -BSL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) Press. 51C 1460 24-HoUR RATE 1,045 3,616 12 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit co~e,ehips;jfnol\e, state "none". f ~;;-i> "', APR 15 200~ None ~~Zd RBDMSBfL ~I'':i~r ¡ w:: ¡ rìDIf'"'lfI..! ^ I Form 10-407 Revised 12/2003 CONTIj¡jÓEÓ ðrJ ~JEAsfe 'Susm L ¡ . STATE OF ALASKA e ALASKA~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alask RECEIVED APR - 92004 O'I&G ',1 ~:' -'~ (; u\::.. 'I ~ ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Base CGL 9599' 8463' None 23SB 9759' 8555' 22TS 9792' 8571' 21TS 9931' 8625' Zone 1 B 10147' 8672' TDF 10448' 8729' Base Sadlerochit 11609' 8755' RECE\VED APR - 92004 A\asKa Oi\ & Gas Cons. Commission Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubbl Title Technical Assistant Date ()..( -0 PBU 18-14B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 203-063 Permit No. I A roval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 nD\h\ ~, AM 0:12:41 3/15/2004 Printed: .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/12/2004 00:00 - 02:00 2.00 MOB P PRE Rig released from H-05A @ 0000 hrs 2/12/2004. Finish rigging down. 02:00 - 15:00 13.00 MOB N WAIT PRE Phase 2 weather conditions. Roads and Pads to DS 18-14B are blocked with snow. WOW with full rig crews. 15:00 - 22:00 7.00 MOB P PRE Release from weather hold. Begin mobilizing 2ES to DS 18. 22:00 - 00:00 2.00 MOB N WAIT PRE On Standby with full crews at request of Fire Chief due to road from GC1 to GC2 not clear for fire access. 2/13/2004 00:00 - 01 :00 1.00 MOB N WAIT PRE Standby with full crews until road is cleared. 01 :00 - 09:30 8.50 MOB P PRE Release from standby. Move Sub to DS 18-14. Currently on the Oxbow near the gravel pit. 09:30 - 00:00 14.50 MOB N WAIT PRE CPS blew a transformer. It will have to be replaced prior to the rig moving under the powerlines @ the intersection of the Oxbow and the West Dock Road. They are not going to be able to replace it until the wind dies down. 2/14/2004 00:00 - 13:00 13.00 MOB N WAIT PRE CPS blew a transformer. It will have to be replaced prior to the rig moving under the powerlines @ the intersection of the Oxbow and the West Dock Road. They are not going to be able to replace it until the wind dies down. 13:00 - 15:00 2.00 MOB P PRE PJSM. Move Sub from Oxbow to DS 18. 15:00 - 19:30 4.50 MOB P PRE PJSM. Lay herculite. Spot Sub. Raise Derrick. RU Floor. 19:30 - 21 :00 1.50 MOB N WAIT PRE Wait on GC1 to GC2 road to be cleared for emergency access per Fire Chief prior to moving the camp and the pits. 21 :00 - 00:00 3.00 MOB P PRE Bridle Down. Berm Sub Prep Herculite for Pits and Cuttings Tank. 2/15/2004 00:00 - 06:00 6.00 RIGU P PRE Move and spot Pits, Shop and Camp. Spot Cuttings Tank. Berm in Cuttings Tank and Pits. Continue rigging up main unit. 06:00 - 08:00 2.00 RIGU P PRE Accept Rig @ 06002/15/2004. Work through Pre-Spud Checklist. Hold Pre-Spud meeting with all personnel 08:00 - 09:30 1.50 RIGU P PRE Install secondary annulus valve. RU lubricator and pull BPV. 600 psi on 4-1/2" x 7-5/8" annulus 09:30 - 11 :00 1.50 KILL P DECaMP RU to displace diesel from the well through the choke. 11 :00 - 15:00 4.00 KILL P DECaMP PJSM. Open well up to a closed choke - 660 psi on TBG and ANN. Circ 9.6 ppg brine @ 3 bpm, 600 psi taking returns to the cuttings tank. SI well. SIDPP - 360 psi, SICP - 380 psi. Blow down circulation lines. Mix 10.8 ppg Brine. 15:00 - 17:30 2.50 KILL P DECaMP Circ 10.8 ppg Brine to 2,270' while maintaining back pressure. SI well. SIDPP - 170 psi, SICP - 320 psi. 17:30 - 19:30 2.00 KILL P DECaMP Bullhead 10.8 ppg fluid to 6,100'. 2.5 bpm @ 840 psi. SI well. Bleed back 3 bbls. Monitor well for 15 min - dead. 19:30 - 21 :00 1.50 WHSUR P DECaMP Blow down surface equipment. Dry rod TWC and test from below. RD circulation lines. 21 :00 - 23:00 2.00 WHSUR P DECaMP ND tree and adapter flange. 23:00 - 00:00 1.00 BOPSU P DECaMP NU BOP's. 2/16/2004 00:00 - 03:30 3.50 BOPSU P DECaMP NU BOP's. 03:30 - 09:00 5.50 BOPSU P DECaMP Test BOP's. 250 psi low, 3,500 psi high. Witnessing of the test waived by Jeff Jones of the AOGCC. 09:00 - 11 :00 2.00 PULL P DECaMP RU lubricator and attempt to pull TWC. Unable to pull. RU hose from Annulus to Tubing. Close blinds and bleed off 300 psi - gained 3 bbls diesel. 11 :00 - 12:00 1.00 PULL P DECaMP Attempt to pull TWC - unable to pull. RD Lubricator and drain stack. 12:00 - 14:30 2.50 PULL P DECaMP Flush top ot TWC. RU lubricator. Pull TWC. Printed: 3/15/2004 10:12:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/16/2004 14:30 - 15:00 0.50 KILL P DECOMP RU circulation lines to choke. SICP - 90 psi, SITP - 90 psi. 15:00 - 16:00 1.00 KILL P DECOMP Circ through choke @ 3 bpm with 10.8 ppg brine to 2,270'. SI well. SICP - 170 psi, SITP - 90 psi 16:00 - 17:00 1.00 PULL P DECaMP RD DSM. MU landing joint. Back out LDS. Pull Hanger to the rig floor. Pulled free @ 160K. 17:00 - 17:30 0.50 KILL P DECaMP CBU - 6.5 bpm, 110 psi. Shut down. SI well. SITP - 140 psi, SICP - 240 psi. 17:30 - 22:00 4.50 KILL P DECOMP Monitor the well while mixing 12 ppg kill fluid. 22:00 - 22:30 0.50 KILL P DECOMP Open well. Circ 12 ppg brine through choke @ 3 bpm while maintaining back pressure. 22:30 - 00:00 1.50 KILL P DECOMP Monitor well. SITP - 30 psi, SICP - 30 psi. 2/17/2004 00:00 - 01 :00 1.00 KILL P DECaMP Monitor Bore Pressures Shut In Tubing Pressure At 30 psi - Shut In Casing Pressure At 30 psi. 01 :00 - 01 :30 0.50 KILL P DECaMP Circulate 12 PPG Brine Through Choke At 3 BPM While Maintaining 100 Psi. Back Pressure 01 :30 - 02:00 0.50 KILL P DECaMP Open Annular And Monitor Well - 10 BPH Static Loss Rate 02:00 - 03:30 1.50 PULL P DECOMP Rig Up Control Line Spooling Unit, Power Tongs And Tubing Equipment - Blow Down Surface Equipment - Lay Down FMC Tubing Hanger, Cross Overs And Landing Joint 03:30 - 07:00 3.50 PULL P DECaMP POH Laying Down 41/2" Tubing Completion Assembly From 2,270' (Top Of Fish) 'NOTE' Items Recovered During This Phase Of Decompletion: 1 Tubing Hanger And 2 Pups 52 Stainless Steel Bands 53 Joints Of 41/2" Tubing 1 SSSV With Pup Joints Top And Bottom 1 Cut Off Joint (No.54) 23.34' Long 07:00 - 07:30 0.50 PULL P DECaMP Rig Down Tubing Tongs And Equipment - Clear And Clean Rig Floor 07:30 - 08:00 0.50 WHSUR P DECaMP Install Wear Bushing And Energize Lock Down Studs 08:00 - 10:00 2.00 FISH P DECOMP Hold Pre-Job Safety Meeting - Rig Up Schlumberger Wire Line Services - Make Up Logging Tools 10:00 - 12:00 2.00 FISH P DECOMP Logging Run No.1 RIH With String Shot - Position And Fire String Shot From 8,409' To 8,421' - POH Lay Down Logging Tools 12:00 - 14:30 2.50 FISH P DECOMP Logging Run NO.2 RIH With Chemical Cutter To 8,420' - Tie In Log And Position Chemical Cutter At 8,420' WLM - POH With Logging Tools 14:30 - 15:30 1.00 FISH P DECOMP Break Down Chemical Cutter And Logging Tools - Rig Down Schlumberger Wire Line And Clear Rig Floor 15:30 - 16:00 0.50 FISH P DECaMP Pick Up Spear And Make Up Baker Fishing Tools To 21' 16:00 - 18:00 2.00 FISH P DECOMP RIH With Fishing Tools Picking Up 4" Drill Pipe From 21' To 2,262' 18:00 - 18:30 0.50 FISH P DECaMP Connect Top Drive And Establish Circulation - String Up And Down Weights At 65,000 Ibs. - Slack Off And Engage Top Of Fish At 2,279' Inserting Spear To 2,285' - Pick Up On Tubing String To 175,000 Ibs. Breaking Remainder Of Tubing Cut At 8,420' - Gain 60,000 Ibs. Of String Up Weight 18:30 - 20:00 1.50 PULL P DECaMP Circulate 11.0 PPG Brine At 3 BPM With 280 Psi. 20:00 - 20:30 0.50 PULL P DECOMP Monitor Well Bore Static Loss Rate At 10 BPH - Blow Down Top Drive 20:30 - 22:00 1.50 PULL P DECOMP POH With Fish (4 1/2" Tubing) Standing Back 4" Drill Pipe In Printed: 3/15/2004 10:12:52 AM .1 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 2/17/2004 20:30 - 22:00 1.50 PULL P DECOMP Mast From 8,420' To 6,150' - Lay Down Fishing Tools And Bottom Half Of Cut Off Joint No. 54 (Length At 18.19') 22:00 - 22:30 0.50 PULL P DECOMP Install Safety Valve - Rig Up 4 1/2" Tubing Handling Tools, Power Tongs And Equipment 22:30 - 00:00 1.50 PULL P DECOMP POH Laying Down 41/2" Tubing Completion Assembly From 6,150' 2/18/2004 00:00 - 04:00 4.00 PULL P DECOMP POH Laying Down 41/2" Tubing Completion Assembly From 6,150' *NOTE* Items Recovered During This Phase Of Decompletion: 146 Joints Of 4 1/2" Tubing 3 GLM With Pup Joints Top And Bottom 1 Cut Off Pup Joint 1.74' Long 04:00 - 05:00 1.00 PULL P DECOMP Rig Down Tubing Tongs And Equipment - Clear And Clean Rig Floor - Monitor Well Bore Static Loss Rate At 6 BPH 05:00 - 06:00 1.00 FISH P DECOMP Make Up Baker Fishing Tools - Pick Up Oil Jars, Bumper Sub, And Over Shot - Followed Up With (12) Steel Drill Collars, Acclerator Jars, (15) HWDP, And Cross Over To 866' 06:00 - 11 :00 5.00 FISH P DECOMP RIH With Baker Fishing Tools From 866' To 3,106' - Pick Up 4" Drill Pipe From 3,106' To 8,333' 11 :00 - 12:00 1.00 FISH P DECOMP Slip And Cut 102 Feet Of 1 1/4" Drilling Line 12:00 - 13:00 1.00 FISH P DECOMP Service Top Drive, Traveling Blocks, And Crown Sheaves 13:00 - 14:00 1.00 FISH P DECOMP RIH From 8,333' To 8,396' - Connect Top Drive And Establish Circulation At 3 BPM With 270 Psi. String Weight Up 165,000#, String Weight Down 140,000#, String Weight Rotating 150,000#, Torque Off Bottom 4,000 ft Ilbs - Tag Top Of Fish At 8,417' And Engage To 8,423' - Rotate Out "K" Anchor 14:00 - 17:00 3.00 FISH P DECOMP Monitor Well Bore - POH With Baker Fishing Tools From 8,423' To 865' 17:00 - 18:30 1.50 FISH P DECOMP Change Out Handling Equipment - Stand Back 31/2" HWDP- Lay Down Acclerator Jars - Stand Back 4 3/4" Drill Collars- POH With Oil Jars And Bumper Sub - Make Service Breaks On Over Shot And Lay Down 41/2" Tubing Cut Off Pup And "K" Anchor - Clear Rig Floor 18:30 - 20:00 1.50 FISH P DECOMP Make Up Packer Milling Assembly - Pick Up Float Sub, 3 Boot Baskets, Packer Mill, And Packer Retrieving Tool And RIH With Bumper Sub, Oil Jars, 4 3/4" Drill Collars - Pick Up Acclerator Jars And RIH With 3 1/2" HWDP And Cross Over To 876' 20:00 - 23:00 3.00 FISH P DECOMP RIH With Baker Packer Milling Assembly On 4" Drill Pipe From 876' To 8,343' - Break Circulation Every 3,000' 23:00 - 23:30 0.50 FISH P DECOMP Break Circulation - Install Top Drive Blower Hose - Record Slow Pump Rates - Blow Thru Choke Line And Choke Manifold - Tag Baker SABL-3 Packer At 8,426' 23:30 - 00:00 0.50 FISH P DECOMP Mill Baker Packer At 8,426' 2/19/2004 00:00 - 03:00 3.00 FISH P DECOMP Mill Baker SABL-3 Packer From 8,426' To 8,430' WOM Rotating 4,000# - 18,000#, RPM 70 To 85, Torque Off Bottom 4,200 ft Ilbs - On Bottom 5,000 ft Ilbs To 7,800 ftllbs, Pump Rate 195 gpm, SPP Off Bottom 1,010 psi, On Bottom 1,080 psi. String Weight Up 160,000#, String Weight Down 140,000#, String Weight Rotating 150,000# - Push Packer Down Hole To 8,455' Placing Tail Pipe WLEG At 8,512' Printed: 3/15/2004 10:12:52 AM .l Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 2/19/2004 00:00 - 03:00 3.00 FISH P DECaMP 'NOTE' Top Of Baker C-2 Tie BAck Sleeve At 8,509' With WLEG Pushed 3' Inside 03:00 - 04:45 1.75 FISH P DECaMP Circulate Hi-Vis Sweep Around At 5 BPM With 1,030 Psi. 04:45 - 05:00 0.25 FISH P DECaMP Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment - Remove Top Drive Blower Hose 05:00 - 08:30 3.50 FISH P DECaMP POH With Baker Fishing Tools And Possible Baker Packer With Tail Pipe From 8,455' To 877' 'NOTE' String Pulled 20,000 Ib Over At 8,444' 08:30 - 10:00 1.50 FISH P DECaMP Change Out Handling Equipment - Stand Back 31/2" HWDP - Lay Down Acclerator Jars - Stand Back 4 3/4" Drill Collars - POH With Oil Jars And Bumper Sub - Make Service Breaks On 3 Boot Baskets, Packer Mill, Packer Retrieving Tool - No Packer Or Fish Recovered - Lay Down Boot Baskets And Dump Recovered Approximately 50 Lbs. Of Metal From Milling Operation - Clear Rig Floor 10:00 - 10:30 0.50 FISH P DECaMP Service Top Drive And Traveling Blocks 10:30 - 12:00 1.50 FISH P DECaMP Make Up Spear Assembly - Pick Up Spear With 3.885 Grapple And Extension, RIH With Float Sub, Pump Out Sub, Bumper Sub, Oil Jars, 4 3/4" Drill Collars - Pick Up Acclerator Jars And RIH With 31/2" HWDP And Cross Over To 870' 12:00 - 15:00 3.00 FISH P DECaMP RIH With Baker Spear Assembly On 4" Drill Pipe From 870' To 8,430' - Break Circulation Every 3,000' 15:00 - 16:30 1.50 FISH P DECaMP RIH From 8,430' To 8,460' - Connect Top Drive And Establish Circulation At 4.2 BPM With 650 Psi. String Weight Up 162,000#, String Weight Down 140,000# - Set Down 40,000 Ibs On Fish Several Times To Engage - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment 16:30 - 20:00 3.50 FISH P DECaMP POH With Baker Fishing Tools And Possible Baker Packer With Tail Pipe From 8,460' To 870' 20:00 - 21 :30 1.50 FISH P DECaMP Change Out Handling Equipment - Stand Back 31/2" HWDP- Lay Down Acclerator Jars - Stand Back 4 3/4" Drill Collars - POH With Oil Jars, Bumper Sub, Pump Out Sub, Float Sub, And Spear - No Packer Or Fish Recovered - Clear Rig Floor 'NOTE' No Apparent Signs That Spear Was Inside Of Fish - Slight Markings On Bottom Of Spear 21 :30 - 23:15 1.75 FISH P DECaMP Make Up Spear Assembly With Cut Rite Bull Nose - Pick Up Spear With 3.885 Grapple Add Longer Extension, RIH With Float Sub, Pump Out Sub, Bumper Sub, Oil Jars, 4 3/4" Drill Collars - Pick Up Acclerator Jars And RIH With 3 1/2" HWDP And Cross Over To 872' 23:15 - 00:00 0.75 FISH P DECaMP RIH With Baker Spear Assembly (No.2) On 4" Drill Pipe From 872' To 2,738' 2/20/2004 00:00 - 02:30 2.50 FISH P DECaMP RIH With Baker Spear Assembly (No.2) On 4" Drill Pipe From 2,738' To 8,430' 02:30 - 03:30 1.00 FISH P DECaMP RIH From 8,430' To 8,460' - Connect Top Drive And Establish Circulation At 4.2 BPM With 650 Psi. String Weight Up 165,000#, String Weight Down 140,000# - String Weight Rotating 155,000# - Observe Bull Nose Going Into Top Of Packer To 8,468' Stack Weight With Pump Preassure Increasing - Engage Fish With Pick Up Weight To 200,000# Printed: 3/15/2004 10:12:52 AM " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/20/2004 02:30 - 03:30 1.00 FISH P DECaMP Grapple Appears To Be Slipping Of Fish - Set Down 40,000 Ibs On Fish Several Times And Re-Engage - Trip Jars At 185,000# And Pull Up To 235,000# Before Grapple Released - Set Back Down Several Times And Re-Engage Fish - Trip Jars At 175,000# And Pull Up To 250,000# Before Grapple Appears To Release - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment 03:30 - 07:00 3.50 FISH P DECaMP POH With Baker Spear Assembly (No.2) On 4" Drill Pipe From 