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Home My WebLink About197-123XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. /' ~ ~- /~'J~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items- Pages: [] Gray.scale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Odginal- Pages: [] Other- Pages: DIGITAL DATA n Diskettes, No. n Other, No/Type 'OVERSIZED [] .Logs of vadous kinds [3 Other Complete COMMENTS: Scanned by: Seve,y Mitdred-Daretha~ Lowell E3 TO RE-SCAN Notes: Re-Scanned by' Beverly Mildred Daretha Nathan Lowell Date: /si ') STATE OF ALASKA ) ALASKA 01L AND GAS CONSERVATION COMII/IISS10I'bE:C WELL COMPLETION OR RECOMPLETION REPORT AND [])~ . E IVE 0 AUG 08 2005 A'as(~tz!~¥C~¡~ ~~~ry o St~O§;8gs 0 Service 12. Permit to Drill Number 197-123 305-117 13. API Number 50- 029-21615-01-00 14. Well Name and Number: No. of Completions 1 a. Well Status: 0 Oil 0 Gas 0 Plugged IBI Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1166' SNL, 403' EWL, SEC. 19, T11 N, R15E, UM Top of Productive Horizon: 3158' SNL, 4880' EWL, SEC. 19, T11N, R15E, UM Total Depth: 4809' SNL, 3590' EWL, SEC. 20, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-__692168 y- 5960712 Zone-__~SP4 TPI: x- 696694 y- 5958837 Zone- ASP4 Total Depth: x- 700415 y- 5957284 Zone- ASP4 --~---------------------- .---------------------. ----------------.-- 18. Directional Survey 0 Yes IBI No 21. Logs Run: MWD, GR 22. Zero Other 5. Date Comp., Susp., or Aband. 6/18/2005 6. Date Spudded 11/02/1997 7. Date T.D. Reached 11/08/1997 8. KB Elevation (ft): 47' 9. Plug Back Depth (MD+TVD) 14046 + 8798 10. Total Depth (MD+ TVD) 14046 + 8798 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/ A MSL CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE Wr. PER FT. GRADE lOP I::JOTTOM lOP I::JOTTOM SIZE 20" 91.5# H-40 Surface 110' Surface 110' 30" 13-3/8" 68# /72# K-55/ L-80 Surface 2830' Surface 2697' 17-1/2" 9-5/8" 47# L-80 Surface 9935' Surface 8303' 12-1/4" 7" 29# L-80 9631' 11830' 8153' 8737' 8-1/2" 4-1/2" 13.5# N-80 11707' 11991' 8727' 8753' 8-1/2" 2-3/8" 4.6# L-80 11983' 14046' 8752' 8798' 2-3/4" 23. Perforations open to Production (MD + TVD of Top and 24. Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SC¡~NNED l'UG 11 2005 26. Date First Production: Not on Production Date of Test Hours Tested SIZE 3-1/2",9.3#, N-80 TVD 25. PBU 18-12A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028321 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 1610# Poleset 2500 sx Coldset III, 400 sx CS II 500 sx Class 'G', 300 sx CS I 450 sx Class 'G' Uncemented Slotted Liner Uncemented Slotted Liner TUBING RECORD DEPTH SET (MD) 11730' AMOUNT PULLED PACKER SET (MD) 11732' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) 11996' 11860' 11864' AMOUNT & KIND OF MATERIAL USED Set CIBP Set Whipstock P&A w/21 BBls Class 'G' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A OIL -BBL PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL -BBL Press. 24-HoUR RATE GAs-McF W ATER-BBL CHOKE SIZE GAS-OIL RATIO GAs-McF W ATER-BBL OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 10-407 Revised 12/2003 RBDMS BFL AUG 1 1 2005 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS ) 29. ) FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit 9915' 8295' None RECEIVED AUG 0 8 Z005 Alaska Oil & G(~S Cons. Commission Anchorage 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. ~/M;~ W. ()~- Teme Hubble' J(2)r\AK µu..ff\.RQ PBU 18-12A Well Number Title Technical Assistant Date 08·05"-05 197-123 305-117 Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Sean McLaughlin, 564-4387 Permit No.1 Approval 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 1 0-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 18-12B Prudhoe Bay Unit 50-029-21615-02-00 205-073 Accept: Spud: Release: Rig: 06/16/05 06/20/05 07/04/05 Nordic #1 PRE-RIG WORK 04/15/05 DRIFTED W/2.70" CENT, 3' STEM, 2.75" GAUGE RING TO 11800' SLM. RAN PDS CALIPER FROM 11070' SLM TO SURFACE. (DUE TO DEVIATION) 04/20/05 SET SS C-SUB AT 3884' SLM. PULLED 1 1/2" RK- 8/0 FROM STA 1. SET 1 1/2" RK- DGLV IN STA 1. PULLED EMPTY C-SUB. 05/12/05 MIRU. CONDUCT BOP TEST. MU/RIH W/2.625" DRIFT X 3" GS X 1.75" DRIFT W/1.75" JSN ON BTM. KILL WELL W/1% KCL. LATCH G8 INTO LINER TOP AT 12030' DWN/12025' UP. PAINT FLAG AT 12000'. POOH. 05/13/05 MU/RIH W/ SETTING TOOL, 2-3/8" CIBP. NO-GO ON LINER TOP, DROP 1/2" PHENOLIC BALL, SET CIBP AT 11996' CORR. POOH. TBG FP'D TO 2500' W/ METH. RDMO. RECEIVED AUG 0 8 Z005 Alaska on & Gas Cons. Commission Anchorage ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 2 18-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 I3PEXPLORAml0N OpE!ratlonsSummaryRep.Q.rt . Alaska Oil & Gas Cons.Commissicm Anchorage Spud Date: 11/9/1986 End: 7/4/2005 kECEIVEQage1. AUG08 2005 Start: 6/11/2005 Rig Release: 7/4/2005 Rig Number: 1 Date From - To Hours Ta.sk Code NPT Phase Description of Operations 6/12/2005 07:30 - 08:30 1.00 MOB P PRE Rig released from 05-36A @ 07:30Hrs on 6/12/2005. Prep to move rig off well. 08:30 - 10:00 1.50 MOB P PRE PJSM. Jack-up rig. Pull rig off well & set down. Clean up location & conduct post operations pad inspection. 10:00 - 12:45 2.75 MOB P PRE PJSM. Install derrick rams. UD windwalls. Scope down derrick. 12:45 - 13:30 0.75 MOB P PRE PJSM. Open up pipe shed. P/U gooseneck with crane & lower down onto trailer. Secure gooseneck on trailer. UD derrick. 13:30 - 14:00 0.50 MOB P PRE Jack-up rig, hook up camp & prep for move. 14:00 - 14:30 0.50 MOB P PRE Held pre-move safety meeting with crew, security, tool services & CPS. CPS strap & confirm rig's height. 14:30 - 18:00 3.50 MOB P PRE Move rig & camp from 05-36A to DS#18. Meanwhile LRS load & kill 18-12. 18:00 - 00:00 6.00 MOB N WAIT PRE Wait for winds to subside below 20 mph. - Winds at 20 mph, gusting 30-35 mph. 6/13/2005 00:00 - 18:00 18.00 MOB N WAIT PRE Continue to wait on wind. - Winds at +/-20 mph, gusting 30-35 mph. 18:00 - 00:00 6.00 MOB N WAIT PRE Continue to wait on wind. - Winds at +/-20 mph, gusting 30-35 mph. 6/14/2005 00:00 - 07: 15 7.25 MOB N WAIT PRE Continue to wait on wind. - Winds at +/-20 mph, gusting 30-35 mph. 07: 15 - 07:45 0.50 MOB N WAIT PRE Winds subside to 13mph with 22mph gusts. Decide to move rig & lay herculite. PJSM. Jack-up rig. Pull rig off forward. Lay herculite in front of well 18-12. 07:45 - 18:00 10.25 MOB N WAIT PRE Continue to wait on wind to subside before raising derrick & windwalls - Winds at +/-20 mph, gusting 25 - 30mph. Meanwhile repair moving system. Through trouble shooting and discussions with Columbia, determined the front driller's side jack has failed. Repair same. 18:00 - 18:30 0.50 MOB N RREP PRE PJSM for removal of the axle wheel assembly. - Still waiting on wind. 18:30 - 00:00 5.50 MOB N RREP PRE Remove axle and wheel assembly. 6/1 5/2005 00:00 - 02:30 2.50 MOB N RREP PRE Continue to work on removal of axle and wheel assy. Bleed off hydraulic oil from cylinder. Attempt to remove cylinder. No Go 02:30 - 03:00 0.50 MOB N RREP PRE Reevaluate plan. Cylinder housing rusted in will not drop out under it own weight. Evaluate options and risk assess options. 