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Home My WebLink About196-039Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. '1-~ ..0~' File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Be~,edy Dianna Vincent Nathan Lowell Date: Is~ RE: IF-18 (196-039) ) ) Subje.ct: .~:·...lF-l~:.·(1~~~d39). }f~~Y1:.N'~.KProbl~l11.-v\lell·.Sl1þv .<nl·.~.~7@C6n()Cöphinips. Ç()l11> Da.te:.MQIl;07N"Qy200512:11:30.;0900 . . . . . .'. . tiøj~·!·'j~Q..····;i~i~~~~r·i~~~mlli~~H~~.~f~!ª~~t~i.§~~~~!~~'~·~~·!i!!:!·!··.·!i··.····' .. Tom: I ran an event query on 1F-18. I remember this well, I think it was a rock maker. This is all the summary I can dig up. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, November 07, 2005 11:08 AM -- To: NSK Problem Well Supv Subject: 1F-18 (196-039) Jerry, I was wondering if you might help me. I was looking into the Kuparuk sand wells that have had laterals added to them. 1F-18 was plugged in late summer 2004 and then 1F-18A and -ALl were drilled. Looks like the horizontal branches have been producing pretty steadily since completed in October 2004. When I pulled up the production report for 1F-18, it shows to have really "crashed" in December 2003. When I checked the well file, I don't find any information as to the reason. Is it possible for you or someone to pull the "summary well ops report"?? A while back you had been able to get a "one-line" summary of activities for several wells. The period I am interested is essentially after the completion report was filed. Aside from a caliper survey and perf report, there isn't anything in the file after the completion report. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: EventlF-18.xls EventlF-18.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 5(;ANNE[.i NO\f Q) 82005 1 of 1 11/7/2005 12:14 PM Event Date Service Type 28-Nov-03 SLICK LINE 29-Nov-03 SLICK LINE 25-Dec-03 SLICK LINE 31-Dec-03 COILED TUBING 1-Jan-04 SLICK LINE 19-Jan-04 SLICK LINE 20-Jan-04 SLICK LINE 21-Jan-04 SLICK LINE 7-Jul-04 TROUBLE WELLS 16-Jul-04 TROUBLE WELLS 19-Jul-04 SLICK LINE 21-Jul-04 SLICK LINE 22-Jul-04 SLICK LINE 27-Jul-04 COILED TUBING 28-Jul-04 COILED TUBING 31-Jul-04 SLICK LINE \ ~G ~-C -:s C:;\ Event Description PULL 1" DV'S FROM STA #1 ,2,3,4,5. SET LGLV IN STA #2. LDFN...IN PROGRESS. SET NEW GLVS IN STATIONS 1, 3, 4,5. RETURNED WELL TO PRODUCTION. [GLV] TAGGED FILL @ 6334' WLM. OBTAINED SAMPLE OF SAME. [TAG] TAG AT 6348' CTMD WITH 2.5" JET SWIRL NOZZLE AND UNABLE TO GO DEEPER. RIH WITH 1.75" NOZZLE AND WORK TO 6359' CTMD, THEN UNABLE TO GO DEEPER. OBSTRUCTION WILL ALSO GET ALONG COIL ON WAY OUT OF HOLE. SUSPECT TREESAVER RUBBER DOWNHOLE. WILL HAVE SIL FIS DRIFT TBG 2.2.68" CENT & 3-PRONG WIRE GRAB TO 6360' SLM. BROUGHT BACK 2 BIG ROCKS. [FCO, TAG] MADE AN ATTEMPT @ FISHING ON OBSTRUCTION IN TBG @6378' WLM. ALSO SD & HUNG UP AROUND 5654' WLM. [FISH] BAILED FILL (FORMATION SAND) FROM 6369' WLM TO 6387' WLM. OBSTRUCTION IN TBG. [MAINTENANCE] BAILED MUD & ROCK'S FROM 6373' WLM TO 6402' WLM [MAINTENANCE] MIT-OA TO 1800 PSI PASSED, POT & PPPOT-T PASSED, FUNCTION TESTED TBG LDS'S (ALL ARE GOOD). PT MASTER VALVE TO 4000 PSI FAILED, PT SWAB VALVE TO 4000 PSI PASSED. [ANN COM ISSUES, WH MAINTENANCE] PRESSURE TEST MASTER VALVE, FAILED [ANN COM ISSUES, WH MAINTENANCE] BAILED SAND I MUD & 3/4" TO 2" ROCKS 6385' SLM TO 6471' SLM, SAMPLES OBTAINED FOR DSE. [TAG] BAILED VERY DRY MUD I SAND AND NUMEROUS ROCKS 3/8" TO 1" DIA 6472' TO 6476' SLM. IN PROGRESS. [TAG, MAINTENANCE] GAUGED TBG TO 2.80" TO 6454' SLM. [TAG] CLEANED OUT FILL TO 6470' CTM WI 2-5/8" JUNK BASKET. JOB SUSPENDED EARL Y-~WILL CONTINUE TOMORROW. [FCO] CLEANED FILL TO 7060' CTM (7088' RKB) WI 1.75" JETSWIRL NOZZLE USING 2# BIO, SLICK SEAWATER. WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2500' WI DIESEL. [FCO] TAGGED D NIPPLE FOR CORRECTION. TAG FILL AT 7540' RKB. 2-Aug-04 TROUBLE WELLS MITMV - FAILED, MITSV - PASSED, DRAWDOWN TEST MV - PASSED, DRAWDOWN TEST SV - PASSED [ANN COM ISSUES, WH MAINTENANCE] 19-Aug-04 SLICK LINE MEASURE SBHP @ 7500' SLM. IN PROGRESS. [PRESSURE DATA] 20-Aug-04 SLICK LINE PULLED 1" OV @ 6930' RKB. PULLED 1" GLV'S @ 2463',4343',5577', & 6303' RKB. SET 1" DV @ 6303' RKB. IN PROGRESS. [GLV] ) 21-Aug-04 SLICK LINE 22-Aug-04 SLICK LINE 25-Aug-04 TROUBLE WELLS 3-Sep-04 ELECTRIC LINE 8-Sep-04 OTHER SET 1" DV' @ 2463',4343',5577', & 6930' RKB. MITIA TO 3000 PSI PASSED. DRIFT TBG WI 11' X 2.70" TO 7510' SLM. IN PROGRESS. [MIT, GLV] RUN CALIPER SURVEY FROM 7530' SLM TO 6800' SLM. MITIA - PASSED, (PRE-CTD) [ANN COM ISSUES, WH MAINTENANCE] SET WEATHERFORD 3.5" CAST IRON BRIDGE PLUG IN 3.5" LINER AT 7450'. TAGGED TOP TO CONFIRM SET. WELL LEFT SHUT IN. [WORKOVER PREP, TAG] BEGIN CTD SIDETRACK OF 1F-18 TO REPLACE DAMAGED WELLBORE. THE SIDETRACK WILL BE AN A & C SAND MULTI-LAT HORIZONTAL PRODUCER TO THE EAST. REFER TO 1 F-18A FOR CURRENT WELL EVENTS. NPP ) STATE OF ALASKA --) ALASKA ulL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged iii Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 4a. Location of Well (Governmental Section): Surface: 792' SNL, 455' WEL, SEC. 19, T11N, R10E, UM Top of Productive Horizon: 2693' NSL, 20' EWL, SEC. 17, T11N, R10E, UM Total Depth: 2980' NSL, 95' EWL, SEC. 17, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 539521 y- 5958733 Zone- ASP4 TPI: x- 539966 y- 5962220 Zone- ASP4 Total Depth: x- 540038 y- 5962508 Zone- ASP4 18. Directional Survey 0 Yes iii No 21. Logs Run: GR Zero Other 5. Date Comp., Susp., or Aband. 9/3/2004 6. Date Spudded 03/04/1996 7. Date T .D. Reached 05/17/1996 8. KB Elevation (ft): 108' 9. Plug Back Depth (MD+TVD) 7838 + 6456 10. Total Depth (MD+TVD) 7939 + 6545 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL , CASING " S,iZE ' 16" , WJ~PER,;FT." 62.5# 29.7# 15.5# 9.3# , , " "<;;RÀDe: . H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD qçJIIN~P~~r!1,Mp,., ~EP:IN~D~~t~~Q:".' :89~~':' " , TOI=:'\I, 'BOTfØM. 'i,T0P',<BQTTQM "ßtze Surface 121' Surface 121' 24" Surface 4254' Surface 3730' 9-7/8" Surface 7208' Surface 5940' 6-3/4" 7000' 7929' 5785' 6536' 4-3/4" 22. 7-5/8" 5-1/2" 3-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED NO\! 0 5 2004 26. Date First Production: Not on Production Date of Test Hours Tested 27. None RBDMS BFL NOV - 4 2004 Form 10-407 Revised 12/2003 24; SIZE 3-1/2",9.3#, L-80 TVD NOV 0 2004 1bJ\Weìt.:cfà~s: :" - ,;.. , :,::.;'~Ci":1 iii DevelopmeAt~cfiJ~oratory 0 Stratigraphic 0 Service 12. Permit to Drill Number 196-039 304-331 13. API Number 50- 029-22654-00-00 14. Well Name and Number: Kuparuk 1 F-18 15. Field / Pool(s): Kuparuk River Ft Ft 16. Property Designation: ADL 025652 17. Land Use Permit: 20. Thickness of Permafrost 1380' ss (Approx.) , " I I II I . I ' , , ' '" ,':Q~MENT¡NGR¡:êQR[) , 230 sx Arcticset I 710 sx AS III, 300 sx Class 'G' 70 sx Class 'G' 99 sx Class 'G' ,AMOUNJ , PULLE:ô ' 'TUBING RECORD DEPTH SET (MD) 7000' PACKER SET (MD) 6999' 25. , ACID¡f=RACTURE,CEMENT SQUEEZE,ETC, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7450' Set CIBP 7395' Set Whipstock GAs-McF W A TER-BBL PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR OIL -BBL TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BBL Press. 24-HoUR RATE 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". -"',. " .-;Ab~~~~ Z i7' "/.: , ~.... ,2..:0.):1',.. ,.,.",...,.,'~~X:~~..., GAs-McF W ATER-BBL ORIGINAL CONTINUED ON REVERSE SIDE CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) bþ , 28. ') 29. ) GEOLOGIC MARKERS 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". Top Kuparuk C 7375' 6067' None Base Kuparuk C 7417' 6100' Top Kuparuk A 7544' 6201' Base Kuparuk A 7682' 6317' 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 Terrie Hubble ~ ~ . c\::lIl ~ Tiüe Technical Assistant Date J /.0:2 -Dl.{ Kuparuk 1 F-18 196-039 304-331 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dan Kara, 564-5667 Permit No. I 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 10-407 Revised 12/2003 Submit Original Only ;1 Well: Field: API: Permit: ) ') 09/11/04 09/13/04 09/29/04 Nordic #2 08/20/04 PULLED OV @ 69301, PULLED GLVS @ 2463',43431,5577',63031 RKB. SET DV @ 6303' RKB. IN PROGRESS. 1F-18A Kuparuk River 50-029-22654-01-00 204-167 Accept: Spud: Release: Rig: 08/21/04 SET DVS @ 24631,4343',5577',6930' RKB. MITIA 3000 PSI, PASSED. DRIFTED TBG W/ 111 X 2.7011 TO 7510' SLM. IN PROGRESS, PRE-RIG WORK 08/22/04 LOGGED CALIPER SURVEY FROM 75301 SLM TO 6800' SLM, 09/03/04 SET WEATHERFORD 3.511 CAST IRON BRIDGE PLUG IN 3.5" LINER AT 74501. TAGGED TOP TO CONFIRM SET. WELL LEFT SHUT IN. ') ') Page 1 ~ BP EXPLORATION O.peratlons Sum.mary'Rep.Q~t Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Date From - To Hours Task Code NPT Phase 9/8/2004 17:00 - 18:00 18:00 - 18:40 1.00 MOB 0.67 MOB P P 18:40 - 19:10 19:10 - 20:10 0.50 MOB 1.00 MOB P P 20:10 - 00:00 3,83 MOB P 9/9/2004 1,33 MOB 6.67 MOB 00:00 - 01 :20 01 :20 - 08:00 P P 08:00 - 00:00 16.00 MOB N MISC PRE 9/10/2004 6.00 MOB 00:00 - 06:00 N MISC PRE 06:00 - 16:00 10.00 MOB N MISC PRE 16:00 - 18:00 2,00 MOB N MISC PRE 18:00 - 00:00 6.00 MOB N MISC PRE 9/11/2004 00:00 - 03:00 3,00 MOB N MISC PRE 03:00 - 06:00 3.00 MOB N MISC PRE 06:00 - 08:00 2.00 MOB P PRE 08:00 - 10:15 2,25 MOB P PRE PRE PRE PRE PRE PRE PRE PRE Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Description of Operations Preparing to move off of 1 D-30a Safety meeting prior to moving off of location. Review premove checklists. Discuss hazards, such as soft pads, culverts, personnel entering moving rig. Confirm that all pre move checklist items have been completed, including rig move notification to Kuparuk security. Perform 1 last walk around to ensure the rig is ready to move. Back rig off well, Move to the end of 1 D pad. Call Kuparuk tool service to confirm the spine road to KOC is blocked to traffic. Enter the spine road, and begin the move to 1 F pad. Weather