8,468' To 872' 07:00 - 09:00 2.00 FISH P DECOMP Change Out Handling Equipment - Stand Back 31/2" HWDP - Lay Down Acclerator Jars - Stand Back 4 3/4" Drill Collars - POH With Oil Jars, Bumper Sub, Pump Out Sub, Float Sub, And Spear - Lay Down Fish (Packer And Tail Pipe OAL 55.20') - Clear Rig Floor 09:00 - 10:30 1.50 CLEAN P DECaMP Make Up Polish Mill Assembly - Pick Up Baker Polish Mill, Cross Over, (3) Boot Baskets, RIH With Float Sub, Bumper Sub, Oil Jars, 4 3/4" Drill Collars - Pick Up Acclerator Jars And RIH With 3 1/2" HWDP And Cross Over To 873' 10:30 - 14:00 3.50 CLEAN P DECaMP RIH With Baker Polish Mill Assembly On 4" Drill Pipe From 873' To 8,495' - Break Circulation Every 3,000' - Install Top Drive Blower Hose 14:00 - 14:30 0.50 CLEAN P DECaMP Polish Baker C-2 Tie Back Sleeve From 8,509' To 8,515' WOM Rotating 2,000# - 5,000#, RPM 70, Torque Off Bottom 4,200 ft Ilbs - On Bottom 5,000 ft Ilbs To 7,800 ftllbs, Pump Rate 195 gpm, SPP Off Bottom 1,010 psi, On Bottom 1,080 psi. String Weight Up 160,000#, String Weight Down 140,000#, String Weight Rotating 150,000# - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment *NOTE* Top Of Baker C-2 Tie Back Sleeve At 8,509' 14:30 - 17:30 3.00 CLEAN P DECOMP POH Laying Down 4" Drill Pipe From 8,515' To 3,734' 17:30 - 18:30 1.00 CLEAN P DECOMP Slip And Cut 100 Feet Of 1 1/4" Drilling Line - Service Crown Sheaves 18:30 - 20:30 2.00 CLEAN P DECOMP POH With Baker Polish Mill Assembly Standing Back 4" Drill Pipe From 3,734' To 873' 20:30 - 22:00 1 .50 CLEAN P DECaMP Lay Down BHA - Lay Down Cross Over, And (15) Joints 31/2" HWDP - Stand Back 4 3/4" Steel Drill Collars -Inspect Polish Mill Verify That Brass On No Go Worn Down - Lay Down Polish Mill, Cross Over, Casing Scraper, (3) Boot Baskets, Float Sub, Bumper Sub, And Oil Jars - Very Little Iron Recovered In Boot Baskets - Clear Rig Floor 22:00 - 00:00 2.00 DHB P DECaMP Hold Pre-Job Safety Meeting - Rig Up Schlumberger Wire Line Services - Make Up Logging Tools - Logging Run NO.1 RIH With CCL- 4.74 Gauge Ring And Junk Basket 2/21/2004 00:00 - 02:00 2.00 DHB P DECOMP Continue With Logging Run No.1 RIH With CCL- 4.74 Gauge Ring And Junk Basket To 9,300' With Out Any Problems Taking Weight - Pick Up And Work Junk Basket To 9,500' Taking Weight And Getting Sticky - POH - Clean Out Junk Basket Recovered Metal And Scale From Pipe 02:00 - 04:00 2.00 DHB P DECaMP Logging Run No.2 RIH With CCL- 4.65 Gauge Ring And Junk Basket To 9,750' With Out Any Problems - POH - Clean Out Junk Basket Recovered Metal Rings And Scale From Pipe - , Basket Had Approximately 2 Gallons Of Material Printed: 3/15/2004 10:12:52 AM " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-1 4 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 2/2112004 04:00 - 05:30 1.50 DHB P DECaMP Logging Run NO.3 RIH With CCL- 4.65 Gauge Ring And Junk Basket To 9,700' With Out Any Problems - POH - Clean Out Junk Basket Recovered Very Little Metal - Scale From Pipe - Basket Had Approximately 1/2 Gallon Of Material 05:30 - 06:30 1.00 DHB P DECaMP Lay Down Junk Basket And Gauge Ring - Change To Larger CCL And Make Up Logging Tools With Haliburton EZSV 06:30 - 08:30 2.00 DHB P DECaMP Logging Run No.4 RIH With CCL-CPST And Haliburton EZSV Packer To 9,700' - Locate Collars Logging Up And Reconfirm Setting Depth - Set Top Of EZSV At 9,596' WLM - Log Up 100 Feet - RIH Tag EZSV Confirm Setting Depth - POH With Logging Tools 08:30 - 09:00 0.50 DHB P DECaMP Rig Down Schlumberger Wire Line And Clear Rig Floor 09:00 - 09:30 0.50 DHB P DECaMP Make Up Mule Shoe And RIH With 4 3/4" Steel Drill Collars- Make Up Haliburton RTTS And By Pass Tools To 376' 09:30 - 11 :30 2.00 DHB P DECaMP RIH With Drill Collars And Haliburton RTTS From 376' To 4,015' - Set RTTS At 3,647' 11 :30 - 13:00 1.50 DHB P DECaMP Circulate Thru Kill Line Close Upper Pipe Rams Test 7 5/8" Casing X 4" HT-40 Drill Pipe At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) - Bleed Pressure To 0 Psi. - Open Top Pipe Rams - Pick Up And Release RTTS - Pump Dry Job And Blow Down Surface Equipment - Drop Rabbit 13:00 - 14:30 1.50 DHB P DECOMP POH With Haliburton RTTS Tools From 4,015' To 376'- Retrieve Rabbit 14:30 - 16:00 1.50 DHB P DECOMP Lay Down Cross Over, By Pass Tool, RTTS, (12) 4 3/4" Steel Drill Collars, And Mule Shoe - Clear And Clean Rig Floor 16:00 - 17:00 1.00 CASE P DECaMP Rig Up Power Tongs - Casing Tools And Equipment 17:00 - 23:30 6.50 CASE P DECaMP Pick Up And RIH With Tie Back Seal Assembly - Baker Lock Connections To Insert Landing Collar Pin End On Joint No.2 - Verify Ported Float By Passing Some Fluid - RIH With 122 Full Joints And 2 Short Joints Of 51/2" BTC 15.5 lb. L-80 Casing To 4,958' - Make Up To Mark Torqued To 4,500 ftllbs. 23:30 - 00:00 0.50 CASE P DECaMP Change Out Handling Equipment To 31/2" DP Elevators - M I U Baker Flex Lock Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment P / U Cross Over, (1) 4" Drill Pipe Pup Joint, RIH w/1 Stand 4" Drill Pipe From Mast To 5,095' 2/22/2004 00:00 - 00:45 0.75 CASE P DECOMP Circulate 5 1/2" Liner Volume At 5 BPM With 360 Psi. - Recorded Liner Weight At 93,000 Ibs. - Rig Down Power Tongs Casing Tools And Equipment - Clear Rig Floor 00:45 - 02:00 1.25 CASE P DECaMP RIH With 51/2" BTC 15.5 lb. L-80 Liner On 4" Drill Pipe From 5,095' To 8,480' - Fluids Out Of Balance Coming Up Drill Pipe Thru Ported Float 02:00 - 03:00 1.00 CASE P DECaMP Pick Up (2) 4" Drill Pipe Singles And Baker Cement Head - Instal1 Manifold And Circulating Lines - Establish Circulation At 4.5 BPM With 600 Psi And Ful1 Returns - Shut Down Pumps Slack Off To "No Go" Working Mule Shoe And Seal Assembly Into Baker C-2 Tie Back Sleeve At 8,509' - Pressure Up To 500 Psi. - Unsting Seals From Tie Back Sleeve To Expose Circulating Ports - Circulate At 4.5 BPM With 600 Psi. 03:00 - 06:00 3.00 CASE P DECaMP Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Prime Up Pumps - Pump 5 BBLS Water - Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Pump 25 BBLS 11.6 PPG Mud Push, Printed: 3/15/2004 10:12:52 AM ,( legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 2/22/2004 03:00 - 06:00 3.00 CASE P DECaMP 42 BBLS (131 Sacks) 13.5 PPG Class "G" Lead Cement At 4.0 BPM - Followed With 59 BBLS (285 Sacks) 15.8 PPG Class "G" Tail Cement At 4.0 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 10.9 PPG Brine At 6.2 BPM With 206 Psi. - Slow Rate And Latch Liner Wiper Plug With 35.5 BBLS Pumped Away - Increase Rate To 6.2 BPM Continue To Displace - Slow Rate To 2.0 BPM With Final Circulating Pressure At 1,150 Psi. - Bump Plug With A Total Of 150.5 BBLS Pumped Slack Off And Sting Seals Into C-2 Tie Back Sleeve - Bleed Off Pressure And Verify Seals Holding (Seals Held) - Cement In Place At 05:12 Hours Increase Pressure To 2,800 Psi. To Set Baker Flex Lock Liner Hanger - Increase Pressure To 4,200 Psi. To Set Baker ZXP Liner Top Packer- Bleed Off Pressure Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Circulate Bottoms Up At Maximum Rate 11.7 BPM With 2,290 Psi. - Estimated Cement To Surface At 8 BBLS. - Top Of Liner At 3,529', Insert Landing Collar At 8,487', Float Valve At 8,491', Tie Back Seal Assembly From 8,509' To 8,515' 06:00 - 07:00 1.00 CASE P DECOMP Pump Dry Job And Blow Down Surface Equipment - Break Down Cement Circulating Lines And Lay Down Baker Cementing Head 07:00 - 08:30 1.50 CASE P DECaMP POH With Baker 5 1/2" Liner Running Tool From 3,530' - Lay Down Running Tool And Clear Rig Floor 08:30 - 09:00 0.50 BOPSU P DECaMP Pull Wear Bushing And Flush Area - Install Wear Bushing And Energize Lock Down Studs 09:00 - 09:30 0.50 CLEAN P DECaMP Service Top Drive And Traveling Blocks 09:30 - 11 :00 1 .50 CLEAN P DECOMP Load Drill Pipe And BHA Into Pipe Shed And Bring Handling Tools And Cross Over Subs To Rig Floor - Rig Up Power Tongs And Equipment For Handling Clean Out BHA 11 :00 - 14:30 3.50 CLEAN P DECOMP Make Up Slim Hole Tools - Pick Up Mud Motor With Float And 43/4" Mill, Pump Out Sub, (1) 3 3/8" Steel Drill Collar - Make Up Cross Overs And 4 3/4" String Mill - Pick Up (5) Steel Drill Collars, Cross Overs, Drilling Jars, (6) Steel Drill Collars To 397' 14:30 - 00:00 9.50 CLEAN P DECOMP Pick Up 2 7/8" Drill Pipe From 397' To 7,017' - Displace Drill String Every 30 Joints 2/23/2004 00:00 - 01 :45 1.75 CLEAN P DECOMP Pick Up 2 7/8" Drill Pipe From 7,017' To 8,374' - Displace Drill String Every 30 Joints - Install Top Drive Blower Hose 01 :45 - 02:00 0.25 CLEAN P DECOMP As Precaution Wash From 8,374' Tag Cement Stringers At 8,457' - Clean Out To 8,469' 02:00 - 02:30 0.50 CLEAN P DECOMP Verify Compressive Strength Of Cement Above 1,000 Psi. - Test 7 5/8" Casing, 5 1/2" Liner Top Packer, And 5 1/2" Casing At 3,500 Psi. Record On Circle Chart For 10 Minutes (Test Good) 02:30 - 06:30 4.00 CLEAN P DECOMP Displace Well Bore To Seawater While Drilling Cement And Float Equipment - Drill Cement From 8,469' To 8,477' - Drill Baker Liner Wiper Plug - Drill Cement From 8,479' To Baker Insert Landing Collar At 8,486' - Drill Insert Landing Collar To 8,487' And Cement From 8,487' To Float Valve At 8,489' - Drill Cement From 8,490' And Clean Out To 8,562' - Work String Mill Thru Area From 8,562' To 8,469' Repeat Process Several Printed: 3/15/2004 10:12:52 AM "- I. . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/23/2004 02:30 - 06:30 4.00 CLEAN P DECOMP Times - WOM Rotating 5,000# - 10,000#, RPM 30, Motor RPM 128, Torque Off Bottom 1,000 ft Ilbs - On Bottom 2,000 ft Ilbs, Pump Rate 150 gpm, SPP Off Bottom 1,600 psi, On Bottom 1,940 psi. String Weight Up 107,000#, String Weight Down 95,000#, String Weight Rotating 102,000# 06:30 - 08:30 2.00 CLEAN P DECaMP POH Stand Back 2 Stands Of 4" Drill Pipe And Remove Cross Over From 8,562' To 8,374' - Change Handling Equipment For 27/8" Drill Pipe - Pick Up 2 7/8" Drill Pipe From 8,374' Tag Haliburton EZSV At 9,584' 08:30 - 09:30 1.00 CLEAN P DECaMP Test 7 5/8" Casing, 5 1/2" Liner Top Packer, And 5 1/2" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) - Blow Down Kill Line 09:30 - 11 :00 1.50 CLEAN P DECaMP Drop Ball Open Circulation Sub And Displace Well To 8.6 PPG Flo-Pro SF Mud System At 6.5 BPM With 3,700 Psi. 11 :00 - 11 :30 0.50 CLEAN P DECaMP Pump Dry Job And Blow Down Surface Equipment - Remove Blower Hose - POH With 4" Drill Pipe From 9,584' To 9,095' 11 :30 - 12:00 0.50 CLEAN P DECaMP Change Out Handling Equipment For 2 7/8" Drill Pipe - Rig Up Power Tongs 12:00 - 16:00 4.00 CLEAN P DECaMP POH With 2 7/8" Drill Pipe From 9,095' To 397' 16:00 - 18:00 2.00 CLEAN P DECaMP POH Laying Down BHA From 397' - Lay Down (12) 31/2" Steel Drill Collars, Cross Overs, Drilling Jars, String Mill, Pump Out Sub, And Mud Motor - Clear Rig Floor 18:00 - 18:30 0.50 BOPSU P WEXIT Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment 18:30 - 21 :30 3.00 BOPSU P WEXIT Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment 21 :30 - 22:00 0.50 BOPSU P WEXIT Pull Test Plug - Install Wear Bushing And Energize LDS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor 22:00 - 00:00 2.00 STWHIP P WEXIT Rig Up Power Tongs - Make Up Whipstock Assembly - Pick Up 1 Steel Drill Collar Make Up Cross Over, Upper Mill, And Starter Mill - RIH Make Up Float Sub, And MWD Tools - Install Pulser Orient And Surface Test At 120 GPM With 500 Psi. 2/24/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT Pick Up Slide And Whipstock Trip Anchor Attach With 25,000 lb. Brass Lug Bolt - Pick Up Bumper Sub, Pump Out Sub, (11) Steel Drill Collars, And Cross Over To 432' 01 :30 - 02:00 0.50 STWHIP P WEXIT Change Out Handling Equipment For 27/8" Drill Pipe 02:00 - 07:00 5.00 STWHIP P WEXIT RIH With Whipstock And Milling Assembly On 2 7/8" Drill Pipe From 432' To 9,134' - Fill Drill String Every 3,000' And Check MWD Tools 07:00 - 07:30 0.50 STWHIP P WEXIT Install Cross Over - Change Out Handling Equipment For 4" Drill Pipe 07:30 - 08:00 0.50 STWHIP P WEXIT RIH With Whipstock And Milling Assembly On 4" Drill Pipe From 9,134' To 9,510' 08:00 - 08:30 0.50 I STWHIP P WEXIT Break Circulation Record Slow Pump Rates - String Weight Up 110,000#, String Weight Down 100,000# - Worked String From 9,510' To 9,550' To Orient Whipstock Slacked Off And Tripped Anchor With 15,000# - Tagged Bridge Plug With Bottom Of Whipstock At 9,584' Set At 74 Degrees Right Of Printed: 3/15/2004 10:12:52 AM '. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/24/2004 08:00 - 08:30 0.50 STWHIP P WEXIT High Side - Picked Up On String 10,000# Above Neutral Weight to Verify That Whipstock Set - Slacked Off To 25,000# Sheared Retaining Bolt 08:30 - 16:00 7.50 STWHIP P WEXIT Milled Window in 5-1/2" Casing From 9,568' To 9,579' (Unable To Reach Desired Depth) WOM 5,000# - 8,000#, Pump Rate 147 GPM, 1,750 Psi. RPM 60 To 100, Torque 3,000 It Ilbs - 4,000 ftllbs. String Weight Up 110,000#, String Weight Down 100,000#, String Rotating Weight 102,000# 16:00 - 17:00 1.00 STWHIP P WEXIT Drop Ball And Open Circulating Sub - Circulate Hi-Vis Sweep At 11.7 BPM With 3,800 Psi 17:00 - 17:30 0.50 STWHIP P WEXIT Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive - Remove Blower Hose - Lay Down 1 Joint Of 4" Drill Pipe 17:30 - 18:00 0.50 STWHIP P WEXIT POH With 4" Drill Pipe From 9,548' To 9,510' - Change Out Handling Tools And Equipment For 2 7/8" Drill Pipe - Rig Up Power Tongs 18:00 - 21 :00 3.00 STWHIP P WEXIT POH With 2 7/8" Drill Pipe From 9,510' To 432' 21 :00 - 23:00 2.00 STWHIP P WEXIT POH Laying Down BHA From 432' - Lay Down Cross Over, (11) 3 1/2" Steel Drill Collars, Pump Out Sub, Bumper Sub, MWD Tools, And Float Sub - POH With 1 Steel Drill Collar, Cross Over, Upper Mill, And Starter Mill - Remove Upper Mill And Starter Mill - Clear Rig Floor 23:00 - 00:00 1.00 STWHIP P WEXIT Pick Up Whipstock Milling Assembly NO.2 - Make Up Starter Mill And String Mill, RIH With Cross Over Sub And 1 Steel Drill Collar, Pick Up Float Sub, Circulating Sub, (11) Steel Drill Collars, And Cross Over To 364' 2/25/2004 00:00 - 00:30 0.50 STWHIP P WEXIT Change Out Handling Equipment For 2 7/8" Drill Pipe 00:30 - 03:00 2.50 STWHIP P WEXIT RIH With Window Milling Assembly On 2 7/8" Drill Pipe From 364' To 9,065' - Fill Drill String Every 3,000' 03:00 - 03:30 0.50 STWHIP P WEXIT Install Cross Over - Change Out Handling Equipment For 4" Drill Pipe 03:30 - 04:00 0.50 STWHIP P WEXIT RIH With Milling Assembly On 4" Drill Pipe From 9,065' To 9,568' 04:00 - 10:30 6.50 STWHIP P WEXIT Top Of Whipstock Window At 9,568' - Bottom Of Previous Mill Run At 9,579' - Ream Out Previous Milled Section From 