03:00 - 08:00 5.00 MOB N RREP PRE Weld strapes to prevent cylinder from separating. Will use bottle jacks to seperate cylinder from rig while stabilizing cylinder with rig loader. 08:00 - 16:00 8.00 MOB N RREP PRE Weld steering arm to jacking cylinder. 16:00 - 00:00 8.00 MOB N RREP PRE Install jack. -- Still Waiting on winds to subside. Consistent 20 - 30 mph winds. 6/16/2005 00:00 - 04:00 4.00 MOB N RREP PRE Reposition axle and wheel assembly under rig. Land asembly in trunion cradle. Continue to WOW. 04:00 - 05:00 1.00 MOB N RREP PRE Complete installation of wheel and axle assembly. Continue to WOW Wind speed 22 with gusts to 30 mph. WC 15. 05:00 - 10:00 5.00 MOB N WAIT PRE Secure damaged cylinder to base. Function and load test. OK. Continue to wait on wind. 10:00 - 14:00 4.00 MOB N WAIT PRE Wait on wind. Printed: 7/11/2005 10:20:10 AM ') ) ~PEXPLORATION . RECEIVEOage2'- ()peratlønsSummaryReport AUG 0 8 Z005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-12 18-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Alaska Oil &~~r.OI1S. Comm¡~sioo cf Date: "/911986 Start: 6/11/2005 PI . orage 7/4/2005 Rig Release: 7/4/2005 Rig Number: 1 Date From·~ To Hours Task Code NPT Phase Description of Operations 6/16/2005 10:00 - 14:00 4.00 MOB N WAIT PRE Bleed down IA to 1000 psi - gas to 1200' MD as per integrity engineer records. 14:00 - 16:00 2.00 MOB N WAIT PRE Continue to WOW and bleed IA. 16:00 - 16:30 0.50 MOB N WAIT PRE Weather letting up. Gusts at 20 mph. Call out crane. 16:30 - 16:45 0.25 MOB P PRE PJSM for raising derrick 16:45 - 20:15 3.50 MOB P PRE Raise derrick and windwalls. 20:15 - 22:00 1.75 MOB P PRE PJSM Move on to well. 22:00 - 23:30 1.50 MOB P PRE NU BOP's. 23:30 - 00:00 0.50 MOB P PRE Pick up injector. 6/17/2005 00:00 - 00:30 0.50 MOB P PRE Continue to PU injector. 00:30 - 03:30 3.00 RIGU P PRE PU goosneck and stab coil. 03:30 - 12:30 9.00 BOPSUF P PRE Test BOP's. AOGCC's John Crisp waived witnessing the BOP test. - Valve #1 failed and rebuilt. 12:30 - 14:00 1.50 WHIP P WEXIT Weld on CTC. Pull test to 35,000 Ibs / pressure test to 3500 psi. 14:00 - 15:30 1.50 WHIP P WEXIT Injector maintenance. 15:30 - 16:00 0.50 WHIP P WEXIT Pump dart. Hit at 38.2 bbls. 16:00 - 17:00 1.00 WHIP P WEXIT Prep tools for setting whipstock. Open swab and master, 17 turns. - Hole on a vac. Fill hole while RIH. 17:00 - 18:00 1.00 WHIP P WEXIT MU BHA #1. MU injector. 18:00 - 20:30 2.50 WHI P P WEXIT RIH with WS setting BHA 20:30 - 22: 15 1.75 WHIP P WEXIT Attempt to tie-in. Erratic MWD signal detection. Adjusting circulating rates. Shut down pump unable to restablish rate pressure at .25 bpm pressure climbing. Decide to POH. 22: 15 - 00:00 1.75 WHIP N DFAL WEXIT POH to investigate apparent flow restriction in BHA. POH filling backside 6/18/2005 00:00 - 01 :30 1.50 WHIP N DFAL WEXIT Change FAIV, orienter, & MWD probe checked check valves. Frow tested orienter believe it to be partially plugged. Will send orienter in for tear down. 01 :30 - 03:30 2.00 WHIP N DFAL WEXIT RIH. 03:30 - 05:30 2.00 WHIP P WEXIT Tie-in log. -20' correction. 05:30 - 06:00 0.50 WHIP P WEXIT RIH to setting depth. Top of WS at 11860'. Orient to 57L. Circluate at 2.36 bpm at 4325 psi for 4 minutes. Bleed off wait 4 minute. Orient to 40L . Attempt to pressure to set WS but getting returns. Attempt to activate FAIV at higher rate. Increase rate to 2.72 bpm at 4570. Return rate 1.70 bpm. Circulate for 4 minutes. Bleed off and wait 4 minutes. Pressure up. Shear at 1700 psi. & .6 bbl of volume. Orientation 23L. PU and set down with 2k. - Preliminary picks: TOWS 11,860', BOWS 11,873' at 23LOHS. 06:00 - 08:00 2.00 WHIP P WEXIT POH 08:00 - 08:45 0.75 ZONISO P WEXIT Lay down BHA. PU cement nozzle. 08:45 - 11 :00 2.25 ZONISO P WEXIT RIH with cementing BHA. Correct to flag at 11,605' MD. Tag WS at 11,870' MD. Flag pipe at 11,860' MD. 11 :00 - 11: 15 0.25 ZONISO P WEXIT Conduct injectivity test. - Well open: Circ 1.0/0.7 bpm, losing approximately 0.4 bpm at 550 psi. - Shut in: - Circ 1.0 bpm at 700 psi WHP, 1000 psi circ pressure. Printed: 7/11/2005 10:20:10 AM -, ) BP EXPLORATION Operations Summary Report RECEIVltÐ3- AUG 0 8 Z005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-12 18-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 6/18/2005 11:00-11:15 0.25 ZONISO P WEXIT 11: 15 - 11 :30 0.25 ZONISO P WEXIT 11 :30 - 12:45 1.25 ZONISO P WEXIT 12:45 - 13:00 0.25 ZONISO P WEXIT 13:00 - 13:20 0.33 ZONISO P WEXIT 13:20 - 13:45 0.42 ZONISO P WEXIT 13:45 - 14:30 0.75 ZONISO P WEXIT 14:30 - 16:30 2.00 ZONISO P WEXIT 16:30 - 17:00 0.50 ZONISO P WEXIT 17:00 - 19:00 2.00 WHIP P WEXIT 19:00 - 19:45 0.75 STWHIP P WEXIT 19:45 - 22:30 2.75 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 6/1 9/2005 00:00 - 03:50 3.83 STWHIP P WEXIT 03:50 - 05:45 1.92 STWHIP P WEXIT 05:45 - 07:00 1.25 STWHIP P WEXIT 07:00 - 09:15 2.25 STWHIP N WAIT WEXIT 09:15 -11:00 1.75 STWHIP P WEXIT 11 :00 - 11 :45 0.75 STWHIP P WEXIT 11 :45 - 20:30 8.75 STWHIP P WEXIT A'aska Oil & Ga~ L;ons. COmml$Si\m spuJOO¡Q~a~~ /9/1986 Start: 6/11/2005 End: 7/4/2005 Rig Release: 7/4/2005 Rig Number: 1 Description of Operations - Circ 1.5 bpm at 1000 psi WHP, 1700 psi circ pressure. - Open well, decrease rate. PJSM for cementing. Pump squeeze cement: - Pressure test lines to 4000 psi with fresh water. - Pump 15.8 ppg squeeze cement, 21 bbls total. - Follow with KCI. - Shut in well with 39 bbls away (1 bbl cement). - Circ 1.5 bpm, 1000 psi, 1300 WIHP to 44 bbls (6 bbls cement) - Circ 1.0 bpm, 1300 psi, 1500 WHP to 48 bbls (10 bbls cement) - Obtained 500 psi squeeze pressure. - Lay in 11 bbls cement, holding 1500 psi WHP to 10,650' MD. PUH to safety at 9200' MD, holding 1500 psi WHP, pumpng 1 bpm. WOC at safety holding 1500 psi WHP. - Pump 30 bbls 2ppb bio at 1.0 bpm down coil. RIH, holding WHP at 1500 psi, pumping 1 bpm. Suspect may be pumping cement away. Bleed off pressure. Verify 1: 1 returns. OK. Continue to cleanout to flag at 11,860' MD. - Some seepage losses once washed by perfs (0.1 bpm) POOH, replacing voidage. - Hole fill indicates minimal to no losses. Jet stack. PJSM. Conduct pipe straightener test. Test postponed until longer sling can be obtained. Current sling is interfering with straightener. MU window milling BHA. RIH. Correct at flag -14.Tag cement at 11842. Mill window 1.52/ 1.49 bpm at 1920 psi, FS = 1700 psi. Continue milling window 1.54 / 1.54 bpm @ 2500 psi. 3K WOB, ROP 1 fph. 11868 BOW Mill open hole to 11878. Ream window. Dry tag. Wait on trucks for fluid swap. POOH with window milling BHA. Lay down BHA. - 2.74 go / 2.73 no-go string mill - 2.73 go / 2.72 no-go pilot mill PJSM. Commence pipe straightener test. - Bring slings to rig floor. - Add slings to top of injector, eliminate interference with UTIM. - Test straighener at 600,700, and 800 Ibs. No indication of pipe straightening. Mic coil. Straightener "egging" the pipe. - Cut 64' of coil. - PJSM. Remove roller above the guide roller, lengthen the section of pipe being