conditions for move are poor. It is raining at the present time and the roads are saturated with water. All culvert crossings and other possible soft spots along the spine road are covered by a single layer of rig mats. Location of the rig at midnight is just short of the KOC/CPF1 pad. Continue move from 10 pad. Arrive at KOC/CPF1 pad. Park rig off to the side of the spine road. Wait while Kuparuk tool service shuttles 190 rig mats from the spine road behind the rig, and places them from the end of the KOC/CPF1 pad to the 1 F pad access road, and starting down the access road. On the move again, Matting 1 FPad access road Stair stepping mats along 1 F Pad access road At midnight, > 1/2 mile down 1 F access road. Moving rig along 1 F-Pad access road. At 0600 hrs the rig approximately 2/3 the way down the access road, Using 4 fork lifts to stair step mats then at midnight, down to 2 because of personnel work time. Back to 4 forklifts at 0600 hrs Moving along. Notified AOGCC, Chuck Sheve wavered witness the BOP test Moving mats for the last move to the pad. WiI still need to mat the Pad 18:00 update. Rig currently about 3/4 of the way down the 1 F pad access road, Continuing to single stack mats, and pull forward on them, then double stack and back up, then repeat. Continuing to inch slowly towards 1 F pad. Raining intermittantly. Rig is 1/4 mile short of 1 F pad as of midnight. Continue shuttling mats back and forth, and slowly moving toward the pad. Continuing to rain. Arrive on 1 F pad. Pull onto pad and stop. Wait for mats to be laid down pad and around to well. Still Raining. Move rig around pad on mats Held Move over well PJSH and move over well. Conducted Pad inspection Rig accepted at 0800 hrs 9-11-2004 63 hr Pad to Pad rig move, 48 hrs on 1 F Pad access road. Set in yard and started NU BOP's. AOGCC Chuch Sheave wavered witnessing BOP test Kuparuk Safety and OS Operator approved setting office at different location. NU BOP's WHP = 750 psi Working to get 1 F17 ESO actuator Printed: 101112004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) -) Page2~ Spud Date: 5/1/1996 End: 9/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/11/2004 08:00 - 10:15 2.25 MOB P PRE panel on rig 10:15 - 14:30 4.25 BOPSUR P PRE PT BOP to 250/3500 psi Hauling fluid and installing reel. 14:30 - 14:50 0.33 BOPSUP P PRE PJSM on pulling reel over pipe shead 14:50 - 15:25 0.58 BOPSUP P PRE Pulling CT over pipe shed. RU actural for ESD on 1F-17 tree. 15:25 - 17:00 1,58 BOPSUF P PRE Cut CT off, pulled wire out, stab on well and pump fluid Pumped= 44 bbl 17:00 - 18:00 1.00 BOPSUP P PRE Unstab injector, cut CT and fish wire, rehead to BHI 18:00 - 18:30 0.50 BOPSUR P PRE Pre spud safety meeting with all rig hands, SWS Team Leader, Nordic Toolpusher, BP, and 1 APC vac truck driver. Discuss present condition of well, hazards and mitigations to the hazards, and the plan forward for tonights tour. 18:30 - 20:30 2.00 KILL P WEXIT Resume attaching Ecoil head to 2" Coil tubing. 20:30 - 20:45 0.25 KILL P WEXIT Safety meeting prior to making up BHA to RI H and kill well. 20:45 - 21 :20 0.58 KILL P WEXIT MU BHA #1: 2.5M JSN - Blind Sub - BHI DPS - EDC - Powercoms - Ball Valve Sub - LaC - uac - CTC. Stab injector on well. 21 :20 - 21 :55 0.58 KILL P WEXIT Circulate mud down coil to finish slack management. Pumping at 2.0 bpm, 3200 psi. 21:55 - 22:10 0.25 KILL P WEXIT Pressure test hardline to tiger tank to 1500 psi. Passed ok. Pressure test lubricator to 3500 psi. Passed ok. Bleed off well to 1000 psi, open master valve. 22:10 - 23:30 1,33 KILL P WEXIT Open up well. WHP=975 psi. RIH, bleeding off well bore fluids to tiger tank thru rig choke. Holding 975 psi on WHo 23:30 - 00:00 0.50 KILL P WEXIT Stop at 7400'. SI pumps and rig choke. Monitor BHA. WHP=975 psi, BHP=3010 psi. Bring pumps on with diesel on the backside, circulating BHP=3100 psi. Holding 975 psi on surface choke. Gradually opening choke as mud gets up around coil. Final BHP while circulating=3475 psi. 9/12/2004 00:00 - 00:15 0.25 KILL P WEXIT Continue to circulate well to mud. 00:15 - 01:30 1.25 KILL P WEXIT POOH following pressure schedule with choke, 01 :30 - 01 :45 0.25 KILL P WEXIT Safety meeting prior to laying down BHA #1, 01 :45 - 02:45 1,00 KILL P WEXIT Lay down BHA #1. 02:45 - 03:15 0.50 KILL N WAIT WEXIT Waiting on Schlumberger hand with pip tags. (He has never been to Kuparuk before and may be lost.) 03:15 - 03:30 0.25 KILL P WEXIT Install RA pip tag into whipstock. 5.67' from top of WS to RA tag. 03:30 - 03:45 0.25 WHIP P WEXIT PJSM re: pressure deployment of WS BHA. 03:45 - 05:30 1,75 WHIP P WEXIT MU BHI MWD BHA in mousehole, PU into lubricator. Distance from no go to MU point is 3,5', MU WF whipstock in hole. MU MWD to WS. Scribe to high side of tray. PU into lubricator. PT to 1000 psi. Bleed off to WHP. RIH, WHP=700 psi. Tag no go, PU 3.5' and set combis. Bleed off lubricator. MU injector. 05:30 - 06:00 0,50 WHIP P WEXIT PT lub to 500 psi, open combis, O-ring leak on lubicator, PUH and slack off 0.5 ft, shut combies and engerize. 06:00 - 06:15 0.25 WHIP P WEXIT Held PJSM on undeploying BHA to change o-ring, 06: 15 - 07:30 1,25 WHIP P WEXIT Set combi, pull tested BHA, Bleed lub pressure, slip chains, and PU lub, close DBV, bleed pressure off CT, Unstab BHA, Change out O-ring, Stab on BHA PT lub 1000 psi. Unlock rams, de- engerize rams, Open Combis. WHP = 377 psi. Need to change packoff following WS setting run, 07:30 - 09:45 2.25 WHIP P WEXIT RIH w/ WS as per schedule 09:45 - 10:35 0,83 WHIP P WEXIT Tie-in from 7200 ft down (Corrected -1 ft) Printed: 10/112004 9:09:13 AM BP EXPLORATION Operations Summary Report 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO, Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: ) ) BP EXPLORATION Operations Summary Report Page 3 ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/12/2004 10:35 - 11 :20 0,75 WHIP P WEXIT RIH to set WS Tagged CIBP at 7452 ft PUH to 7389' RIH to 7404 ft TOW at 7395 ft, Working at closing EDC. Closed Tray oriented TF to 33R from HS Set at 3350 psi Set 2500 Ib down solid. PUH clean 11 :20 - 12:55 1.58 WHIP P WEXIT POOH following pressure schedule Held Pressure un-dep PJSM Fill across top to keep required WHP when OOH 12:55 - 17:00 4.08 WHIP P WEXIT Tagged up, RIH 0.5 ft Set 2-3/8" Combi's, Depressured above combi's, OK, RU Lub and PT to 600 psi, Equalized pressure, PUH with WS running tools, Closed MV/SV. Change out BHA in mouse hole. Stab in lub and stab on well. PT lub to 600 psi. RIH slow, Falling real slow. Worked down to No/Go Closed combi's. Depressured lub, Un stung, DBV to high for Injector head. Stab back on well. PT to 550 psi, released combi's PUH and greased line. RIH and hit No/Go PU 3.8 ft Set combi's and released pressure. Unstabbed lub and stand back in derrick. Ru luband injector head 17:00 - 18:20 1.33 WHIP P WEXIT RIH using presssure schedule 18:20 - 19:00 0.67 STWHIP P WEXIT No GR tool in this BHA. No tie in pass made. Tag top of WS at 7398', Make -3' correction. Up weight = 20 klbs. Kick on pumps. Free spin 3140 psi at 1.55 bpm. BHP=3375 psi. Tag top of whipstock, Confirm depth is still 7395'. Begin window milling. IAP=911 psi, OAP=500 psi. Bleed both down. 19:00 - 20:00 1.00 STWHIP P WEXIT 7395.4', 1.57/1.59/3280 psi. Pit vol=438 bbls. IAP=73 psi, OAP=495 psi. Still bleeding OAP. Getting good motor works and drill ofts every 0,1'. 20:00 - 21 :00 1.00 STWHIP P WEXIT 7396.3', 1.57/1.6/3400 psi. Pit vol=436 bbls. IAP=430 psi, OAP=304 psi. 21 :00 - 22:00 1.00 STWHIP P WEXIT 7397.1',1.57/1,60/3320 psi. Pit vol=436 bbls. IAP=468 psi, OAP=376 psi. Starting to get metal back accross the magnets. 22:00 - 23:00 1.00 STWHIP P WEXIT 7398.2', 1.57/1.59/3230 psi. Pit vol=435 bbls. IAP=497 psi, OAP=426 psi. 23:00 - 23:05 0.08 STWHIP P WEXIT 7399.0', 1.57/1.6/3290 psi. Pit vol=435 bbls. IAP=527 psi, OAP=466 psi. 4,0' milled since start of window. Motor work and WOB suggest that we are in open hole. Attempt to drill ahead. Making hole. Window depth prior to logging correction on next pass is 7395'-7399'. 23:05 - 23:45 0.67 STWHIP P WEXIT Drill 10' of rathole. Getting drill ofts. ROP=10-20 fph. Definately in sand. 23:45 - 00:00 0.25 STWHIP P WEXIT 10' of rathole finished. Begin reaming window. 9/13/2004 00:00 - 00: 15 0,25 STWHIP P WEXIT Continue to ream window. 00: 15 - 01 :30 1,25 STWHIP P WEXIT SI pumps, Dry drift window up and down smooth. POOH for build section BHA. Following pressure schedule while POOH. 01 :30 - 02:00 0,50 STWHIP P WEXIT Tag up at surface, Shut in choke trapping 750 psi on well. Hold PJSM re: pressure undeploy of milling BHA. Discuss proceedure, Review each step on checklist. Discuss hazards and mitigations to hazards, 02:00 - 03:40 1.67 STWHIP P WEXIT Undeploy BHA #3 using the pressure undeploy checklist. Both mills recovered at 2.74" go, 2,73" No-go, Window should be in good shape. Printed: 1011/2004 9:09:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ) Page 4 ... BP EXPLORATION Operations Summary Report 1 F-18 1 F-18 DRILL+COMPLETE PARKER DRILLING CO. 9/13/2004 03:40 - 04:05 From - To Hours Task Code NPT Phase 0.42 DRILL P PROD1 04:05 - 05:20 05:20 - 08:25 08:25 - 10:00 10:00 - 10:15 10:15 - 10:40 10:40 - 13:25 13:25 - 14:05 14:05 - 14:25 14:25 - 17:45 17:45 - 18:00 18:00 - 19:45 19:45 - 20:00 20:00 - 21 :30 21 :30 - 22:50 9/14/2004 22:50 - 23: 15 23: 15 - 00:00 00:00 - 01' 01 :00 - :30 01: - 03:30 03:30 - 04:55 1.25 DRILL P PROD1 3.08 DRILL N DFAL PROD1 1.58 DRILL P 0.25 DRILL P PROD1 PROD1 0.42 DRILL P PROD1 2.75 DRILL P PROD1 0.67 DRILL P PROD1 0.33 DRILL P 3.33 DRILL P PROD1 PROD1 0.25 DRILL P 1.75 DRILL P PROD1 PROD1 0.25 DRILL P 1.50 DRILL P P PROD1 0.42 DRILL 0,75 DRILL 1,00 DRILL 0.50 DRILL 2.00 DRILL P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 1.42 DRILL P PROD1 Start: 9/8/2004 Rig Release: 5/31/1996 Rig Number: Spud Date: 5/1/1996 End: 9/29/2004 Description of Operations Safety meeting re: Picking up and pressure deploying build section BHA. Deploy BHA #4, Build section BHA. MWD tool failed after deploying. Undeploy failed MWO tool. change out BHI MWD, pressure deploy RIH as per pressure schedule Tie-in at GR development at 7263 ft (Corrected -2.5 ft) Closed choke and EDC. RIH tagged at 7402 ft PUH and orient TF to 30 R Wash dow to 7409 ft Drilling TF 33R Qp = 1.55/1.51 bpm BHP = 3447 psi = 11.00 ppg EDC Density = 8.85/8.89 ppg Vp = 426 bbl at 10:48 hrs Taking 50 ft geo samples Drilling TF 28R Qp = 1.55/1.55 bpm BHP = 3436 psi = 11.0 Density = 8.85/8.89 ppg Vp = 434 bbl at 14:00 hrs Centrifuge airing up the mud Wiper trip to window Clean Drilling TF 25R Qp = 1.52/1.53 bpm B Density = 8.85/ 8.89 pg Vp = 445 bbl at 1 . 