9,568' To 9,579' - Mill Window In 5-1/2" Casing From 9,579' to 9,581'- WOM 5,000# - 15,000#, Pump Rate 147 GPM, 1,300 Psi. RPM 60 To 90, Torque 3,000 It I Ibs - 4,500 ftIlbs. String Weight Up 115,000#, String Weight Down 105,000#, String Rotating Weight 110,000# 10:30 - 11 :00 0.50 STWHIP P WEXIT Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 11 :00 - 11 :30 0.50 STWHIP P WEXIT POH With 4" Drill Pipe From 9,581' To 9,065' - Remove Blower Hose 11 :30 - 12:00 0.50 STWHIP P WEXIT Change Out Handling Tools And Equipment For 27/8" Drill Pipe - Rig Up Power Tongs 12:00 - 16:00 4.00 STWHIP P WEXIT POH With 2 7/8" Drill Pipe From 9,510' To 364' 16:00 - 17:30 1.50 STWHIP P WEXIT POH Laying Down BHA From 364' - Lay Down Cross Over, (11) 3 1/2" Steel Drill Collars, Circulating Sub, Float Sub, (1) 3 1/2" Steel Drill Collar, Cross Over, Upper Mill, And Starter Mill - Clear Rig Floor "NOTE" Upper Mill Full Gage At 4 3/4" O.D. Printed: 3/15/2004 10:12:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/25/2004 17:30 - 18:00 0.50 STWHIP P WEXIT Service Top Drive And Traveling Blocks 18:00 - 18:30 0.50 STWHIP P WEXIT Pick Up Window Milling Assembly No.3 - Make Up 4 3/4" Diamond High Speed Mill, String Mill, Cross Over Sub, Sperry Drill Mud Motor, Float Sub, Cross Over, Drilling Jars, Cross Over Sub, Circulating Sub, And Cross Over To 40' 18:30 - 19:00 0.50 STWHIP P WEXIT Change Out Handling Equipment For 27/8" Drill Pipe 19:00 - 22:30 3.50 STWHIP P WEXIT RIH With Window Milling Assembly No.3 On 2 7/8" Drill Pipe From 40' To 8,742' - Fill Drill String Every 2,000' 22:30 - 23:00 0.50 STWHIP P WEXIT Install Cross Over - Change Out Handling Equipment For 4" Drill Pipe 23:00 - 23:30 0.50 STWHIP P WEXIT RIH With Milling Assembly On 4" Drill Pipe From 8,742' To 9,550' - Recorded Slow Pump Rates 23:30 - 00:00 0.50 STWHIP P WEXIT RIH To Top Of Whipstock Window At 9,568' - Bottom Of Previous Mill Run At 9,581' - Ream Out Previous Milled Section From 9,568' To 9,581' - WOM 2,000# - 3,000#, RPM 5 To 10, Motor RPM 240, Torque Off Bottom 1,475 ft I Ibs - On Bottom 2,300 ft Ilbs, Pump Rate 175 gpm, SPP Off Bottom 1,830 psi, On Bottom 2,050 psi. String Weight Up 120,000#, String Weight Down 105,000#, String Weight Rotating 110,000# 2/26/2004 00:00 - 04:00 4.00 STWHIP P WEXIT Milled Window in 5-1/2" Casing To 9,581' - Exited Window Continued To Mill Formation From 9,581' To 9,594' - WOM 2,000# - 10,000#, RPM 5 To 10, Motor RPM 240, Torque Off Bottom 1,475 ft Ilbs - On Bottom 2,300 ft Ilbs, Pump Rate 175 gpm, SPP Off Bottom 1,830 psi, On Bottom 2,050 psi. String Weight Up 120,000#, String Weight Down 105,000#, String Weight Rotating 110,000# *NOTE* Top Of Window 9,568' Bottom Of Window 9,581' 04:00 - 04:30 0.50 STWHIP P WEXIT Pulled BHA Into Casing To 9,520' - Closed Upper Pipe Rams and Preformed FIT Strokes Pmp'd Pressure 2 70 psi 4 160 psi 6 270 psi 8 390 psi 10 510 psi 12 610 psi 13 660 psi Held Test F/10 minutes wI 30 psi Pressure Loss. MW 8.5 ppg, Window TVD 8,442' Pressure 657 psi = 10.00 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams 04:30 - 05:30 1.00 STWHIP P WEXIT Drop Ball And Open Circulating Sub - Circulate Hi-Vis Sweep At 9.6 BPM With 3,640 Psi - Remove Top Drive Blower Hose 05:30 - 06:00 0.50 STWHIP P WEXIT Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive - POH With 4" Drill Pipe From 9,520' To 8,741' 06:00 - 06:30 0.50 STWHIP P WEXIT Change Out Handling Tools And Equipment For 2 7/8" Drill Pipe - Rig Up Power Tongs 06:30 - 09:00 2.50 STWHIP P WEXIT POH With 2 7/8" Drill Pipe From 8,741' To 40' 09:00 - 09:30 0.50 STWHIP P WEXIT Flush And Lay Down Window Milling Assembly - Lay Down Cross Over Sub, Circulating Sub, Cross Over Sub, Drilling Printed: 3/15/2004 10:12:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/12/2004 3/11/2004 Jars, Cross Over Sub, And Float Sub - Remove Diamond High Speed Mill And String Mill - Lay Down Mud Motor 09:30 - 10:30 1.00 WEXIT Pull Wear Bushing And Flush Area - Install Wear Bushing And Energize Lock Down Studs - Clear Rig Floor 10:30 - 12:30 2.00 STWHIP P WEXIT Pick Up 4 3/4" Directional Assembly BHA NO.5 - Pick Up Sperry Sun Mud Motor And Make Up 4 3/4" Hughes STX 20DX Insert Bit - Pick Up Float Sub, Cross Over Sub, And MWDILWD Tools - Orient And Initialize MWDILWD Tools - Pick Up Cross Over Sub, And (2) Flex Drill Collars - Surface Test Sperry Sun Equipment (Test Good) - Pick Up Cross Over Sub, Daily Up Only Jars, Cross Over Sub, Circulating Sub, And Cross Over Sub To 142' 12:30 - 13:00 0.50 STWHIP P WEXIT Change Out Handling Equipment For 27/8" Drill Pipe 13:00 - 16:30 3.50 STWHIP P WEXIT RIH With Directional BHA NO.5 On 2 7/8" Drill Pipe From 142' To 8,843' - Fill Drill String And Test MWD Tools Every 2,000' 16:30 - 17:30 1.00 STWHIP P WEXIT Install Cross Over - Cut And Slip 87 Feet 1 1/4" Drilling Line - Service Crown Sheaves 17:30 - 18:00 0.50 STWHIP P WEXIT Change Out Handling Equipment For 4" Drill Pipe 18:00 - 18:30 0.50 STWHIP P WEXIT RIH With Directional BHA NO.5 On 4" Drill Pipe From 8,843' To 9,550' 18:30 - 18:45 0.25 STWHIP P WEXIT Record Slow Pump Rates - Orient Directional Tool Face To 70 Degrees Right Of High Side - Shut Down Mud Pumps And Slide Thru Whipstock Window From 9,568' To 9,581' With No Problems - Slack Off To 9,590' Establish Circulation - Wash To 9,594' 18:45 - 00:00 5.25 DRILL P PROD1 Drilled 4 3/4" Directional Hole By Rotating And Sliding From 9,594' to 9,780' WOB Rotating 7,000# - 12,000#, WOB Sliding 5,000# To 18,000#, RPM 30, Motor RPM 128, Torque Off Bottom 2,000 ft I Ibs - On Bottom 3,000 ft Ilbs, Pump Rate 147 gpm, SPP Off Bottom 2,080 psi, On Bottom 2,300 psi. String Weight Up 120,000#, String Weight Down 105,000#, String Weight Rotating 110,000# - ART = 1.52 hrs. - AST = 2.48 hrs. 2/27/2004 00:00 - 00:30 0.50 DRILL P PROD1 Take 12 Cassandra Surveys For JORPS Compliance 00:30 - 10:00 9.50 DRILL P PROD1 Drilled 4 3/4" Directional Hole By Rotating And Sliding From 9,780' to 10,075' WOB Rotating 7,000# - 12,000#, WOB Sliding 5,000# To 18,000#, RPM 30, Motor RPM 128, Torque Off Bottom 2,000 ft Ilbs - On Bottom 3,000 ft Ilbs, Pump Rate 147 gpm, SPP Off Bottom 2,080 psi, On Bottom 2,300 psi. String Weight Up 120,000#, String Weight Down 105,000#, String Weight Rotating 110,000# - ART = 1.81 hrs. - AST = 4.9 hrs. 10:00 - 10:30 0.50 DRILL P PROD1 Circulate 10 Minutes - Load Sweep In Drill String - Monitor Well Bore (Static) - Blow Down Top Drive - POH With 4" Drill Pipe From 10,075' To 9,600' 10:30 - 11 :00 0.50 DRILL P PROD1 Madd Pass For Tie In Log At 300 FPH From 9,600' To 9,500' 11 :00 - 12:00 1.00 DRILL P PROD1 Drop Ball And Open Circulating Sub - Circulate Hi-Vis Sweep At 7.2 BPM With 3,040 Psi - Remove Top Drive Blower Hose - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive 12:00 - 12:30 0.50 DRILL P PROD1 POH With 4" Drill Pipe From 9,500' To 8,845' 12:30 - 13:00 0.50 DRILL P PROD1 Change Out Handling Tools And Equipment For 2 7/8" Drill Pipe - Rig Up Power Tongs Printed: 3/15/2004 10:12:52 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 4 18-14B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/27/2004 13:00 - 16:00 3.00 DRILL P PROD1 POH With 2 7/8" Drill Pipe From 8,845' To 142' 16:00 - 18:00 2.00 DRILL P PROD1 Lay Down Directional BHA NO.5 - Lay Down Cross Over Sub, Circulating Sub, Cross Over Sub, Daily Jars, Cross Over Sub, (2) Flex Drill Collars, And Cross Over Sub - Down Load MWDILWD Data - Lay Down MWD Tools, Cross Over Sub, Float Sub, And Sperry Sun Mud Motor - Clear Rig Floor 18:00 - 19:30 1.50 DRILL P PROD1 Pick Up Directional BHA No.6 - Pick Up Sperry Sun Mud Motor With Smith 4 3/4" MDT285QYPX PDC Bit - Pick Up Float Sub, Cross Over Sub, And MWDILWD Tools - Orient And Initialize MWDILWD Tools - Pick Up Cross Over Sub, And (2) Flex Drill Collars - Surface Test Sperry Sun Equipment (Test Good) - Pick Up Cross Over Sub, Daily Up Only Jars, Cross Over Sub, Circulating Sub, And Cross Over Sub To 159' 19:30 - 20:00 0.50 DRILL P PROD1 Change Out Handling Equipment For 2 7/8" Drill Pipe 20:00 - 23:00 3.00 DRILL P PROD1 RIH With Directional BHA No.6 On 2 7/8" Drill Pipe From 157' To 8,862' - Fill Drill String And Test MWD Tools Every 2,000' 23:00 - 23:30 0.50 DRILL P PROD1 Change Out Handling Equipment For 4" Drill Pipe 23:30 - 00:00 0.50 DRILL P PROD1 RIH With Directional BHA No.6 On 4" Drill Pipe From 8,862' To 9,516' 2/28/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Service Top Drive And Traveling Blocks - Install Roll Pins In Grabber Tong Heads 01 :00 - 01 :30 0.50 DRILL P PROD1 Record Slow Pump Rates - Orient Directional Tool Face To 70 Degrees Right Of High Side - Shut Down Mud Pumps And Slide Thru Whipstock Window From 9,568' To 9,581' With No Problems - RIH To 9,982' 01 :30 - 02:00 0.50 DRILL P PROD1 As Precaution Wash And Ream From 9,982' Tag Bottom At 10,075' 02:00 - 03:00 1.00 DRILL P PROD1 Take 12 Cassandra Surveys For JORPS Compliance 03:00 - 00:00 21.00 DRILL P PROD1 Drilled 4 3/4" Directional Hole By Rotating And Sliding From 10,075' To 11,259' WOB Rotating 7,000# - 13,000#, WOB Sliding 5,000# To 18,000#, RPM 30 To 60, Motor RPM 243, Torque Off Bottom 3,000 ft Ilbs - On Bottom 4,000 ft Ilbs, Pump Rate 176 gpm, SPP Off Bottom 2,860 psi, On Bottom 3,300 psi. String Weight Up 122,000#, String Weight Down 110,000#, String Weight Rotating 118,000# - ART = 5.23 hrs. - AST = 7.82 hrs. 2/29/2004 00:00 - 17:00 17.00 DRILL P PROD1 Drilled 4 3/4" Directional Hole By Rotating And Sliding From 11,259' To Casing Point At 12,270' WOB Rotating 7,000# - 14,000#, WOB Sliding 5,000# To 18,000#, RPM 30 To 80, Motor RPM 241, Torque Off Bottom 3,000 ft Ilbs - On Bottom 4,000 ft Ilbs, Pump Rate 174 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,350 psi. String Weight Up 130,000#, String Weight Down 112,000#, String Weight Rotating 125,000# - ART = 7.44 hrs. - AST = 2.93 hrs. 17:00 - 18:30 1.50 DRILL P PROD1 Circulate Hi-Vis Sweep At 4.1 BPM With 2,900 Psi. - Monitor Well Bore (Static) 18:30 - 19:30 1.00 DRILL P PROD1 Wiper Trip And Mad Pass Log - POH From 12,270' To 12,020' With No Problems Normal String Weight Up At 145,000# - POH Working String From 12,020' To 11,999' Pulling 35,000# Above Normal Up Weight - POH From 11,999' To 11,932' With No Problems - POH Working String From 11,932' To 11,883' Pulling 35,000# Above Normal Up Weight - POH From 11,883' To 11,550' With No Problems Printed: 3115/2004 10:12:52 AM · , legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 2/2912004 19:30 - 21 :00 1.50 DRILL P PROD1 Madd Pass Log From 11,550' To 11,240' At 300 Feet Per Hour With No Problems 21 :00 - 23:00 2.00 DRILL P PROD1 Pump Out Of The Hole From 11,240' To 10,961' - POH With Out Pump On From 10,961' To 10,541' Pulling 25,000# To 35,000# Above Normal Up Weight - POH From 10,541' To 9,550' Above Whipstock Window At 9,568' With No Problems - Wash And Clean Rig Floor 23:00 - 00:00 1.00 DRILL P PROD1 Monitor Well Bore (Static) - Service Can-Rig Top Drive And Traveling Blocks - Change Dies In Pipe Grabber 3/1/2004 00:00 - 00:30 0.50 DRILL P PROD1 Adjust Draw Works Mechanical Brakes 00:30 - 01 :30 1.00 DRILL P PROD1 Orient Directional Tool Face To 70 Degrees Right Of High Side - Shut Down Mud Pumps And Slide Thru Whipstock Window From 9,568' To 9,581' With No Problems - RIH To 10,740' 01 :30 - 02:45 1.25 DRILL P PROD1 Madd Pass Log From 10,740' To 11,050' At 300 feet Per Hour With No Problems 02:45 - 03:00 0.25 DRILL P PROD1 RIH With Directional BHA No.6 On 4" Drill Pipe From 11,050' To 11,840' - Taking 20,000# Weight Attempt To Work Thru Area (No Good) 03:00 - 04:00 1.00 DRILL P PROD1 Wash And Ream From 11,840' To 11,930' - Attempt To Run Next Stand In Hole Still Taking 20,000# Weight Above Normal Down Drag - Wash And Ream From 11,930' To Casing Point At 12,270' With 170 GPM At 2,750 Psi. 04:00 - 06:30 2.50 DRILL P PROD1 Circulate Hole Clean At 4.1 BPM With 2,900 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot Liner Running Pill 06:30 - 08:00 1.50 DRILL P PROD1 POH With Directional BHA No.6 From 12,270' To 9,516' With No Problems 08:00 - 09:00 1.00 DRILL P PROD1 Drop Ball Shear Open Circulating Sub And Circulate Bottoms Up At 8 BPM With 3,500 Psi. - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Surface Equipment 09:00 - 09:30 0.50 DRILL P PROD1 POH With 4" Drill Pipe From 9,516' To 8,862' 09:30 - 10:00 0.50 DRILL P PROD1 Change Out Handling Tools And Equipment For 2 7/8" Drill Pipe - Rig Up Power Tongs 10:00 - 11 :30 1.50 DRILL P PROD1 POH Laying Down 2 7/8" Drill Pipe From 8,862' To 6,210' 11 :30 - 14:00 2.50 DRILL P PROD1 POH Standing Back 2 7/8" Drill Pipe In Mast From 6,210' To 158' 14:00 - 16:30 2.50 DRILL P PROD1 Flush And Lay Down Directional BHA No.6 From 158' - Lay Down Cross Over Sub, Circulating Sub, Cross Over Sub, Daily Jars, Cross Over Sub, (2) Flex Drill Collars, And Cross Over Sub - Down Load MWDILWD Data - Lay Down MWD Tools, Cross Over Sub, Float Sub, And Sperry Sun Mud Motor With PDC Bit 16:30 - 17:00 0.50 DRILL P PROD1 Wash Off Rig Floor And Clear Same 17:00 - 17:30 0.50 CASE P COMP Rig Up Power Tongs - Casing Tools And Equipment 17:30-21:15 3.75 CASE P COMP Pick Up And RIH With Shoe Track - Baker Lock Connections To Landing Collar Joint No.3 - Verify Floats Holding - RIH With 88 Joints Of 3 1/2" IBT-M 9.2 lb. L-80 Liner To 2,830' - Make Up To Mark Torqued To 1,400 fVlbs. 21:15 - 22:00 0.75 CASE P COMP Change Out Handling Equipment To 3 1/2" DP Elevators - M I U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool- Mix And Fill Tie Back Sleeve With Pal Mix Sealant And Allow Time For Set Up - Change Out Handling Equipment To 2 7/8" DP Elevators, RIH w/1 Stand 2 Printed: 3/15/2004 10: 12:52 AM , .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 2/12/2004 Rig Release: 3/11/2004 Rig Number: Spud Date: 10/22/1986 End: 3/11/2004 3/112004 21:15 - 22:00 0.75 CASE P COMP 7/8" Drill Pipe From Mast 22:00 - 22:30 0.50 CASE P COMP Circulate 31/2" Liner Volume At 126 GPM With 320 Psi. - 3 1/2" Liner Weight 22,000 Ibs 22:30 - 00:00 1.50 CASE P COMP RIH With 88 Joints Of 3 1/2" IBT-M 9.2 lb. L-80 Liner On 2 7/8" Drill Pipe From 2,961' To 5,126" - Fill 2 7/8" Drill Pipe Every 10 Stands 3/2/2004 00:00 - 02:30 2.50 CASE P COMP RIH With 88 Joints Of 3 1/2" IBT-M 9.2 lb. L-80 Liner On 2 7/8" Drill Pipe From 5,126' To 8,922' - Fill 2 7/8" Drill Pipe Every 10 Stands. 