straightened. This allows for too much room between rollers. - Re-install rollers, 2". - Re test increasing the pressure in increments from 1000 Printed: 7/11/2005 10:20:10 AM ) ) BPEXPLORA TION O.peratiorns·SummaryReport RECEIVEG4"- AUG 0 8 2005 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-12 18-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Alaska Uil & ~as Gems. Commission SpuJö'èh8~at¥/9/1986 Start: 6/11/2005 End: 7/4/2005 Rig Release: 7/4/2005 Rig Number: 1 Date From - To Hours Task Code NPT Phase Description of Operations 6/1 9/2005 11 :45 - 20:30 8.75 STWHIP P WEXIT psi, 1500psi and 1750 psi. Seeing local dimpling at initial point of contact when force is applied to stationary pipe. At 1750 psi pipe is flattening. The force is being applied with 2" roller positioned approximately midway between 2 2" rollers18" apart. Hydraulic force applied to a cylinder with assumed 3" dia piston. Estimated bending stress applied approximately 160,000 psi (with 1000 psi hydraulic pressure on 90,000 psi yield material. Flattening pipe.11 0" ovality but not straightening it any noticable amount. Test terminated. 20:30 - 21 :30 1.00 DRILL P PROD1 Install weld on coil connector. Pull test to 35000. OK. Pressure test to 3500 psi OK. 21 :30 - 22:30 1.00 DRILL P PROD1 MU drilling build BHA 2.6 degree motor. 22:30 - 00:00 1.50 DRILL P PROD1 RIH to 180'. PU 10+' to check coil for damage, just to be safe. OK. Continue to RIH 6/20/2005 00:00 - 01 :30 1.50 DRILL P PROD1 Continue to RIH. Tag at 11893 uncorrected. 01 :30 - 02:00 0.50 DRILL N DFAL PROD1 Orient to 108L Lost pulser signal. Attempt changing pumps checked pulsation dampners etc. 02:00 - 04:10 2.17 DRILL N DFAL PROD1 POH. 04:10 - 05:10 1.00 DRILL N DFAL PROD1 Change out MWD pulser & probe. 05:10 - 05:30 0.33 DRILL N DFAL PROD1 RIH. SHT. Orienter failed. 05:45 - 06:00 0.25 DRILL N DFAL PROD1 POOH. Change out Orienter. 06:00 - 08:30 2.50 DRILL N DFAL PROD1 RIH. 08:30 - 08:45 0.25 DRILL P PROD1 Orient TF to 90L 08:45 - 11 :00 2.25 DRILL P PROD1 Directionally drill to 11,925' MD - Free spin: 3300 psi - 3700-4000 psi at 1.5/1.5 bpm 11 :00 - 11 :45 0.75 DRILL P PROD1 Tie in. No depth correction required RA at 11,870' MD. -- Observed leak from pits ont spill containment. -- Removed lower pa s to evaluate leak path. -- Shut down op Ion and held plan forward/PJSM. -- Resumed eration and commenced evaluating leak path. 11 :45 - 12:30 0.75 DRILL P PROD1 Orient o 80L. Significant reactive torque. 12:30 - 13:15 0.75 DRILL P PROD1 Dir lonally drill to 11,942' MD. - Free spin: 3300 psi - 3700-4000 psi at 1.5/1.6 bpm - 10k CT wt - 60 fph ROP 13:15 - 13:30 0.25 DRILL PROD1 Orient TF again to 50L. 13:30-15:15 1.75 DRILL PROD1 Directionally drill to 11,974' MD. - Free spin: 3300 psi - 3700-4000 psi at 1.5/1.6 bpm - 12k CT wt - 60 fph ROP DRILL P PROD1 Orient TF 80L. Extremely difficult to maintain toolface. DRILL P PROD1 Directionally drill to 12,025' MD. - Free spin: 3300 psi - 4000 psi at 1.5 /1 .6 bpm - 8-9k CT wt 18:00 - 19:00 1.00 DRILL N RREP PROD1 Circulate bottoms up prior to commencing welding operations. Printed: 7/11/2005 10:20:10 AM ) ) il'·~, 'n \ ~?¡' rî"~ J~.., r¡::i ¡I·~ : '.\ W ~: f' f"· ·'1 II' : L ... ". . :.' ~ iI\\' ., : ',. 1; "\ \{ !!, ',j 1\ ~ ~ :U'? rÚ~1 : ~ / !7-~ ',\ 11 [I \ L ~.::;.,J cU.<:-) '\J J=. ::J r-:.:::¡ ;¡iL ¡~ :... , !'r LI \>"'~:, If fl.J \~\''':'~ '\~~, r""J'\ "~I \~j FRANK H. MURKOWSKI, GOVERNOR AI{ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 G /,.' :,- \"..' J-.3 \.,.' .' ",~,'I" ' . '·1'1 , Re: Prudhoe Bay 18-12A Sundry Number: 305-117 SCANh'ED JUN 1 ~(12005 Dear Mr. McLaughlin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field in~pector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a . iday or weekend. A person may not appeal a Commission decision to Superior our: unless rehearing has been requested. ~_ --- DATED this1fti.ay of May, 2005 Encl. M ~- # 2. 7 -oS, '!;Jl)í\- S /2. 7 J 20 OS ) STATE OF ALASKA D75 ,c)Z7;5 ReCËfVI![5 ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2005 APPLICATION FOR SUNDRY APPROVAlrã . 20 AAC 25.280 aska 011 & Gas Cons. Commission Anchorage 1. Type of Request: 181 Abandon / 0 Repair Well 0 Plug Perforations 0 Stimulate o Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver o Change Approved Program 0 Operation Shutdown 0 Perforate [J Re-Enter Suspended Well 9. Well Name and Number: PBU 18-12A / 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): 8798 14046 8798 None Length Size MD TVD Burst 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Sean McLaughlin Title CT Drilling Engineer Signature ~ -- M ({~ Phone 564-4387 Commission Use Only 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 47' 8. Property Designation: ADL 028321 11. Total Depth MD (ft): 14046 Casing Structural Conductor Surface Intermediate Production Liner 110' 20" 2830' 13-3/8" 9935' 9-5/8" 2199' 7" 290' 4-1/2" 2063' 2-3/8" Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 11780' - 14015' 8732' - 8797' Packers and SSSV Type: 7" x 4-1/2" TIW 'SS' packer; 3-1/21' Cameo 'TRDP-1A' TRSV 12. Attachments: III Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: Ma(f!; 2005 o Other o Time Extension 4. Current.Well Class: / III Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 197-123 ,// 6. API Number: / 50- 029-21615-01-00 Junk (measured): None Collapse 110' 2830' 9935' 110' 2697' 8303' 1490 3450 6870 470 1950 4760 9631' - 11830' 11707' -11991' 11983' - 14046' 81531 - 8737' 8727' - 8753' 8752' - 8798' 8160 9022 11200 7020 8537 11780 Tubing Size: 3-1/2",9.3# Tubing Grade: N-80 Packers and SSSV MD (ft): 11732' 2268' Tubing MD (ft): 11730' 13. Well Class after proposed work: / D Exploratory III Development D Service 15. Well Status after proposed work: DOil DGas DWAG DGINJ D Plugged DWINJ III Abandoned D WDSPL Contact Sean McLaughlin, 564-4387 Prepared By Name/Number: Terrie Hubble, 564-4628 Date 5/SI0~ I Sundry Number: 3D5- //7 D Plug Integrity D BOP Test Conditions of approval: Notify Commission so that a representative may witness D Mechanical Integrity Test Other: "- D Location Clearance RBDMS 8Fl ,JUN 0 6 2DD5 COMMISSIONER APPROVED BY THE COMMISSION Date fi1Íuite ORIGINAL ) ) JJ To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: S.M. McLaughlin CTD Engineer Date: May 04, 2005 Re: P&A operations for well 18-12B as part of the CTD sidetrack Well 18-12A is a candidate for a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig. --.,~ rJo The sidetrack, 18-12B, will exit the 4-1/2" liner off a whipstock and target Zone 1. The proposed kick off point ~~Jh"\Î.eS' is in the existing slotted liner, which will be isolated by a cement squeeze. The following describes work d.íçcµ~ç.;~....._. planned for the P&A and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary 1. 