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Home My WebLink About195-194Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~-/~)~/' File Number of Well History File PAGES TO DELETE 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: Bevedy Dianna~ Nathan Lowell TO RE-SCAN Date: Notes: Re-Scanned by: Begedy Dianna Vincent Nathan Lowell Date: Is~ RECEIVED J STATE OF ALASKA ) ALASKA ·IL AND GAS CONSERVATION COMMISSION FEB 0 2 2006 WELL COMPLETION OR RECOMPLETION REPORT AND ~g~a Oil & Gas Cons. Commission Anchorage J 1 a. Well Status: 0 Oil 0 Gas 0 Plugged 181 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: clo P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 12061 FNL, 1175' FEL, SEC. 26, T12N, R09E, UM Top of Productive Horizon: 5081 FSL,2623'FEL, SEC. 24,T12N, R09E, UM Total Depth: 5071 FSL,2019'FEL, SEC. 24,T12N, R09E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528448 y- _ 598~667 _ Zone- ASP4 TPI: x- 532271 y- 5986396 Zone- ASP4 Total Depth: x- 532876 y- 5986398 Zone- ASP4 ..----.---.---------------- ------------------------- ----------.-------.--- 18. Directional Survey 0 Yes 181 No 21. Logs Run: GR I CBl 22. Zero Other 5. Date Comp., Susp., or Aband. 10/24/2005 ,.- 6. Date Spudded 01/03/1996 7. Date T.D. Reached 01/20/1996 8. KB Elevation (ft): 78' 9. Plug Back Depth (MD+ TVD) 8720 + 6633 10. Total Depth (MD+ TVD) 9017 + 6826 11. Depth where SSSV set NIA MD 19. Water depth, if offshore NI A MSL CASING SIZE 16" 9-5/8" GRADE H-40 J-55 J-55 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MO SETTING DEPTH TVO HOLE lOP I::JOTTOM ·1 OP ~OTTOM SIZE Surface 1001 Surface 100' 24" Surface 38301 Surface 3517' 12-1/4" Surface 6268' Surface 52051 8-1/2" 6055' 9010' 50551 68221 6-1/8" WT. PER FT. 62.5# 36# 26# 12.6# 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD 5tANNED fEB ~ 6 2005 26. Date First Production: Not on Injection Date of Test Hours Tested 24. SIZE 4-1/2", 12.75#, L-80 TVD 1 b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 195-194 305-287 13. API Number 50- 029-21248-01-00 14. Well Name and Number: Kuparuk 1Q-02A 15. Field I Pool(s): Kuparuk River Unit 1 Kuparuk River Pool Ft Ft 16. Property Designation: ADL 025634 17. Land Use Permit: 20. Thickness of Permafrost 13801 (Approx.) CEMENTING RECORD 240 sx Coldset II 1000 sx Coldset III, 420 sx CS I 550 sx Class IG', 250 sx CS I 113 sx Class IG' AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6061' PACKER SET (MD) 60611 25. ACID, FRACTURE,CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 85451 - 8555' Shot Cement Squeeze Perfs, 2-1/2" HSD Gun, 6 spf 8688' P&A wI 10 Bbls Behind Pipe 85391 Set Whipstock PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl Press. 24-HoUR RATE GAs-McF W ATER-BBl CHOKE SIZE GAS-Oil RATIO GAs-McF W ATER-BBl Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". AbL I:1.d6l'\~1 RBDMS BFl FEB 0 6 2006 None Form 10-407 Revised 12/2003 '0 ~.< ¡ G i t~cAT~ED ON REVERSE SIDE /Ó.2.¡·6~ A- (;. 28. ) GEOLOGIC MARKERS 29. ) FORMATION TESTS Include and briefly summarize test results. List Intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Top Kuparuk C 82251 6315' None Bottom Kuparuk C 8405' 6429' Top Kuparuk A 8640' 6581' Bottom Kuparuk A 8812' 66931 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 ----(QNIÙ _ ~~ Kuparuk 1 Q-02A 195-194 305-287 Well Number Title Technical Assistant Date Oajoa./D<- Permit No.1 Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Aras Worthington, 265-6802 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only ) ) Well: Field: API: Permit: 1 Q-02B & 1 Q-02BL 1 Kuparuk River Unit 50-029-21248-02-00 & 50-029-21248-60-00 205-142 & 205-186 Accept: Spud: Release: Rig: 11 106105 11 108105 11127/05 Nordic #2 PRE-RIG WORK 09/18/05 MITIA -PASSED. MITOA -PASSED, POT & PPPOT-T&IC -PASSED, PT AND DRAW DOWN TEST MV & SV -PASSED AFTER VALVE CREW SERVICED BOTH VALVES. 09/21/05 TAGGED AT 8573' RKB, EST. 2351 FILL. RECOVERED SAMPLE OF THICK CRUDE AND SAND. ATTEMPTED MEASURE BHP AT 8200' RKB. NO DATA RECOVERED, FAILED BATTERY CONNECTION ON GAUGE. 09/23/05 MEASURED BHP AT 8200' RKB: 3385 PSI. LOGGED CALIPER SURVEY FROM 8579' RKB TO SURFACE. 10/04/05 TAGGED TO AT 8558' RKB WI 3.70"" CENT., 5' STEM, 2.65'"' CENT., 8' STEM, AND 3.75"" GAUGE RING (15' 9"" OAL). JOB COMPLETE. 10/22/05 SHOT A 2.5" HSD GUN LOADED 6 SPF, 101 IN LENGTH. PERF INTERVAL WAS 85451 - 8555'. WELL LEFT SHUT IN. 10/24/05 / PERFORMED A CEMENT SQUEEZE WITH COIL. PRESSURED UP TO 3000 PSI, 10 BBLS. BEHIND PIPE. CLEANED OUT TO 85301. LEFT WELL SHUT IN WITH 900 PSI. 10/25/05 ATTEMPTED TO MILL CEMENT. MOTOR LOCKED UP BEFORE MILLING BEGAN. 10/26/05 MILLED CEMENT FROM 8520' TO 85441 CTMD, CLEANED FILL TO 85801 CTMD. PT SQUEEZE TO 1000 PSI WHP FOR 10 MINUTES. FP WELL TO 2500'. 10/28/05 DRIFTED TUBING. DOWN TO 85981 RKB WI 3.70 CENT., 3' STEM, AND 18' DUMMY WHIPSTOCK (3.7000) 122.51 OAL. HAD TO SLOW SPEED DOWN TO 100' PER MIN. TO GET TOOLS TO FALL SMOOTHLY FROM 6500' SLM TO 72001 SLM (NO PROBLEMS). 10/29/05 RIH WITH WEATHERFORD WHIPSTOCK. MAX 00 WAS 3.7" TOOL LENGTH WAS 31' LONG. SAT DOWN AT 7370'. TAGGED SOLID, POOH WITH TOOL STRING AND WHIPSTOCK. NOTHING ABNORMAL SEEN ON WHIPSTOCK. 10/30/05 SWAPPED LINE BACK POST WHIPSTOCK JOB. 10/31/05 TORQUED ALL WELLHEAD FLANGES TO SPEC. ) ) Page 1 _ BP EXPLORATION Operat:ions Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Q-02 1 Q-02 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Date FrQm - To Hours Task Code NPT Phase 11/6/2005 00:00 - 01 :30 1.50 MOB P PRE 01 :30 - 01 :45 0.25 MOB P PRE 01 :45 - 02:00 0.25 MOB P PRE 02:00 - 02:45 0.75 MOB P PRE 02:45 - 03:30 0.75 MOB P PRE 03:30 - 03:45 0.25 MOB P PRE 03:45 - 04: 15 0.50 MOB P PRE 04:15 - 05:00 0.75 RIGU P PRE 05:00 - 05:45 0.75 BOPSUP P PRE 05:45 - 06:15 0.50 BOPSUP P PRE 06: 15 - 06:30 0.25 BOPSUP P 06:30 - 12:00 5.50 BOPSUF P 12:00- 13:30 1.50 BOPSUR P 13:30 - 17:30 4.00 BOPSUP P 17:30 - 18:00 0.50 RIGU P PRE 18:00 - 18:20 0.33 RIGU P PRE 18:20 - 18:45 0.42 RIGU P PRE 18:45 - 19:45 1.00 RIGU P PRE PRE PRE PRE PRE Start: 11/5/2005 Rig Release: 11/27/2005 Rig Number: Spud Date: 11/5/2005 End: 11/27/2005 Description of Operations ND BOPE and secure in cellar for move. NU tree cap. Pressure test to 500 psi and 4000 psi with diesel. Passed ok. Prepare to move rig off of 10-04 and onto 10-02. Spin tires to warm moving system. Move cuttings box, and other equipment out of the way. Break hardline to tiger tank. Hold PJSM Re: Moving from 10-04 to 10-02. Discuss job assignments. Place block between rig and wellhead. Note - Due to time adjustment, Accept rig at 02:00. Move rig from 10-04 and stage in front of 1 Q-02. Place Herculite around wellhead. Move rig mats from 10-04 to 10-02. Shut in well on driller side of 10-02 (Pad Operator). PJSM prior to moving over well. Attended by all rig hands, MWD hand, TL, TP, WSL, DSO. Move rig over well 1 Q-02. Set rig down over well. Begin rigging up. Begin NU BOPE. Hold Safety Standdown with day crews in conjuction with Tech Limit meeting. Discussed recent field accidents, increased safety awareness with the cold/dark winter weather conditions. Reviewed our commentment to safety on the rig and present working tasks and conditions. Also reviewed hazards we will need to deal with on this particular well concerning pressure deployment of tools. After crew changeout held PJSM and reviewed "SIMOPS Plan" guide to swapping rig over to 2-3/8" coil and NU BOP's. Gave out job assignments to individual crew members and or teams. Install XO flange to BOP stack for this well. Lift reel into reel house and secure. (Will need to allow it to warm-up). Take on 480 bbls of 8.9ppg used Flo-Pro that was in storage at MI. NU BOP stack. Start working on injector changing out gripper blocks from 2" to 2-3/8". Nordic crew change day. Oncoming crews briefed about present work and reviewed SIMOPS Plan. Continue NU BOP choke/kill lines. Continue with injector gripper block swp. Grease choke manifold valves. Prep to test BOP's. Empty 2 upright Flo-Pro tanks in Tank Farm and prep to move tanks to new Tank Farm location which will be out of the way of Nordic #3 operations. Test BOPE. AOGCC witnessing waived by Chuck Sheive. Test 250/low 4000/high. Suspend working on injector until all rams were tested then resumed changing gripper blocks. Finished Tank Farm move. Install internal grapple & pull cable into end of coil. Drawdown test accumulator. Finished installing gripper blocks. Start on gooseneck change over. Pre spud meeting with oncoming night tour and Aras Worthington from Anchorage office. Crew change. Hold Safety Stand down with night tour. Discuss recent inicidents in the rotary world that could have resulted in serious injuries. Discussed complacency, and how safety is a journey, Printed: 11/28/2005 12:59:04 PM ') ') BPEXPLORATION OperaUonsSumrnaryRepørt Page 2_ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 Q-02 1 Q-02 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11/5/2005 Rig Release: 11/27/2005 Rig Number: Spud Date: 11/5/2005 End: 11/27/2005 Date From - To Hours Task Code NPT Pha.se DescriptionofOpera.tions 11/6/2005 18:45 - 19:45 1.00 RIGU P PRE and not a destination. Asked hands to have a renewed commitment to safety. Each hand was asked to make a rig walkaround in an area he does not normally work in and write 2 stop cards. Good participation from all hands on rig. 19:45 - 22:30 2.75 RIGU P PRE Slip and cut 50' of drilling line. 22:30 - 0.00 RIGU P PRE PU injector. Attach packoff. Attach gooseneck. Change packoff elements and brass inserts. 11fi/2005 00:00 - 00:20 0.33 RIGU P PRE PJSM prior to stabbing coil. 00:20 - 01 :00 0.67 RIGU P PRE Pull coil off reel and stab into injector. 01 :00 - 02:30 1.50 RIGU P PRE Make up hose to reverse circulate. Stab injector onto well. 02:30 - 04:05 1.58 RIGU P PRE Reverse circulate 25 bbls of methanol, followed by water spacer then mud to perform slack management. Good audible indication of slack eline moving in the coil. 04:05 - 06:00 1.92 RIGU P PRE SO pumps. Blow back end of coil with rig air to FP. Rig up hardline in reel house, and jupiter cable. 06:00 - 06:30 0.50 RIGU P PRE Held TL meeting and Pre-Spud meeting with daylight crews. 06:30 - 08:45 2.25 RIGU P PRE Continue MU inner reel hardline and e-line junction box. 08:45 - 09:00 0.25 RIGU P PRE PJSM review coil cutting procedures and hazards. 09:00 - 09: 15 0.25 RIGU P PRE Attempt to check well pressures before unstabbing injector. Master vavle is pressure locked. Call valve shop. 09:15 - 11:00 1.75 RIGU P PRE Blowdown kill line to prevent freezing. Unstab injector. Seen 11' of e-line beyond end of coil. Trim back 8' of coil. Install Kendal CTC. Pull test to 40K 11 :00 - 14:00 3.00 RIGU P PRE MU Baker UQC. Cut/slip 60' of .125" slickline then rehead. PU BHA to mousehole and motor/mill to well. Check WHP...slight but enough to flow 1" stream. 14:00 - 14:15 0.25 RIGU P PRE PSJM review "Pressure Deployment" procedures. 14: 15 - 16:30 2.25 RIGU P PRE Pressure deploy BHA #1 following guideline steps.Shut-in well and pop off lubricator seen we've mismeasured spaceout of double ball valves. Too high. Stab lubricator open well and slackoff to lower set depth. Shut-in well again. Remove lubricator and stand back. PT UQC assembly to 3500psi. MEG test tools. Stab injector. Open BOP's. Tag-up set depth. 16:30 - 18:00 1.50 RIGU P PRE RIH w/ BHA #1 18:00 - 18:30 0.50 CLEAN P WEXIT Continue RIH with mill and motor. Clean thru 7370' where eline had trouble with whipstock. Clean to dry tag up at 8612' CTM. Kick on pumps. Start displacement of well to mud. 18:30 - 19:35 1.08 CLEAN P WEXIT Log tie in pass down over RA charecter at 8200'. Make -14.5' correction. RIH at 25 fpm and pumps at 2 bpm. Found hard bottom at 8688'. 19:35 - 21 :00 1.42 CLEAN P WEXIT Pick up off bottom. Kick on pumps to full rate. 4300 psi at 2.5 bpm. Seems high. SO pumps, open EDC. Kick on pumps circ press at 2.5 bpm is 3200 psi. Mud appears to be vis'ed up a bit. SO pumps, shut EDC. Come on line with pumps, POOH pumping at 2.3 bpm, 4000 psi. Got a fair amount of pipe scale/cement chunks while POH. Good call to run the cIeanout run. 21 :00 - 21 :20 0.33 CLEAN P WEXIT Tag up at surface. Start to flow check well. Hold PJSM. Discuss 2 options. Well is dead, Well is not dead and we need to undeploy. Review undeployment proceedure in detail. Assign individuals to tasks on undeployment proceedure. 