02:30 - 03:00 0.50 CASE P COMP Change Out Handling Equipment For 4" Drill Pipe 03:00 - 03:30 0.50 CASE P COMP RIH With 88 Joints Of 3 1/2" IBT-M 9.2 lb. L-80 Liner On 4" Drill Pipe From 8,922' To 9,483' 03:30 - 04:00 0.50 CASE P COMP Circulate Drill Pipe Volume Above Whipstock Window At 2.5 BPM With 1,000 Psi. - String Weight Up 115,000#, String Weight Down 105,000# 04:00 - 05:30 1.50 CASE P COMP RIH With 3 1/2" Liner On 4" Drill Pipe From 9,483' To 12,250' With Minimum Problems 05:30 - 06:00 0.50 CASE P COMP Pick Up Baker Cement Head - Install Manifold And Circulating Lines 06:00 - 07:00 1.00 CASE P COMP Break circulation and tag bottom @ 12,270'. Stage up pumps to 2.75 bpm @ 1,500 psi. 07:00 - 10:00 3.00 CEMT P COMP PJSM. Pump 5 bbls water and test lines to 4,500 psi. Pump 15 bbls CW100, 25 bbls 9.5 ppg Mudpush Spacer, 44 bbls 15.8 ppb Latex Slurry. Flush Lines and drop dart. Displace plug with 85 bbls Perf pill. Bump plug with 2,600 psi. Set down 30K to set hanger. Increase pressure to 3,900 psi to release hanger. Bleed off pressure and check floats - okay. Pressure up to 1,000 psi and unsting. 10:00 - 11 :30 1.50 CEMT P COMP Circulate @ 9,412' - 5 bpm and 2,150 psi for 30 bbls to move cement up the hole. Rotate and weight set packer 4 times @ 60K down weight. No surface indication of packer setting. CBU @ 5 bpm and 1,650 psi - 10 bbls cement returned to surface. Repeat setting process - still no surface indication of packer set. 11 :30 - 12:30 1.00 CEMT P COMP Displace well to 9,412' with seawater - 9 bpm @ 3,500 psi. 12:30 - 13:00 0.50 CEMT P COMP LD cement head. 13:00 - 14:00 1.00 CEMT P COMP Cut drilling line. Clean cement from surface lines, possum belly and shaker base. 14:00 - 18:00 4.00 CEMT P COMP POOH w/4" DP from 9,412' to 6,070'. Changeout handling equipment. POH w/2-7/8" DP from 6,070' to 3,530' 18:00 - 19:00 1.00 CEMT P COMP CBU @ 3,530' - top of the 5-1/2" liner - 6.5 bpm and 1 ,400 psi. 19:00 - 21 :00 2.00 CEMT P COMP POH w/2-7/8" DP from 3,530' to surface. LD liner running tool - dogs sheared. RD handling equipment and clear floor. 21 :00 - 00:00 3.00 BOPSU P COMP Pull wear ring. MU test assembly. Test BOPE to 250 psi low and 3,500 psi high. Notified AOGCC of BOP test. 3/3/2004 00:00 - 01 :30 1.50 BOPSU P COMP Continue test of BOPE to 250 psi low and 3,500 psi high. 01 :30 - 02:30 1.00 CASE N DFAL COMP Attempt to pressure test casing to 3,500 psi twice. Held 1st test for 15 minutes with 500 psi drop. Held 2nd test for 30 minutes with 600 psi drop. Verified no leaks in the surface piping. Call Baker to amempt set of liner top packer. 02:30 - 04:00 1.50 CASE P COMP Service top drive. Changeout lube pump. Adjust brakes 04:00 - 06:00 I 2.00 CASE N DFAL COMP RU handling equipment. Remove perf guns from pipe shed to I load collars. Bring tools to the rig floor. RU handling Printed: 3/15/2004 10:12:52 AM · " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 3/3/2004 04:00 - 06:00 2.00 CASE N DFAL COMP equipment. 06:00 - 11 :30 5.50 CASE N DFAL COMP MU BHA to 372'. Changeout handling equipment. RIHwl 2-718" DP to 5,920'. RD handling equipment. 11 :30 - 13:00 1.50 CASE N DFAL COMP RIH wI 4" DP from 5,920' to 9,412'. 13:00 - 13:30 0.50 CASE N DFAL COMP Attempt to set packer with SO - 52K. 13:30 - 14:30 1.00 CASE N DFAL COMP Test casing to 3,500 psi. Pressure bled off 300 psi in 10 minutes. Check out surface equipment - okay. 14:30 - 15:30 1.00 CASE N DFAL COMP Attempt to set packer wI 60K. Pressure test to 3,500 psi. Pressure bled off as before. Attempt to set packer and pressure test again with same result. 15:30 - 17:30 2.00 CASE N DFAL COMP Pump dry job and POH from 9,412' to 5,926'. Changeout handling equipment. 17:30 - 21 :30 4.00 CASE N DFAL COMP POH with 2-7/8" from 5,920' to 253'. LD BHA and break out running tool. Clear and clean floor. 21 :30 - 00:00 2.50 CASE N DFAL COMP MU stinger with element and Baker Packer and Seals wI drill collars and RIH to 382'. RIH on 2-7/8" DP to 3,287' 3/4/2004 00:00 - 03:30 3.50 CASE N DFAL COMP MU stinger with element and Baker Packer and Seals. RIH on 2-7/8" DP from 3,287' to 9,412'. 03:30 - 04:30 1.00 CASE N DFAL COMP Sting into the top of the 3-1/2" Liner. PU - 135K, SO - 125K. Attempt pressure test down DP to 3,500 psi - loss of 800 psi in 10 minutes - fail. Unsting and circ fluids to warm lines. Sting back in and repeat pressure test - loss of 800 psi in 10 minutes - fail. No indications at surface of surface system leakage. 04:30 - 05:00 0.50 CASE N DFAL COMP Pressure up on annulus to 1,000 psi to test the liner top. Flatline test for 10 minutes. Some concern of hydraulicing out of the seal assembly if we increased pressure to 3,500 psi. 05:00 - 07:00 2.00 CASE N DFAL COMP Bleed off pressure. Unsting. Blow down top drive. PU and set Baker Packer @ 9,399' and test annulus to 3,500 psi. Good 30 minute test. Sting back into seal bore and set down 40K. Pressure test annulus and liner top to 3,500 psi for 30 minutes - good test. 07:00 - 08:30 1.50 CASE N DFAL COMP POH wI 4" DP from 9,412' to 7,337'. Test liner to 1,000 psi for 12 minutes - good test. 08:30 - 11 :30 3.00 CASE N DFAL COMP POH wI 4" DP from 7,337' to 5,937'. RU 2-7/8" handling equipment. POH wI 2-7/8" DP from 5,937' to 387'. 11 :30 - 14:00 2.50 CASE N DFAL COMP LD BHA from 387' to 127'. LD collars. Break out running tool. RD handling equipment. Clear and clean the floor. 14:00 - 15:30 1.50 PERF P COMP PJSM. RU to run 2" PowerJet guns @ 6spf. 15:30 - 18:00 2.50 PERF P COMP PU 1,332' of perf gun assembly - had to replace 1 section. 18:00 - 19:30 1.50 PERF P COMP PU 1,514' of 2-1/16" CS Hydril tubing 19:30 - 23:30 4.00 PERF P COMP RIH wI 2-7/8" DP from 2,846' to 8,777'. Changeout handling equipment. 23:30 - 00:00 0.50 PERF P COMP RIH wI 4" DP from 8,777' to 9,712'. 3/5/2004 00:00 - 01 :00 1.00 PERF P COMP RIH wI 4" DP from 9,712' to 11,857'. 01 :00 - 00:00 23.00 PERF N SFAL COMP While RIH wI DP, smoke started to emit from the Draw Works. Shut down. Conduct Hazard Analysis on the troubleshooting of the malfunction. Troubleshoot cause. Problem with the Electro-Mag brake. Remove Electric Brake with crane and send back to the yard for repairs. 3/6/2004 00:00 - 00:00 24.00 PERF N SFAL COMP Wait on parts for repair of Draw Works. Work on various rig painting projects. Changeout hoses on draw works. Replace top jaw seal on roughneck. 3/7/2004 00:00 - 00:00 24.00 PERF N SFAL COMP Wait on parts for repair of Draw Works. Work on various rig Printed: 3/15/2004 10: 12:52 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 3/7/2004 00:00 - 00:00 24.00 PERF N SFAL COMP painting projects. Replace piping in desander pump manifold. Derrick Inspection. Repair leaks on roughneck. Changeout steam heat core. 3/8/2004 00:00 - 12:00 12.00 PERF N SFAL COMP Wait on parts for repair of Draw Works. Paint projects. Install shaft (hub) in electric brake, inboard and outboard bearings and seals. 12:00 - 20:00 8.00 PERF N SFAL COMP PJSM. Install electric brake. Line up and shim in. RU circulation lines. Install Cat shaft. Install trap door. Release crane. RU catheads and trough. Test circulation lines. Install guards. Test electric brake. 20:00 - 21 :00 1.00 PERF P COMP PJSM. RIH with DP from 11,857' and tag Landing Collar at 12,200'. PU 10' to 12,190' and fire guns. Good indication of firing at surface. Fluid level dropped -4' and then stopped. PU - 130K, SO - 120K. 21 :00 - 22:00 1.00 PERF P COMP POH with 4" DP standing back in the derrick from 12,190' to 10,831'. Monitor well - static. 22:00 - 23:30 1.50 PERF P COMP Slug pipe and blowdown surface equipment. LD 4" DP from 10,831' to 9,245'. 23:30 - 00:00 0.50 PERF P COMP Slip and cut drilling line. 3/9/2004 00:00 - 01 :00 1.00 PERF P COMP Slip and cut drilling line. 01 :00 - 01 :30 0.50 PERF P COMP LD 4" DP from 9,245' to 8,777' 01 :30 - 07:00 5.50 PERF P COMP Change out handling equipment. LD 2-7/8" DP from 8,777' to 2,847'. 07:00 - 09:30 2.50 PERF P COMP Change out handling equipment. LD 2-1/16" from 2,847' to 1,330'. Change out handling equipment for LD Perf Guns. All guns fired. 09:30 - 13:00 3.50 PERF P COMP PJSM. LD firing head and perf guns from 1,330'. 13:00 - 15:30 2.50 PERF P COMP RI H wI 4" DP to 1,680'. LDDP. Clear and clean the floor. 15:30 - 18:00 2.50 RUNCO COMP Pull Wear Ring. RU 3-1/2" 13Cr handling equipment wI compensator. 18:00 - 00:00 COMP PJSM. PU Tail assembly and Baker SABL Packer assembly and RIH. RIH wI 3-1/2" Yam Top, 13Cr completion to 3,287'. TO - 2,900 ftlbs 3/10/2004 00:00 - 05:30 COMP PJSM. RIH wI 3-1/2" Yam Top, 13Cr completion from 3,287' to 6,905'. TO - 2,900 ftlbs 05:30 - 06:30 1.00 COMP RU spooling unit for control line. Test control line to 5,000 psi. 06:30 - 10:30 4.00 COMP RIH with SSSV and 3-1/2" tubing from 6,905' to 9,088'. 10:30 - 12:30 2.00 COMP Change out handling equipment. MU landing joint and hanger. tenminate control line. Land hanger and RILDS. Total of 72 Stainless Steel Bands run. 12:30 - 15:00 COMP RU circulating lines and test to 3,500 psi. Reverse circulate corrosion inhibitor @ 2 bpm, 210 psi. 15:00 - 17:30 COMP Drop Ball and Rod. Test lines to 4,500 psi. Test tubing to 3,500 psi and hold for 30 minutes. Pressure up to 4,500 psi to set SABL Packer and hold for 5 minutes. Bleed tubing to 1,500 psi. Pressure up on annulus to 3,500 psi and hold for 30 minutes. Bleed of pressure to shear DCK - no shear. Repeat 3 times without shearing valve. 17:30 - 18:30 1.00 WHSUR P COMP Dry rod in the TWC and blowdown all surface equipment. RD control line spooler and clear the floor. 18:30 - 23:00 4.50 WHSUR P COMP ND BOPE and adapter flange. NU Tree and adapter flange. Test tree to 5,000 psi. Printed: 3/15/2004 10: 12:52 AM , . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-14 18-14B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2/12/2004 3/11/2004 Spud Date: 10/22/1986 End: 3/11/2004 3/1 0/2004 23:00 - 00:00 1.00 WHSUR P COMP RU lubricator and pull TWC. RD lubricator. 3/11/2004 00:00 - 07:00 7.00 PULL N DFAL COMP PJSM. RIH wI Slickline to pull DCK valve from top GLM @ 3,240'. Tagged up on SSSV wI 2.6" 00 tool. POH. RIH wI 2.4" tool - no go. POH. Increase control line pressure to 6,000 psi and pressure up on tubing to 4,500 psi. Bleed off pressure slowly. SSSV open - verified with Slickline run of 2.4" tool. POH. Pressure up on annulus and shear DCK valve @ 2,350 psi. RD slickline. 07:00 - 08:00 1.00 WHSUR P COMP PJSM. RU LRHOS and circulation lines 08:00 - 09:00 1.00 WHSUR P COMP Reverse circ 95 bbls Diesel - 2.5 bpm, 2,200 psi. 09:00 - 10:00 1.00 WHSUR N DFAL COMP Attempt U-tube - unsuccessful. 10:00 - 12:30 2.50 WHSUR N DFAL COMP Suck back lines and troubleshoot. Pump down tubing - pressured up to 3,500 psi with no communication to annulus. Bleed off pressure and RU to pump down annulus. Pump down annulus with good communication through DCK. Attempt U-tube - unsuccessful. 12:30 - 14:30 2.00 WHSUR N DFAL COMP RD LRHOS to get more diesel. RU LRHOS. Pump 50 bbls diesel, 2.3 bpm, 1,450 psi. Well freeze protected down to Upper GLM @ 3,240. 14:30 - 16:00 1.50 WHSUR P COMP Dry rod BPV. Test from below to 1,000 psi - good. Remove Secondary Annulus Valve and secure the tree and cellar. Release rig 3/11/2004 @ 1600 hours to 15-43 RWO. Printed: 3/15/2004 10:12:52 AM e e t)CJ3 -oÚ2.3 21-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 18-148 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,546.70' MD 9,568.00' MD 12,270.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date -..........."- ," ~ Signed~,r;\\ u /V"\.":\'j ,ç Cl=~ D ')/""'\,- Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) \.1 ') h 0004 . l... "') L.v i',!¡¡~K3 Oil &. Gas Cons. Commisaion ""!I"hMage ;'),¡: ~"~~!'~"" - ~~~\'<\.~ D EFI N ITIVE Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 18 18-14B e Job No. AKZZ2916013, Surveyed: 29 February, 2004 Survey Report 19 March, 2004 Your Ref: API 500292161402 Surface Coordinates: 5960947.74 N, 692100.14 E (70017' 52.1777" N, 148026'39.2081" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 960947.74 N, 192100.14 E (Grid) Surface Coordinates relative to Structure Reference: 1720.73 N, 558.79 E (True) Kelly Bushing Elevation: 46.40ft above Mean Sea Level Kelly Bushing Elevation: 46.40ft above Project V Reference Kelly Bushing Elevation: 46.40ft above Structure Reference SpSi'I""")I-SUI! CRIL.L1NG SERVICeS A Halliburton Company Survey Ref: svy4169 · . Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 - 18-14B Your Ref: API 500292161402 Job No. AKZZ2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9546.70 46.080 156.130 8381.08 8427.48 2852.66 S 1328.74 E 5958129.98 N 693501.37 E -1666.49 Tie-on Point AK-6 BP _IFR-AK 9568.00 46.240 155.820 8395.84 8442.24 2866.69 S 1335.00 E 5958116.11 N 693507.98 E 1.291 -1674.41 Window Point 9593.70 48.310 159.800 8413.28 8459.68 2884.17 S 1342.11 E 5958098.82 N 693515.54 E 13.937 -1683.60 9625.08 52.440 164.310 8433.29 8479.69 2907.16 S 1349.53 E 5958076.03 N 693523.54 E 17.192 -1693.76 e 9653.95 53.760 168.150 8450.63 8497.03 2929.57 S 1355.02 E 5958053.76 N 693529.60 E 11.576 -1701.94 9687.89 55.850 169.300 8470.19 8516.59 2956.77 S 1360.43 E 5958026.71 N 693535.71 E 6.752 -1710.63 9718.94 57.390 171.350 8487.27 8533.67 2982.33 S 1364.79 E 5958001.27 N 693540.72 E 7.415 -1718.07 9746.88 58.650 172.770 8502.07 8548.47 3005.80 S 1368.06 E 5957977.89 N 693544.59 E 6.239 -1724.18 9780.19 60.970 177.580 8518.83 8565.23 3034.48 S 1370.47 E 5957949.28 N 693547.72 E 14.291 -1730.06 9811.51 63.160 181.280 8533.50 8579.90 3062.14 S 1370.73 E 5957921.64 N 693548.70 E 12.562 -1733.70 9839.23 64.820 184.700 8545.66 8592.06 3087.01 S 1369.43 E 5957896.74 N 693548.03 E 12.601 -1735.43 9872.02 67.600 189.870 8558.90 8605.30 3116.75 S 1365.61 E 5957866.91 N 693544.97 E 16.731 -1735.27 9904.08 70.260 194.140 8570.42 8616.82 3146.00 S 1359.38 E 5957837.51 N 693539.49 E 14.942 -1732.65 9932.70 72.590 196.580 8579.54 8625.94 3172.16 S 1352.19 E 5957811.18 N 693532.98 E 11.471 -1728.70 9966.64 75.340 200.910 8588.92 8635.32 3203.03 S 1341.71 E 5957780.05 N 693523.28 E 14.695 -1722.06 9997.52 79.020 205.600 8595.77 8642.17 3230.68 S 1329.81 E 5957752.11 N 693512.10 E 19.006 -1713.62 10026.22 80.810 209.900 8600.80 8647.20 3255.68 S 1316.66 E 5957726.78 N 693499.59 E 16.015 -1703.61 10073.92 79.970 213.270 8608.77 8655.17 3295.74 S 1292.03 E 5957686.11 N 693475.99 E 7.185 -1684.05 10105.11 77.740 220.030 8614.80 8661.20 3320.28 S 1273.78 E 5957661.11 N 693458.38 E 22.433 -1668.93 10133.48 74.790 223.350 8621.54 8667.94 3340.85 S 1255.46 E 5957640.07 N 693440.59 E 15.405 -1653.25 10167.14 73.400 229.220 8630.77 8677.17 3363.22 S 1232.08 E 5957617.12 N 693417.79 E 17.271 -1632.77 e 10198.17 72.340 231.670 8639.91 8686.31 3382.10 S 1209.22 E 5957597.65 N 693395.42 E 8.282 -1612.38 10224.99 75.290 236.090 8647.39 8693.79 3397.27 S 1188.42 E 5957581.96 N 693375.01 E 19.272 -1593.58 10260.24 78.140 241.520 8655.50 8701.90 3415.02 S 1159.08E 5957563.46 N 693346.14 E 17.031 -1566.63 10290.02 81.380 244.820 8660.79 8707.19 3428.24 S 1132.94 E 5957549.58 N 693320.34 E 15.403 -1542.29 1 0318.17 83.500 248.660 8664.49 8710.89 3439.26 S 1107.31E 5957537.91 N 693295.00 E 15.478 -1518.19 1 0352.72 83.720 253.540 8668.34 8714.74 3450.38 S 1074.83 E 5957525.97 N 693262.82 E 14.051 -1487.31 10383.13 80.770 257.460 8672.45 8718.85 3457.92 S 1045.67 E 5957517.68 N 693233.86 E 16.038 -1459.29 10411.65 81.130 261.930 8676.94 8723.34 3462.96 S 1017.97 E 5957511.93 N 693206.29 E 15.529 -1432.41 10444.00 81.320 265.490 8681.87 8728.27 3466.46 S 986.19 E 5957507.62 N 693174.62 E 10.892 -1401.30 19 March, 2004·8:18 Page 2 of 5 DrillQuest 3.03.06.002 · . Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 - 18-14B Your Ref: API 500292161402 Job No. AKZZ2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 10475.14 83.870 270.020 8685.89 8732.29 3467.67 S 955.35 E 5957505.63 N 693143.81 E 16.587 -1370.83 10504.36 84.900 275.030 8688.75 8735.15 3466.38 S 926.30 E 5957506.17 N 693114.75 E 17.424 -1341.85 10537.70 86.850 279.040 8691.15 8737.55 3462.31 S 893.31 E 5957509.40 N 693081.66 E 13.346 -1308.60 10597.76 88.030 278.030 8693.83 8740.23 3453.41 S 833.98 E 5957516.78 N 693022.12 E 2.585 -1248.62 10693.19 87.720 281.610 8697.37 8743.77 3437.14 S 740.02 E 5957530.64 N 692927.78 E 3.763 -1153.39 e 10786.42 88.640 282.520 8700.33 8746.73 3417.67 S 648.90 E 5957547.78 N 692836.19 E 1.388 -1060.57 10849.85 87.720 283.640 8702.34 8748.74 3403.32 S 587.15 E 5957560.54 N 692774.09 E 2.284 -997.53 10880.07 88.490 288.440 8703.34 8749.74 3394.98 S 558.13 E 5957568.14 N 692744.87 E 16.078 -967.71 10911.29 89.290 290.810 8703.95 8750.35 3384.49 S 528.73 E 5957577.87 N 692715.21 E 8.011 -937.26 10942.42 90.120 291.990 8704.11 8750.51 3373.14 S 499.75 E 5957588.48 N 692685.95 E 4.634 -907.11 10972.31 90.400 292.270 8703.97 8750.37 3361.88 S 472.06 E 5957599.03 N 692657.98 E 1.325 -878.25 11005.49 87.990 292.930 8704.44 8750.84 3349.13 S 441.44 E 5957610.99 N 692627.04 E 7.531 -846.30 11037.74 88.640 292.140 8705.39 8751.79 3336.77 S 411.66E 5957622.58 N 692596.96 E 3.171 -815.24 11067.25 89.940 292.760 8705.75 8752.15 3325.51 S 384.39 E 5957633.15 N 692569.41 E 4.881 -786.80 11098.81 88.730 292.780 8706.12 8752.52 3313.29 S 355.29 E 5957644.61 N 692540.01 E 3.834 -756.43 11132.17 89.170 292.420 8706.73 8753.13 3300.47 S 324.50 E 5957656.64 N 692508.90 E 1.704 -724.31 11159.54 89.630 292.930 8707.02 8753.42 3289.92 S 299.25 E 5957666.54 N 692483.39 E 2.509 -697.96 11193.22 89.820 293.960 8707.18 8753.58 3276.52 S 268.35 E 5957679.15 N 692452.15 E 3.110 -665.66 11251.46 90.280 292.890 8707.13 8753.53 3253.37 S 214.91 E 5957700.93 N 692398.14 E 2.000 -609.79 11318.40 91.480 294.330 8706.10 8752.50 3226.56 S 153.58 E 5957726.16 N 692336.15 E 2.800 -545.66 11344.69 92.410 295.390 8705.21 8751.61 3215.52 S 129.74 E 5957736.59 N 692312.03 E 5.362 -520.65 11380.76 91.020 291.560 8704.13 8750.53 3201.16 S 96.68 E 5957750.10 N 692278.62 E 11.291 -486.08 e 11411.75 91.760 291.880 8703.38 8749.78 3189.70 S 67.90 E 5957760.82 N 692249.55 E 2.601 -456.12 11438.50 89.880 291.410 8702.99 8749.39 3179.83 S 43.04 E 5957770.05 N 692224.45 E 7.244 -430.24 11473.71 90.220 292.210 8702.96 8749.36 3166.75 S 10.35 E 5957782.29 N 692191.43 E 2.469 -396.20 11504.94 87.870 292.450 8703.48 8749.88 3154.89 S 18.53 W 5957793.41 N 692162.26 E 7.564 -366.09 11532.32 88.490 292.380 8704.35 8750.75 3144.45 S 43.83 W 5957803.20 N 692136.70 E 2.279 -339.71 11567.32 87.010 291.940 8705.73 8752.13 3131.26S 76.22 W 5957815.56 N 692103.99 E 4.411 -305.95 11597.01 85.590 292.150 8707.64 8754.04 3120.14S 103.68 W 5957825.97 N 692076.25 E 4.835 -277.34 11625.59 85.920 291.990 8709.76 8756.16 3109.43 S 130.09 W 5957836.00 N 692049.57 E 1.283 -249.82 11660.75 85.640 292.070 8712.35 8758.75 3096.28 S 162.60 W 5957848.32 N 692016.74 E 0.828 -215.95 11691.66 86.080 290.110 8714.58 8760.98 3085.18 S 191.36 W 5957858.67 N 691987.70 E 6.483 -186.05 11718.78 90.490 290.070 8715.39 8761.79 3075.88 S 216.81 W 5957867.33 N 691962.02 E 16.262 -159.66 11753.63 93.270 292.360 8714.25 8760.65 3063.27 S 249.28 W 5957879.09 N 691929.24 E 10.332 -125.90 11784.42 93.330 292.580 8712.47 8758.87 3051.53 S 277.68 W 5957890.11 N 691900.55 E 0.739 -96.27 19 March, 2004 - 8:18 Page 3 of 5 DrillQuest 3.03.06.002 . , Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 -18-14B . Your Ref: API 500292161402 Job No. AKZZ2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11811.54 93.390 292.700 8710.88 8757.28 3041 .10 S 302.67 W 5957899.89 N 691875.30 E 0.494 -70.20 11864.74 93.950 293.180 8707.48 8753.88 3020.41 S 351.56 W 5957919.33 N 691825.90 E 1.385 -19.15 11905.78 93.120 294.660 8704.95 8751.35 3003.80 S 389.01 W 5957934.97 N 691788.04 E 4.129 20.03 11954.28 92.440 293.690 8702.60 8749.00 2983.97 S 433.20 W 5957953.68 N 691743.36 E 2.441 66.32 11999.34 90.620 295.150 8701.39 8747.79 2965.34 S 474.21 W 5957971.24 N 691701.88 E 5.177 109.29 e 12045.12 88.670 294.310 8701.68 8748.08 2946.19 S 515.79 W 5957989.32 N 691659.83 E 4.638 152.89 12092.84 89.660 294.760 8702.37 8748.77 2926.38 S 559.20 W 5958008.02 N 691615.93 E 2.279 198.39 12140.23 90.340 294.250 8702.37 8748.77 2906.72 S 602.32 W 5958026.57 N 691572.32 E 1.794 243.59 12186.08 90.890 293.570 8701.88 8748.28 2888.14 S 644.23 W 5958044.07 N 691529.95 E 1.907 287.45 12234.51 91.850 293.760 8700.72 8747.12 2868.71 S 688.57 W 5958062.37 N 691485.12 E 2.021 333.83 12270.00 91.850 293.760 8699.58 8745.98 2854.42 S 721.04 W 5958075.82 N 691452.30 E 0.000 367.80 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 277.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12270.00ft., The Bottom Hole Displacement is 2944.08ft., in the Direction of 194.177° (True). e 19 March, 2004 - 8:18 Page 4 of 5 DrillQuest 3.03.06.002 North Slope Alaska Comments Measured Depth (ft) 9546.70 9568.00 12270.00 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 - 18-14B Your Ref: API 500292161402 Job No. AKZZ2916013, Surveyed: 29 February, 2004 BPXA Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) 8427.48 8442.24 8745.98 2852.66 S 2866.69 S 2854.42 S Survey tool proQram for 18-148 From Measured Vertical Depth Depth (ft) (ft) 0.00 8697.70 9546.70 0.00 7803.61 8427.48 Comment 1328.74 E 1335.00 E 721.04 W Tie-on Point Window Point Projected Survey e To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) BP High Accuracy Gyro (18-14) MWD Magnetic (18-14APB1) AK-6 BP JFR-AK (18-14B) e 19 March, 2004 - 8:18 DrillQuest 3.03.06.002 8697.70 9546.70 12270.00 7803.61 8427.48 8745.98 Page 5 of 5 - e ~C3 --()~ 21-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 18-148 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,546.70' MD 9,568.00' MD 12,270.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ""'";,;,-"._.,~ ,.. ~;"'''''''''.~''' Date Signed \"",-6)~~JY""\ ,"') f..(, ~ --'~ .Q. i~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED IJ !~ P 2 s f)n04 . "" , '- L.V ~" y f'I: ) G Co Com, i,;a~,\avu'.t as ns. misafon f"'.....MAf1A r -_..<j~,-iHYJ'-'~v K"D~ \)\ ~ · . Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 18 18-148 MWD e Job No. AKMW2916013, Surveyed: 29 February, 2004 Survey Report 19 March, 2004 Your Ref: API 500292161402 Surface Coordinates: 5960947.74 N, 692100.14 E (70017' 52.1777" N, 148026'39.2081" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 960947.74 N, 192100.14 E (Grid) Surface Coordinates relative to Structure Reference: 1720.73 N, 558.79 E (True) Kelly Bushing Elevation: 46.40ft above Mean Sea Level Kelly Bushing Elevation: 46.40ft above Project V Reference Kelly Bushing Elevation: 46.40ft above Structure Reference spal"""l"""Y-sul'l D AtL. L..tNGS eAVt c:e 5 A Halliburton Company Survey Ref: svy4170 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 -18-14B MWD Your Ref: API 500292161402 Job No. AKMW2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 9546.70 46.080 156.130 8381.08 8427.48 2852.66 S 1328.74 E 5958129.98 N 693501.37 E -1666.49 Tie-on Point 9568.00 46.240 155.820 8395.84 8442.24 2866.69 S 1335.00 E 5958116.11 N 693507.98 E 1.291 -1674.41 Window Point 9593.70 48.310 159.800 8413.28 8459.68 2884.17 S 1342.11 E 5958098.82 N 693515.54 E 13.937 -1683.60 9625.08 52.440 166.570 8433.30 8479.70 2907.29 S 1349.06 E 5958075.88 N 693523.07 E 21.186 -1693.31 9653.95 53.760 168.210 8450.63 8497.03 2929.82 S 1354.09 E 5958053.49 N 693528.68 E 6.445 -1701.06 9687.89 55.850 170.930 8470.20 8516.60 2957.09 S 1359.11 E 5958026.36 N 693534.39 E 8.989 -1709.35 e 9718.94 57.390 171.100 8487.28 8533.68 2982.70 S 1363.15 E 5958000.86 N 693539.09 E 4.981 -1716.49 9746.88 58.650 173.200 8502.08 8548.48 3006.18 S 1366.39 E 5957977.4 7 N 693542.92 E 7.809 -1722.56 9780.19 60.970 177.740 8518.83 8565.23 3034.87 S 1368.65 E 5957948.85 N 693545.92 E 13.684 -1728.30 9811.51 63.160 181.440 8533.51 8579.91 3062.53 S 1368.84 E 5957921.20 N 693546.81 E 12.562 -1731.86 9839.23 64.820 184.790 8545.67 8592.07 3087.40 S 1367.48 E 5957896.31 N 693546.09 E 12.402 -1733.54 9872.02 67.600 190.040 8558.90 8605.30 3117.13S 1363.59 E 5957866.48 N 693542.97 E 16.924 -1733.31 9904.08 70.260 194.270 8570.43 8616.83 3146.36 S 1357.29 E 5957837.10 N 693537.41 E 14.845 -1730.61 9932.70 72.590 196.660 8579.55 8625.95 3172.51 S 1350.05 E 5957810.78 N 693530.84 E 11.355 -1726.62 9966.64 75.340 200.980 8588.93 8635.33 3203.37 S 1339.52 E 5957779.66 N 693521.11 E 14.672 -1719.93 9997.52 79.020 205.660 8595.78 8642.18 3231.00 S 1327.60 E 5957751.73 N 693509.90 E 18.982 -1711.46 10026.22 80.810 210.020 8600.81 8647.21 3255.98 S 1314.41 E 5957726.42 N 693497.34 E 16.204 -1701.41 10073.92 79.970 213.170 8608.77 8655.17 3296.03 S 1289.77 E 5957685.75 N 693473.74 E 6.745 -1681.84 10105.11 77.740 219.640 8614.81 8661.21 3320.65 S 1271.63E 5957660.68 N 693456.23 E 21.570 -1666.83 10133.48 74.790 223.170 8621.54 8667.94 3341.32 S 1253.41 E 5957639.55 N 693438.55 E 15.943 -1651.27 10167.14 73.400 228.990 8630.78 8677.18 3363.77 S 1230.11 E 5957616.52 N 693415.83 E 17.133 -1630.88 10198.17 72.340 231.250 8639.92 8686.32 3382.78 S 1207.35 E 5957596.93 N 693393.57 E 7.753 -1610.61 e 10224.99 75.290 236.080 8647.39 8693.79 3398.03 S 1186.61 E 5957581.16 N 693373.22 E 20.494 -1591.88 10260.24 78.140 241.050 8655.50 8701.90 3415.90 S 1157.35E 5957562.54 N 693344.43 E 15.925 -1565.01 10290.02 81.380 244.580 8660.79 8707.19 3429.28 S 1131.28 E 5957548.49 N 693318.71 E 15.950 -1540.78 10318.17 83.500 249.070 8664.50 8710.90 3440.26 S 1105.64 E 5957536.87 N 693293.36 E 17.513 -1516.66 10352.72 83.720 252.560 8668.35 8714.75 3451.54 S 1073.21 E 5957524.76 N 693261.23 E 10.059 -1485.85 10383.13 80.770 255.980 8672.45 8718.85 3459.71 S 1044.22 E 5957515.85 N 693232.45 E 14.773 -1458.07 10411.65 81.130 264.190 8676.94 8723.34 3464.55 S 1016.50 E 5957510.30 N 693204.87 E 28.456 -1431.15 10444.00 81.320 263.880 8681.88 8728.28 3467.88 S 984.70 E 5957506.17 N 693173.17 E 1.114 -1399.99 10475.14 83.870 267.760 8685.89 8732.29 3470.12 S 953.91 E 5957503.13 N 693142.44 E 14.822 -1369.70 10504.36 84.900 273.090 8688.75 8735.15 3469.91 S 924.84 E 5957502.61 N 693113.38 E 18.492 -1340.83 10537.70 86.850 278.650 8691.15 8737.55 3466.51 S 891.78 E 5957505.16 N 693080.24 E 17.631 -1307.59 10597.76 88.030 273.650 8693.84 8740.24 3460.08 S 832.15 E 5957510.06 N 693020.46 E 8.545 -1247.62 10693.19 87.720 286.090 8697.39 8743.79 3443.77 S 738.38 E 5957523.97 N 692926.30 E 13.031 -1152.56 19 March, 2004 - 8:14 Page 2 of 5 Dri/lQuest 3.03.06.002 , , Halliburton Sperry-Sun , Survey Report for PBUßOA DS 18 - 18-14B MWD Your Ref: AP/500292161402 Job No. AKMW2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 10786.42 88.640 283.020 8700.35 8746.75 3420.35 S 648.20 E 5957545.07 N 692835.55 E 3.436 -1060.20 10849.85 87.720 282.800 8702.37 8748.77 3406.19 S 586.40 E 5957557.65 N 692773.42 E 1.491 -997.14 10880.07 88.490 290.900 8703.37 8749.77 3397.44 S 557.52 E 5957565.66 N 692744.32 E 26.909 -967.41 10911.29 89.290 282.910 8703.97 8750.37 3388.37 S 527.68 E 5957573.96 N 692714.26 E 25.716 -936.68 10942.42 90.120 289.750 8704.13 8750.53 3379.63 S 497.82 E 5957581.94 N 692684.19 E 22.133 -905.98 10972.31 90.400 295.490 8704.00 8750.40 3368.13 S 470.24 E 5957592.73 N 692656.33 E 19.226 -877.21 e 11005.49 87.990 296.480 8704.46 8750.86 3353.60 S 440.42 E 5957606.49 N 692626.14 E 7.852 -845.84 11037.74 88.640 288.360 8705.41 8751.81 3341.32 S 410.65 E 5957618.01 N 692596.06 E 25.248 -814.79 11067.25 89.940 286.760 8705.78 8752.18 3332.41 S 382.52 E 5957626.19 N 692567.72 E 6.986 -785.79 11098.81 88.730 290.980 8706.15 8752.55 3322.21 S 352.66 E 5957635.63 N 692537.61 E 13.909 -754.91 11132.17 89.170 295.490 8706.76 8753.16 3309.05 S 322.02 E 5957648.00 N 692506.64 E 13.581 -722.89 11159.54 89.630 287.190 8707.05 8753.45 3299.10 S 296.55 E 5957657.29 N 692480.93 E 30.370 -696.40 11193.22 89.820 295.490 8707.21 8753.61 3286.86 S 265.21 E 5957668.73 N 692449.28 E 24.650 -663.80 11251.46 90.280 289.740 8707.16 8753.56 3264.47 S 211.47 E 5957689.74 N 692394.99 E 9.904 -607.73 11318.40 91 .480 289.530 8706.13 8752.53 3241.98 S 148.43 E 5957710.61 N 692331.39 E 1.820 -542.42 11344.69 92.410 277.510 8705.23 8751.63 3235.85 S 122.93 E 5957716.09 N 692305.75 E 45.831 -516.37 11380.76 91.020 273.230 8704.15 8750.55 3232.48 S 87.05 E 5957718.54 N 692269.78 E 12.471 -480.34 11411.75 91.760 284.830 8703.40 8749.80 3227.62 S 56.50 E 5957722.62 N 692239.13 E 37.496 -449.43 11438.50 89.880 286.060 8703.02 8749.42 3220.50 S 30.72 E 5957729.08 N 692213.17 E 8.398 -422.97 11473.71 90.220 295.490 8702.99 8749.39 3208.03 S 2.16W 5957740.71 N 692179.98 E 26.800 -388.81 11504.94 87.870 282.610 8703.51 8749.91 3197.85 S 31.61 W 5957750.12 N 692150.28 E 41.915 -358.34 11532.32 88.490 281.560 8704.38 8750.78 3192.13 S 58.37 W 5957755.17 N 692123.38 E 4.452 -331.09 e 11567.32 87.010 280.620 8705.75 8752.15 3185.40 S 92.69 W 5957761.01 N 692088.90 E 5.008 -296.20 11597.01 85.590 284.570 8707.67 8754.07 3178.94 S 121.60W 5957766.73 N 692059..84 E 14.111 -266.72 11625.59 85.920 304.630 8709.81 8756.21 3167.14S 147.38 W 5957777.87 N 692033.77 E 70.004 -239.70 11660.75 85.640 302.790 8712.39 8758.79 3147.68 S 176.55 W 5957796.58 N 692004.11 E 5.279 -208.37 11691.66 86.080 279.670 8714.65 8761.05 3136.59 S 205.09 W 5957806.93 N 691975.30 E 74.613 -178.69 11718.78 90.490 308.160 8715.48 8761.88 3125.71 S 229.61 W 5957817.18 N 691950.51 E 106.229 -153.03 11753.63 93.270 282.770 8714.32 8760.72 3110.85S 260.79 W 5957831.24 N 691918.95 E 73.244 -120.27 11784.42 93.330 285.150 8712.55 8758.95 3103.44 S 290.62 W 5957837.89 N 691888.95 E 7.719 -89.76 11811.54 93.390 285.140 8710.96 8757.36 3096.36 S 316.75 W 5957844.29 N 691862.64 E 0.224 -62.96 11864.74 93.950 300.670 8707.53 8753.93 3075.77 S 365.51 W 5957863.64 N 691813.38 E 29.150 -12.06 11905.78 93.120 296.070 8705.00 8751.40 3056.31 S 401.54 W 5957882.17 N 691776.86 E 11.368 26.08 11954.28 92.440 283.600 8702.64 8749.04 3039.91 S 447.02 W 5957897.40 N 691730.97 E 25.719 73.21 11999.34 90.620 283.860 8701.44 8747.84 3029.22 S 490.77 W 5957906.97 N 691686.96 E 4.080 117.95 19 March, 2004 - 8:14 Page 3 of 5 Drí1lQuest 3.03.06.002 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12045.12 88.670 296.280 8701.72 8748.12 12092.84 89.660 286.740 8702.42 8748.82 12140.23 90.340 287.940 8702.42 8748.82 12186.08 90.890 286.180 8701.93 8748.33 12234.51 91.850 287.860 8700.77 8747.17 12270.00 91.850 287.860 8699.62 8746.02 / Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 - 18-14B MWD Your Ref: API 500292161402 Job No. AKMW2916013, Surveyed: 29 February, 2004 -- BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 3013.54 S 533.69 W 5957921.55 N 691643.66 E 27.460 162.45 2996.06 S 578.03 W 5957937.88 N 691598.89 E 20.097 208.59 2981.94 S 623.26 W 5957950.84 N 691553.31 E 2.910 255.21 2968.49 S 667.09 W 5957963.17 N 691509.15 E 4.021 300.35 2954.32 S 713.38 W 5957976.15 N 691462.51 E 3.994 348.02 e 2943.44 S 747.14 W 5957986.16 N 691428.48 E 0.000 382.86 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 277.