5 hrs Drill Ahead. 7593', Drill' g ahead build section. 1.53/1.59/3540 psi. WHP= psi. BHP=3456 psi. IAP=405 psi, OAP=650 psi. Pit vol 4 bbls. ROP=erratic, 2-30 fph. INC=96 deg at bit. =60R. Build and turn section landed as per DO. PUH to make tie in pass prior to POOH for lateral section BHA. Motor work and overpull at 7528' when making wiper trip to window. Keep and eye on this on future runs. Log tie in pass over original well gamma marker and RA tag in whipstock. Made -1.8' correction to RA tag. New correlated depths are: Top of window = 7393.2' Bot of window = 7397.2' RA tag = 7399.0' POOH with drilling BHA. Choke hand on location to troubleshoot erratic choke. Tag up at surface. Hold PJSM for BHA undeploy. Pressure undeploy BHA #5. Continue to lay down build section BHA. Safety meeting prior to picking up lateral section BHA. Deploy BHA #6 to drill lateral section using pressure deployment techniques. Pick up new Hycalog bicenter bit as per proceedure. Change out upper and lower check valves as per BHI recommendation. RIH with BHA #6. 1.0 deg motor, Hycalog D8100 bit. Printed: 1011/2004 9:09:13 AM ck3sll. ".;ELL LOG TRANSMITTAL ) /9& -é) 3~ .-» OCT 1 2 2004 ProActive Diagnostic Services, 'nc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage. Alaska 99501 RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S) REPORT OR BLUE LINE Open Hole 1 Res. Eval. CH 1 1 1 Mech. CH 1 F-1 8 8-22-04 Caliper Survey 1 Apt or 2 Color Signed: ~/û<J;- ~ Print Name: #ek,u J. Warpllfa.",;L/ Date: (ofaf r/ PRoAcTivE DiAGNOSTic SERviCES, INC., PO Box 1 }b9 STAffoRd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com SCANNED NO\! 0 5 2004 t';:;" r:::-? n r::;'-" ,,:;;:¡ \~ll/ð\¡rIÞ QU U 1Ft} U L.!=;¡ r~"\ I' i I ,I ¡! ".U' ¡ I ¡ \'",--/ FRANK H. MURKOWSKI. GOVERNOR AI.ASIiA OIL AlQ) GAS CONSERVATI ON COMMISSION 333 W, 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 1, 2004 Dan Kara CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~3#J Re: Kuparuk 1 F -18 Sundry: 3'04-331 Dear Mr. Kara: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. n . Norman Chairman Enclosure STATE OF ALASKA 4; ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED -;ò APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 AUG 2 72004 1. Type of Request: RléI$KiI un Ot IJllit "'UII~. . Abandon [J Repair Well . Plug Perforations [J Stimulate [J Other Anchorage [J Alter Casing [J Pull Tubing [J Perforate New Pool [J Waiver [J Time Extension [J Change Approved Program [J Operation Shutdown [J Perforate [J Re-Enter Suspended Well 'on 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: c/o P.O. Box 196612, Anchorage, AI( 99519-6612 7, KB Elevation (ft): 118" 4. Current Well Class: B Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 196-039 6. API Number: 50- 029-22654-00-00 9. Well Name and Number: KUP 1F-18 8. Property Designation: 10, Field I Pool(s): ADL 025652 Kuparuk River 11. PRESENT WELl CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 7939 6545 7838 6456 None CåSÎnQt.eoom aIze."" "'."M[ ... ... JVD . BIJr'St ~. Junk (measured): 7560 CoIlåOS$ (",,"A, .,..+"r ~r- 121' 4254 7208' 16" 7-5/8" 5-112" 121' 4254' 7208' 121' 3730' 5940' 6890 7000 4790 4990 ~ Liner 929' 3-1/2" 7000' - 7929' 5785' - 6536' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): I 7387' - 7620' 6076' - 6265' Packers and SSSV Type: 3-1/2" Baker 'SABL-3' packer; 3-1/2" Camco 'DS' Nipple Tubing Size: 3-1/2",9.3# Tubing Grade: I Tubing MD (ft): L-80 7000' Packers and SSSV MD (ft): 6999' 499' 12. Attachments: B Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Dan Kara \ ..--.. Title CT Drilling Engineer SiQnature -?') ~ Q 1;-,,--- ,-' I D BOP Sketch 13. Well Class after proposed work: D Exploratory B Development D Service 15. Well Status after proposed work: DOil DGas D WAG D GINJ D Plugged DWINJ B Abandoned D WDSPL September 2, 2004 Date: Contact Dan Kara, 564-5667 Phone 564-5667 Commission Use Only 'J, Prepared By Name/Numbe~ Date 8 'J-7/olf Terrie Hubble. 564-4628 , I Sundry Number: JOt¡-33/ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity '*OP Test D Mechanical Integrity Test D Location Clearance Othe" A.r-- 'i ':> ~ -kc=\.- ù ~O r<? \M. ð ~ -\-- be>: ~~ ~ \J ~t'..,,?ìÌ) <y\'\t).},J 5""0"001 F~t '\ RBDMS BFL SEP 0 2 1011' Approved BV-JJ- ..4 COMMISSIONER ~~~~~~~I~~ION Date 9/Í / ,if --- Form 10-403~' -- " ~brtlit In'Duplicate OR I GI NAL Obp To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Dan Kara CT Drilling Engineer Date: August 26, 2004 Re: Kuparuk River Unit WelllF-18 Prep for a CTD sidetrack Kuparuk River Unit welllF-18 is scheduled for a through tubing sidetrack using the BP operated SLB/Nordic 2 Coiled Tubing Drilling rig. Two laterals will be drilled (IF-18A and IF-18ALl). The existing A Sand perfs will be isolated with existing fill and a cast iron bridge plug below the WS. The following describes work planned for A Sand perf isolation and sidetrack and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. CTD Pre-Rie Summary I. Slickline - Drift tubing and liner. Dummy gas lift valves. Pressure test IA to 2500 psi. Pressure test 0 A ~ to 200Opsi. Run calliper log across liner. . 2. Eline - Set CffiP at approx. 7450'md to abandon A sand perforations. -r ~\c., a ~ Q \0 Ùû. \ :s()~ ~~~ \ CTD Drill and Complete 1F-18A & ALl Droeram: (Form 10-401) V 1. MIRU Nordic 2. NU 7-1116" BOPE, test. 2. CTD install mechanical WS at 7395' MD 3. Mill 2.74" window at 7395' md and 10' of openhole. 4. Drill 3" bicenter hole horizontal sidetrack IF-18A to -9800' TD targeting Kuparuk C4 Sands. 5. Run and drop a 2-3/8" pre-drilled liner from TD of9800', up to -7450' md. 6. Openhole sidetrack at 7450' from the IF-18A wellbore, above the 2-3/8" liner. 7. Drill 3" horizontal sidetrack IF-18ALI from open-hole side track to -9800' TD targeting Kuparuk A4 sand interval. 8. Complete with 23/8" pre-drilled liner from the TD of ALl at 9800', up into the 3-112" liner to -7300'. 9. Post CTD; Run GL V s. Bring on production. The pre CTD work is scheduled to begin as soon as possible. The drilling portion is scheduled for 9/10/04 o-y7 <- \"c\>oc;.~ ~\\J~'J ~~ '\ s ~\\\,,~\ "'~"( "ùçc~'LC) \\ ?co\ f; w,\\~~\\ \<:::'C~.\~\<è -\.~ \t>~~\ Þ\. ~G.~. \,<z:'\~\Q:\-\C"-<:' ~~ ~\.<::.t) \O:~CJ ~\}-'\..{)~~ k: ~ s)\-~\(t,\,,-:> ~ ~'t~"-á ~~<'~~K\--\"~ ~~\-..~\ ~~ '>5ö' (j'oc~~ ?-~~*,'-Ð"~ ~ ~;{) CkN-<.~\-~~l ~ 0.. '-.UY\O-b \<é:. ~€- \ a~ ~PK- d 5"', \ \ d (" ') i 1rCJ- ~ ~/~"t)-aL.\ Danny Kara CT Drilling Engineer 564-5667, 240-8047 CC: Well File Terrie Hubble ConocoPhillips 8QQnc!cc)Ph'I'Ip8 ~. ~ API: 500292265400 SSSVType: Nipple NIP (499-500. OD:3,5OO) TUBING (0-7000, OD:3,5OO, ID:2,992) Gas Lift MandreWalve 1 (2463-2464, Gas Lift .. , MandreWalve 2 (4343-4344. Gas Lift MandreWalve 3 (5577-5578, Gas Lift MandrelNalve 4 (6303-6304, Gas Lift MandreWalve 5 (6930-6931, NIP (6978-6979, OD:3,500) PBR (6988-6987, OD:3,5OO) PKR (6999-7000, OD:3,5OO) PROD, CASING (0-7208, OD;5,5OO, W1:15,50) Perf (7585-7620) ~ . .. .. .- J] ~ - - - - - r-- I---- I---- KRU 1F-18 Well Type: PROD Orig 31811996 ComDletion: LastW/O: Ref Loa Date: TD: 7928 ftKB Max Hole Anole: 45 dea (â) 4900 AnaIe /ã) TS: 39 dea{à)7375 Angle @ TD: 27 deg @ 7939 Rev Reason: Tag fill, recovered ROCKS Last Ucdate: 31512004 Annutar Fluid: Reference Loa: LastTao: 6360' SLM Last Too Date: 1/112004 - ALL STRINGS DescrlDtion CONDUCTOR SUR. CASING PROD. CASING LINER - TUBING Size I TOD 3.500 I 0 Perfonl1lon8 Summary Interval TVD 7387 - 7402 6076 - 6088 Size 16.000 7.625 5.500 3.500 Tub! I I 7585 - 7620 6235 - 6265 TOD 0 0 0 7000 Bottom I 7000 I Zone C-4 Status Bottom 121 4254 7208 7928 TVD 121 3730 5940 7928 TVD 5785 I Wt I Grade I I 9.30 I L-80 I Wt 62.50 29.70 15.50 9.30 Grade H-40 L-80 L-80 L-80 Thread ABM-EUE Thread Ft SPF Date TYD8 Comment 15 4 11125/1999 APERF 2118" Enerjet, 0 deg phase, Orient 0 dea from low side 35 4 6130/1996 IPERF 180degPh;2OdegCCW Orient 2.5" Hollow Case A-4 Gas lift Mandrel8lValve8 St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 2463 2385 BST AXT 2 4343 3794 BST AXT 3 5577 4689 BST AXT 4 6303 5249 BST AXT 5 6930 5732 BST AXT Other 1121111 8. . aulD. ate.\ - JEWELRY Deoth TVD TVD8 499 499 NIP 6978 5768 NIP 6986 5774 PBR 6999 5784 PKR General Nof88 Date I Note 7I22l2OO1 I Taoaed obsIruction /ã)7551 , SLM, aooears to be something solid (metal), Lost jar action /ã)7553' SLM 0/17120011 VIDEO LOG SHOWED COLLAPSED LINER (â)7560' RKB GLV GLV GLV GLV OV DescrlDtion 1.0 1.0 1.0 1.0 1.0 Cameo 'OS' Cameo 'D' NiDDIe NO GO Baker Baker SABL-3 Uner Packer (Slabbed into 3 112" Csa) ..---.. T-1 T-1 T-1 T-1 T-1 Date Run 0,125 1301 112912003 0.156 1331 112912003 0,156 1320 112912003 0.063 1342 1I29l2OO3 0.188 0 1I29l2OO3 Vlv Cmnt ID 2.813 2.750 3.000 3.000 ..--- KRU 1 F-18A & 1 F-18AL 1 Producer Proposed CTD Sidetracks Conoc~iIIi pS Alaska. Inc, G. Cameo os Nipple at 499' MD, 2.813" ID 7-518" 29.7# L-80 casing @ 42 . C4-Sand F. 3.112' 9.3# L.80 tubing wI 3.112' x l' BST 'A){T' mandrels B. 3.W Cameo 0 nipple with 2.75' 10 at 6978' MD (may be milled out to 2.80' for CTO bits) c. Baker 3.112' SABL-3 Liner packer at 6999' MD with PBRlseal assembly 3.5' liner top 0 7000' MO 2-318' liner top 0 +1-7300' MD A. 3-1/2' tubing tail at 7000' 3" openhole Top of Whipstock +1-7395' MD Window in 3.5' clap plug set +1-7450' MD Openhole KOP @ 7450' md off wfd alum kick off tool Fill cleaned out to 7540' AKB \~<;(. c ~~nà()V'--~ Sù \)'~Q.L \ -\a ~ r Ô-\,~~C1.