21 :20 - 21 :55 0.58 CLEAN P WEXIT Flow check of well confirms that well is dead. Break injector. Printed: 11/28/2005 12:59:04 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11n/2005 11/8/2005 11/9/2005 ) ) Page3~ BP EXPLORATION Operations Summary Report 1 Q-02 1 Q-02 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 From-To Hours Task Code NPT Phase 21 :20 - 21 :55 21 :55 - 22:50 22:50 - 00:00 00:00 - 01 :00 01 :00 - 01 :20 01 :20 - 01 :55 01 :55 - 02:05 02:05 - 03:30 03:30 - 04:45 04:45 - 06:30 06:30 - 13:30 13:30 - 13:10 13:10 - 13:40 13:40 - 14:15 14:15 - 15:40 15:40 - 16:00 16:00 - 17:30 17:30 - 20:15 20: 15 - 22:30 22:30 - 23:00 23:00 - 23:15 23: 15 - 00:00 Oo:ou - CI3.00 03:00 - 05:00 0.58 CLEAN P 0.92 STWHIP P WEXIT WEXIT 1.17 STWHIP P WEXIT 1.00 STWHIP P 0.33 STWHIP P 0.58 STWHIP P WEXIT WEXIT WEXIT 0.17 STWHIP P WEXIT 1.42 STWHIP P WEXIT 1.25 STWHIP P WEXIT 1.75 STWHIP P 7.00 STWHIP P WEXIT WEXIT 23.67 STWHIP P WEXIT 0.50 STWHIP P 0.58 STWHIP P WEXIT WEXIT 1.42 STWHIP P WEXIT 0.33 STWHIP P 1.50 STWHIP P WEXIT WEXIT 2.75 DRILL P PROD1 2.25 DRILL P 0.50 DRILL P 0.25 DRILL P 0.75 DRILL P 3.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 ? nl). Dr.ILL P Start: 11/5/2005 Rig Release: 11/27/2005 Rig Number: Spud Date: 11/5/2005 End: 11/27/2005 Descriptionof Operations Lay down BHA #1, clean out mill and motor. MU BHA #2, WF WS setting BHA. WS tray face scribed to orienter. RIH with BHA #2 to set WF whipstock. Pumping at 0.5 bpm thru an open EDC. RIH at 70 fpm. Continue RIH with BHA #2. Log tie in pass down from 8220'. Make -11' correction. Log CCL pass down from 8260'-8540'. Confirmed on depth. Move set depth up to put WS top at 8540' to avoid casing collar deeper. Check PU weight, and found at 32500 Ibs. Bring pumps up. Pressure up on setting tool. Saw indication of set. Set 5000 Ibs on whipstock. Good inciation of set. PU at 31000 Ibs. Confirmed set whipstock. WS tray oriented to 30 deg left of high side. Top of whipstock at 8540' Bot of whipstock at 8553'. Open EDC. Pump at full rate while POOH. Pumping at 3076 psi at 2.3 bpm. Lay down BHA #2, whipstock setting BHA. PU BHA #3, window milling BHA. Running WF 0 deg motor, HCC string reamer, WF window mill. RIH with BHA #3 to mill window. Tagged at 8540.3' Mill window f/ 8540.3' to 8547'. 2.70/2.70 free-spin 3950psi 100-150psi motorwork following time milling schedule. Max wob 6k most time 2-3k. Milled to 8547'. Shut-in well trapping 1000psi. Held for 5min. No leak-off. Called town to confirm pressures and wait times. Drill open hole from 8547' to 8558'. Make 2 up and down reaming passes thru the window. No motor work or problems observed. Dry drift window up and down. No problems observed. POOH to pick up build section BHA. Hold PJSM and review undeployment proceedure. Trap 550 psi on wellhead. Pressure undeploy window milling BHA. Mills recovered in good shape. WF whipstock mill recovered at 3.79" Go, 3.78" No-Go, and had the proper swirl pattern on the face. HCC string reamer recovered at 3.80" Go, 3.79" No-Go. Make up BHI MWD tool for build section. (2.3 deg mtr w HTC bi-center) /Electrically test same. Pressure deploy BHA. Found 305 psi on well. Had trouble getting bit past tbg hanger. Get off well and turn bit 180 deg. Get through tbg hanger ok. Stab coil. Test mwd. Get on well. Run in hole following WHP schedule. Log gr tie in from 8210 to 8250'. Subtract 16' correction. Continue to RIH. Orient to 40L to pass through window. Drill ahead from 8558'. 3535 psi fs @ 2.6 bpm. Drill build from 8570'. 3550 psi fs at? ç: i~vl. u:::>PI:100-200. DHWOB: 1.0-15 k-H, Wtlr'!tjHP/ECD: 66/3651/10.9 ppg. IÞdO/I.¡t"V I: 260/146/320 bbls. -I ...t~lI~ just outside window. ROP averaging 25-30 fph. ~:......, from 8700'. Printed: 11/28/2005 12:59:04 PM KRU 1 Q-028 Injector Proposed CTD Completion 'i!: ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t- ~ 7" 26# J-55 @ 6268 MD' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ..Jí. 9-5/8" 36# J55 @ 3830' 2-3/8" liner top @ +/-8400' M D Window in 4-1/2" KOP at 8550' MD Squeezed A3/ A4-sand peñs 8662' - 8808' md . J(,!-_:~ .......... W ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o DO 0 ~ ~ ~ ~ III L. _n 4-1/2" 12.6# L-BO Fill @ 9010 MD' ;.; ~ i ~ ~ ~ ~ l ~ ~ ~ ~ ?Æ ~ ~ ~ ~ Conoc;p'hiUips Alaska, Inc, E. 4-1/211 Camco OS nipple, 3.87511 min 10 at 500' MC .~ O. 4-1/211 Baker CMU sliding sleeve @ 6009' MD wI 3.812" min IC B. Baker "Hyflo III" liner top packer/SBE/seal assembly at 6119' MC Ä. 3-%11 Otis "X" nipple, 3.81211 min 10 at 7975' MD o Sqz'd C-sand peñs 8369'-8384' md ~ 7J. ~ 't-- ~\'Ø ~...~\ f\ \\~e{. o o o 0 0 o 0 o o 0 o 0 o o o o o I 2-7/811 slotted liner, 4 holeslft, 3/811 hole size 1 Q-02BPB1 A4 Lateral, TO @ 10,552' M0/6596' TVO o 0 . · . · . 0 4 1/8" / 3 %" Openhole 1 Q-02B A4 Lateral, TO @ 11,500' M0/6674' TVO; KOP @ 9975' M0/6605' TVO; PIN: 205-142 -' o o 0 o ooooo~ o 0 0 0 0 0 0 0 ~.J o o o o o o o 1Q-02BL 1 A3 Lateral, TO @ 12,050' M0/6680' TVO; KOP @ 9609' M0/6605' TVO; PIN: 205-186 RE: 1Q-02A (195-194) e e Subject: RE: 1Q702A (195-194) ....... '.', From: "Alls\lP-I)rake, Sharon K" <Sharon.K.Allsup.,Drake@c(),11.qcophiIIips.col11> Date: Thu, 2Q'Oct 2005 15:33:02 -0800 . ,,< ... . To: Thomas '!VIau}~er::<tom _ maunder@a<lr:llin.state.' .","..... . ." ·t::~~. ::.. Tom - the history of the squeezes is attached. I can also send a paper copy of it, if you prefer. Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [!11.?:t..~_1::C?:t:Q!11_!119.:.1J.:nder@admin.:st..9.:te. ak. us] Sent: Thursday, October 20, 2005 11:02 AM To: Allsup-Drake, Sharon K Subject: Re: 1Q-02A (195-194) Hi Sharon, Sorry I am late getting back to you. The full history would be appreciated. Tom Allsup-Drake, Sharon K wrote, On 10/18/2005 4:36 PM: Tom - we have located some events in the file for 1Q-02A relating to the squeezes at the time of the initial drilling. Do you want a summary page of all the squeeze activity at the time of the drilling or the successful squeezes? Thanks, Sharon office phone: 263-4612 fax: 265-6224 . -----Original Message----- From: Thomas Maunder [mailto:t:om maunder@admin.state.ak.us] Sent: Monday, October 03, 2005 2:22 PM To: Worthington, Aras J Cc: Allsup-Drake, Sharon K Subject: 1Q-02A (195-194) Aras and Sharon, I was reviewing the file on 1Q-02A (195-194) and there appears to be a gap in the records. The drilling rig was released in late January 1996. Drilling operations had been problematic with a BHA and one hole section lost (PB1) and the liner top packer setting before the primary cement job could be pumped. The completion report was filed in mid August, but there is no information about the squeeze operation that was performed. There is a report about shooting the squeeze perfs after the drilling rig left but the next information in the file is the actual production perfing operation. Can either of you help me with the missing information?? 10f2 .:'.>': ".~"'~~. 'A . ~CQ~ 3/14/2006 10:29 AM RE: 1Q-02A (195-194) e e Thanks in advance for your assistance. Tom Maunder, PE AOGCC Content-Description: 1 q-02a.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 3/14/2006 10:29 AM e 1 Q-02A Well Events Summary 1 Q-02A Well Events Summary e Date Summary 01/29/96 PERF INTERVAL 8903'-8905' AND 8203'-8205' USING 3-3/8" HOLLOW CARRIER WI BH CHARGES, 6 SPF, & 60 DEG PH. UNABLE TO SET CMT RETAINER; COULD NOT GET GAUGE RINGIJUNK BASKET BELOW 8875', 02/01/96 ATTEMPT TO RUN CEMENT RETAINER. UNABLE TO PASS THRU LINER LOCATOR SEAL ASSEMBLY AT 6070' CTM. WILL ATTEMPT TO RUN W/E-LlNE. 02/03/96 SET CEMENT RETAINER @ 8883' , TAGGED MUD AT 8885', TIGHT SPOT AT 6100' 02/03/96 ATTEMPT TO CEMENT LINER THRU RETAINER AT 8883' RKB. UNABLE TO ESTABLISH INJECTION RATE BELOW RETAINER. 06/14/96 SHOT SQUEEZE PERF @ 8725'-8727' (REF GR DATED 1/29/96) USING 3-318" HOLLOW CASE CARRIER WI BH CHARGES, 6 SPF, AND 60 DEG PH. RAN 3.75" GAUGE RING I JUNK BASKET TO 8700', AND SET HES 4-1/2" FAS-DRILL CMT RETAINER @ 8700' (REF GR DATED 1/29/96) 06/15/96 STUNG INTO CR @ 8700' RKB. UNABLE TO PUMP INTO PERFS 8725 - 8727' W/4000 PSI SURFACE PRESSURE. POH WISTINGER & FREEZE PROTECTED 4-1/2" TUBING FROM 2300' TO SRFACE W/DIESEL. 06/26/96 SET HES FAS-DRILL BRIDGE PLUG @ 8470', SHOT SQZ PERF FI 8440'-8442' USING 3-3/8" HOLLOW CASE CARRIER WI BH CHARGES, 6 SPF, & 60 DEG PH, AND SET HES FAS-DRILL CEMENT RETAINER @ 8385' 06/27/96 CEMENTED THE 4-1/2" LINER W/10 BBLS CL G BY CIRCULATING THROUGH PERFS 8440-8442' & TAKING RETURNS OUT THE PERFS 8203-8205'. FREEZE PROTECTED THE 4-1/2" TBG FROM 2100' TO SURFACE W/DIESEL. 06/29/96 PRESSURE TESTED UPPER SQUEEZE PERFS. ABLE TO INJECT 0.6 BPM AT 3000 PSI. 07/06/96 SQUEEZED PERFS FROM 8203' - 8205' RKB. PUMPED TOTAL OF 21 BBLS CEMENT. SQUEEZED AWAY 14 BBLS AND BUILT SQUEEZE PRESSURE TO 3000#. ATTEMPT TO CLEAN OUT REMAINING CEMENT W/BIOZAN AND TAGGED UP AT 7730' RKB (2 HRS BEFORE THICKENING TIME OF CEMENT). 07/07/96 DRILL HARD CEMENT FROM 7720' - 7800' CTM W/3.75" MILL AND 2-7/8" MOTOR. AVERAGE ROP = 15 FTIHR. FREEZE PROTECT TUBING FROM 2000' TO SURFACE W/DIESEL. 07/29/96 DRILLED OUT CEMENT FROM 7808' TO 8003', PUMPED 15 BBLS BIOZAN FOLLOWED BY SLICK SEAWATER FOR CLEAN UP PULLING OUT OF HOLE. PUMPED 1185 BBBLS SLICK SEAWATER 07/30/96 DRILLED CEMENT FROM 8000' TO 8231' CTM. PRESSURE TESTED SQZE PERFS 8203-8205' TO 2800 PSI. UNABLE TO ESTABLISH INJECTION INTO PERFS. PRESSURE BLEEDS OFF FROM 2800 PSI TO 2540 PSI IN 15 MNUTES. 07/31/96 DRILLED 154' OF CEMENT FROM 8231 TO 8385'. DRILLED CEMENT RETAINER @ 8385'. DRILLED 60' OF CEMENT FROM 8385 TO 8445'. DRILLED BRIDGE PLUG @ 8470' & PUSHED TO 8700' (8705' CTM). PRESSURE TESTED SQUEEZE PERFS (8203- 8205 & 8440-8442') TO 2800 PSI. BLED 0 08/01/96 DRILLED THE CEMENT RETAINER @ 8700' & PUSHED TO 8883'. REAMED AND BACKREAMED FROM 7750 TO 8883'. FREEZE PREOTECTED WITH DIESEL FROM 2500' TO SURFACE. 08/07/96 RAN CEMENT BOND LOG FROM 8879 TO 7400'---HAD SEVERE PULL AT 8000'--- CEMENT QUALITY IS POOR EXCEPT FOR FROM 8842' TO 8846', FROM 8294' TO 8327', AND FROM 8202' TO 8212'. CEMENT IS FAIR FROM 8100' TO 8230'0 08/11/96 SHOT 'A' SAND PERF INTERVAL 8662'-8673',8676'-8681',8686'-8720', & 8802'-8808' USING 2-7/8" HSD WI DP CHARGES, 4 SPF, AND 180 DEG PH. 09/19/96 PUMPED HIGH PRESSURE BREAKDOWN WITH 2240 BBLS SEAWATER AND 11,976# 20/40 PROPPANT. HAD GOOD BREAKDOWN IN FIRST HPBD STAGE. e e CCùlr ~ u¡ 1. r' i.f? U' ~ ¡ ,.1' 1.'. ,.:::::1 !1! d ¡ ¡ ~ ìI\ 1,,1" 1.1-.. \ L.J'iJ FRANK H. MURKOW5KI, GOVERNOR AItASIiA OIL AlVD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Aras Worthington CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~.............""".'....'."'."""" . -:' "~,c. .-'..'.,:,..,.....:". '" :.'. . . . . . . . _._~. ,'''''' ;...Y!o,' ^ . . Re: K~.19:-Q~.. sundî¥tiutriDilr: 305-287 ~ ~ANNEL) NeW (ì 3 2005 Dear Mr. Worthington: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thiSf day of October, 2005 Encl. Sincerely, · CfJ:}-lrJ ~ç -oS- e STATE OF ALASKA ,. t~ /5 j$:.... I ALASKA OIL AND GAS CONSERVATION COMMISSION i KECEfVEfJ1' APPLICATION FOR SUNDRY APPROVAL OCT 032005 \Ûf~ 20 MC 25.280 O· & G C C .. Alaska 11 asons. ommtSSlon 1. Type of Request: B Abandon o Suspend o Operation Shutdown o Perforate o Other Anchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. ~~~,~:nber Conoco Phillips Alaska Inc. o Development o Exploratory 3. Address: o Stratigraphic !HI Service 6. API Number: J clo P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21248-01-00 7. KB Elevation (ft): 78' 9. Well Name and Number: Kuparuk 1Q-02A 8. Property Designation: 10. Field 1 Pool(s): ADL 025634 Kuparuk River Unit 1 Kuparuk River Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9017 6830 8720 ·Yi,·....':~ 6633 8883 None ,.,.."i'··'·· l<i,D'.' 'O;';;"::·'.i,. ii'.'ni' ',P,ii'iY'71'ë tii·P, ,i_ii":;; ~i':; ,.i !=:tfll~tJ Ir::ol - 100' 16" 100' 100' !=:llrf::o~.. 3830' 9-5/8" 3830' 3517' 3520 2020 6268' 7" 6268' 5205' 4980 4330 P LinAr 2955' 4-1/2" 6055' - 9010' 5056' - 6822' 8430 7500 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 8369' - 8905' 6406' - 6753' 4-1/2", 12.75# L-80 6061' Packers and SSSV Type: Baker 'HyfJo III' packer; Packers and SSSV MD (ft): 6061' Camco 'DB' Landing Nipple 500' 12. Attachments: 13. Well Class after proposed work: !HI Description Summary of Proposal o BOP Sketch o Exploratory o Development !HI Service o Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 7, 2005 o Oil o Gas o Plugged !HI Abandoned 16. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission ReDresentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington. 265-6802 Printed Name Aras Worthington Title CT Drilling Engineer Sianature ,.'/:a :w.L\'·, ,¡:p l ~\Wç,cr- A Îl ) Prepared By Name/Number: Phone Cell: 440-7692 Date 16í(,ì/~ Terrie Hubble. 564-4628 Commission Use Only , I :,':J,{)S ---- Conditions of approval: Notify Commission so that a representative may witness Sundry Numbe~:, - ~ r o Plug Integrity ~OP Test o Mechanical Integrity Test o Location Clearance Other: '!>5"OO\",>\ ~"'~ \S<Ji? \-tc,,>.\;-- RBDMS 8Ft 0 CT 0 .) 2DD5 ~ &òANNEL 0, <ó? 20r¡;i \1 ",I, J" Subsequent F R uir') ~' /' ~v" APPROVED BY /() / t/; oS Approv BV'~rl / COMMISSIONER THE COMMISSION Date Form 10-403 e . ed /20 '- .