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12270.00ft., The Bottom Hole Displacement is 3036.78ft., in the Direction of 194.243° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9546.70 9568.00 12270.00 8427.48 8442.24 8746.02 2852.66 S 2866.69 S 2943.44 S Comment 1328.74 E 1335.00 E 747.14 W e Tie-on Point Window Point Projected Survey 19 March, 2004 - 8:14 Page 4 of 5 DrillQuest 3.03.06.002 f "' / Halliburton Sperry-Sun Survey Report for PBU_EOA DS 18 -18-14B MWD Your Ref: API 500292161402 Job No. AKMW2916013, Surveyed: 29 February, 2004 BPXA North Slope Alaska Survey tool program for 18-148 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8697.70 0.00 8697.70 7803.61 12270.00 7803.61 BP High Accuracy Gyro (18-14) 8746.02 MWD Magnetic (18-14APB1) e e 19 March, 2004 - 8:14 Page 5 of 5 DrillQuest 3.03.06.002 18-14B Liner Grade Change (Permit #203-063) . . Winton, As per our conversation, the 5-1/5", 15.5#, L-80 scab liner will be replaced with 5-1/2", 15.5#, J-55 pipe. The Burst and Collapse calcs look good with the lower grade. BP has a surplus of 5-1/2", 15.5#, J-55 pipe available and can save on pipe costs by utilizing this inventory. Thanks, Rob 1 of 1 2/412004 6:42 AM Re: 18-14B Drilling Permit #203-063 . . Rob, AOGCC hereby approves proposed changes to 18-14B (PTD 203-063) drilling operations as described below. All original permit stipulations apply. Winton Aubert AOGCC 793-1231 Tirpack, Robert B wrote: Winton, As per our conversation earlier this week, the permit originally issued to CTD rig Nordic #1 for 18-14B will be used to with rotary drilling rig Nabors 2es. The KOP will move up the hole 360' and the BHL is with-in 500' of the one listed on the permit. .CTD attempted to drill 18-14B, but stopped work after the SCSSV flapper failed and partially blocked the tubing. CTDmanaged to set a IBP and whipstock. Attached is verbiage explaining the work to be performed with Nabors 2es at 18-14B. Please call with any questions or for more information. Regards, Rob Tirpack Ops Drilling Eng GPB Rotary Drilling BPXA 564-4166 office 440-8633 cell «18-14B Permit Application.ZIP» 1 of 1 12/3/2003 10:17 AM 18-14B Drilling Permit #203-063 e ~V? '-Oe - Subject: 18-14B Drilling Permit #203-063 Date: Thu, 13 Nov 2003 11:00:32 -0900 From: "Tirpack, Robert B" <TirpacRB@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Isaacson, William S" <IsaacsWS@BP.com>, "Hubble, Terrie L" <HubbleTL@BP.com> ;).Ö 3~- Ôro3 Winton, As per our conversation earlier this week, the permit originally issued to CTD rig Nordic #1 for 18-14B will be used to with rotary drilling rig Nabors 2es. The KOP will move up the hole 360' and the BHL is with-in 500' of the one listed on the permit. CTD attempted to drill 18-14B, but stopped work after the SCSSV flapper failed and partially blocked the tubing. CTD managed to set a IBP and whipstock. Attached is verbiage explaining the work to be performed with Nabors 2es at 18-14B. Please call with any questions or for more information. Regards, Rob Tirpack Ops Drilling Eng GPB Rotary Drilling BPXA 564-4166 office 440-8633 cell «18-14B Permit Application.ZIP» !..~'~,~m"'"WN^, "^",W~~"m~~~~-~-~_-AWA_____~Nm=mNNmNNN"_NN==~~m "_'m_mm'N~W~-.VAY~'~-~=_~Nm^,'~mNmm==='~'~=~_ =^'~W'N='~~~m_~N~'-' Name: 18-l4B Permit Application.ZIP ~ 18 l4B P . A 1· . ZIP Type: Zip Compressed Data (application/x -zip-compressed) - ermlt pp lcatlon. E d' b 64 nco mg: ase Description: 18-14B Permit Application.ZIP e e To: Winton Aubert - AOGCC Date: November 13, 2003 From: Rob Tirpack - BPXA GPB Rotary Drilling Subject: 18-14B Use Permit #203-063 for Rotary Drilling Ops Approval is requested to use Permit #203-063 to rotary drill 18-14B. This horizontal Ivishak Zone 1A producer has been shut-in since September 2003 due a failed SCSSV and a cretaceous leak. During CTD operations, the SCSSV failed in a partially closed position. The valve was locked open, but a portion of the curved flapper still partially obstructs the tubing. CTD work has been deemed too risky. Slickline/wireline operations are still acceptable. The well bore is providing no production or value to the field as it currently sits. During the CTD operations, a 3-3/8" Baker IBP and whipstock were successfully placed prior to the SCSSV failing. The 18-14A slotted liner has been isolated with the 3-3/8" IBP. Additional isolation will be gained during the sidetrack operations by placing a bridge plug above the current CTD whipstock and fully cementing the 3-1/2" production liner. The proposed horizontal sidetrack will target Zone 1A reserves in the south part of DS18 immediately north of the mid-field graben. The sidetrack is planned as a 2600' MD sidetrack with a fully cemented solid liner completion. In addition to the sidetrack work, a scab liner will be set and cemented to cover a cretaceous leak. The 18-14B sidetrack is currently scheduled for Nabors 2ES beginning around 02/01/03, after completing the H-05A sidetrack. The pre-rig work for this sidetrack will be priority scheduled. Scope Pre-Ria Work: 1. Drift 4-1/2", 12.6#, L-80 tubing to the production packer at 8428' MD. 2. Chemical cut the 4-1/2", 12.6#, L-80 tubing at -8400' MD. 3. Fluid pack T X IA with 9.6 ppg brine and freeze protect same to 500' MD with diesel. 4. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 3000 psi. 5. Function all lock-down screws. Repair or replace as needed. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV in tubing hanger. Secure well. 8. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. 18-14B Drilling Permit e e Ria Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to 9.6 ppg brine. 3. Monitor IA for pressure. Calculate required fluid weight to kill IA. 4. Circulate kill weight fluid. Verify well is dead. 5. Set TWC. Nipple down tree. Nipple up and test BOPE. Pull TWC. 6. Pull 4-1/2" tubing from above pre-rig cut. 7. RIH with fishing BHA, shear out K-Anchor and POOH with same. 8. RIH with packer milling BHA. 9. Mill 7-5/8" X 4-1/2" Baker SABL-3 packer at 8428' MD. Recover packer and tubing tail. 10. Clean out well bore down to 7-5/8" X 5-1/2" liner hanger. 11. RIH with polishing BHA. Polish Baker C-2 tieback sleeve. 12. RU e-line. Run GRUB for 5-1/2",17# casing to 9700'. 13. MU 5-1/2", 17# bridge plug on e-line with CCL. RIH and set at 9670' MD, set as needed to avoid cutting a casing collar. 14. MU and RIH with 5-1/2",15.5# scab liner. Stab liner into C-2 tieback sleeve @ 8509'. 15. Set top of scab liner at 3552' MD and cement in place. Wait on cement. 16. Pressure test casing to 3500 psi for 30 minutes. 17. RIH with 5-1/2" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 18. Swap over to 8.5 ppg milling/drilling fluid. 19. Mill window in 5-1/2" casing at 9650' MD, plus 20' past middle of window. Perform FIT. POOH. 20. MU 4-3/4" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 4-3/4" intermediate interval, building and turning at 14°/100' to a 90° hold angle. 21. Drill the 4-3/4" production interval, targeting the Z1A Ivishak. Drill ahead to an estimated TD of 12,310' MD 22. Run and cement a 3-1/2" solid liner throughout the 4-3/4" wellbore and back into the 5-1/2" drilling liner to 9500' MD. 23. Displace well to clean seawater. 24. Run 3-1/2",9.2#, 13-Cr, VAM ACE completion with SCSSV tying into the 3-1/2" liner top. 25. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 26. Set and test TWC. 27. ND BOPE. NU and test the tree to 5000 psi. 28. Freeze protect the well to -2200' and secure the well. 29. RDMO Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Pre-rig Start Date: 12/01/03 Estimated Spud Date: 02/01/04 Rob Tirpack Operations Drilling Engineer 564-4166 18-14B Drilling Permit It 1ffÆ1fŒ (ID~ fÆ~fÆ~~fÆ . AIt~SIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 18-l4B BP Exploration (Alaska), Inc. Permit No: 203-063 Surface Location: 929' SNL, 341' EWL, Sec. 19, TIIN, RI4E, UM Bottomhole Location: 3869' SNL, 48, WEL, Sec. 24, TIIN, RI4E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you fi-om obtaining additional permits or approvals required by law fi-om other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this /7 day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section VJ4í\- q!/Iø/1ßoJ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMI&N PERMIT TO DRILL 20 MC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 47.7' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028307 7, Unit or Property Name Prudhoe Bay Unit 8. Well Number 18-148 / 9. Approximate spud date 05/05/03 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 /'12200' MD / 8710' TVDss o 17. Anticipated pressure {S~20 MC 25.035 (e) (2)} 90 Maximum surface 2284 psig, At total depth (TVD) 8800' I 3340 psig Setting Depth To Bottom MD 9600' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 692100, Y = 5960948 929' SNL, 341' EWL, SEC, 19, T11 N, R15E, UM At top of productive interval x = 693630, Y = 5957833 4082' SNL, 1791' EWL, SEC, 19, T11N, R15E, UM At total depth A'¡'c x = 691786, Y = 5957999 ~ S...NL, ~~EL, SEC. 24, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028321, 48' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10030' MD Maximum Hole Angle 18. Casing Program S ·f' t' Size pecl Ica Ions Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Liner 11 035 feet 8767 feet 11 035 feet 8767 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 115' 16" 3452' 10-3/4" 8700' 7-5/8" 1803' 5-1/2" 618' 2-7/8" 1540# Poleset 2200 sx CS III, 400 sx CS II 300 sx Class 'G' 115' 3452' 8700' 115' 3452' 7806' 226 sx Class 'G' Uncemented Slotted Liner REG;fX7::ü 7661' - 8748' 8749' - 8764' APR 1 5 2003 Perforation depth: measured Slotted Section: 10352' - 10937' true vertical Slotted Section: 8749' - 8764' Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 1120 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood, 564-4378 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that the fo g ing..is r ' . and corfect to the best of my knowledge \v v..ßb::xA . Title CT Drilling Engineer API Number 50- 029-21614-02 Samples Required 0 Yes JBI No Hydrogen Sulfide Measures g Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K Other: I~St- RoPE to ~ÇOO ps.¿. Æ~ 4Ã Date Rev. 12-01-85 e BP 18-14B CTD Sidetrack e Summary of Operations: A 3%" OH through tubing sidetrack is planned for 18-14A. The sidetrack, 18-14B, will exit the 5%" liner in the Ivishak Z1 B and will build & turn towards a Z1 A target. Phase 1, Well preparation: In preparation for the sidetrack, tubing & casing, wellhead and tree valve pressure integrity will be verified. Following this an inflatable bridge plug will be set in the 5%" liner @ 10,045' to isolate the 2%" slotted liner below. Then a 4%" x 5%" thru tubing whipstock will be run and set @ 10,030'. / Phase 2, CTD Operations : Nordic 1 CTO rig will MIRU with ~COil. After milling a window in the 5%" liner off of the whipstock @ 10,030', -2, 170' o~"\ open hole will be drilled. From the Z1 B KOP, the sidetrack will build to 90° & turn 130° to the west onto a Z1 A reservoir target. A pre drilled 2318" x solid 33h6" liner will complete the well bonsai style, with cement being placed r-- thought the build & back into the parent well. The top of the liner cement will be placed @ 9,600', -430' above the window. Nordic 1 will most likely move onto 18-14A during the second week of May 03. Mud Program: /' Plan to mill the window in the 5%" liner with an 8.6ppg 2% KCI / Y2ppb biozan fluid system. Thereafter an 8.6ppg Flo-Pro mud system will continue to be used to drill the formation. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will a Bonsai style pre-drilled 2W' x solid 33116" L80, run from TO, 12,200'md, (8710'tvdss) to 9,600'æd 5'tvdss). It will be cemented from - 10,700' back to the TOL@9,600',(-430' above ~ window) with approx bb of Class G Latex cement. This will leave -1500' of pre drilled liner to produce the well. In the unlikely event . ement fails to hydraulically isolate the sidetrack a liner top packer will be run to complete the job. -- Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan, (18-14B Plan #3. Max. planned hole angle is 90°) · Magnetic and inclination surveys will be taken with MWO every 30 ft. Logging Real time MWO & Gamma Ray logs will be run over all of the open-hole section. A memory CNL log will be run in the cased hole. Hazards · H2S on 18-14 has not been measured. Max recorded H2S on OS18 is 12ppm from well 18-24AL1, 1/12/00 ./ · There are no planned fault crossings. The risk of encountering a lost circulation event is therefore low. Reservoir Pressure Res. pressure is esti~èd to be 3340 psi at -8800'ss (7.3 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2284 psi. TREE'" WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 7-1/16" FMC FMC BAKER C 55' FETY NOTES: WELL ANGLE> 70 DEG 10001' & > 90 DEG @ 10359'. e 18-14A 4500' 92 @ 10876 10289' 8700' SS 2191' H 4-1/2"CAMCOTRCF-4A TRSV, ID=3.812" I . lVD 3253 5584 7539 10-314" CSG, 45.5#, L-80, 10 = 9.953" GAS LIFT MANDRELS DEV TYÆ VLV LTCH 1 TMPDX DOM BK 36 TMPDX DV BK 37 TMPDX SIO BK PORT DA TE 16 05/05/97 o 02/25/95 24 05/05/97 ST MD 1 3253 2 5723 3 8360 Minimum ID = 2.387" @ 10351' 3-1/2" X 2-7/8" LNR XO 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 8427' 8428' 7-5/8" X 4-1/2" BKR SABL3 A<R, ID = 3.875" 8463' 7-5/8" X 5-1/2" BKR HMC HGR, ID = 4.938" 7-5/8" X 5-1/2" BKR H A<R, ID = 4.812" 4-1/2" TTP, 12.6#, L-80, .0152 bpf, ID = 3.958" I BKR C-2 TIEBACK SLV, 10 = 5.750" DATE 11/08/86 02125/95 04/01/95 09/27/00 02/27/01 8485' 4-1/2" TUBING TAIL WLEG I 8517' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" H 8700' 1- 7-5/8" MILLOUT WINDOW 8700' - 8750' (SECTION MILL) NOTE: PRE-SDTRK WELLBORE HAS BEEN P&A'D AND IS NOT SHOWN BELOW 7-5/8" MILLOUT WINDOW. 