\<j.. 1F-18A, TD @ 9800' md 3 000000000000000000 3.5" 9.3# L.80 @ 7928' MD Lateral (1F-18AL 1), TD @ 9800' md --....- ¡q(p ~ 03c; Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLIPS (ALASKA) INC. August 22, 2004 5520 1 3.5" 9.3 lb. L-80 Tubing and Liner Inspection Type: Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 1 F-18 Kuparuk Alaska 50-029-22654-00 6,822 Ft. (MD) 7,542 Ft. (MD) Side Track Candidate Inspection COMMENTS: This caliper data is tied into the D Nipple @ 6,978' (Driller Depth). This log was run to assess the condition of the tubing to determine potential side track candidacy. The caliper recordings indicate that the interval of 3.5" tubing and liner logged is in good to fair condition. The majority of the tubing is in good condition. Of the 28 joints logged only 3 of the joints (excluding the perforation interval) have maximum recorded penetrations in excess of 20% wall thickness. The damage appears in the form of Isolated Pitting with some line corrosion. 46% Cross-sectional Wall loss is recorded in the perforation interval @ 7,390'. No significant 10 restrictions are recorded in the interval of 3.5" tubing and Liner logged. Cross-sectional drawings of the most significant events are also included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: The joint numbering used in this report is an estimation based upon the average joint length. Isolated Pitting Isolated Pitting Line Corrosion ( 24%) ( 23%) ( 22%) Jt. Jt. Jt. 244.2 @ 235 @ 239 @ 7,493 Ft. (MD) 7,187 Ft. (MD) 7,295 Ft. (MD) No other significant wall penetrations (>20%) are recorded in the interval logged. Perforation Interval ( 46%) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: 7,390 Ft. (MD) Jt. 242 @ No areas of significant cross-sectional wall loss (>6%) are recorded in the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded in the interval logged. I Field Engineer: N. Kesseru Analyst: J. Thompson Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 '<Ids. I Well: Field: Company: Country: 1 F-18 Kuparuk CONOCOPHllLlPS ALASKA INC USA Tubing: Nom.OD 3.5 ins Weight 93 f Grade & Thread l-80 Penetration and Metal Loss (% wall) - penetration body 30 - metal loss body 20 10 40 to over 85% 85% 1 0 Damage Configuration ( body) 20 10 0 isolated pitting general corrosion line ring hole / poss corrosion corrosion ihle hole PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.lD 2.992 ins Nom. Upset 3.5 ins - penetration body 0 225 GlM 1 Bottom of Survey = 246 Analysis Overview page 2 August 22, 2004 MFC 24 No. 00387 1.69 24 J. Thorn son Upper len. 1.2 ins lower len. 1.2 ins Damage Profile (% wall) - metal loss body 50 100 231 241 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 F-18 Kuparuk CONOCOPHllLlPS ALASKA INC USA August 22, 2004 Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 loss 1.0. Comments (%wall) (Ins.) (Ins.) 'Yo (Ins.) 0 50 100 225 6825 () 0.03 10 2 2.94 "" 226 6857 () 0.05 20 2 2.94 Shallow pitting. "" .~ 227 6888 0 0.02 9 2 2.94 "" 227.1 6920 () 0.01 3 2 2.95 PUP 227.2 6929 0 0 0 0 N/A GlM 5 (Latch @ 8:30\ 227.3 6936 0 0.02 9 3 2.93 PUP 228 6946 () 0.02 9 2 2.94 ~ 228.1 6978 0 0 0 0 2.75 D NIPPLE 228.2 6979 0 0.01 3 1 2.96 PUP 228.3 6985 0 0.01 2 1 2.97 PUP 228.4 6999 0 0 0 0 N/A PACKER 229 7004 () 0.04 16 2 2.94 Shallow pitting. "" 230 7032 0 0.03 11 2 2.94 231 7061 0 0.05 19 2 2.92 Shallow nittin\!:. - 232 7097 () 0.03 11 6 2.94 Deoosits. 233 7119 0 0.02 9 2 2.92 234 7149 0 0.03 13 2 2.93 Shallow pitting. 235 7177 0 0.06 23 2 2.94 Isolated pittin\!:. "". 236 7206 0 0.02 9 3 2.92 .. 237 7235 () 0.04 16 2 2.91 Shallow pitting. ... 238 7263 () 0.03 13 2 2.93 Shallow pittin\!:. "" 239 7292 0 0.06 22 6 2.96 Line corrosion. - 240 7321 0 0.04 17 2 2.93 Shallow nitting. ... 241 7349 0 0.03 13 3 2.96 Shallow oittin\!:. .. 242 7378 0 0.24 96 46 2.94 Perforation Interval p 243 7405 0 0.05 18 3 2.91 Shallow uittinl/.. lt. Deuosits. 244 7433 0 0.04 16 4 2.92 Line shallow corrosion. 244.1 7462 0 0.04 15 4 2.92 PUP Shallow pitting. 244.2 7478 0 0.05 21 6 2.93 PUP Isolated pittim!.. - 245 7493 0 0.04 14 4 2.94 Shallow pitting. 246 7522 0 0.05 18 4 2.80 Line shallow corrosion. Lt. Deposits. - I Penetration Body Metal loss Body Page 1 <£as. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 F-18 Survey Date: Kuparuk Tool Type: CONOCOPHILLIPS ALASKA INC Tool Size: USA No. of Fingers: 3.5 ins 9.3 ¡:>pf l-80 Analyst: August 22, 2004 MFC 24 No. 00387 1.69 24 j. ThoO1Qson Cross Section for joint 242 at depth 7390.22 ft Tool speed = 46 NominallD = 2.992 Nominal OD = 3.5 Tool deviation = 44 0 Perforation Interval 46% Cross-sectional Wall loss HIGH SIDE = UP Cross Sections page 1 80"""'" .J'M""" ~ . -== ... is ..~ ""~ , .... .- 44>- , .......... . ~ k.'; ........ ... III ~ 1-'" .. . ....... .... - -., ...... wi .. ~- .. .,..,..... 18'8 ~ KRU a 1M8 ." Of . _J ..... ST1JIIt )EN t1l!l.6Øl.1fi 1:[:.1 MK/U,. From: Sent: To: Subject: Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com] Friday, June 18, 2004 9:36 AM Kara, Danny T Permit authorization Dan, This is the standard verbage that we have forwarded to AOGCC in the past authorizing permit delivery to BP: The Kuparuk CTD program starting up in August 2004 consists of 5 wells. The proposed wells are 1 C-08A, 1 Y -24A, 1 D-30A, 1 F-18A, #5 TBD and will be drilled with BP's Nordic 2 CTD unit and managed through BP's CT drilling organization. BP's CT drilling services are being provided to the operator, ConocoPhillips, via a Shared Service operation. As such, ConocoPhillips authorizes the delivery of these permits to BP (Terrie Hubble). ConocoPhillips does request that BP provide a copy of the approved permits for COP's files (Sharon Allsup-Drake). If you need anything else, let me know. Dan Venhaus ConocoPhillips AK Wells (907)263-4372 office (907)230-0188 cell STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 108 feet 3. Address ExploratoW___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 791' FNL, 454' FEL, Sec. 19, T11 N, R10E, UM (asp's 539521, 5958733) 1F-18 At top of productive interval 9. Permit number / approval number 2589' FNL, 5257' FEL, Sec. 17, T11 N, R10E, UM (asp's 539966, 5962220) 196-039 At effective depth 10. APl number 50-029-22654 At total depth 11. Field / Pool 2297' FNL, 5182' FEL, Sec. 17, T11 N, R10E, UM (asp's 540058, 5962508) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7939 feet Plugs (measured) Tagged Fill (7/16/00) @ 7559' MD. true vertical 6545 feet Effective depth: measured 7559 feet Junk (measured) true vertical 6214 feet ..... , Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 230 Sx AS I 121' 121' SURF CASING 4146' 7-5/8" 710 Sx AS III, 330 Sx G 4254' 3730' PROD CASING 7100' 5-1/2" 70 Sx Class G 7208' 5940' LINER 928' 3-1/2" 99 Sx Class G 7928' 6535' Perforation depth: measured 7387 - 7402'; 7585 - 7620' true vertical 6076- 6088'; 6235- 6265' Alas/<a 0il & Gas Cons, Commission Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 7000' MD. Anchorage Packers & SSSV (type & measured depth) BAKER SAIL-3 LINER PACKER (STABBED INTO 3 1/2" CSG) @ 6999' MD. CAMCO 'DS' @ 499' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 222 894 682 - 147 Subsequent to operation 601 1061 604 160 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~, ~.{~.,~ Title: Dat%repar~dd [/y' jc~h/p e i~me/265_6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE -~.~.~ 1F-18 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 11/23/99: RIH & tagged Fill @ 7575' MD. 11/25/99: MIRU & PT equipment. RIH w/perforating guns & shot 15' of perforations as follows: Added perforations: 7387 - 7402' MD Used 2-1/8" Enerjet carriers & shot the perfs at 4 spf at 0 degree phasing. POOH w/guns. ASF. 7/16/00: RIH & tagged fill @ 7559' MD. RD. Returned the well to production and obtained a valid well test. 01,I OR BEFORE AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS 96-039 CBL L 6990-7794 96-039 7466 T SCHLUMGERGER SLIM1-GR Page: 1 Date: 06/09/98 RUN RECVD 1 07/18/96 1 09/20/96 T 10-407 R COMPLETION DATE / / / DAILY WELL OPS R / / / TO / / / Are dry ditch samples required? yes no And received? Was the well cored? yes no Analysis & description received? Are well tests required? yes no Received? yes no Well is in compliance ~ Initial COMMENTS / / / / / / yes no yes no ARCO Alaska, Inc. Post Office Box 1003o0 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 6, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1F-18 (Permit No. 96-39) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1F-18. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION uuMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS [---] SUSPENDED E~ ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-39 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22654 ~- .......... ...... ' ' .... ~'~ 9 Unit or Lease Name 4 Location ofwell atsurface : f~?~'"'~'~ """~-~¢~,t~-~.,,,-,..,~ ec. 19, T11N,.10 , .op .rodu ,n. _ At Interval !' ~0 Well Number At Total Depth ~ ~ .. ~ ~ Field and Pool ..... , . 2285' FNL, 91' FWL, Sec. 17, TllN, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, elc.) I 6 Lease Designation and Serial No. Nordic #'2 Ricg RKB 32', PAD 76'I ADL 25652 ALK 2578 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 04-Mar-96 17-Ma¥-96 (drillout) 30-Jun-96 (perrd) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 7939'MD&6545'TVD 7838' MD & 6456' TVD YES IXI NO LaI NA feelUD =1380'SS APPROX 22 Type Electric or Other Logs Run GR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" 230 sx AS I 7.625" 29.7# L-80 SURF. 4254' 9.875" 710 sx AS III Lead, 330 sx Class G Tail 5.5" 15.5# L-80 SURF. 7208' 6.75" 70 sx Class G 3.5" 9.3# L-80 7000' 7929' 4.75" 99 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE IDEPTH SET (MD) PACKER SET (MD) ;3.5" 7000' 70~' 7585' - 7620' MD 4 spf 6236' - 6265' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7585' - 7620' total 175997# w/10 ppa of #12/18 @ perfs. left 21119# of prop in wellbore. (11237# of #20/40 and 164760# of #12/18 27 PRODUCTION TEST Date First Produclion IMethod of Operation (Flowing, gas lift, etc.) 7/26/96I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 8/13/96 11.80 TEST PERIOD ¢' 54 8 458 187 176 835 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 144 1005 24-HOUR RATE I~ 1 1 1 4 930 381 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. . ; . .?" 'i. ,: : ,~" -~' ~ '. ORIGINAL ! ,':.:!.,~. ~,~' ~-.: ~: !,: - ~.,., , · ~.'. (i;.i' :'. '..,. ~'.::'.:"'.:0~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE _/9. 30. GEOLOGIC MARY, ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7375' 6067" Bottom Kuparuk C 7417' 6100' Top Kuparuk A 7544' 6201' Bottom Kuparuk A 7682' 6317' Total pump volumes: Categories: 1. 24677 2. 100 3.0 Total for time period: 24777 Total to Date: 24777 FREEZE PROTECT ANNULUS WITH DIESEL 31. LIST OF ATTACHMENTS Directional Survey, Daily Drillin(:j History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well comoletion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date' 8/19/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:iF-18 RIG'PARKER 245 WELL ID: AK8461 AFC: AK8461 TYPE' STATE:ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/03/96 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL'$ 1420M/ 1700M API NUMBER: 50-029-22654-00 03/01/96 ( 1) TD: 0'( 0) SUPV:GRW DAILY: 03/02/96 (2) TD: 0'( 0) SUPV:GRW DAILY: 03/03/96 (3) TD: 121'( 0) SUPV:GRW DAILY: 03/04/96 ( 4} TD: 3397' (3276) SUPV:GRW DAILY: 03/05/96 ( 5} TD: 4265' ( 868} SUPV:GRW DAILY: 03/06/96 ( 6) TD: 4265' ( 0} SUPV:GRW DAILY: 03/07/96 ( 7} TD: 6581' (2316) SUPV:GRW DAILY: 03/08/96 ( 8) TD: 7208' (627) SUPV:GRW DAILY: 03/09/96 (9) TD: 7208' ( 0) SUPV:GRW DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MIRU Move rig camp and modules to DS iF. $111,717 CUM: $111,717 ETD: $0 EFC: $1,531,717 MW: 0.0 MIRU Continue moving rig to DS iF. $57,445 CUM' $169,162 ETD' PV/YP' 0/ 0 APIWL: 0.0 $0 EFC' $1,589,162 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 P/U 4" DP Accept rig @ 1700 hrs. R/U floor. P/U 4" DP. $56,229 CUM' $225,391 ETD' $0 EFC' $1,645,391 MW: 10.0 PV/YP: 23/21 APIWL: 0.0 DRILLING Function test diverter. Drill from 121' to 3397' -- $92,371 CUM: $317,762 ETD' $0 EFC: $1,737,762 MW: 10.0 PV/YP: 27/14 APIWL: 8.5 CEMENTING SURF. CASING Drill from 3397' to 4265' Run 7-5/8" casing to 4254'. Cement surface casing. $122,212 CUM: $439,974 ETD: $0 EFC: $1,859,974 MW: 8.5 PV/YP: 1/ 2 APIWL: 20.0 L/D D.C.'S Cement casing. N/D diverter. N/U BOPE. Test BOPE 300/3000 psi. Test annular 300/3000 psi. $99,383 CUM: $539,357 ETD: $0 EFC: $1,959,357 MW: 8.7 PV/YP: 9/13 APIWL: 9.4 DRILLING Test casing to 2000 psi for 30 min. OK. Drill cement, plug, FE and 10' new hole. Run LOT at 3729' Drill to 6581' $121,169 CUM: $660,526 ETD: $0 EFC: $2,080,526 MW: 9.0 PV/YP: 11/20 APIWL: 6.5 RUNNING INTERMEDIATE CASING Drill to 7208' Run 5-1/2" casing to 7120'. $150,923 CUM' $811,449 ETD' $0 EFC: $2,231,449 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Cement casing. CIP @ 1047 3/8/96. Instatl~pa'ckOff .and test to 30Q0 psi. Freeze protect annulus. Re~leased r'ig"@ 2000 hrs. 3/8/96. $112,418 CUM' $923,867 ETD' $.0 E~C: ..15.2,343,867 Date- 8/19/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 REMEDIAL AND COMPLETION OPERATIONS WELL'iF-18 RIG'PARKER 245 WELL ID' AK8461 AFC: AK8461 TYPE' STATE'ALASKA AREA/CNTY' NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/03/96 START COMP: BLOCK' FINAL: WI: 0% SECURITY:0 AFC EST/UL'$ 1420M/ 1700M API NUMBER: 50-029-22654-00 05/12/96 (10) TD: 7208' PB: 7126' SUPV:DEB DAILY: 05/13/96 (11) TD: 7208' PB: 7126' SUPV:DEB DAILY: 05/14/96 (12) TD: 7208' PB: 7126' SUPV:DEB DAILY: 05/15/96 (13) TD: 7208' PB: 7126' SUPV:DLW DAILY: 05/16/96 (14) TD: 7591' PB: 7199' SUPV:DLW DAILY. 05/17/96 (15) TD: 7939' PB: 0' SUPV: DLW DAILY: TESTING BOPE MW:12.0 LSND Move rig from 1F-19 to 1F-18. Accept rig @ 1800 hrs. 5/11/96. ND tree and NU BOPE. Function test. Test BOPE components. OK. $61,614 CUM: $1,047,095 ETD: $0 EFC: $2,467,095 RIH PU DP MW'll.8 LSND Finish testing BOPE. Test 5.5" casing to 3500 psi for 30 minutes, lost 150 psi, OK. $32,797 CUM: $1,112,689 ETD' $0 EFC: $2,532,689 POH LOOKING FRO PLUG IN D MW: 0.0 Tag bottom @ 7116' MD/PBTD. Test upper and lower kelly cocks to 250 psi/5000 psi. Attempt to circulate, no go. Work & surge pipe, no circulation. Break off & circulate through kelly, OK. Prepare to POH looking for ice plug. POH wet, looking for ice plug. Had ice in first 10 to 12 stands. Try to circulate every 10 stands. 35 stands out @ 0600 & tried circulating, still plugged. $33,432 CUM: $1,179,553 ETD: $0 EFC: $2,599,553 C/O CEMENT @ 7125' MW: 0.0 Circulate warm water to warm up hole @ 2000' Flow nipple leaking at pack off. Remove flow nipple and change packoff rubber. Continue to RIH w/BHA %1. $33,432 CUM: $1,246,417 ETD: $0 EFC: $2,666,417 DRILL AHEAD 4.75" HOLE @ MW:12.0 LSND Continue to C/O cement and float equipment from 7125' to 7199' Nordic. Drill 12' new 4.75" hole from 7199'-7211' Run FIT to 13.74 ppg EMW. Continue drilling 4.75" hole w/BHA %1 from 7211' to 7338' Had gas cut mud from drilling break from 7331' to 7334'. Mud cut to 10.5 ppg. Continue drilling ahead from 7338' to 7591' Continue to get connection gas & light gas cut while drilling. Raised mud weight from 11.8 ppg to 12.0 ppf. $38,174 CUM: $1,322,765 ETD: $0 EFC: $2,742,765 POOH FOR E-LOGS MW:12.5 LSND Continue drilling 4.75" hole from 7591' to 7939' Raised mud weight from 12 ppg to 12.5 ppg continue to get connection gas from 7330'. Circ and condition mud for E-logs. Short trip to 5.5" casing shoe @ 7199' and RIH. Hole in good condition. $36,443 CUM: $1,395,651 ETD: $0 EFC: $2,815,651 Date: 8/19/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 05/18/96 (16) TD: 7939' PB: 0' SUPV:DLW DAILY: 05/19/96 ( 17) TD: 7939' PB: 0' SUPV:DLW DAILY: 05/20/96 ( 18) TD: 7939' PB: 0' SUPV:DLW DAILY: 05/21/96 ( 19} TD: 7939' PB: 0' SUPV:DLW DAILY: 05/22/96 (20) TD: 7939' PB: 0' SUPV: DLW DAILY: 05/23/96 ( 21) TD: 7939' PB: 0' SUPV: DLW FISH FOR LOGGING TOOL MW:12.5 LSND Continue to POOH. R/U Schlumberger. Run (SGT/DITE) Stopped at 7770' Tool either stuck or line. Was pulling 8K with no indication of weight pull @ tool. Came free at rope socket. Top of tool at 7720' bottom @ 7770' POOH. RIH with fishing BHA to 7115' CBU at 5.5" casing shoe. Light gas cut mud. Wash down looking for logging tool fish. $46,206 CUM: $1,488,063 ETD: $0 EFC: $2,908,063 FISHING RIH W/OVERSHOT MW: 0.0 Continue to push Schlumberger tool to bottom. Top of tool at 7886' bottom 7935' work over top of fish. Had 200 psi increase in pump pressure. POOH coming wet. No fish. Rerun overshot on same BHA to 7850' Wash down to fish @ 7886'. Work over top of fish. Overshot coming off @ 150K, rotate over fish w/15K down overshot continues to come off @ 150k. POOH. Hole took 57 bbls over calculated hole fill on trip out. Run 4-9/16" overshot dressed w/3.35" grapple on same BHA. Will fish for 3-3/8" part of tool. $36,408 CUM: $1,560,879 ETD: $0 EFC: $2,980,879 POOH W/WASHOVER TOOL MW:12.5 LSND Continue to RIH w/4-9/16" overshot to 7850' Wash down to 7890' top of Schlumberger logging tool. Pull 6 stands maximum pull 200K swabbing hole. CBU. Gas cut mud. Weight cut to 11.6 ppg from 12.5 ppg. Continue to pull to 5.5" casing shoe @ 7199' Continue to POOH. No fish. Grapple control broke and fish did not into grapple. RIH w/overshot without grapple to wash over tool and clean junk from around tool. Wash from 7754' (gas and oil cut mud on bottoms up cut to 9.5 ppb) . Continue to wash down to 7894' washed over 4' of logging tool. Mud weight cut to 12.1 ppg. Raise mud weight back to 12.5 ppg. $38,292 CUM: $1,637,463 ETD: $0 EFC: $3,057,463 RIH W/BIT FOR CLEAN OUT MW:12.8 LSND Continue to POOH w/overshot w/out grapple used to wash over top of fish. RIH w/grapple to 7873'. CBU light gas cut mud. Work over top of Schlumberger logging tool at 7890'. Jar on fish @ 225k fish came free after 6 hits w/jars. POOH slowly, recover fish. Lost in hole fiberglass cover for G/R tool and rubber bull nose. RIH for clean out and to push any junk from Schlumberger logging tool fish to bottom. $36,620 CUM: $1,710,703 ETD: $0 EFC: $3,130,703 POOH FOR E-LOGS MW:12.8 LSND Continue RIH w/clean out BHA to 7873'. Wash and ream to bottom from 7893'-7935' POOH tight spot @ 7367' work pipe through 3 times. R/U Schlumberger run (SGT/DITE) log stopped 100' below shoe, Pulled 3600# to get free. POOH R/D Schlumberger. RIH clean out BHA. Tight @ 7399' Push junk or ball to 7872' Ream and to 7935' POOH. $34,807 CUM: $1,780,317 ETD: $0 EFC: $3,200,317 LOAD PIPE HOUSE W/3.5" TB MW:12.4 LSND Run (SGT/DITE) log, stopped @ 7368', hanging up @ 7320' coming up. POOH. Run 3.5" liner. Unable to work liner below 7922' Cement 3.5" liner. Set packer @ 6994'. CIP @ 0358 hrs. Date: 8/19/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 4 DAILY: 05/24/96 (22) TD: 7939' PB: 0' SUPV:DLW DAILY: 05/25/96 (23) TD: 7939' PB: 0' SUPV:DLW DAILY: $109,253 CUM: $1,998,823 ETD: $0 EFC: $3,418,823 POOH W/2-7/8" DP TO COMP MW: 0.0 UNKN Test 5.5" casing and 3.5" liner hanger to 3500 psi for 30 min. OK. $33,432 CUM: $2,065, 687 ETD: $0 EFC: $3,485,687 WELL COMPLETED @ 0400 HRS MW: 0.0 Continue to POOH and stand back 2-7/8" DP. Run 3.5" tubing with jewelry. Stab Baker anchor into Baker packer liner hanger @ 7000' tubing measurement. Shear PBR @ ll0k. Space out to land Baker seal assy 1 ft from fully inserted @ 6885' Reverse circulate tubing volume to remove any barite or pipe dope. Reverse in 42 diesel for freeze protection. Put tubing and annulus in communication and equalize back to balance for 2000' +/- TVD. Land tubing and run in LDS, test tubing to 3500 psi for 15 min., OK. Test annulus to 3500 psi for 15 min. OK. N/D BOPE. NU tree. Test packoff to 5000 psi, OK. Test tree to 250/5000 psi. OK. Secure well. Release rig @ 0400 hrs. 5/25/96. $125,773 CUM: $2,317,233 ETD: $0 EFC: $3,737,233 End of WellSummary for Well:AK8461 ii i i ~' · SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-75663 Sidetrack No. Page I of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING CO. -//245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1F/1F#18 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK. WELL DATA ,,, Target 'I'VD (FT) Target Coord. N/S Slot Coord. N/S -792.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSc Target Description Target Coord. E/W Slot Coord. F_JW -456.00 Magn. Declination 27.890 Calculation Method MINIMUM CURVATURE Target Direction (DP) Build~Walk\DL per: lOOft~ 30m~ lomr'l Vert. Sec. Azim. 7.64 Magn. to Map Corr. 27.890 Map North to: OTHER ..................... suRvE~"~ATA ...... Survey Survey incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'I'VD Section N(+) / S(-) E(+) ! W(-) DL Build (+) Right (+) Comment Type (F'r) (DB) (DD) (F'r) ~ gq') (F'r). (Per m0 Fr) Drop (-) Left (-) MWD 0,00 0.00 0,00 0.00 0,00 0.00 0.00 TIE IN POINT ,, -. 03-MAR-96 MWD 121.00 0.00 0.00 121,00 121.00 0.00 0.00 0.130 0.00 0,00 8'MACH 1C-AKO-1.4deg, - 03-MAR-96 MWD 366.43 1.68 88.99 245.43 366.39 0.54 0.06 3.60 0.68 0.68 03-MAR-96 MWD 463.39 1.20 65.75 96.96 463.32 1.29 0.51 5.94 0.77 -0.50 03-MAR-96 MWD 556.88 2.06 294.64 93.49 556.80 2.31 1.61 5.31 3.19 0.92 03-MAR-96 MWD 649.60 5.38 284.06 92.72 649.31 3.28 3.37 -0.42 3.64 3.58 -11.63 ,,, 03-MAR-96 MWD 738.06 7.58 282.75 88.46 737.20 4.27 5.67 -10.13 2.49 2.49 -1.48 03-MAR-98 MWD 833.53 9.62 281.90 95.47 831.59 5.42 8.70 -24.08 2.14 2.14 -0.89 03-MAR-96 MWD 925.59 11.99 283.68 92.06 922.01 7.00 12.55 -40.90 2.60 2.57 1.93 03-MAR-96 MWD 1015.51 13.00 283.97 89.92 1009.79 9.10 17.21 -59.82 1.17 1.17 0.32 ., 03-MAR-96 MWD 1106.72 14.85 281.69 91.21 1098.31 11.06 22.06 -81.26 2.07 1.98 -2.50 · _ 03-MAR-96 MWD 1200.33 16.07 284.68 93.61 1188.53 13.50 27.77 -105.54 1.56 1.30 3.19 03-MAR-96 MWD 1289.38 16.36 301.97 89.05 1274.09 20.18 37.54 -128.11 5.41 0.33 19.42 ., 03-MAR-96 MWD 1382.92 16.07 309.79 93.54 1363.92 32.50 52.81 -149.24 2.35 -0.31 8.36 03-MAR-98 MWD 1472.47 15.79 314.86 89.55 1450.00 46.46 69.33 -167.40 1.58 -0.31 5.66 03-MAR-96 MWD 1 565.61 16.58 308.96 93.14 1539.49 61.00 86.63 -186.72 1.96 0.85 -6.33 03-MAR-96 MWD 1660.19 16.68 306.25 94.56 1630.12 74.55 103.14 -208.16 0.83 0.11 -2.87 , . 03-MAR-96 MWD 1751.67 15.93 313.06 91.48 1717.92 68.11 119.48 -227.92 2.24 -0.82 7.44 .,. 03-MAR-96 MWD 1642.77 15.60 317.27 91.10 1805.60 103.17 137.01 -245.38 1.31 -0.38 4.62 03-MAR-96 MWD 1935.65 15.50 321.82 92.88 1895.08 119.79 1 55.94 -281.51 1.32 -0.11 4.90 03-MAR-96 MWD 2030.39 17.16 330.21 94.74 1986.01 139.71 178.03 -276.28 3.04 1.75 8.86 03-MAR-96 MWD 2124.24 19.55 342.33 93.85 2075.11 1 64.92 205.02 -287.93 4.79 2.55 12.91 03-MAR-96 MWD 2218.64 22.47 352.75 94.40 21 63.26 196.65 237.98 -295.01 5.01 3.09 11.04 ,, 00-MAR-96 MWD 2310.71 24.50 357.28 92.07 2247.71 232.44 274.51 -298.13 2.95 2.20 4.92 .---- ii i i i i i i mil i m ii i i i ii i i i~ i ii i ii i i ii i SURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0450-75663 Sidetrack No. Page 2 of 2 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILMNG CO. - #245 Field KUPARUK RIVER UNIT Well Name & No. PAD 1F/1 F#18 Survey Section Name ANADRILL BHI Rep. CHIP MILCHAK. WELL DATA , , Target TVD p'T) Target Coord. N/S Slot Coord. N/S -792.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~ Target Description Target Coord. F_JW Slot Coord. E/W -456.00 Magn. Declination 27.890 Calculation Method MINIMUM CURVATURE Target Direction (DO) Buil~Wall~DL per: lOOftl~ 30ml-I lOmi-I VerL Sec. Azim. 7.64 Magn. to Map Corr. 27.890 Map North to: OTHER SURVEY DATA .,, Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date TypeT°°l Depth Angle Direction Length TVD Section N(+) I S(-) E(+) /W(-)' DL BuildDrop (+)(-)RightLeft (+) Comment (-) 04-MAR-96 MWD 2399.74 26.61 0.38 89.03 2326.02 270.38 312.89 -298.88 2.81 2.37 3.48 8"MACH lC-AKO-1.4deg. 04-MAR-96 MWD 2493.11 28.85 3.71 93.3~ 2410.67 313.60 356.29 -297.28 2.92 2.40 3.57 04-MAR-96 MWD 2584.48 31.21 6.44 91.37 2489.77 359.27 401.82 -293.20 2.98 2.58 2,99 ..... 04-MAR-96 MWD 2678.35 34.46 7.27 93.87 2568.64 410.16 452.35 -287.11 3.50 3.46 0.88 04-MAR-96 MWD 2768.48 36.63 10.97 90.13 2641.98 462.51 504.05 -278.76 3.39 2.41 4.11 04-MAR-96 MWD 2860.27 38.46 14.40 91.79 2714.76 518.21 558.59 -266.45 3.03 1.99 3.74 04-MAR-96 MWD 3045.95 42.14 11.09 185.68 2856.38 637.78 675.70 -240.10 2.29 1.98 -1.78 04-MAR-96 MWD 3320.05 43.49 14.76 274.10 3057.46 823.20 857.18 -1 98.37 1.03 0.49 1.34 _ , , 04-MAR-96 MWD 3689,93 44.38 15.67 369.88 3323.82 1077.59 1104.81 -131.01 0.30 0.24 0.25 04-MAR-96 MWD 3967.39 43.23 15.46 277.46 3524.05 1267.81 1289.82 -79.47 0.42 -0.41 -0.08 04-MAR-96 MWD 4178.45 44.73 15.49 211.06 3675.93 1413.00 1 431.07 -40.36 0.71 0.71 0.01 06-MAR-98 MWD 4410.70 43.80 14.50 232.25 3842.25 1573.76 1587.65 1.59 0.50 -0.40 -0.43 4 3/4'MACH lXL-1.2-AKO -- 06-MAR-96 MWD 4680.30 44.70 16.60 269.60 4035.37 1760.07 1768.85 52.04 0.64 0.33 0.78 .. 06-MAR-96 MWD 4957.60 44.40 13.10 277.30 4233.02 1953.00 1956.63 101.90 0.89 -0.11 -1.26 ?.i ~ - 06-MAR-98 MWD 5237.10 42.10 17.30 279.50 4436.62 2142.77 2141.58 151.94 1.32 -0.82 1.50 . 06-MAR-96 MWD 5512.00 41.80 11.30 274.90 4641.1 6 2325.11 2319.47 197.31 1.46 -0.11 -2.18 ' · 06-MAR-96 MWD 5788.00 39.10 19.40 276.00 4851.31 2502.27 2491.91 244.29 2.14 -0.98 2.93 , . 07-MAR-96 MWD 6067.20 39.70 13.10 279.20 ,5067.15 2677.31 2661.88 293.76 1.45 0.21 -2.26 07-MAR-96 MWD 6341.00 37.30 21.00 273.80 52.81.54 2845.20 2824.62 343.35 2.00 -0.68 2.89 07-MAR-96 MWD 6618.70 41,20 18.00 277,70 6498.57 3017,11 2990.24 401.79 1,56 1.40 -1.08 07-MAR-96 MWD 6895,60 40.55 16.24 276.90 5705,95 3195,63 31 63.40 455,15 0.48 -0.23 -0.64 07-MAR-96 MWD .. 7141,77 41,85 13.45 246,17 5891,18 3356.66 3320.10 498.68 0.91 0.53 -1,12 07-MAR-96 MWD -~208.00 41.85 13.48 66.23 5940.52 3400.62 ~ 3363.07 "~ 506.98 0.03 0.03 0.00 CLO DIST=3401'AZI=8.57 7~., OFe~ l l~, ~ -- KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1F-18(W4-6)) 1F-18 DATE 06/30/96 DAY 1 DAILY JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0607961832.7 DAILY WORK UNIT NUMBER PERFORATE A SANDS OPERATION COMPLETE [ SUCCESSFUL [ KEY PERSON SUPERVISOR NO YES SWS-S ITTON GOLDEN Initial'J'bgeress IFinalTbgPress I-initiallnnerAnn IFinallnnerAnn IlnitialOuterAnn IFinalOuterAnn 0 PSI 1600 PSI 0 PSI 0 PSI 400 PSI 400 PSI SUMMARY PERFORATED A SANDS F/7585'-7620' (4 SPF, 180 DEG PHASING, 20 DEG CCW F/HIGH SIDE OF HOLE). UNABLE TO PULL GUN #2 OUT OF HOLE AFIER FIRING. RD F/SLICKLINE FISHING. TIME LOG ENTRY 20: 00 MIRU SWS E-LINE & HOT OIL DHP. TGSM: PERFORATING AROUND RIG AND CONSTRUCTION ACTIV1TY.I~I' TO 3000 PSI. 20:40 RIH W/HEAD, CCL, 20' 2-1/2" HOLLOW CASE CARRIER(4 SPF, 180 DEG PHASING, BIG HOLE CHARGES, 20 DEG CCW F/ HIGH SIDE OF HOLE)TIED INTO BOND LOC, DATED 6/29/96. PERFORATED 7600'-7620'.WHP (BEFORE) = 1600 PSI, WHP (AFTER') = 1600 PSI.UNABLE TO I~OH. PULLED 1300~ OVER NORMAL-BROKE FREE. CONTINUED OOH. ASF. 23:15 RIH W/HEAD, CCL, 15' 2-1/2" HOLLOW CASE CARRIER(SAME SPEC. AS ABOVE). TIED INTO BOND LOG. PERFORATED 7585'-7600'.WHP (BEFORE)=1600 PSI, WHP (AFTER) = 1600 PSI.UNABLE TO POOH. GRADUALLY WORKED UP TO 40(X)~ (2700~ ABOVE NORMALY PULLED OUT OF HEAD. DIAGRAM OF FISH IN WELL FILE. 01' 15 RD SWS. PUMPED 5 BBLS DSL IX)WN WELL AT 1/8 BPM. 2500 PSI TO ENSURE DSL CAP.RD HOT OIL. 9/19/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10409 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 q(.,,- o'-t'-I Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date Bi_ RF Sepia DIR MWD Tape 1 F-17 ~/~G ~- 96237 SLIM1-GR MWD 960309 1 ....... 1 F-18 '-/~/~ L~ 96238 SLIM1-GR MWD 960307 1 ,, ,, SIGNED: _~-~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date: July 16, 1996 Transmittal #: 9723 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATe-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 F- 17 06/29/96 6050-6748 1 F- 18 06/29/96 7794-7799 1Q-02A 06/26/96 7900-8680 2M-09A 06/30/96 4900-9292 Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Receipt ~ ~)~ Acknowledge' DISTRIBUTION' RECEIVED Date' ,JUL i 8 1996 Sharon AIIsup-Drake DS Development ATe-1205 Larry.Graht (+Sepia) ~ AC)GCC 3001 Porcupine Drive Anchorage, AK 99501 Chapman/Zuspan NSK Wells Group NSK69 ARCO Alaska, Inc. Post Office 8ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 15, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Permit to Drill for KRU Well 1F-18 Dear Mr. Johnston: The permit to drill application for KRU 1F-18 is being submitted to cover both Parker Rig 245 and Nordic Rig I drilling operations. Parker 245 will drill and set surface and intermediate casing, while Nordic I will drill and set the production liner. Please also note that the request for approval of annular pumping operations has been adjusted slightly from previous applications to reflect the latest version of the AOGCC draft annular pumping regulations, 20 AAC 25.080. The request also covers Nordic 1 proposed operations when on DS 1F. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Mike~. n~ Drill SikeMOevelopment Supervisor A g;:tvED FEB 1 6 1~6 Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 16, 1996 Michael Zanghi, Ddil Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 ':" ' :~?~. ~ . ,. Re: Kuparuk River Unit 1F-18 - . ARCO Alaska, Inc. "' Permit No 96-039 Surf Loc. 777'FNL, 459'FEL, Sec. 19, T11N, R10E, UM Btmhole Loc. 2219'FNL, 87'FWL,. Sec.-.17, T11N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to ddll does not exempt you from obtaining.additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. DaviO W. d~xnston Chairman BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSk.~N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D 1 b Type of Well Exploratory r'-I Stratigraphic Test E] Development Oil X Re-Entry r-I Deepen D Service [~ Develop mentGas ~'1 Single Zone X aultipleZone [~] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 68' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25652, ALK 2578 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.O25) 777' FNL, 459' FEL, Sec. 19, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2436' FNL, 32' FWL, Sec. 17, T11N, R10E, UM 1F-18 #U-630610 At total depth 9. Approximate spud date Amount 2219' FNL, 87' FWL, Sec. 17, T11N, R10E, UM 2/21/96 $200r000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) property line 1 F-09 7971' MD 2219 @ TD feet 80.7'@ 1294' feet 2480 6485' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 650' feet Maximum hole angle 42.7° Maximum surface 2199 pslg At total depth (TVD) 3900 pslg 18. Casing program Settir~l Depth size Specifications Top Bottom Quanlit)/of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD 'I-VD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+_200 CF 9.875' 7.625" 29.7# L-80 LTC 4185' 41' 41' 4226' 3714' 710 Sx Arcticset III & 330 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMod 721 6' 41' 41' 7257' 5941' 70SxClassG Top 500' above cs~] shoe 4.75' 3.5" 9.3# L-80 BTCMod 864' 71 07' 5830' 7971' 6485' 50SxClassG Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) lrue vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner FF_. 1 6 Perforation depth: measured true vedical J~askEt Oil & Gas Cons. Commission An~ora.qe 20. Attachments Filing fee X Property plat [~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis ~-I Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the forl~going is true and correct to the best of my knowledge Signed ~jl~./'~_~ ,,t,e Drill Site Develop. Supv. Date · ~',/ i?'~ Commission Use On~ Permit N_umber ['APl number _ ~- ..-. /., I Approval dater /.., ~ See cover letter for I I°therroquiromonts ConditiOns of approval Samples required I-] Yes ~ No Mud log r~quired [-'] Yes [~ No Hydrogen sulfide measures [] Yes F'~ No Directional survey required 1~ Yes ~--I No Required working pressure for BOPE r"] 2M [-~ 3M [] 5M r"] 1OM ~] 15M Other: DavidOrigina!\N.S;gnadjohnstonDY by order of 'Z. / Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 iDlicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 1F-18 o , , e , . o . , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,226')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test 7-5/8" casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to approximately 100' TVD above the Top Kuparuk (7,257') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE to 5000 psi (annular to 3000 psi). casing to 3500 psi. FEB 1 6 .~a,ska Oil & 6as Cons. Commission Anchorege Pressure test 5-1/2" Drill out cement and 10' of new hole. Perform leak off test to 13.5 ppg EMW. Drill 4-3/4" hole to total depth (7,971') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 3-1/2" liner. Set liner-top packer/hanger with polished seal bore. Run completion assembly. Sting seal assembly into polished bore and pressure test tubing and annulus ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. DRILLING FLUID PROGRAM Well KRU 1F-18 Density PV YP Viscosity Initial Gel 10 Minute Gel AP! Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 __.10% Drill out to intermediate casing 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drill out to liner TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators vED FEB 1 6 1~6 oil & Gas Cons, Commissior,. Anchorage General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure while Parker 245 drills the intermediate hole is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,199 psi could be reached. ARCO Alaska, Inc. will test the Parker BOP equipment to 3000 psi. Maximum anticipated surface pressure while Nordic 1 drills the production hole is calculated using an intermediate casing leak-off of 14.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur when a surface pressure of 3,826 psi is reached. ARCO Alaska, Inc. will test the Nordic BOP equipment to 5000 psi. The nearest existing well to 1F-18 is 1F-09. As designed, the minimum distance between the two wells would be 80.7' @ 1294' MD. Drilling Area Risks: The 1F-18 area is marked by very high reservoir pressures with little or no opportunity for reduction prior to drilling. For this reason Parker 245 will drill and set surface and intermediate casing only, with the intermediate, shoe +100' TVD above the top Kuparuk. For cost reasons, Nordic 1 will move over the well later and drill out to TD, set and cement a liner, and run the 3-1/2" completion. There is very little risk of lost circulation with this casing design, and the offset wells indicate 12.5 ppg mud will be sufficient to safely drill, trip pipe and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. The 5-1/2" casing shoe will be tested to an equivalent mud weight of 13.5 ppg upon drilling out of the intermediate casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS Well KRU 1F-18 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1F-18 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. When Nordic 1 drills out of the intermediate casing to TD, their drilling solids will be hauled to CC-2A. Drilling waste fluids will be hauled to the nearest permitted disposal well, or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. It is requested that 1 F-18 be permitted for annular pumping occurring as a result of the drilling project on DS 1F, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 1F surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi 1 F- 18 Max Pressure = 3818 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 5857 5.500 15.5 L-80 3 LTC-M 4990 4 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 1 F 18 stol #18 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes [NTEQ Your ret : 18 Version ~6 Our ret : prop1467 License : Date printed : 14-Feb-96 Date created : 29-Nov-95 Last revised : 14-Feb-96 1 6 Ai~ska Oil & Gas Cons, Cornl~issio~ Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 40 34.63 Slot location is nTO 17 53.674,w149 40 48.010 Slot Grid coordinates are N 5958748.171, E 539514.603 Stol local coordinates are 777.00 S 459.00 W Reference North is True North Main calculation performed with 3-D MinimumDistance method Object wettpath PGMS <O-6712'>,,3,Pad 1F PGMS <O-9175'>,,16,Pad 1F PGMS <O-6832'>,,15,Pad 1F PGMS <O-8160'>,,14,Pad 1F PGMS <O-8235'>,,13,Pad 1F PGMS <O-6840'>,,12,Pad 1F PGMS <O-8787'>,,11,Pad 1F PGMS <O-7680'>,,lO,Pad 1F PGMS <O-7600'>,,9,Pad 1F PC~S <O-7492'>,,8,Pad 1F PMSS <O-?681'>,,7,Pad 1F GMS <O-9837'>,,6,Pad 1F PC, MS <O-7710'>,,5,Pad 1F PGMS <O-8002'>,,4,Pad 1F PGMS <O-8085'>,,2,Pad 1F PGMS <O-8715'>,,1,Pad 1F 1F-L Version #4,,1F-L,Pad 1F 1F-D Version ~r3,,1F-D,Pad 1F 1F-B Version #3,,1F-B,Pad 1F Ctosest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 4-Aug-92 625.2 700.0 700.0 4-Aug-92 409.8 60.0 120.0 4-Aug-92 433.8 650.0 5160.0 4-Aug-92 467.5 60.0 7860.0 4-Aug-92 501.3 580.0 7970.9 4-Aug-92 327.0 520.0 520.0 4-Aug-92 269.1 400.0 400.0 4-Aug-92 135.1 1875.0 1875.0 4-Aug-92 80.7 1294.4 1294.4 4-Aug-92 842.6 0.0 7860.0 4-Aug-92 737.6 650.0 650.0 4-Aug-92 63?.8 300.0 300.0 4-Aug-92 547.8 0.0 0.0 4-Aug-92 748.0 700.0 700.0 4-Aug-92 442.5 2000.0 2000.0 4-~ug-92 224.2 1481.3 1481.3 12-Feb-96 381.5 650.0 7202.0 12-Feb-96 15.3 480.0 480.0 12oFeb-96 385.5 650.0 650.0 ~Created by : jones For: D PETRASH Date plotted : 14-Feb-96 iPIot Reference is 18 Version #6. ',Coordinates are in feet reference slot #18. iTrue Vedical Depths are reference Estimated RKB. I I I V ARCO ALASKA, Inc. Structure : Pad 1F Well : 18 : Field : Kuparuk River Unit Location : Horth Slope, Alaska i 400 °l 400 _ 800 _ -- 1200. 1600_ 2000 2400_ 2800_ _ 3200_ _ 3600~ 4000 4400_ 4800 5200. 5600. 6000, 6400_ 6800d N 7.72 DEG E 3654' (TO TARGET) ***Plane of Proposal*** ES'I1MATED RKB ELEVATION: 109' ID LOCATION: 2219' FNL, 87' FWL SEC. 17, T11N. RIOE 600 300 I ! I 4O0 0 400 Scale 1 ' 200.00 Eas 0 Base Kup Sands TARGET - T~ Unit A Top Unit B Top Kuporuk (EO0) Begin Angle Orol~ 300 I I --> 600 1 TARGET LOCATION: 2436' FNL. 32' FWL KOP TVD=650 TMD=650 DEP=O 5.00 SEC. 17, TllN, RIOE 6.0O TARGET 9.00 3 DEG / lOO' DLS WD=6218 ~2.0O TMD=7622 15.00 DEP=3654 NORTH 3621 18.00BEGIN TURN TO TARGET TVD=1303 TMD=1317 DEP=-15 E~ST...4__91- ,.~ · ~ 18.92 ~- ~' ' "' V 17.10 16.91 T 17.2`5 2~.84 22.70 24.77 27.00 Naska Oil & Gas Cons. commission 29.37 · 31.~ fi~chofage 34..57 36.97 39.62 Colville 42.30 F'OC TVD=2518 TMD=3007 DEP=555 / W SAK SNDS TVD=3040 TMD=3309 DEP=757 Bose Colville HRZ Midpoint ., B/ W SAK SNDS TVD=5514 TMD=3954 DEP=1192 7 5/8" CSG PT TVD=5714 TMD=4226 DEP=1375 . T/ COLVILLE TVD=5955 TMD=4524 DEP=1576 MAXIMUM ANGLE 42.73 DEG x~ ESTIMATED SURFACE LOCATION: 588~ 777' FELL, 459' I~L 8/ COLVILLE TVD=5036 TMD=6026 DEP=2 SEC. 19. T11N, RIOE 'x ..,.~,~HRZ MIDPOINT TVD=5745 TMD=6991 OEP=3239 ............. %%2'4.~_BEGIN ANGLE DROP TVD=5941 TMD=7257 DEP=3419 MARKER TVD=5965 TMu---/z',.JU L)r,..l'"=O~'q'l z uu ~ T .................... ~1~% · / KUPARUK (EOD) TVD=6045 TMD=7594 DEP=3508 K-lTl UNIT C IYU--OUJ/ .~u=/.~u~ ucr=oo,o ,~, T/ UNIT B TVD=6107 TMD=7477 OEP=3562 TARGET - T/ UNIT A TVD=6218 TMD=7622 DEP=3654 B~// UNIT A4 TVD=6244 TM0=7656 DEP=3676 KUP SNDS TVD=6332 TMD=7771 0EP=3749 TD TVD=6485 TMD=797t DEP=3877 3'lz L tN,~'1Z, 800 ! 200 1600 2000 2400 2800 3200 3600 4000 Vertical Section on 7.72 azimuth with reference 0.00 N, 0.00 E from slot #15 B 5/8 Casing Pt DSC West Sok Sands Top West Sak Sands IEOC ¢o,;- ,,o 900 I 4200 _3900 _3600 _ _3300 _5000 _ _2700 _ _2400 _ _2100 _ _1800 _1500 ~200 900 _ 600 _ f300 0 300 TARGET ANGLE 40 DEG A I I Z O iCreoted by : jones For: D PETRASH !Date plotted : 14-Feb-96 iPIot Reference is 18 Version #6. Coordlnotes are in feet reference slot #18. iTrue Vertical Depths are reference Estimated RKB.! A I I ARCO ALASKA, Inc. Structure : Pad 1F Well : 18 Field : Kuparuk River Unit Location : Nodh Slope, Alaska <7 W e s f ~o,~ ~ · :o.oo 400 560 320 280 240 200 160 120 80 40 0 40 80 120 160 680 I I I I I I I ! I I I I I I I I I I I I I I I I I I I I I 680 _.o ~ / \ 2oo _440 / ~~°° ~ ~oo~ I 4o / ] ~ _.___j ~oo Vo Oo %00050000 I I I i I I I I I t i I I I I I '1 r- I I I I I I I I I l 400 360 320 280 2~ 200 160 120 80 40 0 40 80 120 160 iCreoted by : jones For: D PETRASH 1Dote plotted : 14-Feb-96 Plot Reference is 18 Version ~6. {Coordinates ore in feet reference slot True Vertical Depths ore reference Est:imoted RKB. : 520 1240t 1200l 1160_ _ 1120_ 1080_ 480 440 400 I I I ! A I I 1040_ _ 1000_ _ 960 _ _ 920 _ _ 88,0 _ 840 80O 760 720 _ 680 _ 640 _ 600 ~ 560 1 520 k i I I 480 440 ARCO ALASKA, Inc. Structure : Pad 1F Well : 18 Field : Kuporuk River Unit Location : Horth Slope, Alosko l 4700 k X4600 \ < West ,360 ,320 280 240 200 160 t 20 80 /3400 250O / \ / ~0 / 2900 t I I I I ti i I 400 360 320 280 240 < 40 0 I I I Scole 1 ' 20.00 40 8O %1160 _1120 _1080 1040 FEB 1 6 1996 A~aska Oil & O~s Cons. commission Anchorage ,5800 \ \ I f 80 40 1000 960 ~920 -- _ 880 _ _ 84O _ _ 800 _ _ 760 5cole 1 ' 20.00 4200 k, 4,oo 2200 -- .. I I I I I 200 160 120 West 72O 680 640 600 _ _ 560 A I I Z O KdPARUK RIVER UNI~ 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 2. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASK~ INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16' OU~..LET. 5. ONE 16" HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20' - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 7 ,6 , 5 4 I3 i2 13 5/8" 5000 PSI clOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND Fill ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. & OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. 16" - 2000 PSI STARTING HEAD 2. 11"- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5,~" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM WI PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 1 3-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. Fill BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST All COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE BoTroM PIPE RAMS. TEST BoTrOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUll OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3o00 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACC, OMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 7-1/16" 5000 PSi BOP STACK ACCUMULATOR CAPACITY TEST l~ANNULAR ~ PREVENTER J I I --] t ~ ]CROSS 4 · 3 PIPE RAM > (,2) 1.11 "- 3000 PSI CASING HEAD 2.11'- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 50OOPSl SINGLE GATE W/PIPE RAMS 4. 7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THATTEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRIllING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. .o .o 1996 ~aska Oil & Gas Cons, Anchr~ _IST GEOL AREA IS* PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg [] ON/OFF SHORE ~ ~ attached .................. N Der appropriate ............... N 11 name and number .............. N ted in a defined pool ............. N ted proper distance from drlg unit boundary. . N ted proper distance from other wells ..... N .t acreage available in drilling unit ..... N .ed, is wellbore plat included ........ N only affected party .............. N has appropriate bond in force ........ N .n be issued without conservation order .... N .n be issued without administrative approval. N t be approved before 15-day wait ....... N REMARKS string provided ............... ~ N :asing protects all known USDWs ........ ~ N .dequate to circulate on conductor & surf cng.~_~ N ~dequate to tie-in long string to surf cng . . ._.Y ~ cover all known productive horizons ...... ~signs adequate for C, T, B & permafrost .... tankage or reserve pit ............ N Arill, has a 10-403 for abndnmnt been approved. wellbore separation proposed ......... ~ N ~er required, is it adequate .......... iS~ N fluid program schematic & equip list adequate N :quate .................... N ;s rating adequate; test to 5(~7-~~-~ psig.~ N lifold complies w/API RP-53 (May 84) ...... i occur without operation shutdown ....... ~ N ~ce of H2S gas probable ............ ~ N ~n be issued w/o hydrogen sulfide measures .... Y N ~ented on potential overpressure zones ..... Y y ~ / W~ ~nalysis of shallow gas zones .......... ~ndition survey (if off-shore) ........ ~/~ N ~ame/phone for weekly progress reports . . . ./. Y N [exploratory only] ENGINEERING: COMMISSION: Comments/Instructions: Z O Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the. history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ****************************** , ....... SCHLUMBERGER . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1F- 18 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE .. ALASKA API NUMBER : 50-029-22654-00 REFERENCE NO : 96238 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/09/16 ORIGIN : FLIC REEL NAME : 96238 CONTINUATION # : PREVIOUS REEL : COB~mVT : ARCO ALASKA INC., KUPARUK 1F-18, API #50-029-22654-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/09/16 ORIGIN . FLIC TAPE NABiE : 96238 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC., KUPARUK 1F-18, API #50-029-22654-00 TAPE HEADER KUPAR UK MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL '. FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 1F-18 500292265400 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 6-SEP-96 BIT RUN 1 96238 KADRMAS WHITLOCK BIT RUN 2 BIT RUN 3 19 liN iOE 792 456 117.00 117.00 75.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4253.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 3RD STRING PRODUCTION STRING REMARKS: SLIM1 GR data that includes interpolation processed at AK ICS. No depth shifting done as per Dave Shafer. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE '. FLIC VERSION : O01CO1 DATE : 96/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED ~I~RGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O . 5000 FILE SUM~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 4265.0 7208.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (NIEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: Edited SLIM1 GR data including interpolation processed at AK ICS. No depth shifting was done as per Dave Shafer. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT NA O0 000 O0 0 1 1 1 4 68 0000000000 GRRW SLWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 GRIN SLWD AAPI NA O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHRNA O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 7208.000 GRRW. SLWD -999.250 GRIN. SLWD -999.250 ROP.MWD DEPT. 7000.000 GRRW. SLWD -999.250 GRIN. SLWD 420.000 ROP.MWD DEPT. 6000.000 GRRW. SLWD -999.250 GRIN. SLWD 287.273 ROP.MWD DEPT. 5000.000 GRRW. SLWD -999.250 GRIN. SLWD 211.600 ROP.MWD DEPT. 4265.000 GRRW. SLWD -999.250 GRIN. SLWD -999.250 ROP.MWD 46.033 125.800 208.900 317.900 145.500 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIFiBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREmeNT: O. 5000 FILE SU~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH 4265.0 7208.0 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~V~ RAY $ 07-MAR-96 5.3B 5.5 REAL - TIME 7208.0 4265.0 7208.0 70 41.8 44.7 TOOL NUMBER SLIMi-O13 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) '. FLUID LOSS (C3): RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) MUD AT ~IEASURED TEMPERATURE (MT) MUD AT MAX CIRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE~!ARKS: Raw SLIM1 MWD data. $ LIS FORMAT DATA 6. 750 4253.0 FRESH 9.10 40.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT NA O0 000 O0 0 2 1 1 4 68 0000000000 GR RAW CPS NA O0 000 O0 0 2 1 1 4 68 0000000000 GR MWD AAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 GR INT AAPI NA O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD F/H_RNA O0 000 O0 0 2 1 1 4 68 0000000000 ROPSMWD F/HRNA O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 INT F/HR NA O0 000 O0 0 2 1 1 4 68 0000000000 VDEPMWD FT NA O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 7208.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT -999.250 ROP.MWD 3710.200 ROPS.MWD -999.250 ROPS.INT 46.033 VDEP.MWD 5940.101 DEPT. ROP.MWD 7000.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT 420.000 134.100 ROPS.MWD 125.800 ROPS.INT 125.800 VDEP.MWD 5791.601 DEPT. ROP. MWD 6000.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT 287.273 202.600 ROP5.MWD 208.900 ROPS.INT 208.900 VDEP.MWD 5015.200 DEPT. ROP.MWD 5000.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT 211.600 339.200 ROPS.MWD 317.900 ROPS.INT 317.900 VDEP.MWD 4263.900 DEPT. ROP. MWD 4265.000 CR.RAW -999.250 GR.MWD -999.250 GR.INT -999.250 105.100 ROPS.MWD 145.500 ROPS.INT 145.500 VDEP.MWD 3737.900 ** END OF DATA ** **** FILE TRAILER **** FILE NAFZE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/09/16 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 16-SEP-1996 08:19 PAGE: **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE · 96/09/16 ORIGIN · ?LIC TAPE NAME : 96238 CONTINUATION # : 1 PREVIOUS TAPE COf4~_2TT : ARCO ALASKA INC., KUPARUK 1F-18, API #$0-029-22654400 **** REEL TRAILER **** SERVICE NA~IE : EDIT DATE : 96/09/16 ORIGIN : FLIC REEL NAM~ : 96238 CONTINUATION # : PREVIOUS REEL : COf~_2~T : ARCO ALASKA INC., KUPARUK 1F-18, API #50-029-22654-00