0 AC-LDS/POT; AC-PPPOT-IC, T 2. S DGLV 3. S Caliper tubing 4. F MIT-IA,OA._ L:J 5. C DummyA,V& drift for~ 3-1/2" x 4-1/2" Gen II WS. Drift to 11900' 6. C MCCl-/G1:(Iog for depth control Ii 7. C Set CIPB in solid 2-3/8" joint -11983'-12013' - no go on top of 2-3/8" liner 8. C Set Baker whipstock at 11 ,860' , 20/deQ)LOHS, two R/ A tags 9. C Squeeze cement past whipstock('(20J1bl of 15.8 ppg cmt) 10.0 Bleed flowline and blind flange. Àe~ve wellhouse, level pad for Nordic The pre CTD work is slated to begin on 5/20/05. Sean McLaughlin CTD Drilling Engineer 564-4387 CC: Well File Sondra Stewman/Terrie Hubble IREE = . WELLHEAD = ACTUÄTOR= KB. ELEV = ",,"'" .",,,.,,,,,,,,,,.,,,,, BF. ELEV i:: KOP= 'rViaxÄrÏgle'; .. .""."" """""" .". Datum MO = Oatum"ND = 3-1/8" FMC FMC AXELSON 47' 23.8' 1200' ""","''''''''','''''' """" , . 94 @ 13405' .. .. .. " ""..",,,,,,. ". N/A 8800' SS ') 13-3/8" CSG, 72#, L-80, 10 = 12,347" 1-1 2830' rJI Minimum ID = 1.941" @ 11984' TOP OF 2-3/8" 4.6# LN R I 9-5/8" X 7" TIW LNR HGR 1-1 9631' iiIj¡¡¡¡¡, 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9935' µ I 3-1/2" TBG-PC, 9.3#, N-80, .0087 bpf, 10 = 2,992" 1-1 11718' TOPOF 4-1/2" SLOTTED LNR, 13,5#, 10 = 3.92" 1-1 11780' 7" LNR, 29#, L-80, ,0371 bpf, 10= 6,184" 1-1 11830' TOP OF 2-3/8" LNR, 4,6#, L-80, ID = 1,941" 1-1 11984' 1 ÆRFORA TION SUMIV1ARY REF LOG: ARRAY SONIC on 12/01/86 ANGLE AT TOP ÆRF: 85 @ 11780' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" SL TO 11780 - 11996 0 12/23/86 2-1/2" 6 11830-11983 0 11/13/99 23/8" SLTD 12013-14015 0 11/08/97 I 4-1/2" LNR, 13,5#, N-80, .0152 bpf, 10 = 3,920" 1-1 12191' 1 18-12A I) L I I S )TYNOTES: FHUTIW HBBP PACKERS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT WIE (x51 02) PRIOR TO PRESSURE TESTING. WELL ANGLE> 70° @ 10097' & > 90° @ 12048'. 2268' 1-1 3-1/2" CAMeO TRDP-1A TRSV, 10 = 2.812" ~ GAS LIFT IV1ANORELS ST MD "NO OEV TYÆ VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 SO RK 20 11/24/97 9399' 1-1 3-1/2" OTIS X NIP, 10 = 2.813" 1 11718' 1-1 TIWOVERSHOTASSY,ID=4.75" 1 11720' 1-1 TIW POLISHED RISER W/ 2.813" X- PROFILE 11730' 1-1 BTM OF TIW OVERSHOT ASSY 1 11732' 1-1 7" X 4-1/2" TIW SS PKR, 10 = 3,00" 1 11~83' 1-1 2,70" BKROEPLOYMENTSLV, 10= 1.995" 1 4-1/2" LNR SIDETRACK WINDOW 11991' - 11999" (OFF CMT RAMP) 12013' 1-1 TOP OF 2-3/8" SL TO LNR, 10 = 1.941" 1 , , , , , , , , , , , , , , , , , , ' ,I 14015' 1-1 BTM OF 2-3/8" SL TO LNR , , , , , , , , , , I 2-3/8" BKR PACKOFF BUSHING, 10 = 1.00" 1-1 2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, 10 = 1.941" 1-1 14045' DATE 12/23/86 11/08/97 10/20/01 09/13/03 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CH/KA K CORRECTIONS CMOfTLP DATUM MD CORRECTION DATE L It.. r. :8 ~r1 :8 I I ..: I I I 1 I I I l~ , , " , , , " , " " REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 18-12A ÆRMIT No: 1971230 API No: 50-029-21615-01 SEC 19, T11 N, R15E, 1166' FNL & 402' FWL BP Exploration (Alaska) \fREE = , '" WELLHEAD = ÄCrukrÒR = KB. ELEV = BF. 8..E\Î ~ KOP= Max Angle = Datum MD = Datum lVD = 3-1/8" FMC FMC AXELSON 47' 23.8' 1200' 94@ 13405' N/A 8800' SS ) 18-128 Proposed CTO Sidetrack . '" 2-3/8" cmt'ed and perfed J ~ ~I chanical Whipstock 11860' " 11983' 1-1 2.70" BKR DEPLOYMENT SLV, ID= 1.995" \ , , , , , , , , , , , , , , , , " ' ,I 14015' 1-1 BTM OF 2-3/8" SL TD LNR , , , , , , I 2-3/8" BKRPACKOFFBUSHING, ID= 1.00" 1-1 14015' " ' 2-3/8" LNR, 4.6#, L-80, FL4S, .0039 bpf, ID = 1.941" 1-1 14045' , 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2830' r.J Minimum ID = 1.941" @ 11984' TOP OF 2-3/8" 4.6# LN R I 9-5/8" X 7" TIW LNR HGR 1-1 9631' 9-5/8" CSG. 47#, L-80, ID = 8.681" 1-1 ,9935' 13-1/2" TBG-PC, 9.3#, N-80, .0087 bpf, ID = 2.992" 1-1 11718' TOPOF 4-1/2" SLOTTED LNR. 13.5#, ID = 3.92" 1-1 11780' 1 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 11830' ~ TOP OF 2-3/8" LNR, 4.6#, L-80. ID = 1.941" 1-1 I IBP 1-1 ÆRFORA TION SUMMARY REF LOG: ARRAY SONIC on 12/01/86 ANGLE AT TOP PERF: 85 @ 11780' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4-1/2" SL TO 11780 - 11996 isolated proposed 2-1/2" 6 11830 - 11983 isolated proposed 2 3/8" SL TO 12013 - 14015 isolated proposed 4-1/2" LNR, 13.5#, N-80, .0152 bpf, ID = 3.920" 1-1 12191' DATE 12/23186 11/08/97 10/20/01 09/13/03 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK CHIKAK CORRECTIONS CMOffiP DATUM MD CORRECTION DATE - ~ L I I I 11 I ~ I f g , , , , , , , , , , REV BY COMMENTS SJ...·1NOTES: FHUTIW HBBP PACKERS HAVE REDUCED TEST PRESSURE LIMITS IN SOME CASES. CONTACT WIE (x51 02) PRIOR TO PRESSURE TESTING. WELL ANGLE> 70° @ 10097' & > 90° @ 12048'. 2268' 1-1 3-1/2" CAMCO TRDP-1A TRSV, ID = 2.812" GAS LIFT MANDRELS ST MD lVD DEV lYÆ VLV LATCH PORT DATE 1 3790 3503 34 CA-MMG-2 SO RK 20 11/24/97 9399' 1-1 3-1/2" OTIS X NIP, ID = 2.813" 1 11660' 11660' 11718' 11720' 11730' 11732' - Top of 2-3/8" Liner - Top of Cement TIW OVERSHOT ASSY, ID = 4.75" 1 1-1 TIW POLISHED RISER W/ 2.813" X- PROFILE 1-1 BTM OF TIW OVERSHOT ASSY 1 1-1 7" X 4-1/2" TIW SS PKR, ID = 3.00" 1 / 1-1 13925' 1 4-1/2" LNR SIDETRACK WINDOW 11991' - 11999" (OFF CMT RAMP) 12013' 1-1 TOP OF 2-3/8" SL TD LNR, ID = 1.941" I PRUDHOE BAY UNIT WELL: 18-12A ÆRMIT No: 1971230 API No: 50-029-21615-01 SEC 19, T11 N, R15E, 1166' FNL & 402' FWL BP Exploration (Alaska) , ·SO l&-Ð Ð (rlJ ¿ ~ 20(/) / ~cv~1~~«.d . tÀ~ ~ð-J , 8f h~ ÚVu.J-C.., ~c;;I::i-/« 'UdJllIbD ¿ -::::Jf2 ~ -Ä ~ ,¿JtA~ fJ ~ cyJ-~ FkL ~ ~ Sundry Approvals for 18-12A and J-17B ) ) Subject: Sundry Approvals for 18-12A and J-17B From: "Senden, Leslie B" <SendenLB@BP.com> Date: Fri, 27 May 2005 10:41: 14 -0800 To: . Cathy Foerster ·<cathy..Joerster@admin.state.ak.us> çç:jarle_williamson@admin.state.ak.us,."Verseput,Tim" <V ersep T@BP .com>, ·"Pospisìl, Gordon" <:P'ospi$G@B~.c{)1n> Cathy As we discussed on the phone today, I would like to provide a little additional background associated with 18-12A and J-17B to facilitate AOGCC approval of the sundry applications. 18-12A has not been cycled in more than three years and the last time it was brought online (after a 9 month shut-in) in 2001, it tested at over 50,000 GOR. Based on this, we see no resource potential remaining in the current location. The decline curve analyses done by the AOGCC for these wells appeared to be based on SLP, rather than a forecast of incremental black oil. For GD wells at or near the marginal GOR of the facility, it is important to subtract condensate and VBLs from the forecast because they will be produced anyway from whatever well is brought into the facility in lieu of the well in question. Also, it is appropriate to subtract a "gas backout" to account for the oil that would be produced by the next well in the stack. These factors give us a remaining incremental black oil recovery that is substantially lower than the AOGCC estimate. Noting the difference between our coil and rotary sundry packages, we will begin providing the same type of information for coil sidetracks as we do for rotary. Hopefully this will give you the information you need to approve the sundries. Thanks for taking the time to talk this through today! --Leslie 1 of 1 5/27/2005 10:51 AM ) Date: To: From: Subject: May 10, 2005 Pile Jane Williamson Prudhoe Well 18-12A - Plug Back in Preparation for SIT Attached are plots of production history and decline analysis for the subject well. The well has produced only 4 months since 1/1/2001. The well likely was shut in due to GOR constraints (roughly 27 MSCF/STB). Prior to this time, the well produced at above 400 BPD. I project roughly 430 MSTB remaining reserves if a limiting GOR of 80 MSCFISTB is used (roughly 162 BPD). Due to the potential of significant reserves being abandoned, we need additional justification for the abandonment. The following needs to be discussed with BP prior to decision on sundry approval. . Why are the reserves of this current wellbore being abandoned? · Are there mechanical problems in the current wellbore which lead to the decision to SIT? What are they? · What is the proposed bottomhole location for the SIT? · Will the new sidetrack drain the oil abandoned with this plugback? ~.