-..."'", ~bmi n Duplicate rt¢~ lJRIG\NAL ~. ~'~ECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 9 Z005 APPLICATION FOR SUNDRY APPRO"""oil&GasCons.Commí¡)~';" 20 AAC 25.280 Anchorage e STATE OF ALASKA e o Alter Casing o Change Approved Program o Suspend 0 0lfliY!on Shutdown o RepairWell*I~~a~~ls( o Pull Tubing 0 Perforate New Pool o Perforate o Stimulate o Waiver 2. Operator Name: Conoco Phillips Alaska Inc. 3. Address: clo P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: o Development 0 Exploratory o Stratigraphic !HI Service 99519-6612 78' 9. Well Name and Number: Kupa 8. Property Designation: ADL 025634 Total Depth TVD (ft): 6830 100' 16" 3830' 9-5/8" 6268' 7" 2955' 4-1/2" 3520 4980 2020 4330 8430 7500 Perforation Depth MD (ft): 8369' - 8905' Packers and SSSV Type: Perforation Depth TVD (ft): 6406' - 6753' Baker 'Hyflo III' packer; Camco 'DB' Landing Nipple Tubing Grade: L-80 Packers and SSSV MD (ft): 6061' 500' Tubing MD (ft): 6061' 12. Attachments: !HI Description Summary of Proposal o Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is Printed Name Aras Worthingto 13. Well Class after proposed work: o Exploratory 0 Development !HI Service 15. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged OWINJ !HI Abandoned o WDSPL ue and correct to the best of my knowledge. Title CT Drilling Engineer Contact Aras Worthington, 265-6802 Phone Cell: 440-7692 Commission Use Only Date Prepared By Name/Number: ~ Terrie Hubble, 564-4628 Notify Commission so that a representative may witness Sundry Number: 30S"- a&- o Mechanical Integrity Test o Location Clearance Other: () ~, ~\~,\"",~~ ~\\ ~C)'Ç>~7-\ Subs uent Form Required: l.\() COMMISSIONER APPROVED BY THE COMMISSION Date Submit In Duplicate OR I r:¡ t\¡,IAI 'j.\ i \;.)1 \¡ A. e e abp To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Aras Worthington CTD Engineer Date: September 27,2005 Re: Prep Kuparuk 1 Q-02A for CTD sidetrack Sundry approval is requested to prepare 1 Q-02A for a Coiled Tubing Drilling sidetrack. 1 Q-02A sidetrack was drilled in 1996 as a conventional A-sand injector. C-sand perfs were added in 1998. The proposed sidetrack (lQ-02B) is a single lateral A-sand injector, requiring that the existing A&C sand perfs be shut-off. --- The sidetrack, 1Q-02B, is scheduled to be drilled by Nordic 2 on or about November 10,2005. The plan calls for existing A&C sand perfs to be squeezed and the sidetrack drilled from a window to be milled in the B-3 shale. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre-Rie:Work. . . ~ <6 b~\<> \":, M.,\~\,,^,~t--\, ~D ~~,->~("""lQ: Ç><L~ 1) Complete mtegnty testmg. \ - 2) Pump a minimum of 8 bbls cement to squeeze off the existing A&C sand perfs. -V '- \ 3) Mill out cement to ~8600' MD wi CTU. v::\? o..,\>~~CL . 4) Pressure-test squeeze. 5) Remove flow line, remove well house, and level pad. M- '1't1 The pre CTD work is slated to begin about October 1,2005. ,0 ( \ Rie:Work 1) MIRU Nordic 2 and test BOPE. 2) Mill 3.80" window. 3) Drill ~3200' sidetrack into A-sand target. 4) Run slotted liner. 5) RDMO. up\ _~ (\c~' Post-Rie: Work 1) Move well house, install production flow line. 2) Bring Injector online. Aras W ortbington CTD Drilling Engineer 265-6802 CC: Well File Sondra Stewman/Terrie Hubble e ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY e KRU 1 Q-02A .. 1 Q-02A NIP (500-501, API: 500292124801 Well Type: INJ AnQle @) TS: 50 deQ @) 8225 SSSV Type: Nipple Orig 8/11/1996 Angle @ TD: 49 deg @ 9017 00:4.500) Completion: Annular Fluid: Last W/O: Rev Reason: TaQ by ImO Reference LOQ: Ref LOQ Date: Last Update: 7/30/2002 Last TaQ: 8720 TD: 9017 ftKB SLEEVE-C Last TaQ Date: 6/13/2000 Max Hole AnQle: 59 deQ @) 6584 (6009-6010, Casing String - ALL STRINGS 00:4.500) Descriotion Size Too Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 100 100 62.58 H-40 SUR. CASING 9.625 0 3830 3517 36.00 J-55 TUBING PROD. CASING 7.000 0 6268 5205 26.00 J-55 (0-6061, ::1 I: LINER 4.500 6055 9010 6822 12.60 L-80 00:4.500, Tubing String - TUBING 10:3.958) Size I Too I Bottom I TVD I Wt I Grade I Thread 4.500 I 0 I 6061 I 5060 I 12.75 I L-80 I ABM EUE Peñorations Summarv 11L Interval TVD Zone Status Ft SPF Date Tvoe Comment (1J06O.ro)1, I.-I 8203 - 8205 6301 - 6302 UNITD C 2 0 7/6/1996 Sqz 00:4.500) 8369 - 8384 6406 - 6416 C-1 15 4 1 0/19/199~ RPERF 2.5" HSD, 180 deg ph, +/- 90 dea from low side 8440 - 8442 6452 - 6453 UNITB 2 6 6/26/1996 SHOT SQUEEZE PERFS; 3 3/8" Hollow Carrier; 60 deg. phasinQ SETTING J ---- I 8662 - 8673 6595 - 6602 A-4 11 4 8/11/1996 APERF 180 deQ. ph; 2 7/8" HSD SLEEVE 8676 - 8681 6604 - 6608 A-3 5 4 8/11/1996 APERF 180 deQ. ph; 2 7/8" HSD (6113-<)114, 8686 - 8720 6611 - 6633 A-3 34 4 8/11/1996 APERF 180 deQ. ph; 2 7/8" HSD 00:6.000) 8725 - 8727 6636 - 6638 A-3 2 0 6/14/1996 8802 - 8808 6686 - 6690 A-2 6 4 8/11/1996 APERF 180 deQ. ph; 2 7/8" HSD 8903 - 8905 6752 - 6753 2 6 1/29/1996 IPERF 60 dea. ph; 3 3/8" HC PKR ~I Stimulations & Treatments (611~120, Interval Date Tyoe Comment 00:5.875) 8725 - 8727 6/14/1996 Shot Sqz Perfs 8440 - 8442 6/26/1996 Shot Sqz Perfs 8203 - 8205 7/6/1996 Squeeze Perfs Pumped 21 bbls ofCmt; Squeezed away 14 bbls NIP Other luas eauio. etc. . JEWELRY (J975-7976, Depth TVD Type Description ID 500 500 NIP Cameo 'DB' LandinQ 3.875 00:3.828) 6009 5024 SLEEVE-C Baker 'CMU' SlidinQ 3.812 6055 5056 TIEBACK Baker SettinQ Sleeve 5.500 Squeeze E I 6060 5059 TTL 3.958 Perfs 6061 5060 PKR Baker 'Hvflo III' 5.063 (820:H!205) 6113 5096 SETTING Baker Liner Setting Sleeve 5.500 - - SLEEVE Perf - - 6119 5100 PKR Baker 'Hvflo III' 5.063 (8369-8384) - - 7975 6153 NIP Otis 'X' LandinQ 3.812 - - 8883 6739 Baker CEMENT RETAINER(See WSR 2/3/96) RETAINER 3.000 Shot Sqz E I Perfs (8440-8442) Perf - - - - (8662-æ73) - - - - Perf - - (8676-8681) - - - - = = Perf - - (8686-8720) - - - - - - Shot Sqz E I Perfs (8725-8727) Perf - - (8802-æoB) - - - - - - RETAINER (8883.æ84, 00:4.500) Perf - r-- (89Q3.8905) - f-- - r-- KRU 1 Q-U2A Injector Proposed CTC Completion 9-518" 36# J55 @ 3830' e 7" 26# J-55 @ 6268 MD' e 2-3/8" liner top @ +1-8400' MD Window in 4-1/2" KOP at 8550' MD '-", 4-1/2" 12.6# L-80 @9010 MD' E. 4-1/2" Cameo OS nipple, 3.875" min 10 at 500' MD DODD 0.4-1/2" Baker CMU sliding sleeve @ 6009' MD w/3.812" min ID B. Baker "Hyflo III" liner top packerlSBE/seal assembly at 6119' MD A. 3-%" Otis "X" nipple, 3.812" min 10 at 7975' MD .. Sqz'd C-sand perfs 8369'-8384' md o o o o o o o o Squeezed A3/A4-sand perfs 8662' - 8808' md Fill . . . . . . . o o o o 0 o 0 o o o o o o o ConocJPhillips Alaska, Inc. A3/A4 Lateral, TO @ 11750' md o o o 0 0 o o o o o o o o o 2-7/8" slotted liner liner, 4 holes/ft, 3/8" hole size OEV 9/21/05 Re: [Fwd: Re: 1 Q-02A perf plugging] e e Subject: Rc: [Fwd: Re: I Q-02A perf plugging] From: Thomas Maunder <tom_maundcr@admin.state.ak.us> Date: Mon, 03 Oct 2005 12:52:49 -0800 To: "Worthin!,J'Íon,Aras J"<Aras.LWorthington@conocophjJ1ips.com> Aras, Thanks for addressing my question on the volume. As far as what you relate on the whipstock, the procedure is your preference just so long as sufficient cement is placed. Good luck with the operations. Tom Maunder, PE AOGCC Worthington, Aras J wrote, On 10/3/2005 11 :46 AM: Tom, Sorry about the e-mail address mix-up; rest assured you're not the only one frustrated. This last message did make it however, as well as the one about the sundry form; I've forwarded to Terrie Hubble @ BP to resolve. ------------ As for cement volume: I did put a minimum on the summary, not knowing for sure then how we would proceed with the squeeze. You are correct to assume we will likely pump a lot more: The C-sands are often thirsty. Also, after I wrote/sent in the summary we have since discussed and planned this a good deal more and at this point plan to set the whipstock above the A-sand and squeeze cement past it (A-sands) as well as above it (C-sands). I realize this is not reflected on the summary but assume it makes no difference from your perspective - am I correct in this assumption? Thanks, Aras -----Original Message----- From: Thomas Maunder [~~P to :t.s?.!!l~~~s!~r@admin. st?-t~_:...9:k. us] Sent: Monday, October 03, 2005 10:49 AM To: Worthington, Aras J Subject: [Fwd: Re: 1Q-02A perf plugging] Message 2 -------- Original Message -------- Subject: Re: 1Q-02A perf plugging Date: Mon, 03 Oct 2005 07:09:09 -0800 From: Thomas Maunder <tom maunder@admin.state.ak.us> Organization: State of Alaska To: Aras Worthington <a.i~or_t:::£1:~~C2~9_C::9-Phillip§._:_:::-'2~.? CC: Sharon Allsup-Drake <Sharon.K.Allsup-Drake@conocophillips.com> References: <433F2584.9020706@admin.state.ak.us> Aras, I attempted to undeliverable. Sharon, I know send this message on Saturday and it came back Here goes again. you didn't do this sundry but would you check with Aras 10f2 10/3/2005 12:54 PM Re: [Fwd: Re: 1 Q-02A perf plugging] e e and see if he gets this message. Thanks, Tom Thomas Maunder wrote, On 10/1/2005 4:10 PM: Aras, I am in on Saturday catching up. With regard to you cementing plan on this well, your planned 8 bbls is correctly stated as a minimum. Based on the perf length and squeezing a little away, I would think you are likely to be pumping a greater volume. Is that correct?? Tom Maunder, PE AOGCC 20f2 10/3/2005 12:54 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supen'isor .----' Ké11{( (/Z~/D4 DATE: Wednesday. June 23. 2004 SlIBJECT: Mechamcallmegrlty Tests CONOCOPHILLIPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector 1 Q-O~A KUPARUK RIV UNlT IQ-O~A Src: InspeclOr Re\'iewed By: P.I. Supn' -~ Comm NON-CONFIDENTIAL Permit Number: 195-194-0 Inspector Name: Chuck Scheve Inspection Date: 6/19/2004 \Vell Name: KUPARUK RJV UNIT IQ-02A Insp Num: mitCS04061920J324 Rellnsp Num: API \Vell Number: 50-029-21248-01-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 Q-02A Type Inj. P TVD 6830 IA 1300 :!200 2190 2190 P.T. 19519-10 TypeTest Spy Test psi 1265 OA 500 600 600 600 Interval -I'YRTST P/F p Tubing ~-I5Ü ~.150 2-150 2.150 Notes: Pretest pressures observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. \Vednesda~. June 23. 2004 Page 1 of I Q-02A Status Change Subject: 2F-17, 19, 1Q-02A Status Change Date: Thu, 18 May 2000 10:33:33 -0900 From: "Eric L Zuspan" <N1052~ppco.com> To: steve mcmains~admin.state.ak.us, blair_wondzell~admin.state.ak.us As per Blairs request this e-mail is to notify the AOGCC of status changes on the following Kuparuk wells. Please disreguard the 403's sent in previously. The sundry for 3Q-08A was a 404 report of a conversion done last year. If' you have any questions please call me at 659-7285 Eric Well PTD Permitted Status Current Status As of 1Q-02A 95-0194-0 Prod Inj 8/1/96 ~J2F-17 96-0204-0 Prod Inj 11/1/97 ~q2F-19 96-0201-0 Inj Prod 6/1/97 1 of 1 5/18/00 10:52 AM PERMIT 95-194 95-194 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS ~L GR/EWR4 -MD ~7900-8680 ~/6273-8348 PB1 Page: 1 Date: 07/21/98 RUN RECVD 1 07/18/96 1,3-4 08121/96 95-194 GR / EWR4 - TVD B~5212-6401 PB1 1,3-4 08/21/96 95-194 95-194 7395 CBT 10 -407 DAILY WELL OPS ~T/6550-8295 ~7400-8873 ? d~eOMPLETION DATE ~ / 1 ! / ~J / R /A/t-~/V)--/ TO ~ /// /~/ 3,4 08/21/96 FINAL 10/07/96 ? I? 1751 Are dry ditch samples required? yes ~)-And received? yesf no Was the well cored? Are well tests required? %yes Well is in compliance Initial COMMENTS yes ~0~,~_Analysis & description received? ~-~__Received? .~.~-~---n-o-~-- y~ no ~ I 0/3/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'I-i'N: Sherrie NO. 10437 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1Q-2A c~ ~'-_ lc)c{ CBT 960806 1 1 ..... , 1 Y- 13 ~ ~ - O t ~- INJECTION PROFILE 960820 I 1 ~-25 ~.~-O<~c~ F~RODucTIONPROFILEW/DEFT 960821 '1 ' I '" 1 ............ 2X-12A ~%- ['-I~., GAS LIFT SURVEY 960810 I 1 2X-17 ~-- I~ [ PRODUCTI.O.N PROFILE 960810 I 1 3. A.-18 c~G- t'~'"5 usrr 960907 I 1 3A-18 'q,,- CBT 960907 I 1 3G-25X ~.(E'. - I:~(~ CBT 960809 I 1 , . .. ., _ SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 6, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1Q-02A (Permit No. 95-194) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1Q-02A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIEGION WELL COMPLETION OR REOOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS r'~ SUSPENDED E~ ABANDONED [] SERVICE r~ Classification changed to Injection well 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-194 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 -." ;~':7,'::~ ;-~:.~?-"; 50-029-21248-01 4 Location of well at surface :i ~O~.~"~'~'~.._~ i"~ ......... '~"~ i~~~~! 