3.50" BKR G LNDNG SUB, ID = 2.992" I 5-1/2" LNR, 17#, L-80, .0232 bpf, ID=4.767" H 10312' I 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" I I BOTTOM OF 2-7/8" SLOTTED LNR H 2-7/8" BKR O-RING SUB, 10 = 1.250" I 2-7/8" LNR, 6.5#, L-80, FL4S, .0058 bpf, ID = 2.387" I REV BY COMMENTS ORIGINAL COMA..ETION RIG SIDETRACK CTD ( 2-7/8" SL TD LNR) SIS-1s1 CONVERTED TO CANVAS SIS-LG FINAL DATE REV BY COMMENTS 10/24/01 CHlKAK CORRECTIONS PRUDHOE BAY UNIT WELL: 18-14A ÆRMIT No: 195-0070 API No: 50-029-21614-01 4350' FSL & 4613' FEL, Sec. 19, T11N, R15E BP Exploration (Alas ka) 10-3/4" CSG, 45.5#, L-80, 10 = 9.953" FETY NOTES: WELL ANGLE> 70 10001' & > 90 DEG @ 10359', Minimum ID::: 2.387" @ 10351' 3-1/2" X 2-7/8" LNR XO ST DATE 1 3253 3253 05/05/97 2 5723 5584 DV 02/25/95 3 8360 7539 SIO 05/05/97 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3,958" H 8427' 4-1/2" TIP, 12.6#, L-80, .0152 bpf, ID = 3.958" I BKR C-2 TIEBACK SLV, ID = 5.750" 7-5/8" X 5-1/2" BKR HMC HGR, ID = 4.938" 7-5/8" CSG, 29.7#, L-80, ID = 6,875" . H 8750' 7-5/8" MILL OUT WINDOW 8700' - 8750' (SECTION MILL) NOTE PRE-SDTRK WELLBORE HAS BEEN P&A'D AND IS NOT SHOWN BELOW 7-5/8" MILLOUT WINDOW. 10291' 10351' 10352' PBTD H 10937' I COMMENTS INAL COMPlËTION RIG SIDËTRACK CTD( 2-7/8" SLT'DLNR) S18-lsl CONVERTEDTOCANVA8 SIS-LG FINAL PRUDHOE BA Y UNIT WELL: ÆRMIT No: API No: 4350' FSL & 4613' FEL, BP Amoco Pnr~tlt WelJpath: Tie on MÐ: WElLPATH DETAilS Phîm#318.148 500292161402 18·14A 10001Jro Rig: Ref. Datum: 27, 14A 2/1611995 00:00 6$.700 V.se<:tlon _I. 277.00' <¡rko/.s ~~~¡ÿ 0.00 0.00 ~=:::¡~D 0,-01) -- -- ..---------.__... _____.___nm REFERENCE INFORMATION 65.70 SECTION ØETAU.S 8644.94 .ø".n.55 flS58.$2 8GM',!>ß 8700.5& .ß100.IHf -81'01).1i6 <l7-oM~2 -8104.42- 31-06.$8 87.08"'6 :ii:~~ m.;¡¡g 1459,39 -O.OG 14511;.11 ;.rn 146$.3$ ,GOo 1470.3fì- 27.0(1 1276.69 27..00- 1012.511 12.00 tlVl.37 1-2.1)0 593.00 12.00 359,6~ 12.1)0 126.1:8 12.0:0 -i07.0S 1:2.1.10 :~:~:: ~i:~g .1825.,81 .183ß.11 ·1844.21 -1855.83 .159.3,43 .142:U"" -123:VJ:l ~g:~~ -5US.\H' -.265.4$ ·:¡!:3.1IO 27:00 Target '316~21 -$195.80 .3214.42- .3252:.111 .34$1.33 .342&.\U! .337-5.83 .3294.44 ·3213.07 ·3131.69 -30fiD.32 :~~~~:~: 35~:~g 35.00 mtOO 00.00 W,o.) Mjß 90.00 .q,¡ø.OO ANNOTATIONS MO Anøo.tat1ø1'i 8100 8150 8200 8250 8300 8350 .s:: 8400 1- Q> 8450 Q 7i 8500 Co» 1: 8550 Q> :> 8600 Q> e ... 8750 8800 8850 - +- !" -3200 1:: <) -3300 Z "'- .....-3400 -- .s:: '5 -3500 <) en -3600 LEGEND T Azimuths to True North Magnetic North: 26.020 Magnetic Field Strength: 57554nT Dip Angle: 80.85' Date: 4/212003 Model: BGGM2002 Plan: Plan #3 (18-14fP!an#3 18~14B) M Date: 4/2/2003 Created By: Srij Potnis -2400 -2500 -2600 -2700 -2800 -2900 -3700 -3800 -3900 -4000 -4100 -800 -700 -600 -500 -400 -300 -200 -100 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 West(ø)/East(+-) [100ftlin] -1850-1800-1750-1700-1650-1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 0 50 Vertical Section at 277.00' [50ft/in] 4/2/2003 3:03PM ObP B.!ÞHngheS IN:~ Planning Re~ B.. B.."'" IllIG... [NTEQ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Model: Alaska, Zone 4 Well Centre BGGM2002 ~_._----'-'-"-------'---------'-'-----'-'---~'-.,._--_.'_.'. ------,._-~----------------~---~--_.__.._-------------._-,_._,--_..__._._.._-,------_.._~-------- 18-14B Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 18-14B T3.1 18-14B T3.2 8644.94 8653.55 8658.62 8666.66 8700.58 8700.58 8700.58 8701.92 8704.42 8706.58 8708.46 8710.08 --I Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft Latitude: 70 17 35.252 N 691583.44 ft Longitude: 148 26 55.555 W North Reference: True Grid Convergence: 1.46 deg --' Slot Name: 14 Well: 18-14 18-14 Well Position: +N/-S 1720.96 ft Northing: 5960947.74 ft Latitude: +E/-W 560.77 ft Easting: 692100.14 ft Longitude: Position Uncertainty: 0.00 ft 70 17 52.178 N 148 26 39.208 W Wellpath: Plan#3 18-14B 500292161402 Current Datum: 27: 14A 2/16/1995 00:00 Magnetic Data: 4/2/2003 Field Strength: 57554 nT Vertical Section: Depth From (TVD) ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 18-14A 10001.00 ft Mean Sea Level 26.02 deg 80.85 deg Direction deg 277.00 Height 65.70 ft +N/-S ft 0.00 0.00 -3118.14 -540.05 5957817.00 691640.00 70 17 21.511 N 148 26 54.944 W 0.00 -3118.14 -540.05 5957817.00 691640.00 70 1721.511 N 148 26 54.944 W 0.00 -3330.63 23.74 5957619.00 692209.01 70 17 19.421 N 148 26 38.516 W 0.00 -3575.25 904.82 5957397.00 693096.00 70 17 17.015 N 148 26 12.845 W 0.00 -3665.78 1393.70 5957319.00 693587.01 70 17 16.124 N 148 25 58.601 W 0.00 -3202.68 1357.52 5957780.99 693539.00 70 17 20.678 N 148 25 59.653 W 0.00 -3081.47 803.40 5957887.99 692982.00 70 17 21.871 N 148 26 15.798 W 0.00 -2975.74 267.90 5957980.00 692444.00 70 17 22.911 N 148 26 31.402 W 0.00 -2815.02 -227.18 5958128.00 691945.00 70 17 24.492 N 148 26 45.828 W 0.00 -2755.39 -446.74 5958181.99 691724.00 70 17 25.078 N 148 26 52.226 W 8700.00 -3381.38 873.77 5957590.00 693060.00 70 17 18.922 N 148 26 13.749 W 8710.00 -2912.52 -404.74 5958026.00 691770.00 70 17 23.533 N 148 2651.002 W Targets Annotation 10001.00 10030.00 10050.00 10090.00 10423.33 10698.33 10893.33 11143.33 11393.33 11643.33 11893.33 12143.33 TIP KOP 3 4 5 6 7 8 9 10 11 12 ObP B"'HUgheS IN:~ Planning Re~ Biií. u_ HUGill. ïNTEij"-'-- Annotation 8710.41 TD Plan: Plan #3 Date Composed: 41212003 Identical to Lamar's Plan #3 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10001.00 70.84 163.97 8644.94 -3169.21 1450.39 0.00 0.00 0.00 0.00 10030.00 74.58 163.66 8653.55 -3195.80 1458.11 12.94 12.90 -1.07 355.43 10050.00 76.06 164.72 8658.62 -3214.42 1463.38 9.00 7.38 5.32 35.00 10090.00 80.80 174.63 8666.66 -3252.91 1470.36 27.00 11.86 24.77 65.00 10423.33 90.00 264.63 8700.58 -3481.33 1278.69 27.00 2.76 27.00 90.00 10698.33 90.00 297.63 8700.58 -3428.98 1012.58 12.00 0.00 12.00 90.00 10893.33 90.00 274.23 8700.58 -3375.83 826.37 12.00 0.00 -12.00 -90.00 11143.33 89.40 304.22 8701.92 -3294.44 593.00 12.00 -0.24 12.00 91.20 11393.33 89.48 274.22 8704.42 -3213.07 359.64 12.00 0.03 -12.00 -90.00 11643.33 89.55 304.22 8706.58 -3131.69 126.28 12.00 0.03 12.00 90.00 11893.33 89.61 274.22 8708.46 -3050.32 -107.09 12.00 0.02 -12.00 -90.00 12143.33 89.66 304.22 8710.08 -2968.94 -340.46 12.00 0.02 12.00 90.00 12200.00 89.66 297.42 8710.41 -2939.92 -389.09 12.00 0.00 -12.00 -90.00 ft 10001.00 70.84 163.97 8644.94 -3169.21 1450.39 5957816.82 693630.98 -1825.81 0.00 0.00 TIP 10025.00 73.94 163.71 8652.20 -3191.18 1456.76 5957795.02 693637.91 -1834.81 12.94 355.43 MWD 10030.00 74.58 163.66 8653.55 -3195.80 1458.11 5957790.44 693639.38 -1836.71 12.94 355.51 KOP 10050.00 76.06 164.72 8658.62 -3214.42 1463.38 5957771.97 693645.12 -1844.21 9.00 35.00 3 10075.00 78.98 170.95 8664.03 -3238.26 1468.51 5957748.26 693650.86 -1852.21 27.00 65.00 MWD 10090.00 80.80 174.63 8666.66 -3252.91 1470.36 5957733.66 693653.08 -1855.83 27.00 63.65 4 10100.00 80.81 177.37 8668.26 -3262.76 1471.05 5957723.84 693654.02 -1857.72 27.00 90.00 MWD 10125.00 80.93 184.20 8672.23 -3287.42 1470.71 5957699.17 693654.32 -1860.39 27.00 89.56 MWD 10150.00 81.17 191.03 8676.12 -3311.89 1467.44 5957674.64 693651.67 -1860.12 27.00 88.48 MWD 10175.00 81.54 197.85 8679.89 -3335.81 1461.28 5957650.57 693646.13 -1856.92 27.00 87.41 MWD 10200.00 82.02 204.65 8683.47 -3358.85 1452.32 5957627.30 693637.76 -1850.84 27.00 86.39 MWD 10225.00 82.61 211.43 8686.81 -3380.71 1440.68 5957605.16 693626.68 -1841.95 27.00 85.41 MWD 10250.00 83.31 218.20 8689.88 -3401.06 1426.52 5957584.45 693613.04 -1830.37 27.00 84.51 MWD 10275.00 84.10 224.94 8692.62 -3419.64 1410.04 5957565.46 693597.05 -1816.28 27.00 83.68 MWD 10300.00 84.97 231.67 8695.01 -3436.18 1391.47 5957548.45 693578.90 -1799.86 27.00 82.93 MWD 10325.00 85.90 238.38 8697.00 -3450.46 1371.06 5957533.65 693558.87 -1781.35 27.00 82.29 MWD 10350.00 86.90 245.07 8698.57 -3462.27 1349.10 5957521.28 693537.22 -1760.99 27.00 81.76 MWD 10375.00 87.93 251.74 8699.70 -3471.46 1325.89 5957511.51 693514.25 -1739.07 27.00 81.34 MWD 10400.00 89.00 258.41 8700.37 -3477.89 1301.76 5957504.46 693490.29 -1715.90 27.00 81.04 MWD 10423.33 90.00 264.63 8700.58 -3481.33 1278.69 5957500.43 693467.32 -1693.43 27.00 80.86 5 10425.00 90.00 264.83 8700.58 -3481.48 1277.03 5957500.24 693465.67 -1691.80 12.00 90.00 MWD 10450.00 90.00 267.83 8700.58 -3483.08 1252.09 5957498.00 693440.77 -1667.24 12.00 90.00 MWD 10475.00 90.00 270.83 8700.58 -3483.38 1227.09 5957497.07 693415.80 -1642.46 12.00 90.00 MWD 10500.00 90.00 273.83 8700.58 -3482.36 1202.11 5957497.45 693390.80 -1617.55 12.00 90.00 MWD 10525.00 90.00 276.83 8700.58 -3480.04 1177.23 5957499.13 693365.86 -1592.56 12.00 90.00 MWD 10550.00 90.00 279.83 8700.58 -3476.42 1152.49 5957502.12 693341.05 -1567.57 12.00 90.00 MWD 10575.00 90.00 282.83 8700.58 -3471.51 1127.98 5957506.40 693316.42 -1542.64 12.00 90.00 MWD 10600.00 90.00 285.83 8700.58 -3465.32 1103.76 5957511.97 693292.05 -1517.85 12.00 90.00 MWD 10625.00 90.00 288.83 8700.58 -3457.87 1079.90 5957518.80 693268.01 -1493.26 12.00 90.00 MWD 10650.00 90.00 291.83 8700.58 -3449.19 1056.46 5957526.88 693244.36 -1468.94 12.00 90.00 MWD ObP ~ BP . Baker Hughes INTEQ Planning RePM B.. 8"iICIIII ....IIIS í~TEii--·- MD ft 10675.00 90.00 294.83 8700.58 -3439.29 1033.51 5957536.19 693221.16 -1444.95 12.00 90.00 MWD 10698.33 90.00 297.63 8700.58 -3428.98 1012.58 5957545.96 693199.98 -1422.92 12.00 90.00 6 10700.00 90.00 297.43 8700.58 -3428.21 1011.10 5957546.70 693198.48 -1421.36 12.00 270.00 MWD 10725.00 90.00 294.43 8700.58 -3417.28 988.62 5957557.05 693175.73 -1397.71 12.00 270.00 MWD 10750.00 90.00 291.43 8700.58 -3407.54 965.60 5957566.20 693152.46 -1373.67 12.00 270.00 MWD 10775.00 90.00 288.43 8700.58 -3399.02 942.10 5957574.11 693128.76 -1349.31 12.00 270.00 MWD 10800.00 90.00 285.43 8700.58 -3391.74 918.18 5957580.78 693104.67 -1324.69 12.00 270.00 MWD 10825.00 90.00 282.43 8700.58 -3385.72 893.92 5957586.17 693080.26 -1299.87 12.00 270.00 MWD 10850.00 90.00 279.43 8700.58 -3380.98 869.38 5957590.28 693055.60 -1274.94 12.00 270.00 MWD 10875.00 90.00 276.43 8700.58 -3377.53 844.62 5957593.10 693030.77 -1249.94 12.00 270.00 MWD 10893.33 90.00 274.23 8700.58 -3375.83 826.37 5957594.33 693012.48 -1231.62 12.00 270.00 7 10900.00 89.98 275.03 8700.58 -3375.29 819.72 5957594.70 693005.82 -1224.96 12.00 91.20 MWD 10925.00 89.92 278.03 8700.60 -3372.45 794.89 5957596.91 692980.92 -1199.96 12.00 91.20 MWD 10950.00 89.86 281.03 8700.65 -3368.31 770.24 5957600.41 692956.17 -1174.99 12.00 91.20 MWD 10975.00 89.80 284.03 8700.72 -3362.89 745.83 5957605.21 692931.64 -1150.11 12.00 91.19 MWD 11000.00 89.73 287.03 8700.83 -3356.20 721.75 5957611.28 692907.40 -1125.39 12.00 91.18 MWD 11025.00 89.67 290.Q3 8700.96 -3348.25 698.05 5957618.62 692883.50 -1100.89 12.00 91.17 MWD 11050.00 89.61 293.03 8701.11 -3339.08 674.79 5957627.19 692860.02 -1076.70 12.00 91.15 MWD 11075.00 89.55 296.03 8701.29 -3328.70 652.05 5957636.98 692837.03 -1052.86 12.00 91.14 MWD 11100.00 89.50 299.03 8701.50 -3317.15 629.89 5957647.96 692814.57 -1029.45 12.00 91.11 MWD 11125.00 89.44 302.02 8701.73 -3304.46 608.35 5957660.10 692792.72 -1006.53 12.00 91.09 MWD 11143.33 89.40 304.22 8701.92 -3294.44 593.00 5957669.73 692777 .12 -990.07 12.00 91.06 8 11150.00 89.40 303.42 8701.99 -3290.73 587.46 5957673.29 692771.49 -984.12 12.00 270.00 MWD 11175.00 89.40 300.42 8702.25 -3277.51 566.25 5957685.96 692749.95 -961 .46 12.00 270.01 MWD 11200.00 89.40 297.42 8702.51 -3265.42 544.37 5957697.49 692727.77 -938.27 12.00 270.04 MWD 11225.00 89.41 294.42 8702.77 -3254.49 521.89 5957707.84 692705.02 -914.62 12.00 270.07 MWD 11250.00 89.41 291.42 8703.03 -3244.76 498.87 5957716.98 692681.75 -890.59 12.00 270.10 MWD 11275.00 89.42 288.42 8703.28 -3236.24 475.37 5957724.90 692658.05 -866.22 12.00 270.13 MWD 11300.00 89.43 285.42 8703.53 -3228.96 451.46 5957731.56 692633.96 -841.60 12.00 270.16 MWD 11325.00 89.44 282.42 8703.78 -3222.95 427.19 5957736.95 692609.55 -816.79 12.00 270.19 MWD 11350.00 89.46 279.42 8704.02 -3218.21 402.65 5957741.06 692584.90 -791.85 12.00 270.22 MWD 11375.00 89.47 276.42 8704.25 -3214.77 377.89 5957743.87 692560.06 -766.86 12.00 270.25 MWD 11393.33 89.48 274.22 8704.42 -3213.07 359.64 5957745.10 692541.77 -748.54 12.00 270.28 9 11400.00 89.48 275.02 8704.48 -3212.53 353.00 5957745.47 692535.11 -741.87 12.00 90.00 MWD 11425.00 89.48 278.02 8704.71 -3209.69 328.16 5957747.67 692510.22 -716.88 12.00 89.99 MWD 11450.00 89.48 281.02 8704.93 -3205.55 303.51 5957751.18 692485.47 -691.91 12.00 89.97 MWD 11475.00 89.49 284.02 8705.16 -3200.13 279.11 5957755.97 692460.94 -667.03 12.00 89.94 MWD 11500.00 89.49 287.02 8705.38 -3193.44 255.Q3 5957762.04 692436.69 -642.31 12.00 89.91 MWD 11525.00 89.50 290.02 8705.60 -3185.50 231.32 5957769.38 692412.80 -617.82 12.00 89.88 MWD 11550.00 89.51 293.02 8705.81 -3176.33 208.07 5957777.95 692389.32 -593.62 12.00 89.86 MWD 11575.00 89.52 296.02 8706.03 -3165.96 185.33 5957787.74 692366.32 -569.78 12.00 89.83 MWD 11600.00 89.53 299.02 8706.23 -3154.41 163.16 5957798.72 692343.87 -546.37 12.00 89.81 MWD 11625.00 89.54 302.02 8706.44 -3141.71 141.63 5957810.86 692322.02 -523.45 12.00 89.78 MWD 11643.33 89.55 304.22 8706.58 -3131.69 126.28 5957820.48 692306.42 -506.99 12.00 89.76 10 11650.00 89.55 303.42 8706.64 -3127.98 120.74 5957824.05 692300.79 -501.04 12.00 270.00 MWD 11675.00 89.55 300.42 8706.83 -3114.76 99.52 5957836.72 692279.24 -478.38 12.00 270.01 MWD 11700.00 89.55 297.42 8707.03 -3102.67 77.65 5957848.24 692257.06 -455.19 12.00 270.03 MWD 11725.00 89.56 294.42 8707.22 -3091.75 55.16 5957858.59 692234.31 -431.54 12.00 270.05 MWD 11750.00 89.56 291.42 8707.41 -3082.01 32.14 5957867.74 692211.05 -407.51 12.00 270.08 MWD 11775.00 89.57 288.42 8707.60 -3073.49 8.64 5957875.65 692187.34 -383.14 12.00 270.10 MWD 11800.00 89.57 285.42 8707.79 -3066.22 -15.27 5957882.31 692163.25 -358.52 12.00 270.12 MWD 11825.00 89.58 282.42 8707.98 -3060.20 -39.53 5957887.71 692138.84 -333.71 12.00 270.15 MWD 11850.00 89.59 279.42 8708.16 -3055.46 -64.08 5957891.81 692114.19 -308.77 12.00 270.17 MWD -- .' .