- ~f# 'Î-~;S (J ~'- " ~C; ßJ.A ¿\. ~ ~ ~ j ~.~ vf~':Hv .' ~, ~ ~'¡D '~/' J .ß..~ ~ ~ I~. ~ ~..\~ .- ~ ~,-r>. ~ ':£h~"i/ü jP<L- ~ C7 / . ~ ~~ DS 18-12A Plug Back Page 1 of3 ) 100 50 PRUDHOEBA.Y, PRUDHŒOL PBU_DS18 PRUDHOE BA.Y 1a.12A 1= 0,5 ~ 0.1= 0,05 ~.. 0,01 ) 1,0 0.8 Cl29216150100 19) Producro 01 Well Well on Goo IrocIlon - WoIoonWoI«lrectlon Dåe 0,0 I I I 1997 98 99 2000 01 02 03 04 05 Dåe 4500 04 05 02 03 100 50 029216150100:150 Cum Oil Prod ( MWiJbl ) Cum Gas In] ( Bel) Cum Gas Prod (Bel) Cum Water InJ (MVbbl ) Cum Water Prod ( MVbbl ) I I I - 10 1 0,5 0.6- 0.4 - 0,2 4000 3500 3000 2500 - I, PPT,PRESS 1J2921615)100: 19:) I 1997 04 05 i i i ; : ' :' ::'::,'::':: ::: I 1~~1~1~1 ~1~11~1 ~ì~I~1 ~I~I ~I~I~I ~i~l~ì ~ì~i~1 ~71~i~~~1 ~I~ Prudhoe Well 18-12A Decline wi 162 BPD limit, 80 MCF/STB limiting GOR Remaining Reserves - 500 MBD 0,1 '"''I''''' ""'I'"'' "'"I''''' 99 03 98 2000 01 02 Dåe 1 ??oo 5000 :ê' :ë ~ 1000 - 6' ~ O ~ Õ 500 - 100 I 250 I 500 eunOI A'oo(Mtij) DS 18-12A Plug Back 2000 Dåe A1ase Case Nare b Di qi ti Ie ErdRåe FiraRåe Cun A'cx1 Cu1\ Dåe ResEJ\e! EUR Fae::ast Erded By Fae::ast Dåe 01 Case1 1 Q,252453Aa 4CO tij/d 1213112004 01131f.201Q 162 tij/d 161.3æ tij/d 712.331 Mtij œl3112OO5 421.153 Mtij 1133.48 Mtij Råe .... 0':\ i: '. ~ -.r..~_.,........ - '''''~--.'''."''''.'''''''~''--''''''''''''''''-- I 750 I 1000 Page 2 of3 1250 ,. 'ê :::" e. 1000 6' e:- O) ãí 0:: Ô 500 - 1??oo 5000 - 100 ' " " , " " '" 1997 98 ) Prudhoe Well 18-12A Decline wi 162 BPD limit, 80 MCF/STB limiting GOR Remaining Reserves - 500 MBD ) A1ase 01 Case Nare Case1 b 1 Di O.25Ae. qi 400 ttj/d ti 12/3112004 te 02128'2010 Erx:I Ráe 162 ttj/d Fira Ráe 1oo.9!) ttj/d CllT\ A'od. 712331 Mttj CllT\ Dáe œl3112CŒ ResEI\eS 427.438 Mttj EUR 1139,77Mttj Faa::ast Ended By Ráe Faa::ast Dáe 99 '"I''''''''''' "'"''''''1''' ""I 2000 01 02 03 04 "" I '" I' 05 DS 18-12A Plug Back 06 'I' " 10 07 Page 3 of3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1165' FNL, 4551' FEL, Sec. 19, T11N, R15E, UM At top of productive interval 3649' FNL, 4211' FEL, Sec. 20, T11N, R15E, UM At effective depth At total depth 4808' FNL, 1689' FEL, Sec. 20, T11N, R15E, UM 12. Present well condition summary 5. Type of Well: Development__X Exploratory__ Stratigraphic__ Servia__ 6. Datum elevation (DF or KB feet) RKB 47 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 18-12A 9. Permit number / approval number 97-123 10. APl number 50-029-21615-01 11. Field / Pool Prudhoe Bay Oil Pool Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Surface 2783' 13-3/8" Production 9888' 9-5/8" Liner 2199' 7" Slotted Liner 211' 4-1/2" Slotted liner 2063' 2-7/8" Perforation depth: 14046 feet Plugs (measured) 8798 feet !"," i'i"i] (~..,' 'i '!999 14046 feet Junk (measured) Alaska Oil & Gas Cons, 8798 feet Anchorage Cemented Measured Depth True vertical Depth 161o# Pole. set 11 O' 11 O' 2500 sxcs ,~ &4oo sx cs H 2830' 2697' 500 Sx Class G & 300 Sx CS I 9935' 8303' 450 Sx Class G 11830' 8737' Uncemented 11991' 8753' Uncemented 14046' 8751' measured 4-1/2" Slotted Liner f/11780' - 11991'; 2-3/8" Slotted Liner f/12013' - 14015'; Reperrd f/11830' - 11983'. true vertical 4-1/2" Slotted Liner f/8732' - 8753'; 2-3/8" Slotted Liner f/8755' - 8797'; Reperf'd f/8737' - 8752'. I'ubing (size, grade, and measured depth) 3-1/2"9.3#, N-80 PCT @ 11732' MD. Packers & SSSV (type & measured depth) 7" X 4-1/2" TIW PACKER @ 11733' MD. 3-1/2" CAMCO TRDP-1A SSSV @ 2269' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiFBbl Prior to well operation 575 Subsequent to operation 628 Representative Daily AveraRe Production orlnjection Data Gas-Mm Water-Bbl 13091 0 11269 0 Casing Pressure Tubing Pmssure - 1065 964 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedErin Oba ~~ ~_ Title ARCO EngineeringSupervisor Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 18-12A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/11-12/1999: MIRU work platform & CTU. PT'd BOPE to 4000 psi. Killed well w/Seawater. Spotted FIo Pro across perfs. MU perf guns. RIH w/Tubing Conveyed Perf Guns & reperforated 153' of the 4-1/2" slotted liner @: 11830'- 11983' MD (Zone 1) Reference Log: Sonic 12/01/1986. Used 2-1/2" carriers and all shots @ 6 SPF, 60° phasing, & balanced press. POOH w/guns. Verified ^SF. RDMOL. Returned well to production & obtained a valid well test. RECEIVED DEC 01 1999 ~Oil& GasC, oos.~n And~Or~le AOGCC Geological Materials Inventory . PERMIT 97-123 ARCO Log Data Sent Received ~ 'R---SCHLUM ' I'1'97T 10:14046: ........... 11/7/1997 11/20/199,7 .... SRVYRPT ~f SCHLUM 11977.1-14047 12/22/1997 12/30/1997 ~'~0-407 CompletionDate /[/~ / ? ~ Daily,vellops q/.J )/f~) r Are dry ditch samples required? yes ~ no And received? ~----h~y~s--~7_- - no Was the well cored? yes ~ no Analysis description received? Aretests required? y~ ~./ no Received? .... &?~ ......... no Well is in compliance Initial Comments Box Wednesday, October 13, 1999 Page I of 1 STATE OF ALASKA DEC 0 199 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANIl ati &( asC0.s. commission Status ol We~ Clas~slficatlon of S.rv.~w~ch0rage Oil X Gas__ Suspenaed__ .~J~anOOned__ Service__ 2 Nar'ne ot Ope.q~or 7 Pem'~t Number ARCO Alaska, Inc. 97-123 3 Address 8 APl Number P.O. Box 100360. Anchorage, AK 99510-0360 ! _FTC-.. ~.~ 50-029-21615-01 4 Locatmn of w~l at sudace [* ~-.^.~];]/...~ -/- ~..~;, / ] i ~~i~';'';~[rr~'~'~[~'~ 9 Un.il or Lease Name i ...... i "i!"~'~' i 1! ¥'~ ~ PRUDHOE BAY UNIT 1166' FNL, 402' FWL, Sec 19, TllN, R15E, UM. 2123' FSL, 4881' FWL. Sec 19, T11N. R15E. UM. ' 18-12A 4808' FNL. 1689' FEL Sec 20, T11N, R1 SE, UM. : _ .; PRUDHOE BAY FIELD 5 Elevation ~n te~ (m~licate KB, DF. etc.) 6 Lease Oes~grm~m ~ Serial No. 47' RKB ADL 28321 PRUDHOE BAY OIL POOL 12 Da~e Spucldea 13 Da'e T.D. Rea~nea 14 Da~e Comp. ~ ~ At~ancl. 1,5 Water DepOt. ~ offshore 16 No. of 11/2/97 11/8/97 '~ 1/8/97 N/A 1 17 Totai Depth tMD+TVD) 18 Plu~_ Back DeCX~ (MD+I'VD) 19 Directional ~ 20 Depth wner~ $SSV se~ 21 Thickness of Perrnatroet 14046' MD / 8751' TVD 14046' MD / 8751' 'I'VD YES_X NO__ 2268' feet MD 1900' Iapprox) 22 Type Elecmc er Other Logs Run MWD. GR. 23 CASING. LINER AND CEMENTING RECORD SETTING DEPTH CASING Sl~l= WT. PER FT. CWa, AE~ TOP BOTTOM HOLE SIZE CEMENTING RECORD ~ PULLED 20' 91.5# H-40 Surf 110' 30' 1610 # Poleset 13-3/8' 68/72# K-55/L-80 Surf 2830' ! 