9 Unit or Lease Name 1206' FNL, 1175' FEL Sec. 26, T12N, R09E, DM. ............. Kuparuk River Unit At Top Producing Interval 503' FSL, 2632' FEL, Sec. 24, T12N, RDE, UM At Total Depth r: .... '~ ..... %.;;-'7~ f 1Q--02A · 11 Field and Pool 502' FSL, 2027' FEL, Sec. 24, T12N, RDE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation a?d Serial No. Nordic Ricj #1 RKB 25', Pad 53'I ADL 25634 ALK 2579 1~ Date Spudded I 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions January 3, 1996 (sidetrack) January 20, 1996 11-Au~-96 (perf'd) NA feet MSL 1 · 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 9017'MD &6830'TVD j8883 MD &6735 TVD YES r~ NO--L_JI NA feetMDI = 1380'ss APPROX 22 Type Electric or Other Logs Run GR/CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 100' 24" 240 sx CS 11 9.625" 36# J-55 SURF. 3830' 12.25" 1000 sx CS III Lead, 420 sx CS I 7" 26# J-55 SURF. 6268' 8.5" 550 sx Class G & 250 sx CS I 4.5" 12.6# L-80 6055' 9010' 6.125" 1113 sx Class G KICKOFF SIDETRACK @ 6268' NORDIC OR 6280' NABORS 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI . PACKER SET (MD) 8440'-8442' MD 6 spf 6448'-6450'TVD (squeeze perfs) 4.5" 6055' 6055' & 6113' i 8903'-8905' MD 6 spf 6748'- 6749'TVD (squeeze perfs) 8203'-8205' MD 6 spf 6297'- 6298'TVD (squeeze perfs) 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 8662'-8673' MD 4 spf 6599'-6606'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USE..D 8676'-8681' MD 4 spf 6608'- 6611' TVD 8440'-8442' squeezed w/10 bbls Class G cement 8686'-8720' MD 4 spf 6614'-6637'TVD 8802'-8808' MD 4 spf 6690'-6694'TVD 8203'-8205' squeezed w/14 bbls Class G cement 8725'-8727' MD 6 spf 6632'-6634'TVD 27 PRODUCTION TEST , . Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GASoMCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) iPrass. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .-~:.. :.. ~:¢-~ '~:.'~ '!: ..;. ~ :...' . . . ,,., : ~. .~,,, : ,::. ;-, !',' :, ~,, : ..... ,. ,. ', ',;-t.: ¢,',. · ' ....... , ,, · Form 10-407 Submit in duplicate Rev. 7-1-80 ~INUED ON REVERSE SIDE 30. GEOLOGIC MARKE~ 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 8225' 6318' Bottom Kuparuk C 8405' 6433' Top Kuparuk A 8640' 6585' Bottom Kuparuk A 8812' 6696' Freeze protect annulus with diesel _IST OF ATTACHMENTS Dali), Operations Summar),, Directional Survey I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed 1~~ ~. ~ ..... Title 01~ [',l~lC,r,~:El/, DATE · , INSTRUCTIONS ~eneral' This form is designed for submitting a complete and correct well completion report and log on ill types of lands and leases in Alaska. r, em 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt rater disposal, water supply for injection, observation, injection for in~situ combustion. rem 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements jiven in other spaces on this form and in any attachments. tern 16 and 24: If this well is completed for separate production from more than one interval (multiple :ompletion), so state in item 16, and in item 24 show the producing intervals for only the interval reported n item 27. Submit a separate form for each additional interval to be separately produced, showing the :lata pertinent to such interval. tem 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). tern 23: Attached supplemental records for this well should show the details of any multiple stage cement- ng and the location of the cementing tool. .. , -. tem 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In.-.~ ,-'~.:'.. "~.. '..' '"' ection, Gas Injection, Shut-in, Other-explain. ":'~'"~ .tern 28: If no cores taken, indicate "none". .. ,.. '~ 10-407 ate: 3/28/96 ARCO ALASKA iNCORPORATED WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iQ-02A RIG:NO RIG WELL ID: AK8317 AFC: AK83!7 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ OM/ 1056M API NUMBER: 50-029-21248-01 12/28/95 (1) TD: 8035' PB: 8035' SUPV:DEB DAILY: 12/29/95 (2) TD: 8035' PB: 8035' SUPV:DEB DAILY: 12/30/95 (3) TD: 8035' PB: 8035' SUPV:DEB DAILY: 12/31/95 ( 4) TD: 6468' PB: 8035' SUPV:DEB DAILY: 01/01/96 ( 5) TD: 6468' PB: 6468' SUPV:DEB DAILY: 01/02/96 ( 6) TD: 6468' PB: 6468' SUPV:DEB DAILY: 01/03/96 (7) TD: 6273' PB: 6468' SUPV:DLW PREPARE TO KILL WELL MW: 0.0 Accept rig @ 0700 hrs. 12/27/96. Prepare well site. Prepare to kill well. $0 CUM: $0 ETD: $0 EFC: $0 POH LD 3-1/2" COMPLETION MW: 0.0 Pump mud to kill well. Well dead. Test BOPE. Test pipe rams & blinds to 250/3500 psi, annular to 250 psi & 3000 psi. Test mud cross, HCR, choke and kill lines, mud manifold, choke manifold, all floor safety valves to 250/3500 psi. Start to POH LD tubing. $0 CUM: $0 ETD: $0 EFC: $0 RIH W/CEMENT RET. PU DP MW: 0.0 POH LD 3.5" tubing & jewelry. Recovered all tubing & jewelry thru seal assembly from PBR on top packer. RIH w/cement retainer. $0 CUM: $0 ETD: $0 EFC: $0 NU BOPE MW: 0.0 RIH w/cement retainer. Set cement retainer @ 6468' MD. Test casing & retainer to 3500 psi for 15 minutes, no loss. OK. Pump cement to P&A well. CIP @ 1140, 12/30/95. 'C' & 'A' ssands abandoned, well to be sidetracked. ND tubing head and packoff and install modified packoff and tubing head. Test new packoff to 3000 psi for 15 minutes, OK. NU BOPE. $0 CUM: $0 ETD: $0 EFC: $0 CIRCULATING HOLE CLEAN MW: 0.0 NU BOPE. RIH with section milling assembly %1. Mill section from 6268' to 6309' MD. Hole getting sticky and packing off. Work pipe free. Continue working pipe and circulate until hole cleaned up and pipe moves freely. Continue milling section to 6318' MD. $0 CUM: $0 ETD: $0 EFC: $0 REVERSE CIRC. TO CLEAR DP MW: 0.0 Work & rotate pipe, circulate hole clean. Prepare for squeeze. Pump cement slurry for squeeze. $0 CUM: $0 ETD: $0 EFC' $0 POOH KO BHA MW: 0.0 CIP @ 0700 hrs. Est. TOC +/- 5875'. Hold pressure for squeeze for 2.5 hours. Clean out green cement from 6133' to 6273' 5' below 7" section window. POOH for kickoff assembly. ate: 3/28/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 DAILY: 01/04/96 ( 8) TD: 6521' PB: 6273' SUPV:DLW DAILY: 01/05/96 ( 9) TD: 6721' PB: 0' SUPV: DLW DAILY: 01/06/96 (10) TD: 6731' PB: 0' SUPV: DLW DAILY: 01/07/96 (11) TD: 7188' PB: 0' SUPV: DLW DAILY: 01/08/96 (12) TD: 7694' PB: 0' SUPV:DLW DAILY: 01/09/96 (13) TD: 7758' PB: 0' SUPV:DLW DAILY: 01/10/96 (14) TD: 8136' PB: 0' SUPV: DLW DAILY: 01/11/96 (15) TD: 8345' PB: 0' SUPV:DLW DAILY: $0 CUM: $0 ETD: $0 EFC: $0 WORK ON PULSATION DAMPENE MW: 0.0 RIH with test motor and MWD. Continue RIH w/kick off BHA to 6273'. Slide and sidetrack out of 7" section from 6273'. Run leak off test @ 6330' MD with 10.2 ppg mud weight. Pressured up slowly to 750 psi bleed back to 700 psi, 12.76 ppg EMW. Continue to directional drill 6-1/8" hole from 6330' to 6521'. Pulsation dampener went out on pump, unable to pump over 3 bpm. Pull back into casing shoe @ 6318'. Hole in good condition. Work on pulsation dampener. $0 CUM: ~$0 ETD: $0 EFC: $0 DRILL 6-1/8" @ 6700' MW: 0.0 Continue directional drill 6-1/8" hole from 6521' to 6590' sliding and rotating for build and direction. Slide from 6590' to 6600'. Lost pump pressure. Check for surface leaks. Slide from 6600-6620' Lost pump pressure. Looking for leak. Found pump to have washed out behind suction valve seat. Repair suction seat. Continue directional drill 6-1/8" hole from 6620' to 6721' $0 CUM: $0 ETD: $0 EFC: $0 RIH W/BHA %2 MW: 0.0 Continue directional drilling 6-1/8" hole from 6721' to 6731' POOH. RIH w/BHA %2. Work pipe but unable to get below 5840'. POOH. Change bit. RIH. $0 CUM: $0 ETD: $0 EFC: $0 DRILLING 6-1/8" HOLE @ 71 MW: 0.0 Make MAD pass with LWD fro 6580-6670'. Continue directional drilling 6-1/8" hole from 6731' to 7188' $0 CUM: $0 ETD: $0 EFC: $0 TRIP FOR BIT & TEST BOPS MW: 0.0 Continue to directional drill 6-1/8" hole from 7188' to 7694'. POOH for bit and test BOPs. $0 CUM: $0 ETD: $0 EFC: $0 DRILL 6-1/8" HOLE @ 7758' MW: 0.0 Test BOPs and manifold 300-3500 psi. RIH from shoe tight 6248' to 6368' push around window. RIH to 7654' Ream from 7654' to 7694'. $0 CUM: $0 ETD: $0 EFC: $0 DRLG W/6-1/8" HOLE @ 8136 MW: 0.0 Continue directional drilling 6-1/8" hole from 7758' to 8136'. $0 CUM: $0 ETD: $0 EFC: $0 TRIP IN HOLE W/BHA%5 MW: 0.0 Continue directional drilling 6-1/8" hole from 8136' to 8345' $0 CUM: $0 ETD: $0 EFC: $0 ate' 3/28/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page' 3 01/12/96 (16) TD: 8345' PB: 0' SUPV: DLW DAILY: 01/13/96 (17) TD: 8345' PB: 0' SUPV:DLW DAILY: 01/14/96 (18) TD: 7835' PB: 0' SUPV:DLW DAILY: 01/15/96 (19) TD: 7694' PB: 0' SUPV:DLW DAILY: 01/16/96 (20) TD: 8168' PB: 0' SUPV:DLW DAILY: 01/17/96 (21) TD: 8198' PB: 0' SUPV: WJP DAILY: 01/18/96 (22) TD: 8609' PB: 0' SUPV: WJP DAILY: STUCK PIPE @ 8017' MW: 0.0 RIH w/BHA %5. Started to take weight 25K. Ream 20' started packing off 2500 psi. Bleed off and work pipe. Stuck and unable to move string. Jar on stuck pipe. Jar down and torque pipe. No movement. RIH w/Free-point tool, stopped at 4850' POOH. Rerun free-point unable to get below 6313' POOH. $0 CUM: $0 ETD: $0 EFC: $0 STUCK @ 7853'-8017' MW: 0.0 RIH with string shot. Spot string shot across connection at 7853'. RIH with fishing BHA to 7840' Screw into fish @ 7853'. Torque up and jar on fish. Unable to move fish. $0 CUM: $0 ETD: $0 EFC: $0 3/5" DP O/E @7880' KICK 0 MW: 0.0 Continue to jar on stuck pipe @ 7853' with fishing BHA. Unable to move fish or establish circulation. Run string shot. Spot string shot at TOTCO ring @ 7815'. Fired string shot and made back off. Released torque from drill pipe got 2 rounds back. Work pipe free. POOH w/wire line. Recovered 1 monel DC's. Top of fish now 7883'. Bit @ 8017'. Total 134.02' lost in hole. RIH with O/E DP to 7880. Pump cement. CIP @ 0608 hrs. $0 CUM: $0 ETD: $0 EFC: $0 REAM TO TOP CEMENT MW: 0.0 Test BOPs and manifold 300/3500 psi. OK. RIH with 3.5" to 7665'. Try to establish circulation packing off with anything over 1 bpm. Work pipe rotate. Unable to get good circulation. Ream from 7464' to 7694'. $0 CUM: $0 ETD: $0 EFC: $0 DRILL 6-1/8" HOLE @ 8168 MW: 0.0 Continue to ream & clean out 6-1/8" hole due to packing off problem from 7694'-7738'. Firm cement @ 7738' At 7738' slide 140 deg right of high side to sidetrack well bore. To pass tools lost in hole from 7783'-8017' Rotate and slide for direction from 7894' to 8168' now sliding for direction. $0 CUM: $0 ETD: $0 EFC: $0 REAMING TO BOTTOM MW: 0.0 Drill 6-1/8" hole from 8168' to 8198'. RIH to 7402' . Could not pump - packed off. Kelly up. Establish circulation, pump bottoms up. Blow down and stand back kelly. Continue RIH to TD. Could not circulate at TD - packed off. POH to 7402', kelly up and establish circulation. Wash and rotate down singles. $0 CUM: $0 ETD: $0 EFC: $0 PREPARING FOR WIPER TRIP MW: 0.0 Wash and rotate singles to bottom. Drill 6-1/8" hole 8198' to 8609'. CBU, prepare for wiper trip to 8200' $0 CUM: $0 ETD' $0 EFC' $0 rte: 3/28/96 ARCO ALASKA iNCORPORATED WELL SUMMARY REPORT Page: 4 01/19/96 (23) TD: 8768' PB: 0' SUPV: WJP DAILY: 01/20/96 (24) TD: 8801' PB: 0' SUPV:WJP DAILY: 01/21/96 (25) TD: 9017' PB: 0' SUPV:WJP DAILY: 01/22/96 (26) TD: 9017' PB: 0' SUPV:WJP DAILY: 01/23/96 (27) TD: 9017' PB: 0' SUPV: WJP DAILY: 01/24/96 (28) TD: 9017' PB: 0' SUPV: DEB DAILY: 01/25/96 (29) TD: 9017' PB: 0' SUPV:DEB DAILY: WORKING STUCK PIPE MW: 0.0 Drill 6-1/8" hole from 8609' to 8768' . DP became stuck one joint off bottom while making connection at 8768' Will not move up or down and will not rotate, but circulation is OK. Appears differentially stuck. Work pipe (jarring up and down). Reduce mud weight while continuing to work pipe. Continue to reduce mud weight while working pipe. Pump SFT pipe-freeing agent down to BHA. Jar on pipe while pumping 1 bbl SFT from DP to annulus each hour. $0 CUM: $0 ETD: $0 EFC: $0 DRILLING 6-1/8" HOLE MW: 0.0 Jar on stuck pipe while pumping SFT. Work pipe free. Precautionary ream to bottom @ 8768' Drill 6-1/8" hole from 8768' to 8801' $0 CUM: $0 ETD: $0 EFC: $0 POH TO RUN 4-1/2" LINER MW: 0.0 Drill 6-1/8" hole from 8801' to 9017' . POH to run 4.5" liner. $0 CUM: $0 ETD: $0 EFC: $0 POH W/LINER SETTING TOOL MW: 0.0 Run 4.5" liner. Established circ at 2.5 bpm, 1000 psi to condition hole for cementing. Annulus packed off and pressure spiked to 3000 psi, setting liner top packer. No pick up, set down or circulation possible. Attempted to fail packer with up and down weight - no good. Not possible to cement or set liner hanger with packer set. Release from liner and POH with drill pipe and setting tool. $0 CUM: $0 ETD: $0 EFC: $0 RUNNING 4.5" COMPLETION Test BOPE. Run 4.5" completion. MW: 0.0 $0 CUM: $0 ETD: $0 EFC: $0 POH W/4.5" COMPLETION MW: 0.0 Continue to run 4.5" completion assembly. Test 7" x 4.5" annulus to 3500 psi, no good, liner top packer leaking. Test held 3500 psi for 10 minutes, then started bleeding off. Verified that all surface equipment was holding and verified tubing string integrity. Annulus bleeds from 3500 psi to +/-1000 psi in 3 to 4 minutes, but cannot keep pump on hole - minimal injection rate. No returns from tubing on annulus test. Tubing bleeds from 2500 psi to =/- 1000 psi in 5 to 6 minutes with slow returns from the annulus, but cannot keep pump on hole - minimal circulation rate. POH. $0 CUM: $0 ETD: $0 EFC: $0 RIH W/LINER TIEBACK/PKR A MW: 0.0 POH, stand back 4.5" tubing. RIH w/4.5" liner tieback/packoff assembly on DP. $0 CUM: $0 ETD: $0 EFC: $0 ~te' 3/28/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 5 01/26/96 (30) TD: 9017' PB: 0' SUPV:DEB DAILY: 01/27/96 (31) TD: 9017' PB: 0' SUPV:DEB DAILY' 01/28/96 (32) TD: 9017' PB: 0' SUPV:DEB DAILY: RUNNING 4.5" COMPLETION A MW: 0.0 Continue to RIH with 4.5" liner tieback/packoff assembly on DP, drifting DP with 2-1/8" rabbit, using DP bleeder plug to prevent flowback. Stab seal assembly into seal bore and locate out muleshoe at bottom of seal bore. Verify position & check seals with 500 psi on annulus, no return out DP. Set liner hanger. Pressure up to 3000 psi and set liner top packer, felt setting pins shear at 1800 psi, ball seat shifted at 3000 psi. Test annulus to 3500 psi for 15 minutes, lost 10 psi, OK. Top of liner @ 6055' MD. Re-run 4.5" tubing. Running slow to minimize flowback. $0 CUM: $0 ETD: $0 EFC: $0 CLEAN PITS & SECURE WELL MW: 0.0 Continue to run 4.5" completion assembly. Test annulus to 3500 psi for 15 minutes, lost 50 psi, OK. Test tree & packoff to 250 psi & 5000 psi. Freeze protect well. Secure well. $0 CUM: $0 ETD: $0 EFC: $0 RIG RELEASED Release rig @ 0730 hrs. 1/27/96. MW: 0.0 $0 CUM: $0 ETD: $0 EFC: $0 End of WellSummary for Well:AK8317 ARCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1Q-02A(W4-6)) WELL 1 Q-02A DATE 01/29/9 6 DAY 2 JOB SCOPE DRLG SUPPORT NON-STIM CAPITAL OPERATION COMPLETE I S~CCESSFUL KEY PERSON DAILY WORK PERF / SET CMT RETAINER YES YES -Fi~-a~ Initial Inner Ann Initial 'bgPress I DALLY SUMMARY I JOB NUMBER 1228951622.6 UNIT NUMBER SUPERVISOR BAILEY PAIGE FinallnnerAnn IlnitialOuterAnn IFinalOuterAnn 0 PSI 0 PSi 0 PSI PERF IN IP_.RVAL 8903'-8905' AND 8203'-8205' USING 3-3/8" HOLLOW CARRIER W/BH CHARGES, 6 SPF, & 60 DEG PH. UNABLE TO I SET CMl' RETAINERi COULD NOT GEl' ~UGE RING/JUNK BASKET BELOW 8875'. TIME 09:30 10:30 11:15 12:30 13:15 13:45 ' 14:30 15:00 15:30 16:00 17:00 17:15 . 17:45 18:30 19:00 19:15 20:15 21:00 22:00 =, LOG ENTRY MIRU SWS. HELD SAFETY MTG. PT LUB TO 3000~; TEST OK. RIH W/GUN#1 - WGT. BAR, PERF GR, 3-3/8" HOLLOW CARRIER W/BH CHARGES, 6 SPF, 60 DEG PH HAVING TROUBLE GE I lING BELOW 6598'; WILL STANDBY AND WAIT FOR DHP. APPEARS TO BE APPROX SAME DEPTH AS SEVERAL DAYS AGO. CLEANOUT OF MUD APPARENTLY DID NOT HAVE MUCH EFFECT A I ! I:::MPT TO PUMP DOWN USING DHP; IMMEDIATELY PRESSURED UP TO 3500#. UNABLE TO ESTAB CIRC; POH W/GUN#1 AT SURF W/GUN#1 RIH W/1-11/16" GR/CCL LOGGED F/TD TO 7800' (TIED INTO LINER DETAIL / ROP LOG); TD = 8943' POH W/TOOL S-I HING AT SURF W/-i-OOL S1 HING PT LUB TO 3000~; ~i--ST OK. RIH W/GUN#1 - CCL, 3-3/8" HOLLOW CARRIER W/BH CHARGES, 6 SPF, 60 DEG PH PUT 1000~ ON WH: FIRED GUN#1. PRESSURE INCR TO 1200~. POH W/GUN#1. AT SURF W/GUN#1 PT LUB TO 3000#; iESTOK. RIH W/GUN~2 - CCL, 3-3/8" HOLLOW CARRIER W/BH CHARGES, 6 SPF, 60 DEG PH PUT 1000~ ON WH. FIRED GUN#21POH W/GUN. AT SURF W/GUN#2 RIH W/WGT BAR, JUNK BASKET, 3.62" GAUGE RING UNABLE TO GET DEEPER THAN 8875' WITH JUNK BASKET; POH AT SURF W/TOOL S/HING RDMO. KUPARUK RIVER UNIT WELL SERVICE REPORT KI(1Q-02A(W4-6)) 1Q-02A DATE 08/11/96 DAY 23 JOB SCOPE JOB NUMBER RIG SIDETRACK, SIDETRACK SUPT 1228951622.6 DAILY WORK PERFORATE A2, A3, & A4 INTERVALS WITH 2 7/8" HSD, 4 SPF, 180 DEG. PHASING. OPERATION COMPLEFE { SUCCESSFUL YES YES Irfitial Tbg Press I Final TUg Press I 750 PSI 900 PSI DAILY SUMMARY 180 DEO PH. KEY PERSON SWS-BAILEY UNIT NUMBER SWS #8337 Initial Inner Ann Final Inner Ann I 0 PSI 0 PSI I SUPERVISOR PAIGE Initial Outer Ann [ Final Outer Ann 0 PSI! 0 PSI SHOT 'A' SAND PERF INTERVAL 8662'-867Y, 8676'-8681', 8686'-8720', & 8802'-8808' USING 2-7/8" HSD W/DP CHARGES, 4 SPF, AND TIME LOG ENTRY · 09:00 MIRU SWS #8337 W/BAILEY~FORMAN-NOLD. HOLD BUMPER SAFETY MEETING. 10:30 OBTAIN RADIO SILENCE AND ARM A 20' 2 7/8" CARRIER GUN WITH 11' AT 4 SPF, A 3' SPACER AND 5' AT 4 SPF. RIH WITH GUN AND CCL. 11:30 TIE-IN TO SWS GR/CCL DATED 29-JAN-96. 12:00 PUT 1500 PSI ON TUBING WITH TRIPLEX AND LOG INTO POSITION AT 8659.5' TO SHOOT FROM 8662' TO 8673' AND FROM 8676' TO 8681' AT 4 SPF AND 180 DEG PHASING. FIRED GUN AND WHP DROPPED TO 1300 PSI. FLAG LINE AT 8625'. POOH RUN gl. ' 1~:30 AT SFC, LAY DOWN GUN #1, SHUT DOWN OPERA~ON~ RUN TO ~ PAD AND CLEAN SLOP TANK AND SPOT ON PAD NEAR 2X-17 WHERE TRUCK WAS YESTERDAY. , 14:30 ARM 2 7/8" HSD 20' GUN, 4 SPF, 180 DEG PHASING. RIH. STOP AT FLAG AND ADJUST TO 8625'. DROP TO 8825' ANDFOUR COLLARS. 15:30 PUT 1500 PSI ON WELL WITH TRIPLEX AND LOG INTO POSITION AT 8684.5' TO SHOOT FROM 8686' TO 8706'. FIRED GUN AND PRESSURE DROPPED TO 1250 PSL REFRESH FLAG AT 8625'. POOH, 16:00 AT SURFACE. LAY DOWN GUN #2 AND ARM GUN #3, 14', 4 SPF, 180 DEG PHASED GUN. 17:30 PUT 15130 PSI ON TUBING WWITH TRIPLEX. LOG UP TO 8698.5' TO SHOOT FROM 8706' TO 8720' AT 4 SPF, 180 DEG PHASING. SHOT PERFS AND PRESSURE DROPPED TO 1380 PSI. POOH. ~ , 18:00 ~ OOHW1THGUN#3. LAY DOWN GUN #3. ARMGUN#4. RIH WITH 6' 4 SPF 2 7/8" HSD GUN. 18:35 19:45 CATCH FLAG AT 8625'. DROP DOWN TO TX).(8854'). APPLY 1500 PSI TO TUBING WITH TRIPLEX PUMP. LOG INTO POSITION AT 9796.5' AND SHOOT GUN. PRESSURE DROPPED FROM 1600 PSI TO 1400 PSI. POOH., AT SFC. START R/D. S__RRY-SUN DRILLING SERVICES ANCHOPJ%GE ALASKA PAGE ARCO ALASKA, INC KUPARUK/lQ- 2A 500292124801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 011896 MWD SURVEY JOB NUMBER: AK-MM-951269 KELLY BUSHING ELEV. = 78.00 OPERATOR: ARCO ALASKA INC FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS iNCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6288.00 5214.88 5136.88 45 7 N 51.55 E .00 1601.41N 2261.55E 6392.91 5284.15 5206.15 52 30 N 67.10 E 13.16 1640.91N 2329.33E 6488.19 5339.29 5261.29 56 46 N 69.79 E 5.03 1669.40N 2401.59E 6584.28 5390.33 5312.33 59 3 N 72.83 E 3.59 1695.46N 2478.70E 6678.25 5439.32 5361.32 58 17 N 84.72 E 10.83 1711.07N 2557.21E 2733.10 2811.31 2888.77 2969.53 3047.02 6771.53 5488.51 5410.51 58 4 N 89.79 E 4.62 1714.87N 26~6.34E 6869.35 5539.91 5461.91 58 31 S 88.10 E 1.89 1713.64N 2719.55E 6964.32 5589.36 5511.36 58 42 N 89.43 E 2.23 1712.70N 2800.60E 7057.98 5638.11 5560.11 58 33 N 86.64 E 2.55 1715.44N 2880.51E 7150.58 5686.29 5608.29 58 43 N 85.81 E .79 1720.65N 2959.41E 3119.91 3194.29 3266.86 3339.99 3413.29 7246.26 5735.94 5657.94 58 45 N 85.08 E .65 1727.14N 3040.94E 7340.70 5785.08 5707.08 58 31 N 86.50 E 1.31 1733.07N 3121.36E 7435.18 5835.53 5757.53 56 57 N 89.99 E 3.54 1735.53N 3201.19E 7532.01 5889.49 5811.49 55 18 N 88.26 E 2.25 1736.75N 3281.57E 7625.15 5943.71 5865.71 53 28 N 87.53 E 2.07 1739.52N 3357.23E 3489.53 3564.51 3637.45 3710.34 3779.67 7677.06 5974.84 5896.84 52 49 N 89.55 E 3.36 1740.59N 3398.75E 7755.40 6020.74 5942.74 55 25 N 88.71 E 3.44 1741.56N 3462.21E 7851.56 6074.90 5996.90 56 1 S 88.90 E 2.14 1741.68N 3541.66E 7949.80 6133.19 6055.19 51 10 S 85.89 E 5.51 1738.16N 3620.61E 8041.84 6192.08 6114.08 49 14 S 83.75 E 2.76 1731.79N 3691.03E 3817.51 3875.08 3946.65 4016.20 4076.83 8132.86 6251.37 6173.37 49 27 S 82.55 E 1.03 1723.55N 3759.59E 8229.02 6313.23 6235.25 ~0 26 S 83.04 E 1.09 i714.32N 3,332.~iE 8322.42 6372.68 6294.68 50 37 N 88.98 E 6.60 1710.60N 3904.51E 8418.17 6433.91 6355.91 49 52 N 89.98 E 1.12 1711.27N 3978.11E 8546.11 6516.22 6438.22 50 2 N 87.68 E 1.38 1713.27N 4076.02E 4134.97 4196.70 4259.81 4326.37 4415.38 8640.84 6577.46 6499.46 49 24 S 89.93 E 2.04 1714.70N 4148.26E 8768.00 6660.20 6582.20 49 24 S 89.93 E .00 1714.58N 4244.82E 9017.00 6822.21 6744.21 49 24 S 89.93 E .00 1714.35N 4433.91E 4481.05 4567.93 4738.07 THE CALCU~TION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4753.79 FEET AT NORTH 68 DEG. 51 MIN. EAST AT MD = 9017 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 64.20 DEG. TIE IN POINT 6288' INTERPOLATED DEPTH 9017' S ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC KUPARUK/1Q-2A 500292124801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 011896 JOB NIIMBER: AK-MM-951269 KELLY BUSHING ELEV. = 78.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTIC~L DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6288.00 5214.88 5136.88 1601.41 N 2261.55 E 1073.12 7288.00 5757.58 5679.58 1730.21 N 3076.50 E 1530.42 457.30 8288.00 6350.80 6272.80 1710.81:N 3877.93 E 1937.20 406.78 9017.00 6822.21 6744.21 1714.35 N 4433.91 E 2194.79 257.60 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S. ~{RY-SUN DRILLING SERVICES ~'~-_NCHORAGE ALASKA PAGE ARCO ALASKA, iNC KUPARUK/lQ- 2A 500292124801 NORTH SLOPE BOROUGH COMPUTATION DATE: 2 / 20 / 96 DATE OF SURVEY: 011896 JOB NUMBER: AK-MM-95!2S9 KELLY BUSHING ELEV. = 78.00 FT. OPER3~TOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 6288.00 5214.88 5136.88 1601.41 N 2261.55 E 1073.12 6382.95 5278.00 5200.00 1637.72 N 2322.18 E 1104.95 31.83 6560.52 5378.00 5300.00 1689.32~N 2459.34 E 1182.52 77.57 6751.64 5478.00 5400.00 1714.63 N 2619.45 E 1273.64 91.11 6942.45 5578.00 5500.00 1712.52 N 2781.91 E 1364.45 90.81 7134.60 5678.00 5600.00 1719.65 N 2945.79 E 1456.60 92.16 7327.13 5778.00 5700.00 1732.36 N 3109.81 E 1549.13 92.53 7511.82 5878.00 5800.00 1736.24 N 3264.97 E 1633.82 84.69 7682.32 5978.00 5900.00 1740.63 N 3402.96 E 1704.32 70.50 7857.03 6078.00 6000.00 1741.57 N 3546.16 E 1779.03 74.71 8020.27 6178.00 6100.00 1733.57 N 3674.79 E 1842.27 63.24 8173.87 6278.00 6200.00 1719.52 N 3790.51 E 1895.87 53.59 8330.81 6378.00 6300.00 1710.72 N 3911.00 E 1952.81 56.95 8486.60 6478.00 6400.00 1711.46 N 4030.44 E 2008.60 55.79 8641.67 6578.00 6500.00 1714.70 N 4148.89 E 2063.67 55.07 8795.36 6678.00 6600.00 1714.56 N 4265.60 E 2117.36 53.69 8949.06 6778.00 6700.00 1714.41 N 4382.31 E 2171.06 53.69 9017.00 6822.21 6744.21 1714.35 N 4433.91 E 2194.79 23.74 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVA_~TVRE) POINTS 0 !=! I I_1._ I N 13 WELL LOG TRANsMrITAL . To: State of Alaska August 20, 1996 Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 c~ ~-- [~ t4 RE: MWD Formation Evaluation Logs - 01Q-02A PB 1 AK-MM-951269 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.' /Inn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Gamma Ray and Resistivity Logs: 2" x 5" TVD ~ Ray and Resistivity Logs: 1 Blueline 1 Blueline 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Howard 0kland 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ff" 1~ q ::}F ? ) ~[ ~' MWD Formation Evaluation Logs - 01Q-02A PB 1 AK-MM-95 I269 August 15, 1996 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.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. AUG 2 1 199,-$ ,, ,,:, ~,~e~ Cons. C~mm~$sim~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Date' July 1.6, 1996 Transmittal #: 9723 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 F- 17 Cement Bond Log 06/29/96 6050-6748 1 F- 18 Cement Bond Log 06/29/96 7794-7799 1Q-02A Cement Bond Log 06/26/96 7900-8680 2M-09A Cement Bond Log 06/30/96 4900-9292 Acknowledge' Date: DISTRIBUTION: RECEIVED duLi 8 1~96 Sharon AIIsup-Drake DS Development . ATO~I 205 Larry Graht (+sepia) ; AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Chapman/Zuspan NSK Wells Group NSK69 CONSERVATION COMMISSION March 18, 1996 William S. Isaacson Drilling Engineer Kupamk Drill Site Development ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 ?-z - 079 Requested annular disposal of cement washdown water from coiled tubing cement squeezes Dear Mr. Isaacson: The Commission has received your request for authorization for disposal of cement washdown water from cement squeeze operations in the annuli of wells currently being utilized by Parker Rig #245. The washdown water would be generated by cement squeeze operations on the following wells: 1Q-02A, 1Q-20A, 1 Q-22, and 2M-09. Disposal would take place into the annuli of wells being used by Parker Rig #245 on drill sites 1F, 2A, or 2M, for which annular disposal has already been authorized. ARCO Alaska, Inc. (ARCO) must demonstrate that complying with the limitation of disposal through the annular space of a well on the same pad is imprudent. There are annuli available for disposal on the lQ pad. The cement squeeze operations will each generate an estimated 30-50 bbls of water and 1 bbl of cement. Grind and inject facilities are not required for disposal of the cement washdown water generated during these squeeze operations. Pending submittal of information that it is imprudent not to do so, the Commission denies the request by ARCO Alaska, Inc. to dispose of cement washdown water from the 1Q-02A, 1Q-20A and 1Q-22 wells in the annuli of wells not located on lQ pad. The cement washdown water from these wells may be either injected into annuli on the lQ pad, or disposed of in a Class I well. The Commission also suggests the cement washdown water from the 2M-09 well be temporarily stored and disposed of when Parker Rig #245 is conducting annular injection operations on the 2M pad. As an. alternative to storage, the cement washdown water from the 2M-09 well may also be disposed of in a Class I well. Chairman J. David Norton, P.E. Commissioner ITuckennan Babcock Commissioner !996 9'50AM ARCO ALAS[iA INC No. 80?5 P. 2/2 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-03;0 Te;$phon$ 907 276 1215 qz - Mr. David W. Johnston, Chairman Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 /90~ 279-1433 90 276-7542 (fax) Re: Annular Disposal of 'Drilling Wastes' for '-r'H~, o~. Cement Squeeze Operations on KRU Wefts 1Q-02A, 1Q-20A, 1Q-22, and 2NI-09 Gentlemen: ARCO hereby requests a waiver to the AOGCC Regulations covering Annular Disposal of Ddlling Waste recently adopted by the Commission on January 31, 1996. This waiver is requested to cover ARCO's cement squeeze operations on wells 1Q-02A, 1Q-20A, 1Q-22, and 2M-09. Each of the lQ wells were recently drilled and completed. Due to difficulties in the cementing portion of the drilling operations, cement squeezes will be necessa~, prior to bringing the wells on service. Well 2M-09 is currently planned for sidetrack operations and a cement squeeze is necessary in order to plug and abandon the existing wellbore. The waiver being requested is to Sect]on (d), Part (4) of 20 AAC 25.080., which limits the annular disposal of drilling waste, to ddiling operations on the same ddll pad as the annulus being injected into. ARCO requests the AOGCC grant permission to allow cement wash-water generated from cement squeeze operations on the aforementioned wells, be injected into the annulus being used at that time by Parker #245 on ddll site 1F, 2A, or 2M. We appreciate your consideration of this request. If you have any questions or require any additional information on this matter, please contact me at 263-4622. Sincerely, h, William S. Isaacson Drilling Engineer Kuparuk Drill Site Development A~CO Al.~k% Inc. is a Subaidiary of AQsnQcEichfiel(ICompaay i996 9'50AM ARCO ALASKA ARCO Alaska, Inc. dl FACSIMILE ._T_R_ ANSMISSION Number of Pages (Cover +): No. 807,5 ?. i/~ I II I II I II · I II ! Il I II I I! I II I II · ii I II I II I II II II II II II Ii II II II II II II II .! !! ....... il II II Il I! II .......... I1 II !1 II II II Ii II II II n II II II II II Ii II II II I! !! !! . B. From: Phone: Location: 13'~ LL Location: Ao(.-cc Copies To: _J FAX #: Phone #: Kuparuk Drill Site Development P. O. BOX 100360 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATO-1209 Subject: Comments: Co~ [.R 3ATT. O 14 . MEMORANDUM TO: /- David J o..b~, Chairman' THRU: Blair Wondzell ~- -~' P. I. Supervisor '~/~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 28,1995 FILE NO: aaull2cd.doc FROM: John Spaulding,~=.¢ SUBJECT: Petroleum insp.~--~oi~,, BOPE Test .,Nordic 1 ARCO KRU 1Q-2/~ Kuparuk River Field PTD 95-194 Thursday December 28, 1995: I traveled this date to ARCO's Kuparuk River Field to witness the BOPE test on Nordic rig 1. The AOGCC test report is attached for reference. I noticed during the test that while the hydraulics were able to pressure up the system adequately there seemed to be some time lag. Upon further inspection it was noted that the accumulator hydraulic reservoir was extremely Iow on fluid and needed re-filling. The hydraulic 'system was checked for leaks and none were found. The test went well with no failures observed. Summary; I witnessed the BOPE test on Nordic rig 1 with no failures, 3.5 hours test time. Attachments: aaull2cd.doc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: X Nordic Rig No. 1 PTD # 95-194 Rep.: Rig Rep.: 8119' Location: Sec. ARCO 1Q-2 '~ Set @ Weekly Other DATE: 12/28/95 Rig Ph.# 659-7115 Shawn McKeirnan Don Breeden 26 T. 12N R. 9E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok Quan. Test Press. P/F 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 250/3,500 P 25O/3,5O0 P 250/3,500 P N/A MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quart Pressure P/F N/A N/A 1 250/3,500 P 1 250/3, 500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 250/3, 500 P 26 250/3, 500 P 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 3 @ 2150 Average 3,000 P 2,150 P minutes 39 sec. minutes 52 sec. Remote: X' Psig. ~-:--.~ TEST RESULTS Number of Failures: 0 ,Test Time://3.5,) Hours. Number of valves tested 16 Repair or Replacement of Failed --quipment will be made within 0 ~. Notify the Inspector and follow with Written or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: resumed testing. Accumulator hydraufic off storage tank was Iow on fluid aflowing air into the hydraulic system. Filled and'"" Distribution: orig-Well File c - Oper./Rig c - Database c- Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AAU LL2CD.XLS ALASKA OIL ~ GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 18, 1995 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-036 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 1Q-02A ARCO Alaska, Inc. 95-194 1206'FNL, 1175'FEL, Sec. 26, T12N, R9E, UM 638'FSL, 3188'FWL, Sec. 24, T12N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to re-ddll the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W ~ohnston ~ Chairman~ BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMIS,b, ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X lb Type of Well Exploratory ~'~ Stratigraphic Test [] Development Oil X Re-Entry r~ Deepen ~] Service D Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF er KB) 10. Field and Pool ARCO Alaska, Inc. RKB 78', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designation_.2.. ~,,~d_ Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL,~T~'3, ~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1206' FNL, 1175' FEL, Sec. 26, T12N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 597' FSL, 2554' FWL, Sec. 24, T12N, RgE, UM 1Q-02A #U-630610 At total depth 9. Approximate spud date Amount 638' FSL, 3188' FWL, Sec. 24, T12N, R9E, UM 12/30/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'I'VD) property line 1Q-03 8962' MD 597' @ Tarcjet feet 60' @ surface feet 2560 6816' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 6284' feet Maximum hole angle 59.7° Maximum surface 2606 psig At total depth (TVD) 3300 psig 18. Casing program Settin9 Depth size Specifications Top Bottom Quantit),. of cement Hole Casing Weight Grade Coupling Length MIl TVD MD 'I'VD (include sta~le datat 6-1/8" 4-1/2' 12.6# L-80 NSCT 2832' 6130' 5111' 8962' 6816' 378sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 8576 feet Plugs (measured) 1995 true veflical 6 91 3 feet oEC -- 1 Effective depth: measured 8 03 5 feet Junk (measured) ~ 0il & Gas Cons. Com~ true vertica 6511 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 6 3' 1 6 ' 240 Sx CS II 10 0' 10 0' Surface 3793' 9-5/8' 1000 sx CSIII, 420 sx Cell 3830' 3520' Intermediate Production 8082' 7 ' 550 sx Class G, 250 sx CS I 81 19' 6576' Liner Perforation depth: measured 7577'-7591', 7767'-7837', 7896-7906' MD true vedical 6166'-6176', 6311'-6363', 6408'-6415' TV• 20. Attachments Filing fee X Property plat E~ BOPSketch X Diverler Sketch D Drilling program X Ddlling fluid program X Time vs depth plot ~ Refraction analysis ~ Seabed report D 20 AAC 25.050 requirements X 21. I hereby certif~that the for~)going is true and correct to the best of my knowledge Signed Yt'~ (~7/ Title Drill Site Develop. Supv. Date / " ( ~ / ~ Commission Use Only Permit Number . v L~API number ___ .. ~ Approval date~ ~ ~ I See cover letter for ~'--",,,/~'~,/ I 50-~)~.,~ -.~--/,,,,.~- ~' ~;~-' 4:~ / I /r-~ "/~'-~-~I other requirements Conditions of app"roval Samples required E] Yes '1~ No Mud Icg required ~ Yes J~ No Hydrogen sulfide measures ~] Yes I--I No Directional survey required [] Yes I--! No Required working pressure for BOPE ~] 2M [] 3M E] 5M [~] 10M D 15M Other: ~]~!~i'i~)Signed By VtL Johnston " by order of Approved by Commissioner the commission Date Fnrm 1(I-4A1 Fl~.v 7-P4-R.q R.hmit~ in trinlir.,3t~ REDRILL PLAN SUMMARY Well 1Q-02A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Injector 1206' FNL, 1175' FEL, SEC 26, T12N, R9E, UM 597' FSL, 2554' FWL, SEC 24, T12N, R9E, UM 638' FSL, 3188' FWL, SEC 24, T12N, R9E, UM 8962' 6816' Nordic Rig 1 12-30-95 15 Drill Fluids Program: Milling Section in 7" casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.5 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to wei~lht up 9.4-9.8 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Bariod Model 2 Tandem Shale Shaker Swaco 6 cone desilter Triflow vacuum Degasser, Poor Boy Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators RECEIVED OEC - 1 1995 Alm~m Oil & G~ Oons. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/'rbg 4-1/2", 12.6#, L-80, NSCT Tubing 4-1/2", 12.75#, L-80, EUE Length To.D (MD/TVD) Btm {MD/I'VD 2832' 61307 5111' 8962? 6816' 7760' 22'/22' 6130'/5111' Cement Calculations: Casino to be cemented: 4-1/2" in 6-1/8" open hole Volume = 378 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 60%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,606 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3300 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,606 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards- Lost Circulation: Overpressured Intervals: Other Hazards: The well will kick off out of the 7" Casing +/-250' TVD below the K-10 and +/-450' above the K-5 interval. These intervals are suspect lost circulation zones throughout the field, however recent infill drilling on lQ Pad did not encounter lost circulation in this area. Well 1Q-22 was ddlled to the immediate north of 1Q-02A and 1Q-23 was ddlled to the immediate south.' 1Q-23 was ddlled with 11.5 ppg mud without any loses and lQ- 22 held 12.4 ppg mud without any problems. The kick-off point in 1Q-02A is below any zones which would be of pressure concern pdor to weighting up for the Kuparuk interval. None Directional' KOP: Max hole angle: Close approach: 6284' MD / 5215' TVD 59.7° (in sidetrack portion) No Hazards RECEIVED OEC - 1 1995 Naska 0~1 & C-as Cons. C~lmissi~ Anchorage Page 2 Logging Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL/CBT Notes': Incidental fluids developed from ddlling 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. RECEtV L) OEC - 1 1995 Page 3 KRU 1Q-02A GENERAL SIDETRACK PROCEDURE PR . . E-RIG WORK: RU coiled tubing unit. RIH and clean out fill to 50' below A Sand perfs. Place a balanced cement plug from 50' below the A Sand to the tubing tail (+/-68' above top A Sand perf). RU slickline unit. RIH and dummy off all GLMs, leave deepest GLM open. Pull dummy valves from all C Sand mandrels leaving open pockets. 3. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH laying down all tubing and jewelry. 5. RU E-line unit. RIH with cement retainer and set at 6480' MD-RKB (200' below top of proposed section in 7" casing). . PU DP and RIH to cement retainer. Pump cement squeeze below retainer into C Sand perfs filling 7" casing to top of bottom packer. Unsting from retainer and spot 3 bbl cement on top of retainer. Circulate well to milling fluid. POOH standing back DP. 7. RIH w/section mill. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in the 7" casing from 6280'- 6330'. POOH w/mill. . RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. POOH. . RIH w/6-1/8" bit, mud motor, MWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. 10. Run 4-1/2" liner to TD w/150' of overlap to top of milled section. 11. 12. Cement liner. Set liner hanger and liner top packer. POOH w/DP. Pressure test casing and liner lap to 3500 psi for state test. Page 4 RECEIVEI 0£0 - 1 1995 Oil & Gas Coos. Commissio~ Anc~e 13. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate.. Test tubing and annulus. 14. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 15. Clean out well to PBTD w/coiled tubing. Run Cement Bond Log and Perforate through tubing. Lower Limit: Expected Case: Upper Limit: 13 days 15 days 19 days No problems milling section, drilling new hole, or running completion. Difficulties encountered milling section, or drilling new hole. WSI 11/30/95 Page 5 RECEIVED DEC - 1 995 Alas~ Oil & Gas Cons. Com~ Anchorage KOP - SIDETRACK PT TVD=5214.88 TMD=6284 DEP--2753.13 45.12 DEG N 51.55DEG E NORTH 1601.41 EAST 2261.55 ARCO ALASKA, Inc. Structure : Pad lQ Well : 2A Field : Kuparuk River Unit Location : Norlh Slope, Alaska ID LOCATION: 638' FSL, 3188' FWL SEC. 24, T12N, R9E ~o,~ ~ · ~.oo E a s f 21OO 2250 2400 2550 2700 2850 3000 3150 3300 3450 3600 3750 3900 4050 4200 4350 4500 [ I I I t } I I ] I I I I I I I I t i I I I I I ! I I I I I I I I I .2250 - _2100 N 64.2 DEG E ~~ ~ - 4142' (TO TARGET) // '~ "k · **P~NE OF PROPO~L**. ~ ~~ ¢~ I 4950_ ~ &. ~ 1500 TARG~ LOCATION: ~:oo ~ -~ ,~o ~ KOP - S~D~CK PT WD=5215 TUD:6284 DEP=2733 SEC. 2 525O ' X 47''0 .D=6244 - TMD=8107 .... 49.56 DER=4142 ~Created by : jone~ FOr: ~ ]S~CSON' 6 / 1~' aLS 5~0_ ~ 52.~5 ~O~H _L~3 iDote plotted: 8-Nov-95 ~ ' Plot Reference is ~ V~ion ~7. X ~ ,True Ve~icol Depths o .... t ...... RKB (NorOic~l). 5700 MAXIMUM ANGLE ~ ~&~ ANGLE DROP ~D=5900 TM0=7524 DEP=3707 59.66 DEG ~ ~ -~o:~ .~z k ,oo. 6150_ TARGET - T/ UNIT D ( so.oo K-] ~=6~75 UD=8002 DEP=4068 6300_ - -~TMD~621~ DFP=4496 x 7/ UNII A ~D-8562 1MD-8585 DEP-4469 ~ r/ A3 INIERVAL ~D=6588~IMD=8621 DEP= 496 ~ - - - 6750~ s~ooJ ~ OI & Gas ~s. ~mm~ ~o~o_ ~~e TARGET ANGLE 48 DEG I I I I I i I I I I I [ I I I i I ! I I I ~ I ~ i I I t I I ~ I 2550 2700 2850 ~000 3150 3S00 3450 ~600 3750 3900 4050 4200 4350 4500 4650 4800 4950 Scole 1 : 75.00 Vedicel Secfion on 64.20 ezimufh wifh reference 0.00 N, 0.00 E from slof ~2A 7-1/16" 5000 PSI BOP STACK PIPE RAM I L__ 5 BLIND RAM> I MUD CRO~4 I ' 3 PIPE RAM J I ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT 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 TO250 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. CLOSE TOP 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 BO~-FOM PIPE RAMS. TEST Bo%roM 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 LINES 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. 1.11" - 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - $000PSI 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 RECEIVED OEC - 1 1995 Alaska 0il & Gas Con~. ~u.~lr,ssion Anchorage NORDIC /ZIG # ! LEVEL 3 la..} ~ ST[AU COlt. U ' II PIPE DOOR" l I io CH~U4G£ 3(Y' WAUCWAY P'[L~ PT.'T $ NORDIC RIG #! LEVEL 2 ,~',' uIX },IOU.~ .PUM~-I MUD ROOM , i i'" ' I 150 II II II /- ,'"' "~ II .' [,,,-,,~_ I I ~ "I I SHAKER PiT MUD P~ 150 B~ . , ,- , . , , . . ' FUEl. TANK 7~00 O~S .':. : ,; ':,,. :~ .-. . ... : ·..:. ;-:.' .~ ~. , STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COMMI;::,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc, . 3. Address P. O. Box 100360, Anchorage, AK 99510 Abandon ..~ Suspend Operation Shutdown Re-enter suspended well Alter casing _ Repair well_ Plugging ..~ Time extension Stimulate Change approved program_ Pull tubing _ Variance Perforate _ Other X -' 6. Datum elevation (DF or KB) 4. Location of well at surface 1206' FNL, 1175' FEL, Sec. 26, T12N, R9E, UM At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service Plugback for Reddll RKB 90', Pad Elev. 53' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Q-02 9. Permit number 84-232 10. APl number 50-029-21248 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 909' FSL, 1738' FVVL, Sec 24, T12N, RgE, UM At effective depth 1118' FSL, 2006' FWL, Sec. 24, T12N, R9E, UM At total depth 1336' FSL, 2295' FWL, Sec. 24, T12N, R9E, UM 12, Present well condition summary Total Depth: measured 8576' feet - (approx) true vertical 691 3' feet Plugs (measured) Effective depth: measured (approx) true vertical 8035' 6511' feet Junk (measured) feet None 13. Casing Length Structural 6 3' Conductor Surface 37 9 3' Intermediate Production 72 87' Uner Perforation depth: measured 7577'-7591 ', true vertical 6166'-6176', Size 16' 9-5/8 · 7' 7767'-7837', 6311'-6363', Cemented 240 Sx CS II Measured depth True vertical depth 100' 100' 1000 sx CSIII & 3830' 3520' 420 sx CS II 550 sx Class G 81 19' 6576' sx cs,RECEIVED 7896'-7906' 6408'-6415' Description summary of proposal OEC - 1 1995 Alaska Oil & Gas Cons. Com~ An~orage Detailed operation program__ BOP sketch Tubing (size, grade, and measured depth) 3-1/2', J-55, @ 7699' MD Packers and SSSV (type and measured depth) Baker FB-1 @ 7669'~ BAKER FHL @ 7392'~ Baker FVL SSSV @ 1792' Attachments 14. Estimated date for commencing operation December 20, t99.5 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service 17. I hereby certify pat t.~he forgoing is true and correct to the bes! of my knowledge. Sic, lned ,///{ ~.-~/~~J~'//[ Title Drill Site Development Supervisor (_ .~. ~k FOR COMMISSION USE ONLY Conditions of approval: '~-ot~fy Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- Date IApproval No. I Approved by' the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE KRU lQ-02 SUNDRY OBJECTIVE to P & A WELL FOR SIDETRACK OPERATIONS (reference attached plugback schematic) PRE-RIG WORK: .: 1. RU coiled tubing unit. RIH and clean out fill to 50' below A Sand perfs. Place a balanced cement plug from 50' below the A Sand to the tubing tail (+/-68' above top A Sand perf). 2. RU slickline unit. RIH and dummy off all GLMs, leave deepest GLM open. Pull duminy valves from all C Sand mandrels leaving open pockets. 3. Set BPV in tubing. Install VR plug in annulus valve if necessary. WORKOVER RIG WORK: 1. 2. 3. 4. 5. , . , MIRU Nordic Rig. La? hard-line to tree. Pull B PV and VR plug. Load pits w/kill weight mud. Circulate well to kill weight mud. Ensure well is dead. ND tree. NU and test B OPE. Screw in landing joint. POOH laying down all tubing and jewelry. RU E-line unit. RIH with cement retainer and set at 6480' MD-RKB (200' below top of proposed section in 7" casing). PU DP and RII-I to cement retainer. Pump cement squeeze below retainer into C Sand perfs filling 7" casing to top of bottom packer. Unsting from retainer and spot 3 bbl cement on top of retainer. Circulate well to milling fluid. POOH standing back DP. RIH w/section mill. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in the 7" casing from 6280' - 6330'. POOH w/mill. RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. WSI 11/28/95 oEC - 1 1995 Alaska C81 & Gms Cons. commission Milling Fluid 1Q-02 Proposed P' gback AP! #: 50-029-21248 RKB = 90' GL= 53' 9-5/8" 36#, J-55 set @ 3830' MD 17.0 ppg Cement Kick-off plug 6080'- 6430' MD 7" Casing section milled 6280' - 6330' MD 18.0 ppg Mud from 6430' - 6480' MD. 7" Baker 'K-I' Cement Retainer @ 6480' MD with cement squeezed below retainer down to bottom packer. Abandoned C Sand Perfs Abandoned A Sand Perfs 7", 26#, J-55 3-1/2" x 7" Baker 'FHL' Retrievable production packer w/PBR bbi @ 7392' MD. RECEIVED Top perforation @7577' MD Bottom perforation @ 7591' MD 3-1/2' x 7" Baker 'FB-I' Permanent packer @ 7669' MD. OEC - 1 1995 Alaska Oil & Gas Co~s. Commission An~orage A Sand Perfs isolated by cement plug from tubing tail at 7699' to +/-7956' MD. Top perforation @7767' MD Bottom perforation @ 7906' MD Top of fill at +/-7956' MD. PBTD =8035' MD TD = 8576' MD WSi 11/29/95 WELL PERMIT CHECKLIST CC~.Z~'~y PROGRAM: exp [] dev [] redr!l~ serv [] ON/OFF SHORE ADMINISTRATION 1. 2. 3. 4. 5. 7. 8. 9. 10. !1. 12. 13. Permiu fee attached .................. Lease n'umber appropriate ............... Y Unique well name and number .............. Y r 1~ . ~e_~ located ±n a defined ~coi ............. Well located proper distance from dr!g unit boundary. . v Well located proper distance from other wells ..... Y Sufficient acreage available in drilling unit ..... v If deviated, is we!!bore plat included ........ Operator only affected par~-y .............. Operator has appropriate bond in force ......... Permit can be issued without conse~;ation order .... Permit can be issued without administrative approval. . Can per, it be approved before !5-day wait ....... ENGINEERING REMARKS "GEOLOGY '' :'' 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. !7. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... ~/~n~ 26. BOPE press rating adequate; test to ,m~~u~ psig. k~/ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ........ 29. Is presence of H2S gas probable ............ 30. Permit can be issued w/o hydrogen sulfide measures 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Contact name/phone for weekly progress reports . . [exploratory only] Comments / Instructions: HOW/lib - A:~FORMS%cheklist rev 11/95 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. Memory Multi-Finger Caliper Log Results Summary t ~r.-lqY / U \0 it Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. September 23, 2005 6530 1 4.5" 12.6 lb. L-80 Tubing & Liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log IntvI1.: 1 Q-02A Kuparuk Alaska 50-029-21248-01 Suñace 8,546 Ft. {MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: S(;A~N!ELJ OCT $ 120D5 This caliper data is tied into the IIr' Nipple @ 7,975' (Driller's Depth). This log was run to assess the condition of the 4.5" tubing and liner with respect to corrosive and mechanical damages. The 4.5" tubing appears in good condition, with no wall penetrations in excess of 20%. The 4.5" liner logged appears to be in good to fair condition with respect to corrosive damage, with the exception of 41 % wall penetration in joint 262 (8,415'). The damage recorded in the liner appears mainly in the form of isolated pitting in a few joints. Perforation intervals are recorded in joints 256 (8,203'-8205') and 261 (8,369'- 8,384') of the liner interval logged. Buildup is recorded in Joints 263, 264, and 265 of the liner, with a minimum I.D. of 3.47" in joint 264.(8,463'). No significant areas of cross-sectional wall loss are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are 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: Isolated Pitting Isolated Pitting Isolated Pitting Isolated Pitting ( 41 %) ( 23%) ( 21 %) ( 21%) Jt. Jt. Jt. Jt. 262 @ 260 @ 263 @ 264 @ 8,415 Ft. (MD) 8,333 Ft. (MD) 8,459 Ft. (MD) 8,464 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wa~lloss (> 13%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Buildup Buildup Buildup Minimum I.D. = 3.47" Minimum I.D. = 3.53" Minimum I.D. = 3.73" Jt. Jt. Jt. 264 @ 263 @ 265 @ 8,463 Ft. (MD) 8,455 Ft. (MD) 8,505 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing and liner logged. I Field Engineer: N. Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I PmActive Diagnostic Services, Tne. I P.O. Box 1.369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (281) 565-1369 E-mail: PDS@rnemorylog.com Prudlloe Bay Field Office Pl1one: (907) 659-2307 Fax: (907) 659-2314 Well: Field: Company: Country: 1 q..o2A Kuparuk ConocoPhiliips Alaska, inc. USA Survey Tool Type: Tool Size: No. Qf Fingers: Fg: Weight 12.6 f Nom.oD 4.5 ins L-80 3.958 ins Penetration and Metalloss (% wall) penetration body 150 100 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 3 1 2 0 0 Damage Configuration ( isolated general line ring pitting corrosion corrosion Nom. Upset 4.5 ins Damage Profile (%w¡:dl) 50 2 Bottom of Survey = 266 I Analysis Overview page 2 REPORT JOINT TABULATION Pipe: Body Wall: Upset Wall: Nomina! 1.0.: 4.5 in 12.6 ppf L·80 0.271 in 0.271 in 3.958 in Company: Country: Survey Date: 1 Q-02A Kuparuk ConQcoPhillips Alaska, Inc. USA September 23,2005 I Joint Jl Dep~~ Pen. PE'e. i ,Vtetal Min. Profile No. (Ft.) Body 1.0. Comments I (Ins.) (I ns. ) 0 100 ~L_._. -20 r 0.01 ¡ 3.89 PUP 1 -17 0.03 ? :2 3.88 Shallow oittiml.. 2 27 0.03 3.86 3 56 0.03 3.88 4 90 0.03 ') 3.89 ittil1Q. 5 121 0.04 3.89 ittim!. 6 152 0 0.03 ? 3.88 ittimz. 7 185 m 3.86 ittimz. 8 217 0.02 1 3.88 9 248 0.03 1 3.88 Shallow Dittim!. _10 279 4 13 :2 3.89 Shallow Dittim~. __ 11 310 0.03 11 1 3.88 12 341 0.04 15 =H=HH ittim~. 13 372 0.03 10 14 403 0.ü2 7 15 435 0.03 1 1 15.1 466 0.01 3 PUP -- 15.2 472~ I 0 DB Nirmle 15.3 474 ", 1 PUP 16 480 0.02 1 17 ')11 0.03 ! I--.JJL ')43 0.03 19 '17') 0.03 20 606 0 0.03 i~ 21 637 0 0.03 22 668 0 0.04 Shallow oittinQ. 23 701 '0 0.02 24 733 0 0.ü3 '1 Shallow oittinQ. 25 764 ¡ 0.ü3 [) ~...... 795 0.ü3 Shallow DittinQ. 27 ~7 0.03 Shallow Dittir1\!. 859 0.05 7 Shallow DÎuinQ. 29 89 0.03 1 30 922 0.03 1 89 Shallow Ditting. 31 953 0.04 1 39 Shallow Ditting. 32 I 984 0.03 11 38 33 r 1016 0.04 Shallow pitting. 34 1047 0.02 35 1079 0.03 Shallow Dittim~. 36 1110 I n 0.03 It 37 1141 0.03 ~ 1173 0.03 1 P Shallow Dittim~. 1205 0.03 1237 0.03 . Dittim~. 1268 0.ü3 Shallow Dittim~. 42 1299 0.02 43 1331 0.03 Shallow nittim!i. !'I 44 1363 0.03 !'I 45 1393 0.04 Shallow oittim~. !'I 46 1425 0.03 1 I Shallow oittimz. !'I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: CompanY: Country: Survey Date: 1Q"()2A Kuparuk ConQçoPhillips Alask~ Inc. USA September 23,2005 Pen. Pen. lvtetal . ¡"m,,<,p Profile Joint Jt. Depth Pen. Min. No. (Ft.) I~~:~~;t Body LD. Comments ¡Of ..11\ \ IQ VV"", (ins.) (Ins.) 0 50 100 47 1457 (1 3.87 ittin\!. III 48 I ."t gq III 49 I 3.88 ittin\!. . SO ---..Æ~nittinQ. III 51 ! w oittin\!. III 52 1614 3.89 Shallow flittin\!. . 53 1646 3 3.89 54 1677 (1 0.03 3.87 55 1709 +1 0.03 3.88 56 1741 0.02 3.88 57 1773 0.04 3.87 58 1804 0.03 3.88 59 1835 0.03 3.89 Shallow Ditting. 60 1867 0.03 3.89 61 1898 0.04 1 3.87 Shallow oittim~. 62 1930 0.04 1 3.89 Shallow oittim~. I 63 1961 0.03 1 3.89 64 1993 (1 0.03 1 3.89 Shallow Dittim~. 65 2024 0 0.03 1 3.87 66 2056 0 0.04 1 1 3.89 Shallow úittim~. 67 2087 ! 0.03 1 :3 3.88 ShalloW oittiŒZ. ~ ! 0.04 1 ' ¡ Shallow oitting. ( 0.ü3 1 1 70 ! H 2 71 2213 .It_", 72 2245 ~ 3 osits. pi 73 2276 Denosits. pi 1--. 74... 2308 .1 75 2339 ow nittinQ. .. 76 2371 3.89 77 2402 0 3.89 ... 78 2433 0.03 3.88 79 2465 0.04 3.87 Shallow oitting. 80 2497 0.04 3.87 Shallow oitting. 81 2528 0.04 3.90 Shallow oittin\!. ~_ . 2559 0.04 3.90 Shallowoittimr. 8312591 0.ü3 3.87 I 84 I 2623 0.03 3.89 III 85 2653 0.02 3.88 86 2685 (1 0.03 3.87 87 2717 3 17 'J 3.87 Shallow oittin\!. 88 2749 () 0,03 12 2 3.85 Shallow oittinQ. 89 2781 0 0.04 15 2 3.89 Shallow pitting. i 90 2812 0 0.04 14 3 3.88 Shallow oittinQ. 91 2843 0.03 12 2 3.86 Shallow oittimz. 92 2874 0.03 1 1 3.89 Shallow oitting. 93 2906 0.04 11 2 3.87 Shallow pitting. 94 2938 0.03 1 3 3.88 95 2969 0.03 If 1 3.88 I 96 3000 0.03 I 1 3.88 Page 2 I TABULATION Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: 1 Q-02A Kupafuk ConocoPhiUips Alaska, Inc. USA September 23,2005 Company: Joint Jt. Depth PerL Pen. Pen, ~ Min. .., ,.c, , ,,-,,,,,¡;C No. (Ft.) ~pset Body 1.0. Comments 101 ...Ih \10 """'''I (Ins.) (Ins.) 0 100 97 3032 0.03 13 :2 · Shallow oittint!. " 98 3064 0.03 In " 99 3095 0.02 1 " 100 3127 0.03 101 3158 0.06 3. osits. 102 3189 0.04 3. sits. 103 3221 0.04 3 ..JM. 3253 0.03 3. 105 3284 n 0.04 3.89 <::¡"'"l!mAl oittim::!. 106 3315 (1 0.03 3.89 107 3347 (1 0.04 3.89 Shallow nittinQ. 108 3378 (1 0.04 3.88 Shallow nittinQ. 109 3409 (1 0.04 3.85 Shallow nittinQ. 110 3440 (1 0.04 3.89 Shallow nittinQ. 111 3473 0.02 3.88 112 3505 0.03 H 3.88 Shallow nittinQ 113 3536 0.04 13 ~~M Shallow oittinQ. 114 3567 0.04 14 1RR Shallow nittinQ. Ú, Deoosits. 115 3599 0.03 12 1.87 Shallow nittinQ. Lt. Deoosits. ... 116 3631 0.03 12 387 Shallow oittinQ. 117 3662 3.87 Shallow oittinQ. Lt. Deoosits. 118 3693 3.87 Shallow oittinQ. 119 3726 3.88 Shallow oittinQ. 120 3757 3.89 Shallow oittinQ. 121 3788 Shallow oittinQ. 122 3819 Shallow oittinQ. 123 3852 Shallow rJÍttinQ. ! t Deoosits. 124 3883 0 0 Shallow oittinQ. 125 3914 0.04 Shallow oittim~. 126 3945 0.04 Shallow Dittim::!. 127 3977 0.03 It. Deoosits. 128 4008 0.03 8i 129 4040 0.ü3 ~_i!lLo~itting. 130 4072 0 0.03 131 4103 0 0.03 3.88 Shallow nittinQ. 132 4134 m1 3.86 Shallow nittinQ. 133 4166 04 1 3.86 Shallow nittinQ. 134 4198 H 3.87 135 4229 . H 3. 136 4261 0.04 1 3. Shallow oittinq. I 137 4294 0.04 1 'j Shallow oittinq. 138 4325 0.03 11 ~, 3.86 139 4356 0.03 Ii 1 3.89 140 4387 0.03 r 3.88 141 4419 O. 1tt 3.88 Shallow oittinQ. Lt Deoosits. 1-. 142 4451 3.88 Shallow nittinQ. 143 4483 3.87 Shallow nittim~. 144 4514 I q HI; Shallow nittim::!. 145 4545 3.86 L..J.~J? 4577 0 3.88 Shallow nittinQ. Page 3 JOINT TABULATION Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Cql,intry: Survey Date: Joint No. jt. Depth (Ft.) PC'rL (Ins.) 147 4608 0 148 4640 n 149 4672 0 Jr mt+t 153 479+H 154 4829 155 4861 156 4892 157 4922 158 4954 159 4986 160 5017 161 5049! I 162 5080! 163 5113 I 164 5144 165<;176 166 5207 167 5238 168 5270 169 5301 170 5332 171 5365 172 5396 173 5427 174 5457 175 5488 176 5521 177' 5552 178 5584 179 5616 180 5647 181 5678 =1£82 5711 18 5741 1 5773 185 5804 186 5836 187 5867 188 58991 189 5930 n 190 §961 190.1 190.2 5999 191 6005 191.1 6035 0 191.2 6051 0 191.3 6052 [) I =it Pen. Pen. Metaf Min. Body 1.0. (Ins.) (Ins.) 000..·gO~3 ~ If~T8'1 Shallow oitting. =::itt=:t= Shallow oittinQ. 0.03 W ) 0.03 1 n 0.04-L1;L 3.88 Shallow oitting. 0.05-L1!L- 3,84 Shallow oittinQ. 0.03 3.87 Shallow Dittim;¡. 0.04 3.86 w Ditting. 0.04 3.87 I Shallow oittim~. 0.ü3 3.88 0.03 3.87 00.,0043 ~... $ Shallow pittinQ. Lt. Denosits. , I Shallow pitting. 0.03 "X 0.03 :2 0.03 i:)1 0.031 0.02 0.03 0.02 0.03 1 : 0.03 If 0.04 0.04 )¿: 3.87 Shallow lJittinQ. 3.86 ShaHow lJitting. 3.87 3.86 3.86 3.86 3.86 Shallow oittinQ. 3.86 3.85 3.87 3.82 3.87 3.86 3.87 3.86 Lt. Deoosits. 3,85 3.84 Shallow Ditting. 3.83 Shallowoittim;¡. 3.84 Shallowoìttìm;¡. It. npoosits. 3.83 I Shallow oitting. HiR Shallow oittim~. Shallow oittim;¡. . Shallow pittÎm;¡. I t. Denosits. iT? 3.85 ., 1 3.83 1~OWOittinQ' .~. ~~:::¿:~:~~:~:: Lt. Deoosits. 1 Shallow oittinQ. It. Deoosits. 3.85 f ¡ 3.81 SlidinQ Sleeve 3.89 Shallow oìttim1:. 3.88 PUP N/A Tie Back 3.93 PUP 1 n o \I o ")a ow nittinQ. 1 0.ü3 0.04 0.04 0.04 0.03 0.03 0.03 0.04 0.04 0.04 0.01 o 0.04 0.ü3 o 0.01 1 4 1 Q-02A Kuparuk ConocoPhillips Alaska,lnc. USA September 23, 2005 Comments .~. n~~ '_~";' Profile o 50 100 ! I I I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in 1 Q-02A Kuparuk ConocoPhillips Alaska, Inc. USA September 23,2005 Joint Jt. Depth Pen. Pen. Pen. ¡Viet,,! Min. Profile No. (Ft.) I(~~~:)t Body 1.0. Comments (Ins.) (Ins.) 0 100 191.4 6067 0 191.5 6083 0 f't1 inQ Sleeve 191.6 6094 0.00 JI 191.7 6110 0.02 JI 191.8 6127 0 \J ac kf'r 191.9 6142 0.01 PUP 192 6148 0.01 193 6180 0.01 194 6212 ( 0.00 195 6244 0.01 196 6276 0.01 197 6308 0.01 1 198 6340 0.01 1 199 6373 0.01 1 200 6404 0.01 1 201 6436 , 0.01 1 202 6468 ì 1 1 203 6501 I 204 6533 12 1 Shallow pitting. 205 6565 II 206 6597 207 6630 208 6663 0.01 209 6695 0.00 210 6726 0.01 211 6759 0.02 212 6790 0.01 213 ) 0.02 214 æ+ 0.01 215 6888 0.Q1 216 6920 t 0.02 t 217 6951 0.03 ( 218 6983 (I 0.05 8 . Lt. !II 219 7015 .04 (;, I 220 7047 .01 221 7079 .01 222 7112 223 7144 ¡ 224 7175 225 7207 226 7239 227 7271 0.01 228 7303 0.01 Irm 0.01 o 7367 0.Q1 f 7400 0.00 7431 ( 0.00 233 7463 0.02 234 7495 0.02 235 7529 0.01 5 I I I I PDS REPORT JOINT TABULATION SHEET Pipe: Body WaU: Upset WaU: Nominal LD.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in WeU: Field: Company: Country: Survey Date: 1 Q-02A Kuparuk ConocoPhillips Alaska, Inc. USA September 23, 2005 I Joint Jt. Depth Pen, Pen. Metif Min. n~~· '~~Profile No. (Ft.) ~::~:E;t Body 1.0. Comments {O;cr .m \ '" "q,,} (Ins.) (Ins.) 0 50 100 236 7561 () 0.01 3.93 237 7592 (] 0.01 3.92 238 7623 (] 0.01 3.93 ._~ 239 7654 () 0.01 3.92 240 7687 (] 0.03 1 'I 3.91 Lt. Deoosits. 241 7719 ±±±! 3.92 242 7751 3.93 243 7784 3.93 244 7815 0.01 n 245 7848 0.02 246 7880 0.01 247 7912 0.01 248 0.03 fj 1-248.1 75 0 ) X Nipple 249 7976 0.02 ¡r 250 8008 0.03 ') 251 8039 0.02 252 8071 I 0.02 253 8101 0.03 î 1-_254 8n') 0.02 . ... 255 8168 (] 0.Q3 . 256 8199 n 0.39 I, ,) CI S Perf. Interval. 257 8231 () 0.03 258 8262 n 0.03 I 259 8294 n ~ 3.93 260 8326 n 3.93 Isolated oittinQ. . ..261 8358 ) 3.88 Perforation Interval. 262 8390 ~ 3.88 Isolated oittiml. Lt. Deoosits. 263 8422 1 ''1 3.53 Isolated oiti:imr. Deoosits. 264 8460 3.47 Isolated Diti:imz. Deposits. 265 8496 3.73 Isolated oittim!. Deoosits. 266 8528 I 0.05 3.84 Shallow oittimt Lt. Denosits. Page 6 - - PDS Report Cross Sections Well: Field: Company: Country: Tubin : lQ-02A Kuparuk ConocoPhiHips Alaska, Inc. USA 4.5 ins 12.6 pf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal SeptemÞer 23, 2005 MFC 40 No. 00432 2.75 40 M. T ahtouh for Joint 262 at depth 8414.634 ft Tool speed = 63 NominaltD 3,958 Nominal OD = 4.500 Remaining wall area = 97 % Tool deviation = 61 0 Finger 2 Penetration = 0.112 ins ISQlated pitting 0,11 ins = 41% Wall Penetration HIGH SIDE = UP page 1 Report C s ns Well: Field: Company: Country: Tubin : 1 Q-02A Kuparuk ConocoPhillips Alaska, Ine. USA 4.5 ins 12.6 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 23, 2005 MFC 40 No. 00432 2.75 40 M. Tahtouh Section for Joint 260 at depth 8332.823 ft Tool 62 Nominal ID =: 3.958 Nominal 00= Remaining wall area =: 98 % Tool deviation =: 61 0 Finger 28 Penetration =: 0.061 ins Well: Field: Company: Country: Tubin : - 1 Q-02A Kuparuk ConocoPhillips Alaska, Inc USA 4.5 ins 12.6 f L-80 100% at depth 8454. .._-~ PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: September 23, 2005 MFC 40 No. 00432 2.75 40 M. Tahtouh Finger 31 Projec:tiQn 8 ins Minimum 3.53 ins HIGH = UP 3 - - - - - - - PDS Report Cross Sections Well: Field: Company: Country: Tubin : Survey Date: Tool Type: Tool Size: No.ofFingers: Anal st September 23,2005 MFC 40 No. 00432 2.75 40 M. Tahtouh lQ-02A Kuparuk ConocoPhillips Alaska, Ine. USA 4.5 ins 12.6 f L-80 Tool speed = 63 Nominal 10 ;: 3.958 Nominal 00 Remaioing wall area = 100 % Tool deviation;: 35 0 Finger 18 Projection -0.397 ins Buildup Minimum 1.0. ;: 3.47 ins HIGH SIDE;: UP 4 - - SLEEVE-C (600).0010, 00:4.500) TUBING (0.ß061, 00:4.500, 10:3.958) T1L (6000-6061, 00:4.500) SffilNG SLEEVE (6113-6114, 00:6.000) PKR (6119-6120, 00:5.875) NIP (1975-7976, 00<3828) Squeeze Peffi; (8203-8205) Perf (8369-8384) Shot Sqz Peffi; (ß440:8442) Perf (8662-8673) Perf (8676-8681) Perf (e686-8720) ShotSqz Peffi; (872fr87'l1) Perf (8802-8808) RETAINER (8883-8884, OD:4.5OO) Perf (89Q3.8905) KRU ..pe Subfile 2 is type: LIS TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOSS API NUMBER: j;',:~ . · 500292124870 OPERATOR: .... TAPE CREATION JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK MM 951269 S. BURKHARDT D. WESTER SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 12-AUG-96 MWD RUN 4 S. BURKHARDT D. WESTER 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE 26 12N 9E 1206 1175 79.10 77.60 52.60 CASING DRILLERS ,~l~v .... , ~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 6268.0 6. 125 8348.0 MWD - EWR4/GR. ALL DEPTHS ARE MEASURED BIT DEPTHS. RUN 1 WAS DIRECTIONAL ONLY. NO DATA IS PRESENTED. MWD RUNS 3 & 4 WERE DIRECTIONAL WITH GAMMA RAY (SGRC), & ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4). ALL GAMMA RAY DATA WAS AQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS (DGR/SGRC) . THIS WELL, 1Q-02A PB1, WAS DRILLED TO 8348' & SUBSE- QUENTLY ABANDONED WHEN THE BOTTOM HOLE ASSEMBLY WAS LOST IN THE HOLE AT THE START OF RUN 5. NO DEPTH SHIFTS WERE APPLIED AS THIS IS THE DEPTH REFERENCE FOR THIS WELL (PER STEVE MOOTHART, ARCO). FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 6550.0 8295.0 6550.0 8302.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 6731.0 7694.0 4 7694.0 8348.0 MERGED PASS. CN WN FN COUN STAT : ARCO ALASKA, INC : 1Q-02A PB1 : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records. 117 Tape File Start Depth = 8348.000000 Tape File End Depth = 6550.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 28777 datums Tape Subfile: 2 202 records... Minimum record length: Maximum record length: 38 bytes 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NIIMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SIIMMARY VENDOR TOOL CODE START DEPTH GR 6550.0 EWR4 6550.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7640.0 7647.0 08-JAN-96 ISC 2.11 DEP 2.15R / SP4 5.01 MEMORY 7694.0 6731.0 7694.0 0 53.5 58.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NI3MBER P0433SP4 P0433SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.125 6268.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MI/D VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MI/D AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MIID CAKE AT MT: DISP. LOW SOLIDS 10.30 58.0 9.5 1100 7.0 .450 72.0 .000 125.8 .300 72.0 .550 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT : ARCO ALASKA, INC : 1Q-02A PB1 : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 75 Tape File Start Depth = 7700.000000 Tape File End Depth = 6550.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18409 datums Tape Subfile: 3 140 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER' FILE NUMBER: 3 RAW MWD' Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY \~NDOR TOOL CODE START DEPTH GR 7641.0 EWR4 7648.0 $ LOG HEADER DATA DATE'LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8295.0 8302.0 10-JAN-96 ISC 2.11 DEP 2.15R / SP4 5.01 MEMORY 8348.0 7694.0 '8348.0 0 46.8 54.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0433SP4 P0433SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.125 6268.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGP) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: DISP. LOW SOLIDS 10.90 52.0 10.0 1900 5.4 .400 69.0 .000 133.0 .300 69.0 .500 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 4. $ : ARCO ALASKA, INC : iQ-02A PB1 : KUPARUK RIVER : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 47 Tape File Start Depth = 8348.000000 Tape File End Depth = 7635.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40194 datums Tape Subfile: 4 112 records... Minimum record length: Maximum record length: 38 bytes 998 bytes Tape Subfile 5 is type: LIS 96/ s/~2 01 **** REEL TRAILER **** 96/ s/13 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 13 AUG 96 1:54p Elapsed execution time = 1.43 seconds. SYSTEM RETURN CODE = 0