- --- ------ ---... .~---_._--_._- . - - ---------_.._._.."'_..._------------_._-,---,-~-----~--- - ----_._._------~~-~._----_._--~-----------------_._---_.------.-.- -- _._--_._-_.._--~.__."..._-~ ObP _ BP __ Baker Hughes INTEQ Planning Report B.. BA_ ...... "'"--'~-""--~-'-'~- INTEQ 11 11900.00 89.61 275.02 8708.50 -3049.78 -113.73 5957896.23 692064.40 -258.79 12.00 90.00 MWD 11925.00 89.61 278.02 8708.67 -3046.94 -138.57 5957898.43 692039.51 -233.79 12.00 89.99 MWD 11950.00 89.61 281.02 8708.84 -3042.80 -163.22 5957901.93 692014.76 -208.82 12.00 89.97 MWD 11975.00 89.62 284.02 8709.01 -3037.38 -187.62 5957906.73 691990.23 -183.94 12.00 89.95 MWD 12000.00 89.62 287.02 8709.18 -3030.69 -211.71 5957912.80 691965.98 -159.22 12.00 89.93 MWD 12025.00 89.63 290.02 8709.34 -3022.75 -235.41 5957920.13 691942.09 -134.73 12.00 89.91 MWD 12050.00 89.63 293.02 8709.50 -3013.58 -258.66 5957928.71 691918.61 -110.53 12.00 89.89 MWD 12075.00 89.64 296.02 8709.66 -3003.21 -281.40 5957938.50 691895.61 -86.69 12.00 89.87 MWD 12100.00 89.65 299.02 8709.82 -2991.66 -303.57 5957949.48 691873.15 -63.28 12.00 89.86 MWD 12125.00 89.66 302.02 8709.97 -2978.96 -325.10 5957961.62 691851.31 -40.36 12.00 89.84 MWD 12143.33 89.66 304.22 8710.08 -2968.94 -340.46 5957971.24 691835.70 -23.90 12.00 89.82 12 12150.00 89.66 303.42 8710.12 -2965.23 -345.99 5957974.81 691830.07 -17.96 12.00 270.00 MWD 12175.00 89.66 300.42 8710.27 -2952.01 -367.21 5957987.48 691808.53 4.71 12.00 270.00 MWD 12200.00 89.66 297.42 8710.41 -2939.92 -389.09 5957999.00 691786.35 27.90 12.00 270.02 TO -- -- All Measurements are from top of Riser 7/9/2002 "- Q) CJ) .- a: bttm of bag BAG top of bag middle of slips Blind/Shears .......................... middle of pipe/slips TOTs /" middle of pipes Mud Cross middle of flow cross middle of blindlshears TOTs /' Flow Tee 1'055041 . DATE ~/12/2003 CHECK NO. 055041 __ DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 3/12/2003 INV# CK030603N ./ PERMIT TO DRILL \ 8- \,Sß H THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ e BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK 99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 055 041 CONSOLIDATED COMMERCIAL ACCOUNT PAY: e TO THE ORDER OF: II· 0 5 5 0... Ii II· I: 0... Ii 2 0 ~ a t¡ 5 I: 0 Ii 2 ? a t¡ b III e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing wen_, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. Pn,OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, . data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. DRY DITCH An dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07/10/02 C\jody\templates WELL PERMIT CHECKLIST COMPANY /JP% WELLNAME/ðY~ /~-/~~ PROGRAM: Exp Dev~ RedrllX Re-Enter Serv Wellbore seg FIELD & POOL C,.c.¡ÓJ ft') INIT CLASS be.-v /-0'/ ï GEOL AREA q~t"'.) UNIT# /( ~(~ ON/OFF SHORE ...sz:¡) ..... ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . fY~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . · . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . Y N 1'// ~ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . ~~ 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located w/in area & strata authorized by injection order#_ ~~,A', (Service Well Only) 14. All wells w/in X mile area of review identified. · . . . N ' ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . '¥-N- 16. Surface casing protects all known USDWs. . . . . . . . . . . 4'-N- fÚll\- 17. CMT vol adequate to circulate on conductor & surf csg. . . . ¥-N- 18. CMT vol adequate to tie-in long string to surf csg. . · . . ·0 . . --¥:::-f<t" 19. CMT will cover all known productive horizons. . . . . . . . . . ~~ CT[)l-L 20. Casing designs adequate for C, T, B & permafrost. · . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . *Y N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . œ'N 24. If diverter required, does it meet regulations. . . . . . . . . . .-¥-tr I'i I Æ- 25. Drilling fluid program schematic & equip list adequate. . . . . j N fW"4' fH J¡..1 ß.. t- ffJ1 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N . APPR DATE 27. BOPE press rating appropriate; test to ~500 psig. .. . N ;14.ç /) 2. Z ¡ 'f t? b/ . \lJGÄ- 4-1 {(¡,! ()~ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N · 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y~ (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-t'i- Al/A- GEOLOGY 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y~I APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . $AAIi. l/J'/ ~)~ 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . · . . . . . (Exploratory Only) 36. Contact namelphone for weekly progress reports. · . . . . . GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER0 Comments/Instructions: RP~ TEM JDH JBR cëör .S'~ ( /~ DTS ~03 ~C:. V' MJW SFD - WGA Rev: 07/12/02 e e G:\geology\permits\checklist.doc e e 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. e e Sperry-Sun Drilling Services LIS Scan Utility * I HL-/l $Revision: 3 $ LisLib $Revision: 4 $ Mon Apr 12 09:37:44 2004 Át )-('¡~) Reel Header Service name...... .......LISTPE Date. . . . . . . . . . . . . . . . . . . . . 041 04/12 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/04/12 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 18-14B 500292161402 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 12-APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002916013 J. SACK J. RALL 1 D. MWD RUN 2 MW0002916013 J. BOBBITT R. BORDES 1 MWD RUN 3 MW0002916013 J. SACK R. BORDES 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 MW0002916013 J. SACK R. BORDES 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 IlN 15E 929 341 46.40 17.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 9568.0 # REMARKS: e e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 18-14 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9568'MD/8442'TVD; THE BOTTOM WAS AT 9580'MD/8450'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK AND MILL THE WINDOW. 5. MWD RUN 2 COMPRISED DIRECTIONAL WITH GM. UPHOLE, TIE-IN (BEHIND CASING) SGRC DATA WERE ACQUIRED WHILE POOH AFTER THE COMPLETION OF RUN 2. THESE DATA ARE MERGED WITH RUN 1 MWD DATA. 6. MWD RUN 3 COMPRISED DIRECTIONAL; GM; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA FOR 2 SEPARATE INTERVALS WERE ACQUIRED DURING 2 DIFFERENT SHORT TRIPS. THESE DATA ARE PRESENTED SEPARATELY. 7. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 6 FEET DOWNWARD, PER E-MAIL FROM K. COONEY, BP EXPLORATION (ALASKA), INC., DATED 3/19/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 1 - 3 REPRESENT WELL 18-14B WITH API#: 50-029-21614-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12270'MD/8746'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record 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 GR ROP FET RPX RPS RPM RPD $ e e START DEPTH 9471. 0 9574.0 10035.5 10035.5 10035.5 10035.5 10035.5 STOP DEPTH 12220.0 12276.0 12230.0 12230.0 12230.0 12230.0 12230.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9471. 0 12276.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 9465.0 12270.0 BIT RUN NO 1 2 3 MERGE BASE 9582.0 10075.0 12270.0 MERGE TOP 9465.5 9582.0 10075.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9471 12276 10873.5 5611 9471 12276 ROP MWD FT/H 0.2 194.28 91. 8926 5381 9574 12276 GR MWD API 13.94 264.38 63.3403 5499 9471 12220 RPX MWD OHMM 8.35 1450.97 140.826 4390 10035.5 12230 RPS MWD OHMM 8.4 2000 191.759 4390 10035.5 12230 RPM MWD OHMM 8.21 2000 198.68 4390 10035.5 12230 RPD MWD OHMM 9.63 2000 336.067 4390 10035.5 12230 FET MWD HOUR 0.27 19.79 1.19461 4390 10035.5 12230 First Reading For Entire Fi1e..........9471 Last Reading For Entire Fi1e...........12276 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type............... .LO e e Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SFXE SEDP SEMP SESP SEXP SRAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10689.5 10700.5 10700.5 10700.5 10700.5 10700.5 10747.5 STOP DEPTH 11504.0 11514.0 11514.0 11514.0 11514.0 11514.0 11560.0 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 10029.5 MERGE BASE 12270.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX M.z\D OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10689.5 11560 11124.8 1742 10689.5 11560 RAT MAD FT/H 0.01 1951.23 278.841 1244 10747.5 11560 GR MAD API 48.77 105.49 69.1898 1243 10689.5 11504 RPX MAD OHMM 90.94 194.89 122.734 1251 10700.5 11514 RPS MAD OHMM 101. 34 232.5 148.329 1251 10700.5 11514 RPM MAD OHMM 102.88 220.41 149.09 1251 10700.5 11514 RPD MAD OHMM 94.03 492.88 212.24 1251 10700.5 11514 FET MAD HOUR 14.47 34.85 25.701 1251 10700.5 11514 e First Reading For Entire File..........l0689.5 Last Reading For Entire File...........11560 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/04/l2 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name............ . STSLIB. 003 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 e header data for each bit run in separate files. 1 .5000 START DEPTH 9465.5 9568.0 STOP DEPTH 9553.5 9582.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 21-FEB-04 Insite 4.3 Memory 9582.0 9568.0 9582.0 .0 .0 TOOL NUMBER 93091 4.750 3550.0 Flo-Pro 8.50 59.0 9.8 11000 5.0 .000 .000 .0 .0 e e MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .IIN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel I 2 3 Name DEPT ROP GR MWD010 MWD010 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9465.5 9582 9523.75 234 9465.5 9582 ROP MWD010 FT/H 0.33 4.96 2.0269 29 9568 9582 GR MWD010 API 14.7 48.84 23.2146 177 9465.5 9553.5 First Reading For Entire File..........9465.5 Last Reading For Entire File...........9582 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 4 header data for each bit run in separate files. 2 .5000 e VENDOR TOOL CODE GR ROP $ START DEPTH 9554.0 9594.5 STOP DEPTH 10037.5 10075.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API Name Service Unit DEPT FT ROP MWD020 FT/H Min 9554 0.26 Max 10075 140.57 27-FEB-04 Insite 4.3 Memory 10075.0 9582.0 10075.0 48.3 80.8 TOOL NUMBER 93091 4.750 9580.0 Flo-Pro SF 8.50 51. 0 9.5 11400 4.5 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean 9814.5 54.6003 Nsam 1043 962 e .0 120.0 .0 .0 First Reading 9554 9594.5 Last Reading 10075 10075 e e GR MWD020 API 13.94 264.38 28.2908 968 9554 10037.5 First Reading For Entire File..........9554 Last Reading For Entire File...........10075 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record_.65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPM RPX RPD GR ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 10029.5 10029.5 10029.5 10029.5 10029.5 10038.0 10075.5 STOP DEPTH 12224.0 12224.0 12224.0 12224.0 12224.0 12214.0 12270.0 # 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: 29- FEB-04 Insite 4.3 Memory 12270.0 10075.0 12270.0 72.3 94.0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 93091 178424 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 9580.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Flo-Pro 8.50 e e MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 51. 0 9.4 9500 5.4 .700 .340 .650 .740 71. 0 155.0 71. 0 71. 0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. ...... ..........0 Data Specification Block Type... ..0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10029.5 12270 11149.8 4482 10029.5 12270 ROP MWD030 FT/H 0.2 194.28 100.658 4390 10075.5 12270 GR MWD030 API 14.3 229.18 72.776 4353 10038 12214 RPX MWD030 OHMM 8.35 1450.97 140.826 4390 10029.5 12224 RPS MWD030 OHMM 8.4 2000 191. 759 4390 10029.5 12224 RPM MWD030 OHMM 8.21 2000 198.68 4390 10029.5 12224 RPD MWD030 OHMM 9.63 2000 336.067 4390 10029.5 12224 FET MWD030 HOUR 0.27 19.79 1.19461 4390 10029.5 12224 First Reading For Entire File..........10029.5 Last Reading For Entire File...........12270 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.006 Physical EOF File Header e e Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE SGRC SEDP SEMP SESP SEXP SFXE SRAT $ 6 header data .5000 3 1 for each pass of each run in separate files. START DEPTH 10683.5 10694.5 10694.5 10694.5 10694.5 10694.5 10741.5 STOP DEPTH 11498.0 11508.0 11508.0 11508.0 11508.0 11508.0 11554.0 # 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: 29-FEB-04 Insite 4.3 Memory 11550.0 10740.0 11550.0 72.3 94.0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 93091 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 9580.0 # 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo-Pro 8.50 51. 0 9.4 9500 5.4 .700 .340 .650 .740 71. 0 155.0 71. 0 71.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # e e Data Format Specification Record Data Record Type.................. C Data Specification Block Type.....C Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD031 FT/H 4 1 68 4 2 GR MAD031 API 4 1 68 8 3 RPX MAD031 OHMM 4 1 68 12 4 RPS MAD031 OHMM 4 1 68 16 5 RPM MAD031 OHMM 4 1 68 20 6 RPD MAD031 OHMM 4 1 68 24 7 FET MAD031 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10683.5 11554 11118.8 1742 10683.5 11554 RAT MAD031 FT/H 0.01 1951. 23 278.841 1244 10741.5 11554 GR MAD031 API 48.77 105.49 69.1898 1243 10683.5 11498 RPX MAD031 OHMM 90.94 194.89 122.734 1251 10694.5 11508 RPS MAD031 OHMM 101. 34 232.5 148.329 1251 10694.5 11508 RPM MAD031 OHMM 102.88 220.41 149.09 1251 10694.5 11508 RPD MAD031 OHMM 94.03 492.88 212.24 1251 10694.5 11508 FET MAD031 HOUR 14.47 34.85 25.701 1251 10694.5 11508 First Reading For Entire File..........l0683.5 Last Reading For Entire File...........11554 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.. .... .04/04/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 04/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number.... ..01 Next Tape Name...........UNKNOWN Comments..... ............STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04/04/12 Origin...................STS Reel Name... .... .........UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF t . Physical EOF End Of LIS File e e