17.5' 2500 Sx CS ill & 400 Sx CS II t 9-5/8' 47# L-80 Surf 9935' I 12.25' 500 Sx Class G & 300 Sx CS I 7' 29~ L-80 9631' 11830' t 8.5' 450 Sx Class G 4-1/2' 13.5~ N-80 11780' 11991'! 8.5' Uncemented (Slotted Liner) 2-3/8' 4.64f L-80 11983' 14046' ! 2_75' Uncementecl (Slotted liner) 24 Pedorat[ons open to Production (MD+TVD of Top ar~ Rottom and 25 TUBING RECORD interval, s~ze and numbe~) SIZE DEPTH SET MD PACKER MD 4-1/2' Slotted liner interval: 3-1/2' l'bg 11732' 11732' 11780 - 11991' MD: 8732 - 8706' 7-VD and 26 ACID, FRACTURE, CEMENT SQUEF, ZE, ETC. DEPTH INTERVAL MD AMT & KIND MATERIAL USED 2-3/8' Slotted liner interval: 12013 - 14015' MD: 8707- 8749' TVD 27 PRO DL~TION TEST Date First pro<3uc~on Melhod of Operatior~ (Flow~_, gas ~. 11/25/97 Flowing w/lift gas Date of Test Hou~ Testea I PRODUCTION FOR OI1. - BBL GAS - MCF 'WATER - BBL CHOKE SIZE I GOR 11/27/97 6 TEST PERIOD] 3355 Flow Tubing Press Casing Press~ CALCULATED OIL - i~,BL GAS - MCF WATER - BBL OIL GRAVITY - APl (co~) 741 24HOUR RATE X 1517 5090 96 28 ~ DATA Brief clescnpt~:m of lithok:x3y, poros~'y, fractures, appare~ ~ps a~3 presence of od, gas, or water. ~ ~ chB~S. ' This 10-407 submitted as clirected per the 10-401 form .aDprove~l 6/30/97 (issued Permit # 97-123). Form 10-407 Subm~ in dul~llcate ORIGINAL GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Top Sadlerochit 9915' 8295' N/A 3f LIST OF ATTACHMENTS Summary of 18-12A Coil Tubing Wellbore Extension Drilling Operations. 321 hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~f~ (~,~ "/~~ ~'J'VI~. Engineering Supervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL 18-12A DESCRIPTION OF WORK COMPLETED CTU WELLBORE EXTENSION DRILLING 9/27/97: MIRU CTU & PT equipment. RIH w/2.8" milling BHA & tagged POB at 12148' MD. Milled through POB and backreamed smooth. RIH & tagged guide shoe at 12191' MD. Milled through guide shoe and out the end of the 4-1/2" liner into the formation to 12202' MD. Jetted slotted liner w/biozan. POOH w/BHA. RD. 10/10/97: MIRU CTU & PT equipment. RIH w/nozzle & loaded well with Hot 1% KCI Water & Crude. Tagged bottom at 12192' MD, then pumped 11 bbls of 17 ppg Neat Class G cement to spot a kickoff plug for pending CT drilling. POOH w/CT leaving estimated TOC at 11170' MD. Shut in well holding 1000 whp on cement. RD. 10/29/97 - 10/30/97: MIRU CTU. Standbyfor rig maintenance. 10/31/97: PT BOPE & RU CTU. RIH w/milling BHA. 11/1/97: PT cement plug to 1500 psi; no leakoff. 11945' MD. Tagged TOC at 11460' MD. Milled cement from 4-1/2" liner to 11/2/97: Reamed cement to 12000' MD, and circulated biozan & Hi Vis sweeps. POOH w/underreamer. RIH w/2.8" window mill & swapped well to FIo Pro. Started milling a window through the 4-1/2" slotted liner at 11991' MD. 1113/197: Completed milling window to 11999' MD, then continued drilling formation to 12012' MD. RIH w/drilling BHA & drilled sidetrack hole w/2.75" bicenter bit to 12147' MD. POOH w/BHA. 11/4/97: Continued drilling horizontally to 12462' MD. POOH w/BHA. 1115197: RIH w/drilling BHA. Drilled to 12600' MD w/mud loss to 22 bph. Drilled to 13032' MD w/periodic shod trips to window to sweep hole. Vis pill & worked to free pipe. Pumped Hi Vis pills to slow mud loss. Stuck BHA at 13005' MD. Pumped Hi 11/6/97: Circulated Crude around BHA & pulled free. Tripped to window & reamed back to bottom while circulating Crude, then continued drilling to 13224' MD w/short trips to window. POOH w/BHA. 11/7/97: RIH w/drilling BHA. Drilled to 13960' MD w/wiper trips to window. 11/8/97: Drilled to TD at 14046' MD. POOH pumping Hi Vis pill to tubing tail to slow 60 bph mud loss. RIH w/2-3/8" slotted liner assembly. Landed liner on bottom at 14046' MD. Released from liner & POOH circulating to Seawater from the top of liner located at 11983' MD. 11/9/97: POOH circulating top 2300' to Meth-Water. Blew down CT, ND BOPE, NU & PT tree. RD CTU & MOL. Placed the well on initial production w/gas lift & obtained a valid production test. Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) November 7, 1997 Larry Grant Arco Alaska Inc. Anchorage, Alaska Mr. Grant Enclosed is a copy of the survey program, and performance letter for 18-12a. Please let me know if you have any questions regarding this data. Craig Brown or myself can be reached at (907)-349-4511. Sincerely, Mark Brown Cell Manager, Anadrill Arco Coil Tubing Criag Brown Field Service Manager RECEtV ~0V 2.0 199T Gas ~ns. Com.rvis~on Anchorage Lessons Learned: In tracking the hours on bha, starting to realize that we are not going to be getting much more than 250 hours on these size tools. Anadrill appreciates the opportunity to provide Arco Alaska Inc. with Directional Survey (DSS) and Logging While Drilling (LWD). We look forward to continue working for you in the future. Sincerely, Mark Brown Cell Manager Craig Brown Field Service Manager Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) ti-7. 12,% Date: Well Name: Company: API#: Location: Field: Rig: November 7, 1997 DS 18-12a Arco Alaska Inc. 50-029-21615-01 NSB, Alaska Prudhoe Bay Nabors 3S Anadrill Personnel: Field Crew: Cell Manager: Mark Brown Cell Engineers: Don Webb Doug Hinnaland Field Support: . Alaska District Manager: Martin-Varco Field Service Manager: Craig Brown Services Provided: MWD SHARP GAMMA RAY MWD SHARP (DSS) ORIENTER Service Dates 10/31 - 11/7/97 11/1 - 11/7/97 Depth Interval 11959' - 14046' 11995'- 14046' Operating Statistics: Total MWD Pumping hours: 141.5 Total MWD Below Rotary hours: 173 Total MWD Footage: 2087 Total MWD Runs: 8 Job Performance: Directional: SHARP MWD was picked up on 10/31/97 to drill cement and tie in gamma ray marker @ 10831' SHARP Gamma Ray and (DSS) was used from 11959' to 14046' which was TD. Shocks: Anadrill constantly moniters shocks in realtime and recorded. No major shocks were incountered in realtime or recorded. Washout Detection: Washouts can be detected from monitering pump pressure, and motor differencial pressure with same pump rates. RECE VEU t40V 20 1997 Alaska Oil & Gas Cons. Commission Anchorage Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (faxl Date: Well Name: Company: API#: Location: Field: Rig: November 7, 1997 DS 18-12a Arco Alaska Inc. 50-029-21615-01 NSB, Alaska Prudhoe Bay Nabors 3S AnadriH Personnel: Field Crew: Cell Manager: Mark Brown Cell Engineers: Don Webb Doug Hinnaland Field Support: Alaska District Manager: Martin. Varco Field Service Manager: Craig Brown Services Provided: MWD SHARP GAMMA RAY MWD SHAar~ (DSS) ORIFNTER Service Dates 10/31 - 11/7/97 11/1 - 11/7/97 Depth Interval 11959' - 14046' 11995' - 14046' Operating Statistics: Total ~MWD Pumping hours: Total ~MWD Below Rotary hours: Total MWD Footage: Total MWD Runs: 141.5 173 2087 8 Job Performance: Directional: SHARP MWD was picked up on 10/31/97 to drill cement and tie in gamma ray marker @ 10831'. SHARP Gamma Ray and (DSS) was used from 11959' to 14046' which was TD. Shocks: Anadrill constantly moniters shocks in realtime and recorded. No major shocks were incountered in realtime or recorded. Washout Detection: Washouts can be detected from monitering pump pressure, and motor differencial pressure with same pump rates. Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) Client ................... : ARCO ALASKA INC. Field .................... : PRUDHOE BAY Well ...................... DS 18-12A API number ................ 50-029-21615-01 Job number ................ 40001632 Rig ....................... NABORS 3S County/State .............. Prudhoe Bay State/Country ............. Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : MSL Depth reference .......... : RKB GL above permanent ....... : 17.00 ft KB above permanent ....... : 48.00 ft DF above permanent ....... : 49.00 ft Vertical section origin. Latitude (+N/S-) ......... : -2788.10 ft Departure (+E/W-) ........ : 6309.30 ft Platform reference point Latitude (+N/S-) ......... : 70.2980 ft Departure (+E/W-) ........ : -148.4444 ft Azimuth from rotary table to target: 109.40 degrees RECEIVbu N. 0V 20 199;7 Survey re~ortc~jaska Oil & Gas Cons, Oomrilis$i0n ~chorage Spud date ................ : 31-0ct-97 Last survey date ......... : 07-Nov-97 Total accepted surveys...: 53 MD of first survey ....... : 11977.10 ft MD of last survey ........ : 14046.00 ft Geomagnetic data Magnetic model ........... : BGGM 1996 version Magnetic date ............ : 30-0ct-1997 Magnetic field strength..: 1147.50 HCNT Magnetic dec (+E/W-) ..... : 28.55 degrees Magnetic dip ............. : 80.76 degrees MWD survey Reference Criteria Reference G ............... 1003.50 mGal Reference H ............... 1150.00 HCNT Reference Dip ............. 80.76 degrees Tolerance of G ............ (+/-) 3.00 mGal Tolerance of H ............ (+/-) 7.00 HCNT Tolerance of Dip .......... (+/-) 0.30 degrees Corrections - Magnetic dec (+E/W-) ..... : 28.55 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 28.55 degrees (Total az corr = magnetic dec - grid cony) Seq Measured Incl Azimuth Course TV-D # depth angle angle length depth (ft) (deg) (deg) (ft) (ft) 1 11977.10 83.80 113.7 0.00 8704.20 2 11990.00 83.72 113.9 12.90 8705.60 3 11997.00 84.30 112.0 7.00 8706.33 4 12048.00 91.00 114.0 51.00 8708.42 5 12067.20 88.20 115.0 19.20 8708.56 6 12127.13 91.40 113.5 59.90 8708.77 7 12156.61 91.13 119.2 29.50 8708.11 8 12187.13 89.14 122.9 30.50 8708.04 9 12224.96 90.69 132.9 37.90 8708.10 10 12285.03 88.25 143.2 60.00 8708.66 !! 12342.05 86.61 138.5 57.10 8711.22 12 12388.55 88.73 131.5 46.50 8713.11 13 12410.26 89.90 127.1 21.70 8713.37 14 12493.01 87.36 121.8 82.70 8715.35 15 12575.81 88.97 116.3 82.80 8718.00 16 12612.35 89.15 113.7 36.50 8718.60 17 12697.92 88.70 108.1 85.60 8720.21 18 12749.15 89.15 104.5 51.20 8721.17 19 12770.88 88.64 103.2 21.80 8721.59 20 12800.06 87.90 100.6 29.20 8722.47 21 12833.86 87.05 98.3 33.80 8723.96 22 12864.86 87.10 98.0 31.00 8725.54 23 12937.66 90.00 102.8 72.80 8727.38 24 12953.08 89.00 102.0 15.40 8727.52 25 13012.81 87.55 99.8 59.70 8729.32 13021.84 86.30 101.3 9.00 8729.80 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) 100f) type 6877.17 -2788.10 6889.96 -2793.28 6896.91 -2795.99 6947.73 -2815.89 6966.85 -2823.85 6309.30 6897.88 113.84 0.00 TIP 6321.03 6910.71 113.84 1.66 MWD 6327.44 6917.67 113.84 28.24 MWD 6374.32 6968.59 113.83 13.71 MWD 6391.79 6987.78 113.84 15.49 MWD 7026.53 -2848.45 7055.79 -2861.53 7085.66 -2877.26 7121.55 -2900.51 7174.13 -2945.07 6446.39 7047.67 113.84 5.90 MWD 6472.81 7077.12 113.85 19.34 MWD 6498.94 7107.38 113.88 13.77 MWD 6528.80 7144.11 113.95 26.70 MWD 6568.85 7198.84 114.15 17.64 MWD 7222.78 -2989.29 7264.65 -3022.12 7285.05 -3035.86 7364.85 -3082.61 7446.40 -3122.78 6604.86 7249.83 114.35 8.71 MWD 6637.69 7293.29 114.48 15.72 MWD 6654.48 7314.27 114.52 20.98 MWD 6722.62 7395.68 114.63 7.10 MWD 6794.94 7478.16 114.68 6.92 MWD 7482.72 -3138.20 7568.24 -3168.72 7619.35 -3183.09 7641.05 -3188.30 7669.98 -3194.30 6828.01 7514.65 114.68 7.14 MWD 6907.93 7600.02 114.64 6.56 MWD 6957.06 7650.67 114.59 7.08 MWD 6978.22 7672.08 114.56 6.40 MWD 7006.78 7700.55 114.51 9.58 MWD 7703.23 -3199.81 7733.59 -3204.20 7805.44 -3217.33 7820.73 -3220.64 7879.74 -3231.92 7040.09 7733.16 114.44 6.97 MWD 7070.74 7762.88 114.38 0.98 MWD 7142.29 7833.49 114.25 7.70 MWD 7157.33 7848.56 114.23 8.32 MWD 7215.92 7906.63 114.13 4.41 MWD 7888.62 -3233.57 7224.76 7915.37 114.11 21.68 MWD ? r Anadrill 1111 East 80th Avenue Anchorage, Alaska 99518-3304 (907) 349-4511 (907) 349-2487 (fax) 27 13106.75 92.15 103.1 84.90 8730.95 7972.80 -3251.50 7307.69 7998.41 113.99 7.21 MWD 28 13147.25 92.08 103.2 40.50 8729.45 8013.04 -3260.71 7347.10 8038.17 113.93 0.30 MWD 29 13173.93 89.30 102.7 26.70 8729.13 8039.56 -3266.69 7373.12 8064.38 113.90 10.58 MWD 30 13193.46 88.85 102.7 19.60 8729.45 8059.02 -3271.00 7392.24 8083.60 113.87 2.30 MWD 31 13235.08 88.45 108.1 41.60 8730.43 8100.50 -3282.04 7432.32 8124.72 113.83 13.01 MWD 32 13302.12 88.10 112.8 67.00 8732.44 8167.44 -3305.43 7495.05 8191.56 '113.80 7.03 MWD 33 13341.54 91.75 119.6 39.40 8732.50 8206.53 -3322.81 7530.37 8230.90 113.81 19.59 MWD 34 13405.22 93.70 124.7 63.70 8729.47 8268.57 -3356.66 7584.23 8293.83 113.87 8.56 MWD 35 13429.'44 92.20 125.0 24.20 8728.22 8291.86 -3370.47 7604.06 8317.56 113.91 6.32 MWD 36 13463.78 88.59 124.7 34.40 8727.98 8325.01 -3390.12 7632.28 8351.33 113.95 10.53 MWD 37 13482.45 86.90 122.5 18.70 8728.72 8343.12 -3400.46 7647.85 8369.75 113.97 14.83 MWD 38 13502.93 85.55 121.8 20.40 8730.06 8362.98 -3411.29 7665.08 8389.90 113.99 7.45 MWD 39 13540.45 83.45 119.3 37.60 8733.67. 8399.69 -3430.32 7697.31 8427.07 114.02 8.66 MWD 40 13563.25 82.86 118.3 22.80 8736.38 8422.02 -3441.22 7717.14 8449.63 114.03 5.07 MWD 41 13600.00 85.70 116.4 36.70 8740.04 8458.18 -3457.99 7749.57 8486.08 114.05 9.30 MWD 42 13685.19 88.15 112.8 85.20 8744.61 8542.89 -3493.40 7826.91 8571.14 114.05 5.11 MW-D 43 13729.27 87.75 112.4 44.10 8746.19 8586.89 -3510.34 7867.60 8615.19 114.05 1.28 MWD 44 13772.17 88.50 110.3 42.90 8747.60 8629.75 -3525.94 7907.53 8658.02 114.03 5.20 MWD 45 13806.37 89.90 112.4 34.20 8748.07 8663.92 -3538.39 7939.38 8692.18 114.02 7.38 MWD 46 13817.30 90.45 112.8 10.90 8748.04 8674.80 -3542.58 7949.44 8703.08 114.02 6.24 MWD 47 13899.20 90.90 115.3 81.90 8747.08 8756.42 -3575.95 8024.22 8784.96 114.02 3.10 MWD 48 13927.18 89.90 114.6 28.00 8746.88 8784.29 -3587.76 8049.61 8812.96 114.02 4.36 MWD 49 13941.91 89.90 115.0 14.70 8746.91 8798.92 -3593.92 8062.96 8827.66 114.02 2.04 MWD 50 13967.76 87.20 116.0 25.90 8747.56 8824.67 -3605.04 8086.33 8853.54 114.03 11.26 MWD 51 14006.06 87.65 115.3 38.30 8749.28 8862.70 -3621.61 8120.82 8891.78 114.04 2.17 MWD 52 14020.00 87.40 114.9 13.90 8749.88 8876.52 -3627.50 8133.40 8905.67 114.04 3.39 MWD 53 14046.00 87.40 114.9 26.00 8751.06 8902.37 -3638.43 8156.96 8931.64 114.04 0.00 MWD TONY KNOWLE$, GOVEI~NOF~ ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 27, 1997 Erin Oba, Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay' Unit 18-12A ARCO Alaska, Inc. Permit No: 97-123 Sur. Loc. 1166'FNL, 402'FWL, Sec. 19, TllN, R15E, UM Btmnhole Loc. 4592'FNL, 1696'FEL, Sec. 20, T11N, R15E, UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exmnpt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to ~vitness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David ~ohnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll _ Redrill X lb. Type of Well Exploratory_ Stratigraphic Test _ Development Oil ~X Re-Entry__ Deepen __X Service_ Development Gas_ Single Zone _~X Multiple Zone_ 2. Name o! Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 47' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28321 Prudhoe Bay Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1166' FNL, 402' FWL, Sec 19, T11N, R15E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 2123' FSL, 4881' FVVL, Sec 19, T11N, R15E, UM. 18-12A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 4592' FNL, 1696' FEL, Sec 20, T11N, R15E, UM. August, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 13981' MD / 8802' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth N/A Maximum hole an~lle 94° Maximum su~a~ 2800 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2-3/4" 2-3/8" 4.6 L-80 FL4S 1900' 12100' 8766' 13981' 8802' Slotted Liner (Uncemented) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary A L Totaldepth: measured 12390 feet Plugs(measured)ORIGIN true vertical 8809 feet Effective depth: measured 12148 feet Junk (measured) true vertical 8771 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" 1610 # Poleset 110' 110' Surface 2800' 13-3/8" 2500 Sx CS III & 400 Sx CS II 2830' 2696' Production 9908' 9-5/8" 500 Sx Cl G & 300 Sx CS I 9935' 8302' Liner 2192' 7" 450 SxCl G 11830' Slotted Liner 411' 4-1/2" Uncemented 12191' Perforation depth: measured Slotted Liner: 11780-12191' dUl\J 1 91997 true vertical "Slotted Liner: 8732- 8778' --~]~ CJl,& Gas Cons. '. 20. Attachments Filing fee :x Property plat_ BOP Sketch ~ Diverter Sketch _ Ddlling program _~x Ddlling fluid program ~ Time vs depth pict Refraction analysis Seabed report _ 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my know edge ~ ~' ¢.. $~ o Q ,4, ~ 5 '¥ ~ ~' ~ ~V~ct. f"r.~ c~ 2 (~ ~'-.~_'~ Si~ned -"~,,~ ~ , ~;1¢:2~ Titlle Engineering Supervisor Date ~, ~ /~::~- ~"7 "~ Commission Use Only Permit Number APl number Appr~)/_..al~dat~(~¢~_.. ~ ~2:~ ¢ ..~¢~" See cover letter for 77-/~,,~ 50- O~.,.~ '=' ~,. j'~'/,,~"" ~/' ./ ¢ other requirements Condiiions of approval Samples required Yes ~1o Mud I~ required_ Yes ~No Hydrogen sulfide measures ,7~Yes _ No Directional survey required ~'Wes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M X 3500 psi for CTU Other: d - ginal Signed By by order of ~ '-'~:;~ ? ~ ~'~ Approved b¥ Ravid W. Johnston Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 18-12A CT Extension and Completion Intended Procedure Oh|ective: Directionally drill -1800', 2-3/4" horizontal extension from the Complete with 2-3/8" slotted liner. existing wellbore. Intended Procedure: RU CTU/Nabors 3S. RIH and mill out pack-off bushing and shoe in 4- 1/2" slotted liner. Spot cement in remaining 8.5" open hole fi'om 12390' to 12191' md. Load well with +8.9 ppg polymer mud. Directionally drill -1800' of 2-3/4" horizontal hole to access Romeo reserves. · Run 2-3/8" slotted liner to TD. · RD CTD, return well to production. June 16,1997 DS 18-12A Proposed Wellbore Sketch Extension of Wellbore & Completion 3-1/2" Camco TRDP-1A SSSV '~ 81" ID 2268' ~ 3-1/2" Production Tubing Camco GLM @ 3790' 3-1/2" Otis "X" Nipple 7" Liner top 9-5/8" Shoe 9935' 9399' 9631' 2.375" Slotted Liner 7" Liner Shoe 11830' 4-1/2" Slotted Liner to 12191' TIW Seal Assy, SS Packer @ 11732' 2.75" Openhole +/-1800' I· Original 8.5" hole 2.375" TOL TD'd @ 12,390' -12100' TD +/- 13900' 18-1 2 A PLAN 0 Rev. 1 ARCO ta-t2A PLAN JUNE 13. 1597 -~--~ ................................. ~'., ~"~' ~ ,~' ~ / ............ . 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T~ 6~-- ........ ~'~-.~'~ .......... ~-~-~ .....~'~'~0 ........... i~¢:~'~ ..... -~4~.~0 ~S.70 -0.~ -~,'~ ......... ~"' ....................................... ~'~'~b' ......... ~':i ~ ................ ~ ~=-'""' ~'~ ~6 .......... i'~2~-~~ ..... :~'i:~6 ' ' ~ ~-~E~ ...... ~:'~'~: :;::~-~ ........ i :~: ....... ~7~:.~C-~ ........ -~'~aT'~; 18-12 Dmi. .4.~C0 ALASKA,,',,.,'" '"' 18-12 .- -3C0'3 F_.A,'V and N/S Scale 1 inch 3C0 ~ -.3303 -360C P_Af-~E 0¢ VERT SEC, Tn lC;d,-e7~ RE_,~---.'-.¥E 1"$ --~UE N::::)R'I'H C ,' Drilling Wellhead Detail ~ CT Injector Head Methanol Injection Otis 7" WLA Quick Connect ~ L I I Alignment Guide Flange 11 I' 7-1/16", 5M Ram Type Dual ~~ ~ , , Gate BOPE Flanged Fire Resistant Man e Kelly Hose to Dual HCR Choke Manifold \ Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7" Riser .~ Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure f3.5") ' Cutters or Combination Cutter/Blinds Slip/ Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Shop Fuel Boilers · Water Mu~ Tanks Pump Fire Ext. 6O/4O I TrplxI Ext. ,~Pipe ra,~ I-'C/) Plre Ext. Dowell Drilling I Equipment Trailer Preferred Major Equipment Layout for CT Drilling WELL PERMIT CHECKLISToo. ,.Y /~"~ .~__/~ FROGRAM: expo dev~redrl~servO wellhore segO ann disp para reqO GEOL AREA F?~ UNIT#' '" -//gS~) ON/OFF SHORE ~v~ ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Y Lease number appropriate ............... Y Unique well name and number .............. Y Well located in a defined pool .............. Y Well located proper distance from drlg unit boundary. . .Y Well located proper distance from other wells ..... Y Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ........ ....... Operator has appropriate bond in force. . ........ Y Permit can be issued without conservation order ..... )Y Permit carl be issued without administrative approval. . Can permit be approved before 15-day wait ........ REMARKS ].4. 15. 16. 17 18 19 2O 21 22 23 24 25 26 27. 28. 29. Conductor string provided ................ Y N ~ Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf cng. . Y N CMT vol adequate to tie-in long string to surf cng . . . Y N CMT will cover all known productive horizons ....... Y /~ Casing designs adequate for C, T, B & permafrost .... Q N N Adequate tankage or reserve pit ............ If a re-drill, has a 10-403 for abndnmnt been approved..--Y-----N--/~c Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate .......... .-%~----N--/L~/~-~ Drilling fluid program schematic & equip list adequate .Y~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ____~_~,~ psig~_~ N Choke manifold complies w/API RP-53 (May 84) ...... ~ N Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ ~ N 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y//~ ~ ~ ~ 32. Seismic analysis of shallow gas zones .......... y N ~ 33. Seabed condition survey (if off-shore) ........ /Y N /~-'d A~R D~TE] 34. Contact name/phone for weekly progress reports . . ./. Y N ~ ~______~a//~ [exploratory only] ~ GEOLOGY: HOW/dlf - A:\FORMS\chekhst ~ev 01/97 ENGINEERING: COMMISSION: Comments/Instructions: