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Home My WebLink About200-041Image~oject Well History' File Cover I:~le XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~. ~)C)- ~ ~-~ L Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: D Grayscale items: [3 Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY; BEVERLY ROBIN VINCENTSHERYI~~INDY Scanning Preparation x 30 = BY: BEVERLY ROBIN VINCENTSHERYL(~r¥1NDY = TOTAL PAGES ~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~C~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~" YES BY: BEVERL~INOENT SHERYL MARIA WINDY DATE: 7~~S~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES BY; BEVERLY(~VINCENT SHERYL MARIA WINDY DAT~ff"~--~S/~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BAS18 DUE TO QUALITY, GRAYECALE OR COLOR IMAGES ) NO NO RESCANNEDB¥; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE; General Notes or Comments about this file: Quality Checked 12/10102Rev3NOT$canned.wpd ~".. MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc t ~, Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJP'hillips P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-6830 June 1, 2004 RECEIVE~D . JUN 072004 Alaska Oil & Gas Cons.., CommissiaH t\m.:h!1r¡1çi~~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3H-10A (APD # 200-041 /303-273) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P&A operations on the Kuparuk well 3H-1 OA. If you have any questions regarding this matter, please contact me at 265-6830 or Kelly McLu re at 265-6059. Sincerely, ~t~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad OP'~,~r^,1 REC' ~E~VE.[) """". .1 II' If" (, STATE OF ALASKA \ J UNO 7 '2.Uü4 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT rANlDi\~øGons. Gommissi Oil 0 Gas U Plugged U Abandoned ~ Suspended U WAG 0 1b. Well Class: A\1thUl a~E: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 No. of Completions - Other - Service 0 Stratigraphic Test 0 12. Permit to Drill Number: 1a. Well Status: GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 1320' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At Top Productive Horizon: Total Depth: 1348' FNL 3544' FEL, Sec. 12, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498655 y- 6000335 TPI: Total Depth: x- 500110 18. Directional Survey: Yes 0 No~ Zone- 4 Zone-4 Zone-4 y- 6000308 21. Logs Run: GR 22. 5. Date Comp., Susp., ,/ or Aband.: May 9. 2004 6. Date Spudded: December 1, 2000 7. Date TD Reached: December 3, 2000 8. KB Elevation (ft): 76' RKB 9. Plug Back Depth (MD + TVD): 3555' MD 10. Total Depth (MD + TVD): 6365' MD / 5988' TVD 200-041 / 303-273 13. API Number: 50-103-20087-01 14. Well Name and Number: 3H-10A }1 ~ 1 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25531 11. Depth where SSSV set: SSSV @ 1793' 17. land Use Permit: ALK '2657' 19. Water Depth, if Offshore: N/A 20. Thickness of Permafrost: feet MSL 1591' MD CASING SIZE GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 115' Surface 115' Surface 3024' Surface 3023' Surface 6264' Surface 5902' 6264' 6365' 5902' 5988' PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Abandoned GAS-MCF 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". ¥.~~ ~~\t<è ~ '''-1i/''^fof./:¡.(:;'-\ WT. PER FT. 62.5# 40# 15.5# 16" 9.625" 7" 2.375" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): perfs squeezed off 26. Date First Production n/a Date of Test Hours Tested press. 27. psi Production for Test Period --> Calculated 24-Hour Rate-> OIL-BBL OIL-BBL Flow Tubing Casing Pressure NONE Form 10-407 Revised 12/2003 HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" 225 sx AS I 12.25" 1300 sx AS III, 100 sx AS I, 300 sx Class G 8.5" 450 sx Class G, 200 sx AS I casing window, open hole 24. cement retainer @ 3555' TUBING RECORD DEPTH SET (MD) n/a PACKER SET 6186' SIZE n/a 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6160'-6270' 2.5 bbls into open hole W A TER-BBL CHOKE SIZE GAS-OIL RATIO GAS-MCF WATER-BBL OIL GRAVITY - API (corr) CORE DATA BfL JU~ 1 A ?""l\ ...,.,,'... ~ A £~~:~I ~ ,~',_',",,':,.,.~ ..,J.. j '-'''''-''~-,- -. ~"-,. ^"...- , '. "." ~",",,"..~,.__h--';' 0 RTsTNÃT- G~ -- 28. ,~ 29. ( GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". n/a RECEr\/E.D JUN 0 7 2004 A\as"a 0,'\ & ('>~~ Cnn<c ('r'''''''''"I\..ç':("''l N/A 1\ 'i.]iD!..J "II,~" lIW1?,'¡\,i'I~,,)t.::~, Anchmô!£\ß 30. LIST OF ATTACHMENTS Summary of Daily Operations, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelly McLure @ 265-6059 Printed Name Randy Thomas Title: Signature ~ t ~, °l1one Kuparuk Drilling Team Leader '2G.r6-£>o Date 6 (/ (Df! Prepared by Sharon Allsup-Drake 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 abour 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". OR\G\NAL Form 1 0-407 Revised 2/2003 ( .PHILLlPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY , - - 3H-10A sssv ( 1793-1794, 00:3.500) Cement Sheath (614%264, 00:3.500) PACKER (6186-6187, 00:6.151) TUBING (().{ì257, 00:3.500, 10:2.992) PROD CAS I NG (().{ì264, 00:7.000, Wt:26.00) .¡ .:.... 1:8« API: 501032008701 SSSV Type: TRDP (see note) ( KRU Well Type: INJ Orig 12/8/2000 Completion: Last W/O: 12/3/2000 Angle ~ TS: deg ~ Angle @ TD: deg @ Annular Fluid: Reference Log: Last Tag: 6270 CTD Last Tag Date: 12/3/2000 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURF CASING 9.625 PROD CASING 7.000 CSG WINDOW 2.800 OPEN HOLE 2.800 Tubll1gString-TUBI NG Size I Top 3.500 0 Gas I..ift MandrélsNalvês St MD TVD Man Man Mfr Type 1 2242 2242 CAMCO KBUG 2 3630 3630 CAMCO KBUG 3 4427 4427 CAMCO KBUG 4 4797 4797 CAMCO KBUG 5 5138 5138 CAMCO KBUG 6 5477 5477 CAMCO KBUG 7 5820 5820 CAMCO KBUG 8 6127 6127 OTIS LBX MERLA øtljerf)lu'g$¡êqÜiÞ;¡.étc;:i~,J EWEIlR¥ Depth TVD Type 1793 1793 SSSV 3H-10A Ref Log Date: TD: 6365 ftKB Max Hole Angle: 0 deg @ Rev Reason: Format update by ImO Last Update: 7/9/2002 Top 0 0 0 6264 6270 Bottom TVD Wt Grade Thread 115 115 62.50 H-40 3024 3024 36.00 J-5S 6264 6264 26.00 J-5S 6268 6268 0.00 6365 6365 0.00 Otis Series '10' NOTE: SSSV hydraulics are disconnected at the tree. The SSSV is NOT locked out. 5/23/2002 Cement Cement Sheath, 2.995" OD, 2.8" ID, set 6/11/2002 Sheath PBR Baker PBR PACKER Baker 'FHL' Packer TBG CUT CHEMICAL CUT 6149 6149 6172 6172 6186 6186 6202 6202 VMfr V Type V OD Latch Port TRO DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 DMY 1.0 BK-2 0.000 0 0 Description Date Run 6/111989 6/1/1989 12/13/1987 6/1/1989 6/1/1989 12/13/1987 6/1/1987 12/22/1987 Vlv Cmnt ID 2.813 2.800 2.992 2.992 2.992 Date Note 6/11/2002 P&A'd original hole w/cement & retainer 11/6/2000. TOC sheath @ 6149' CTD; CTO drilling to 6365'. Hole collapsed to 6270' and CTD ST suspended indefinitely. .( '~ ( 3H-10A Well Events Summary Date Summary 04/20/04 MITOA passed, POT-T passed, PPPOT-T failed, POT-IC failed, PPPOT-IC failed, Function test LDSls 0 [ANN COM ISSUES, WH Maintenance] 04/23/04 LOCKED OUT OTIS SERIES 10 SSSV @ 17931 RKB.D [SSSV Work] 04/28/04 PERFORMED A CEMENT SQUEEZE WITH 15.8 PPG CLASS G CEMENT FROM 6160' MD DOWN TO THE WINDOW @ 6270' MD. SQUEEZED 2.5 BBLS INTO THE OPENHOLE. WASHED DOWN TO 61601 MD WITH A BALL DROP CEMENT NZL USING 2# BIOZAN GEL. 05/02/04 PT TUBING 2500# HOLDING, DRIFT AND TAG TO 61301 WLM CEMENT TOP, BLEED TUBING TO 0 AND IA INTO TANKSET UP, PULLED AND LEFT OPEN STA# 1 @ 6127' RKB, [Tag, GLV] 05/03/04 CUT TUBING FOR UPCOMING RIG WORK. SHOT STRING SHOT FROM 61011 TO 61131 AND THEN CHEMICAL CUT TUBING AT 61121 05/03/04 PUMP 290 BBLS OF SW DOWN TUBING TAKING RETURNS TO OPEN TOP. PUMP 100 BBLS DIESEL DOWN lA, THEN U-TUBE FOR FREEZE PROECTION IN IA AND TUBING. t/ Jr:-~ (p I). ':> ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-1 0 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/6/2004 08:30 - 12:00 3.50 MOVE DMOB DEMOB 3.00 MOVE MOB DEMOB 2.00 MOVE MOB DEMOB 1.50 MOVE RURD DEMOB 2.50 MOVE POSN DEMOB 2.00 MOVE RURD DEMOB 12:00 - 15:00 15:00 - 17:00 17:00 - 18:30 18:30 - 21 :00 21 :00 - 23:00 23:00 - 23:15 0.25 WELCTL SFTY DECOMP 23: 15 - 00:00 0.75 WELCTLNUND DECOMP 5n /2004 00:00 - 01 :30 1.50 WELCTL NUND DECOMP 01 :30 - 03:00 1.50 WELCTL OTHR DECOMP 03:00 - 06:00 3.00 WELCTL BOPE DECOMP 06:00 - 08:00 2.00 WELCTL NUND DECOMP 08:00 - 12:30 4.50 WELCTL BOPE DECOMP 12:30 - 15:00 2.50 WELCTL EaRP DECOMP 15:00 - 16:30 1.50 DRILL PULD DECOMP 16:30 - 17:30 1.00 DRILL CIRC DECOMP 17:30 - 21 :00 3.50 DRILL PULD DECOMP 21 :00 - 21 :45 0.75 WELCTL TRIP DECOMP 21 :45 - 22:00 0.25 WELCTL OTHR DECOMP 22:00 - 00:00 2.00 WELCTL NUND DECOMP 5/8/2004 00:00 - 01 : 15 1.25 WELCTL NUND DECOMP 01:15-03:15 2.00 WELCTL NUND DECOMP 03: 15 - 04:45 1.50 WELCTL NUND DECOMP 04:45 - 06:15 1.50 WELCTL NUND DECOMP 06:15 - 08:45 2.50 WELCTL BOPE DECOMP Unhooked service lines and blow down rig, moved rig complex's from sub and moved sub base off well, staged complex's on pad Moved sub base and rig complex's 15 miles from 3S pad to 3H pad, spotted sub base over well 3H-10B Moved camp, truck shop and sewer plant from 3S pad to 3H pad Spot and RU camp, sewer plant and truck shop Spotted rig's complex's, rock washer and pipe shed Hooked up service loops and lines between complex's, got steam and water going on rig and completed rig acceptance check list, held pre-spud mtg with crew coming off tour Accepted Rig @ 23:00 hrs 5/6/2004 Held PJSM with rig crew on checking well pressures, ND tree and NU BOP's Removed VR plug from lA, checked well pressures, IA -0-, OA -0-, tbg has BPV installed, ND FMC, model 75, 31/8", 5M tree Fin ND Tree and installing blanking plug in tbg hanger PU & RU BOP testing equipment and valves Tested choke manifold to 250 psi low and 5,000 psi high, prep 11" x 7 1/16" DSA NOTE: Chuck Scheve with AOGCC waived witnessing of BOP test NU 11" x 71/16" DSA , set on BOP stack & NU Tested rams and valves to 250 psi low and 5,000 psi high, tested annular to 250 and 3,500 psi, tested rams and annular with 3 1/2" test jt, RD test tools Retrieved blanking plug, Took several attempts before retrieve blanking plug, LD same, attempted to pull BPV with no sucess MU 3 1/2" landing jt and MU into hanger, PU 90K and hanger and tbg came free, LD landing jt and found several pieces of metal around BPV, removed BPV and LD hanger, tbg st wt 85K Note 31/2" Tbg was cut at 6,112' WL Circ hole with clean seawater, recovered 100 bbls of diesel used for freeze protection, circ hole at 7 bpm at 800 psi POOH LD 31/2" 9.3#, J-55, BTC tbg, POOH LD 57 jts tbg, control line and 33 clamps, POOH to SSSV and LD same (Total length LD 1,774.09'), cleared rig floor MU Baker 7" storm packer and valve, RIH and set at 96', POOH with setting tool Pressure tested packer to 1,000 psi for 5 min & ck ok ND BOP stack and set off, ND 135/8" 3M x 71/16" 5M Tbg head, with several bolts in head while loosening slowly, csg began moving up with tbg head at report time Note: Held pre-spud meeting with new crew coming on tour Fin ND Tbg head, allowed csg and tbg head to move up, csg stopped after moving up hole 4 3/4", removed tbg head and pack-off, loaded pipe shed with 4" HWDP & 4 3/4" DC's MU Baker 7" csg spear, stung into csg, PU 69K (34K over blk wt) and removed csg slips, installed new slips and set with 34K st wt, installed new pack-off and LD 7" csg spear NU re-conditioned 135/8" 3M x 71/16" 5M tbg head and tested pack-off to 3,000 psi, good test NU BOP stack and riser RU and tested 4" rams to 250 psi low and 5,000 psi high, annular to Printed: 5/25/2004 9:34:47 AM .( ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 5/8/2004 06:15 - 08:45 2.50 WELCTL BOPE DECOMP 08:45 - 09:45 1.00 WELCTL TRIP DECOMP 09:45 - 15:00 5.25 DRILL TRIP DECOMP 15:00 - 16:30 1.50 DRILL RIRD DECOMP 16:30 - 16:45 0.25 DRILL PULD DECaMP 16:45 - 20:00 3.25 DRILL TRIP DECOMP 20:00 - 20:30 0.50 DRILL CIRC DECOMP 20:30 - 21 :45 1.25 DRILL TRIP DECOMP 21 :45 - 22:00 0.25 LOG SFTY DECOMP 22:00 - 00:00 2.00 LOG ELOG DECOMP 5/9/2004 00:00 - 01 :30 1.50 LOG ELOG DECOMP 01 :30 - 01 :45 0.25 DRILL DEQT DECOMP 01 :45 - 04:15 2.50 WINDOWPULD DECOMP 04:15 - 04:30 0.25 WINDOWCIRC DECOMP 04:30 - 05:45 1.25 WINDOWTRIP DECOMP 05:45 - 06:30 0.75 WINDOWSETW DECOMP 06:30 - 06:45 0.25 WINDOWCIRC DECOMP 06:45 - 11 :45 5.00 WINDOWSCML DECaMP 11 :45 - 13:00 1.25 WINDOWCIRC DECOMP 13:00 - 14:00 1.00 DRILL LOT DECOMP 14:00 - 16:00 2.00 WINDOWTRIP DECaMP 16:00 - 17:00 1.00 WINDOWPULD DECOMP 17:00 - 18:00 1.00 WINDOWOTHR DECOMP 18:00 - 19:45 1.75 DRILL PULD PROD 19:45 - 20:00 0.25 DRILL SFTY PROD 20:00 - 20:30 0.50 DRILL TRIP PROD 20:30 - 23:30 3.00 DRILL TRIP PROD Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 250 and 3,500 psi, RD, cleared rig floor RIH to 96' with 7" storm packer retrieving tool and latched onto pkr, released same and POOH LD packer Fin POOH with 31/2" completion, LD 139 jts of 31/2" 9.3#, L-80 BTC tbg, and 7-GLM's, total recovered from well, 196 jts tbg, 7-glm's, 1 SSSV, control line and 33 clamps RD 3 1/2" handling tools, cleared rig floor and installed wear bushing MU cleanout BHA #1, 6 1/8" bit, scraper and upper whipstock mill, XO TIH with BHA #1 PU 29 jts, 4" HWDP, jars and 91 jts of 4" XT-39 Dp, TIH to 3,752', no problems st wt 93K up & dn Circ 1 complete hole volume with clean seawater, circ at 8 bpm at 800 psi Monitored well-static, POOH LD bit, scraper and mill Held PJSM with rig crew and Schlumberger wireline on operations RU SWS, MU 6" gauge ring I junk basket with CCL, RIH to 3,700' with no problems, logged up from 3,700' to 3,000' for CCL to set CIBP for whipstock, POOH with 6" gauge ring I junk basket and LD, preparing to run 7" CIBP MU Baker 7" CIBP, RIH on wireline and set at 3,555', POOH, RD SWS Tested 7" csg and CIBP to 3,000 psi for 10 min, good test MU & RIH with BHA #2, Baker 7" btm trip whipstock and milling assembly with MWD and oriented same, 4-4 3/4" dc's, RIH with 9 stds 4" HWDP and 1 std 4" DP to 1,145' Shallow tested MWD and checked ok TIH with whipstock on 4" DP to 3,489' Est circ at 295 gpm, 1,200 psi and worked DP down orienting whipstock to 28 deg left of high side from 3,489', tagged CIBP at 3,555" DP (3,555' WL), set whipstock and sheared off same, top of whipstock at 3,537', st up wt 90K, dn 94K with seawater Displaced out seawater in well over to 10.2 ppg LSND mud, rot wt 91 K, up wt 90K, dn wt 94K Milled window in 7" csg from 3,537' to 3,568' MDI 3,559' TVD, top of window at 3,537' MDI 3,529' TVD, btm of window at 3,549' (12' window, 19' of open hole), 2-14K wom, initial rpm's 70, final rpm's 125, torque ave 3K ft-Ibs, max torque 7K ft-Ibs, circ rate 300 gpm at 1,300 psi Pumped hi vis fiber sweep and circ hole clean, worked mills thru window while circ, circ at 300 gpm at 1,200 psi, after circ clean, worked mills thru window with no pump or rotation several times with no problems, had good recovery from sweep and magnets while milling window, PU to above top of window RU & performed FIT to 13.6 ppg EMW with 10.2 ppg MW, 627 psi at 3,529' TVD POOH with milling assembly BHA #2 to 228', stood back HWDP POOH LD 4 3/4" Dc's, MWD and whipstock mills, upper mill in gauge Pulled wear bushing and flushed out stack, re-installed wear bushing and cleared rig floor PU & Began MU 6 1/8" directional BHA #3, oriented and uploaded MWD Held PJSM with crew on loading radioactive sources Fin MU BHA #3, loaded radioactive sources and RIH with HWDP to 1,104', shallow tested MWD and ck ok TIH with BHA #3 PU singles of 4" XT-39 DP from pipe shed, TIH to 3,534' (above window at 3,537') v Printed: 5/25/2004 9:34:47 AM Re: 3H-IOB Procedure Change (C , 3"-~ ~ '- 0c:RJ-\ Subject: Re: ~Procedure Change From: Thomas Maunder <to~ maunder@admin.state.ak.us> Date: Fri, 07 May 2004 15:04:52 -0800 To: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> 1/ ~ d-OO/OLfJ Kelly, et al: This is as we discussed. The LOT outside the window is one of the controlling factors whether you might need to squeeze or not. The other factor would be the ability to "get away" from the old well track. In either case, having hole to put cement in rather than perforations to put cement through will likely improve your chances of success. Good luck with the operations. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, As per our discussion we had a change in procedure for the 3H-10A decomplete phase. The original and approved plan turned in for the permit to drill the sidetrack 3H-10B planned for perforating the 7" casing and squeezing cement into the annulus prior to setting the whipstock and milling the window in the 7.0" casing. The change in plan is to not perform the perforate and squeeze prior to milling the window due to limited control of cement placement in the annulus above the perfs, ie. the cement falling versus getting lift. We will have to perform a FIT or LOT to a minimum of 13.0 ppg whichever occurs first prior to drilling the hole section anyway. If the 13.0 ppg minimum is not achieved then a suicide squeeze will be performed and a new FIT/LOT will be performed again before drilling ahead. Any questions please contact me. Regards, Kelly McLure Kelly McLure Operations Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) 907-240-5905 (cell) loft 6/22/2004 10:57 AM STATE OF ALASKA ,, ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Annular Disp. Other 1. Type of Request: Abandon Alter casing Change approved program Suspend [~ Operation Shutdown ~] Repair well [] Plug Perforations [~ Pull Tubing r-'] Perforate New Pool r'-] Perforate ['-'] Vadance Stimulate [--] Time Extension Re-enter Suspended Well 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 4. Current Well Class: Development E~ Exploratory ['-] Stratigraphic [~ Service [~ 5. Permit to Drill Number: 200-041 6. APl Number: 50-103-20087-01 7. KB Elevation (ft): RKB 76' 9. Well Name and Number: 3H-10A 8. Property Designation: 10. Field/Pool(s): ADL 25531, ALK 2657 Kuparuk River Field / Kuparuk Oil 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): 6365' 5988' 6270' 5907' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' S U R F CAS I NG 3024' 9-5/8" 3024' 3023' PROD CASING 6264' 7" 6264' 5902' CSG WINDOW 4' 2-3/8" 6268' 5900' OPEN HOLE 95' 2-3/8" 6365' 5988' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6268'- 6365' 5905'- 5988' 3-1/2" J-55 6257' Packers and SSSV Type: Packers and SSSV MD (ft) Baker 'FHL' packer packer @ 6186' SSSV= Otis Series ~10' SSSV= 1793' 12. Attachments: Description Summary of Proposal r-~ 13. Well Class after proposed work: Detailed Operations Program [~ BOP Sketch r"-] Exploratory E~ Development O Service ~ 14. Estimated Date for Commencing Operat O9/24/03 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil r-~ Gas [~ Plugged r'-] Abandoned ~[-~'] WAG r'~ GINJ [~ WINJ [~ WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas t'~'"~~~~ Commission Use Only Signature contact: Shane Cloninger @ 265,6829 Title: GKA Drilling Team Leader Phone ?,..~.5'-6'~c2 Date ~ ~'f( ~O~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number: Plug Integrity E~] BOP Test ~ Mechanical Integrity Test Other: ? Subsequent Form Required: L~O~ ~S BFL OCT ,'! :~:,~ .... Approved by: ~ Location Clearance r--'] RECEIVED Form 10-403 Revised 2/2003 · SEP 1 6 2003 0 ~ 'i?~l!]~ ,~"?~iaska Oil & Gas Cons. Commissior, Anchorage At cou ,ss.o. Date: .... '" ' ' "' SUBMIT IN DUPLICATE 3H-lOB Drilling Program Sundrv~, Re-enter and Abandon, Well 3H-10A {" Revision No.O Saved: 8-Sep-03 Pre-Rig Well Work: 1. Check all lock down screws on the 7-1/16" x 5M tubing head flange. Test the packoffs on the 7" casing and the 9-5/8" casing. Check the OA for pressure and then pump + 90 bbl of diesel down the OA to establish injectivity (relevant to squeeze operations later) and to insure freeze protection. 2.File Sundry notice - plug back. Notify AOGCC field inspector 24 hours before commencing CTU work. 3. RU CTU. Open the SSSV and RIH to the CTD window at 6270' MD. Spot + 5 bbl, class "G" cement, plug on bottom. Pull up to + 6000' MD and squeeze away 1-3 bbl if possible. The intended TOC should be at least 6150' MD. Circulate and displace the tubing with seawater while maintaining final squeeze pressure on the cement plug. POOH and freeze protect with + 20 bbl of diesel from 2000' to surface. POOH. Maintain final squeeze pressure on the well. Close the SSSV and R/D CTU. SI. 4. After + 48 hours, open the SSSV and test the cement plug to 2500 psi. Open the well and "flow check" for at least an hour. 5.RU SLU. Tag the cement plug to verify TOC. Pull the lowest dummy GLV possible. RD. 6. Perform a CMIT to 3000 psi against master valve, on chart for 30 minutes. Close the SSSV and repeat the CM1T against the SSSV (from below), on chart for 30 minutes. 7. RU E-line. ]et-cut the 3-1/2" tubing above TOC (to be determined). RD E-line. 8. Remove the necessary well houses and flowlines. Rig 1. . . Work: Notify the AOGCC field inspector 24 hours before spud and BOP test. MI/RU Doyon 141. Install a TWC. ND the upper tree assembly. NU and test the 13-5/8" BOPE to 250# / 3500# (note: a 7-1/16" x 13-5/8" DSA or spool is required). Retrieve the TWC. , ,... Engage the 3-1/2" tubing with a spear. L/D the tubing hanger. Screw in to the tubing and circulate the well clean with seawater. L/D the tubing, control line, bands, and GLM's. P/U a 6-1/8" milled tooth bit and a casing scraper. P/U 3-1/2" HWDP and DP. Circulate bottoms up with seawater at + 3700' MD. POOH. , R/U E-Line. Run a CCL/Gage Ring/Junk Basket to +__ 3700'. Make.a CCL log from _+ 3700' up to +_ 3000'. POOH. RIH and perforate 8 squeeze holes at +_ 3610'-12'. POOH. Close the blind rams, and with the OA open, establish injection into the Squeeze holes at _+ 2 bpm. Note: run a hose from the OA valve to an isolated pit to catch returns. 5. Set a 7" RTNR at + 3584' MD: the RTNR must be _> 2' above a casing collar and > 20' below a casing collar: the actual depth is adjustable. POOH. R/D E-line. Note: If sufficient injection rate cannot be established at 1500-2000 psi, consider a suicide squeeze. If this becomes the plan, set the RTNR on E-Line as planned and then perforate a second set of squeeze holes above the RTNR at + 3510'-12'. R/D E-Line. . RIH with the stinger for the RTNR on drill pipe from the derrick. Sting into the RTNR and re-establish injection with the OA open. Note: If a suicide squeeze is attempted, circulate through the RTNR and both sets of perforations. . R/U Dowell. Mix and pump + 200 sx (41 bbl) of class "G" cement + < 2% CaCI2 to accelerate the compressive strength curve. Squeeze the O.H. x 7" annulus with the OA open as before. Displace the cement with 3 bbl of fresh water followed by + 22 bbl of seawater. If the pressure data indicates "lift", Printed: 8-Sep-03 3H- 10B DRILLING PROGRAM. doc Page I of 3 15. 16. 17. Sundry. to Re-enter and Abandon, Well 3H-10A Revision No.0 Saved: 8-Sep-03 Displace the well above the TOL with seawater (+ 115 bbl) and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. R/U and run the 4-1/2" tubing with the PBR seal nipple. RIH and tag the TOL. Space out the tubing string with pup joints such that there remains 1'-2' of free travel in the seal assembly. Install the tubing hanger and landing joint. Displace the well above the TOL with clean seawater. Sting into the PBR and land the tubing hanger. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. Install a TWC. ND BOPE. NU and test the 4-1/16" (51vi) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to + 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). ]~nstall a BPV. R/D and IVl/O Doyon 141. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run a GR/CCL/$CI~IT from PBTD to TOL. 4. Perforate the Kuparuk as directed. R/D E-Line. 5. Install new"S" riser and replace the well house(s). 6. Secure waiver for ACC 20.25.4.~2 (b.) before injecting water, etc. Printed: 8-Sep-03 3H- l OB DRILLING PROGRAM. doc Page 3 of 3 KRU - 3H-10A Injector ConocoPhillips 16"x30" insulated conductor (~ +/- 115' MD 9-5/8" 36# J-55 3024' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000~ Flange Up 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2.. OTIS Series 10 SSSV: at 1793' MD, 33 stainless Bands Valve #1: 3-1/2" x 1" CAMCO KBUG wi DMY: at 2242' MD Valve #2: 3-112" x 1" CAMCO KBUG w/DMY: at 3630' MD Valve #3: 3-1/2" x 1" CAMCO KBUG wi DMY: at 4427' MD Valve #4: 3-112" x 1" CAMCO KBUG w/DMY: at 4707' MD Valve #5: 3-112" x 1" CAMCO KBUG wi DMY: at 5238' MD Valve #6: 3-1/2" x 1" CAMCO KBUG wi DMY: at 5477' MD Valve #7: 3-112" x 1" CAMCO KBUG w/DMY: at 5820' MD Valve #8: 3-1/2" x 1-1/2" OTIS Merla w/DMY: at 6127' MD 1 Joint 3-1/2", J-55, 9.3# EUE 8rd Mod x 30.27'. 1 Pup Joint 3-1/2", J-55, 9.3# EUE 8rd Mod x 6.10' Baker '80-40' PBR. Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom 7" 26# J-55 6763' MD 6327' TVD CTD Window at 6270' MD. Shale Collapsed. Abandoned Sidetrack. Baker Inflatable TTRtnr Kuparuk D Sand: 6348' - 6356' MD Kuparuk C Sand: 6362' - 6450' MD Kuparuk A Sand: 6480' - 6510' MD TD @ 7946' MD / 6101' TVD (300' MD below Miluveach) Skip Coyner 6/27/03 KRU - 3H-10B De-Complete C noc hillips 16"x30" insulated conductor (~ +1- 115' MD 9-5/8" 36# J-55 3024' MD PBR: 6172' - 6186' MD PKR: 6186'- 6193' MD 630O' MD 7" 26# J-55 6763' MD 6327' TVD Perforate squeeze holes at 3610-12' MD Set RTNR at +/- 3584" on E-Line Block Squeeze w/100-200 sx Class "G" Cut and Pull the Tubing at above 6000' MD Valve ~8: 3-112" x 1-1/2" OTIS Merla w/DMY: at 6127' MD 1 Joint 3-1/2", J-55, 9.3# EUE 8rd Mod x 30.27', 1 Pup Joint 3-1/2", J-55, 9.3# EUE 8rd Mod x 6.10' Baker '80-40' PBR. Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom CTD: P & A the CTD Sidetrack, CTD Window at 6270' MD. Shale Collapsed, Baker Inflatable TTRtnr Kuparuk D Sand: 6348' - 6356' MD Kuparuk C Sand: 6362' - 6450' MD Kuparuk A Sand: 6480' - 6510' MD TD @ 7946' MD / 6101' TVD (300' MD below Miluveach) Skip Coyner 6/27/03 KRU - 3H-10B Whipstock 16"x30" insulated conductor ~ +/- 115' MD 9-518" 36# J-55 3024' MD Top/Whipstock: at 3562' MD EZSV' 3584' lVtD \ \ LOT ~ 13.0 ppg ConoCoPhillips PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD Kuparuk (3H-10A) D Sand: 5974' - 5981' TVD C Sand: 6986' - 6061' TVD A Sand: 6087' - 6112' TVD 7" 26# J-55 6763' MD 6327' TVD TD @ 7946' MD / 6101' TVD (300' MD below Miluveach) Skip Coyner 7/07/03 KRU - 3H-10B Sidetrack Hole ConocoPhillips 16"x30" insulated conductor @ +1- 115' MD 9-5/8" 36# J-55 3024' MD Top/Whipstock: at 3562' MD EZSV: 3584' MD ...::~ DriJJ 6-1/8" Ho~e thru the Kuparuk sands & TD in the Mi~uveach Inflatable TTRtnr: 6300' MD sha~e +1- 6319' MD ! 6189' TVD, Expected MW = 11.7 ppg \ \ \ 7" 26# J-55 6763' MD 6327' TVD \ TD {~ +1- 6319' MD / 6189' TVD (TD 200' MD below Kuparuk A-sand) \ \ \ \ \ Skip Coyner 7/07/03 KRU - 3H-10B Liner 16"x30" insulated conductor ~ +/- 115' MD 9-518" 36# J-55 3024' MD ConocoPhillips +/- 3400' MD Top/Whipstock: at 3562' MD EZSV' 3584' ~D PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD 7" 26# J-55 6763' MD 6327' TVD FlexLock, ZXP Liner Top Packer & 80-47 PBR 4-Y2" NSCT & IBT-mod Liner set thru the Kuparuk (see Well Plan for details) Hole Angle 13° to 15° Built to 30° at T/Kuparuk C- sand +/- 6014' MD / 5925' TVD TD (~ +/- 6319' MD / 6189' TVD (TD 200' MD below Kuparuk A-sand) Skip Coyner 7/07/03 KRU - 3H-10B Completion COnocoPhillips 16"x30" insulated conductor @ +/- 115' MD 9-5~8" 36# J-55 3024' MD 4-1/2" FMC Gen IV tubing hanger, 4-%" L-80 IBT-mod pin down. 4-1/2", L-80, 12.6~, IBT-mod Spaceout Pups as Required. 4-1/2'', 12.6#, L-80, IBT-mod Tubing (see Well Plan for details) +/- 3400' MD Top/Whipstock: 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD 7" 26# J-55 6763' MD 6327' TVD FlexLock, ZXP Liner Top Packer & 80-47 PBR 4-1/2.. NSCT & IBT-mod Liner set thru the Kuparuk (see Well Plan for details) TD (~ +/- 6319' MD / 6189' 'FVD (TD 200' MD below Kuparuk A-sand) Skip Coyner 7/07/03 KRU - 3H-10B Completion - Revised 16"x30" insulated conductor @ +1-115' MD 9-5~8" 36# J-55 3024' MD ConocOphillips SSSV profile 4-1/2" NSCT Tubing GLM +/- 3400' MD Baker HMC, ZXP & 80-47 PBR Top/Whipstock: 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD :. · . · .. . · .. . 4-Y2" NSCT Liner set thru the Kuparuk MIT profile A & C Sand perfs 7" 26# J.55 6763' MD 6327' TVD Johnny Golden 9/29/03 {' 3H-10B Liner Detail No. Item Length Notes 1 ea 5" x 7" ZXP Liner Packer w/5" x 10' PBR 14.0' TOL = 3400' 1 ea 5" x 7" FlexLock Liner Hanger: 5" BTC pin 6.0' 5" BTC pin down 1 ea Crossover: 5" BTC box X 4-1/2" NSCT pin 2.0' GKA #10637705 60 ea 4-1/2", 12.6#, L-80, NSCT, R-2 (get rid of inventory) 1800.0' GKA #10527842 1 ea Crossover: 4-1/2" NSCT box X IBT pin 3.0' GKA #10535630 + cplg 23 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 liner joints 690.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint 8.0' GKA #10542482 1 ea 4-1/2" "X" Nipple, IBT (Selective, 3.813" Bore) 2.0' GKA #10541991 1 ea 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint 8.0' GKA #10542482 9 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 liner joints 270.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBT Landing Collar 2.0' GKA #10643747 2 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 liner joints 60.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBT-Mod Float Collar 3.0' GKA #10643745 2 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 liner joints 60.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 Float Shoe 3.0' GKA #10643746 3H-10B Tubing Detail No. Item Length Supplier 1 ea 4-1/2", 112.6#, L-80 Landing joint 30.0' GKA Inventory 1 ea FMC, Gen IV, 4-1/2" Tubing Hanger + pups 10.0' GKA #10616626 15 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 tubing 450.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBTPup Joint 10.0' GKA#10542484 1 ea 4-1/2" "X" Nipple, IBT (Selective, 3,813" ID) 2.0' GKA #10541991 1 ea 4-1/2", 12.6#, L-80, IBT Pup Joint 10.0' GKA#10542484 94 ea 4-1/2", 12.6#, L-80, IBT-Mod, R-2 tubing 2820.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBT Pup Joint 10.0' GKA #10542484 1 ea 4-1/2" x 1" KBG-2 GLM w/Shear valve 5.0' Cameo (or Alpine stock) 1 ea 4-1/2", 12.6#, L-80, IBT Pup Joint 10.0' GKA #10542484 1 ea 4-1/2", 12.6#, L-80, IBT, R-2 tubing joint 30.0' GKA #10542463 1 ea 4-1/2", 12.6#, L-80, IBTPup Joint 10.0' GKA #10542484 1 ea 4-1/2 .... X"Nipple, IBT (Selective, 3,813" ID) 1.0' GKA #10541991 1 ea 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint 10.0' GKA#10542484 1 ea X-O: 5" LTC pin x 4-1/2" IBT-Mod box 3.0' Need to cut this X-O 1 ea PBR "Bullet" Seals with 5" LTC box up 12.0' Baker 7", 26# X 5" ZXP Liner Top Packer wi 10Ft. 5.25" ID Tieback Extension cornoc°%illips LINER SCHEMATIC 3H-10B 5" RS Nipple 7", 26# X 5" FLEX LOCK Rotating Liner Hanger wi 5" BTC pin down X-O: 5" BTCBox X 4-1/2" NSCTpin ~. xx jts 4-1/2" 12.6# NSCT Liner X-O: 4-%" NSCT box.X IBT-M pin xx jts 4-%", 12.6# IBT-M Liner w/a 3.813" "X" nipple above the Kuparuk Landing Collar w/4-%" IBT-M 2 Jts 4-%" IBT-M Liner Float Collar wi 4-1/2" IBT-M 2 Jts 4-%" IBT, M Liner Float Shoe' 4-1/2" IBT 3-1/2" Drill Pipe to Surface Rotating Dog Sub HR Running Tool RS Packoff 4-%" Liner Wiping Plug 7-29-03-- Drawn by Jose Iguaz, ConocoPhillips 4-1/2" NSCT Completion Tubing At +/- 500 ft 4-1/2'' IBTBox Pup Joint x 10 ft (#10542484) "X" Nipple, 3.813", IBT, (#I054t991) 4-1/2" IBTBox Pup Joint x 10 ft (#10542484) XXX Joints 4-1/2" IBT Completion Tubing 4-1/2" IBTBox Pup Joint x 10 ft (#10542484) 4-1/~'' X 1" Camco KBG-2 Gas Lift Mandrel wi shear Valve 4-1/2" IBTBox Pup Joint x 10 ft (#10542484) 1 Joint 4-112" IBT Tubing (#10542463) 4-%" IBTBox Pup Joint x 10 ft (#10542484) "X" Nipple, 3.813", IBT, (#10541991) 4-1/2" IBT~o_x pup Joint x 10 ft (#10542484) x-o: 4-1/2" IBTBox x 5" LTCpin [make this X-O] or [add a 5" Dbl pin (LTC x BTC) & a 4-1/2'' IBT cplg to #10541943] 10 ft. X 5.25" OD Bullet Seal Assembly w/ 5" LTC Box Up Permitto Drill 20004t0 MD 6365 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 7110/2003 Well Name/No. KUPARUK RIV UNIT 3H-10A Operator CONOCOPHILLIPS ALASKA INC 5988 J Completion Dat 12/8/2000 f Completion Statu SUSP Current Status SUSP UIC Y REQUIRED INFORMATION Mud Log N.__~o Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt MWD & GR Name Interval Log Log Run Scale Media No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments [~'~-' Dir Directional Survey 6264 6365 Open 4/20/2001 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y N~ Chips Received? ~ Analysis ~ R~.c~.iv~.d ? Daily History Received? ~ N Formation Tops ~)/N Comments: Compliance Reviewed By: 3H-10A and 3H-14A status Subject: 3It-10A and 3H-14A status Date: Tue, 24 Sep 2002 07:07:12 -0800 From: "Dan Venhaus" <dvenhaus@ppco.com> To: winton_aubert~admin.state.ak.us CC: "Michael B Mooney" <mmooney~ppco.com>, "Johnny O Golden" <jgolden@ppco.com> Winton, Regarding your memo to Mike Mooney dated July 26, 2002: Well Completion Reports (10-407) were filed for both 3H-10A and 3H-14A in February 2001 designating them as suspended wells. Please let me know if your records do not contain these reports and I can fax them to you. If you have any questions, you can reach me at 263-4372 or cell phone 230-0188. Thanks, Dan Venhaus PAI Drilling & Wells ALASKA OIL AND GAS CONSERVATION C0~I~I~SSION July 26, 2002 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mike Mooney Wells Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re~ Kuparuk River Unit 3H-10A (PTD #200-041) Kuparuk River Unit 3H-14A (PTD #200-020) Dear Mr. Mooney: AOGCC records indicate that Kupamk Well 3H-10A drilling operations were shutdown on December 7, 2000 and that Kuparuk well 3H-14A drilling operations were shutdown on November 27, 2000. Per 20 AAC 25.072 (d), well operations must resume within 12 months, or the well be suspended or abandoned. Please file appropriate documents notifying the Commission of your plans for 3H-10A and 3H-14A no later than August 26, 2002. Thank you for your attention to this matter. Sincerely, Winton Aubert Petroleum Engineer ir STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _X Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1320' FNL, 4997' FEL, Sec. 12, T12N, RSE, UM At top of productive interval At effective depth At total depth 1348' FNL, 3544' FEL, Sec. 12, T12N, RSE, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 498655, 6000335) (asp's 500110, 6000308) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-10A 9. Permit number / approval 200-041 10. APl number 50-1 11. Field / Pool Kuparuk Rive / Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 3024' PROD CASING 6264' OPEN HOLE 97' OPEN HOLE 4' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13. Attachments Description 14. Estimated date for commencing ope~ June 1,2002 16. If proposal was verbally Name of approver 6365 5988 6270 5907 Size 16" 9-5/8" 7" 3" 2.8" open hole · 6268' - feet Plugs (measured) feet feet Junk (measured) feet Cemented 225 sx AS I 1300 sxAS III, 100 sx Class G 450 sx Class G, open hole open hole Depth True vertical Depth 115' ~~ 115' 3024' 3023' 6264'~ 5902' 63651 5988' 6268 5900' open hole · 590~ 5988' CEIVED 3-1/2", 9.3#,, @ 6257' Bake~ . packer @ 6186' MD. SERIES '10' @ 1793' MD. proposal__ Detailed op 15. Status of well c Date approved Oil __ Service__X ~alka 011 & Gas Cons. Corr~issio~ ^.cl age program __ BOP sketch__ as: Gas __ Suspended 17. I hereby certify that Signed Conditions is true and correct to the best of my knowledge. --//~//~ Title: Wells Team Leader FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test _ Subsequent form required 10- Questions? Call Dan Venhaus 263-4372 Date .~f/,,/~ ! Prepared b~/ Sharon AIIsup-Drake 263-4612 by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88' SUBMIT IN TRIPLI CATE ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_X Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1320' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 5. Type of Well: Development _ Exploratory _ Stratlgraphic _ Service__X (asp's 498655, 6000335) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-10A 9. Permit number / approval number 200-041 / 10. APl number 50-103-20087-01 At effective depth At total depth 1348' FNL, 3544' FEL, Sec. 12, T12N, RSE, UM (asp's 5OOl lO, 6000308) 11. Field / Pool Kuparuk River Field / Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 6365 feet 5988 feet Plugs (measured) Effective depth: measured 6270 feet true vertical 5907 feet Junk (measured) Casing Length Size CONDUCTOR 115' 16" SURF CASING 3024' 9-5/8" PROD CASING 6264' 7" OPEN HOLE 97' 3" OPEN HOLE 4' 2.8" Cemented Measured Depth True vertical Depth 225 sx AS I 115' 115' 1300 sxAS III, 100 sx AS I, 300 s) 3024' 3023' 450 sx Class G, 200 sx AS I 6264' 5902' open hole 6365' 5988' open hole 6268' 5900' Perforation depth: measured open hole · 6268' - 6365' true vertical open hole · 5905' - 5988' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 6257' MD. Packers & SSSV (type & measured depth) Baker FHL packer @ 6186' MD. OTIS SERIES '10' @ 1793' MD. RECEIVED DEC 1 2001 AlaskaOil & Gas Cms. Commission 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl N/A Representative Daily Average Production or Iniection Data Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ Oil __ Gas Suspended __X Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Dan Venhaus 263.4372 Date ~'/~/iA// Prepared by Sharon A//sup-Drake 263-4612 Form 10-404 Rev 06/15/88' ORIGINAL SUBMIT IN DUPLICATE 3H-14A and 3H-10A shutdowns Subject: 3H-14A and 3H-10A shutdowns Date: Mon, 12 Feb 2001 20:53:57 -0000 From: "Venhaus, Dan E" <VenhauDE~BP.com> To: "'tom_maunder~admin. state.ak.us'" <tom_maunder~admin. state.ak.us> CC: "Rauf, Paul C" <RautPC~BP.com>, "Gantt, Lamar L" <GanttLL~_~BP.com>, "Stanley, Mark J (ANC)" <StanleMJ~BP.com> Tom, CTD operations were shutdown on sidetracks 3H-14A and 3H-10A due to problematic Kalubik shales. Both wells have KOPs in the Kalubik which is collapsed just outside the window. Drilling through the Kalubik was unavoidable, due to directional limitations and/or existing completion problems. Both are loaded with KWF and a backpressure valve set. 3H-14A Nabors 3S moved over well 3H-14A on November 15, 2000. A two-string window was milled followed by drilling 1017' of openhole, of which 600' was horizontal. During a short trip to the window, packing off and sticking problems prevented getting the BHA back through the Kalubik shale. An attempt to plugback with cement and redrill through the Kalubik was unsuccessful and resulted in leaving a fish (motor & bit) across the window. This occurred on November 26 at which time it was decided to suspend this operation and move to the next well. Fishing operations were considered risky due to the small clearance around the BHA across the window. 3H-10A Nabors 3S moved from 3H-14A to 3H-10A on November 27, 2000. Again, the KOP was located in the Kalubik, but it was considered a less risky operation than the 3H-14A sidetrack due to a cleaner window through one string. The window was milled successfully but only 101' of Kalubik was drilled when failure of the shale occurred. The hole completely collapsed just 15' outside of the window. The decision to suspend operations was made December 3. Nabors 3S moved off December 7. I hope this "closes the loop" on the Operations Shutdown for these two wells. Let me know if you need any other information. Thanks, Dan Venhaus 230-0188 cell 564-5273 BP 263-4372 Phillips 1 of l 7/25/2002 1:13 PM DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/27/2000: 11/28/2000: 11/29/2000: 11130/2000: 12/01/2000: 12/02/2000: 12/03/2000: 12/04/2000: 12/05/2000: 1 2/06/2000: 12/07/2000: 1 2/08/2000: MIRU CTU & Nabors 3S, Accepted rig 1800 hrs, Continued RU - hampered by weather. Began BOPE test. Completed BOPE test. RIH w/BHA & tagged TOC @ 6149' MD, Milled pilot hole to 6210', Milled cement to 6264' MD, POOH w/BHA, RIH w/window milling BHA. Tied-in. Commenced window milling operations through the 7" casing, Milled window f/6264' -. 6268' & 10' of FM to 6278'. Dressed window & POOH, RIH & dressed window interval, POOH, RIH & drilled to 6300', Drilled ahead to 6365' (call TD), Pumped 2 Soletex Pill, Short trip to window, Unable to get back to BTM, Unable to get through window because of sticking & packing off due to Kalubik shale problems, POOH w/BHA, RIH w/CT nozzle & jetted to 6270' MD. Unable to jet any further. POOH w/CT, Evaluating options, Weather deteriorating, Made decision to move off well because of Kalubik shale instability. Weather hold. RIH w/CT nozzle & displaced 10 ppg mud over to 12,3 ppg KWF, POOH & FP'd well, Began RDMOL, CTU#4 off location 2300 hrs. Weather hold. 3S on standby, Weather hold, 3S on standby, · Weather hold, 3S on standby. RDMOL Nabors 3S, ' Well 3H-10Ai is currently suspended. Future options are currently being evaluated, Sidetrack Summary Page I KRU 3H-10A Pr(uducer P&A Completion 9-5/8" 36# J-5 (~ 3024" PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" 5M FMC Gen IV tubing hanger w/BPV 1793' MD 3-1/2" Otis Series '10' SSSV 3-1/2" 9.2# J-55 BTC AB-mod IPC tubing to packer w/ 3-1/2" x 1" Camco 'KBUG' mandrels spaced as: GLM# ME) 1 2242' 2 3619' 3 4427' 4 4797' 5 5138' 6 5477' 7 5820' Tubing to window loaded with 12.3 ppg NaBr brine 6127' MD 3-1/2" x 1-1/2" Otis LBX mandrel 6172' MD 3-~" Baker PBR 6186' MD Baker 3-1/2" x 7" FHL packer 6205' MD 3-%"tubing tail 7" 26# J-SS 6268' · · · · · 6264' - 6268' MD 7" window 6270' MD PBTD - collapsed openhole Openhole loaded with 10 ppg FIo-Pro mud 6365' MD TD of 3" openhole DEV 12/4/01 February 8, 2001 0920 Place call to Dan Venhaus regarding 3H-10Ai...(200-041)...Kalubik shale problems caused them to suspend operations...occurred at office move time...left message requesting information...did mill window in casing and had some open hole, but unable to get beyond window at the end. February 9, 2001 1500 Call from Dan Venhaus 1530 Call from Paul Rauf...does reports on CTU operations...told him to get Venhaus to send us some emails describing the situations on the wells. February 13, 1450 Call from Dan Venhaus...upcoming coil sidetracks...3H-16 and 3K-22 will now use Nordic 1. 2001 Will send and email and fax to update the files. i STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. status of well Classification of Service Well Oil D Gas D Suspended D Abandoned D Service D 2. Name of Operator ~ ~ 7. Permit Number Phillips Alaska, Inc. L~¢.,,C,,~_'_.L 200-041 3. Address ~~i' 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ., · . 50-103-20087-01 4. Location of well at surface _"'r....5 ~,.__~,~,,/.._/ 9. unit or Lease Name 1320' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM (asp's 498655, 6000335) i.""~'"'-:" ~'-" -'"'"~i'"".' Kuparuk Unit At Top Producing Interval., 10. Well Number 11. Field and Pool 1348' FNL, 3544' FEL, SEC 12, T12N, RSE, UM (asp's 500110, 6000308) 1 ~"--' ............................ ~ Kuparuk Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 76 feetI ADL 25531 ALK 2657 Kuparuk Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions December 1, 2000 December 3, 2000 December 8, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 6365' MD / 5988' TVD 6270' MD / 5907' TVD YES ~1 No [--1I 1793' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD & GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 225 SxAS I 9-5/8" 36.0# J-55 Surface 3024' 12-1/4" 1300 Sx AS III, 100 Sx AS I, & 300 Sx Class G 7" 26.0# J-55 Surface 6264' 8-1/2" 450 Sx Class G & 200 Sx AS 24. Pedorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6202' 6186' 6268'- 6365' MD; 5905' - 5988' TVD; open hole 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Pedod > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. · This 10-407 is submitted as directed per the 10-401 form approved April 14, 2000 (Permit #200-041) ? B B F L sEP 2 d 2002 FEB 0 2 2001 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate Alaska 0il & Gas Cons. Commission Anchorage GEOLOGIC MARKERS 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 of Kalubik 6139' 5794' 31. LIST OF ATTACHMENTS Summary of 3H-10Ai CT Sidetrack Drilling Operations + Plugback Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed Title PAl Coiled Tubin.q Ddllin.q En.qineer Date February 1,2001__ Dan Venhaus INSTRUCTIONS Prepared by Paul Rauf 564-5799 General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVE,, Item 28: If no cores taken, indicate "none". .o,m10-407 FEB 0 Z001 Alaska Oil & Gas Cons. Commission Anchorage ~ 3H-10Ai · DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 11/27/2000: 11/28/2000: 11/29/2000: 11/30/2000: 12/01/2000: 12/02/2000: 12/03/2000: 12/04/2000: 12/05/2000: 12/06/2000: 12/07/2000: 12/08/2000: MIRU CTU & Nabors 3S. Accepted rig 1800 hrs. Continued RU - hampered by weather. Began BOPE test. Completed BOPE test. RIH w/BHA & tagged TOC @ 6149' MD. Milled pilot hole to 6210'. Milled cement to 6264' MD. POOH w/BHA. RIH w/window milling BHA. Tied-in. Commenced window milling operations through the 7" casing. Milled window f/6264' - 6268' & 10' of FM to 6278'. Dressed window & POOH. RIH & dressed window interval. POOH. RIH & drilled to 6300'. Drilled ahead to 6365' (call TD), Pumped 2 Soletex Pill. Short trip to window. Unable to get back to BTM. Unable to get through window because of sticking & packing off due to Kalubik shale problems. POOH w/BHA. RIH w/CT nozzle & jetted to 6270' MD. Unable to jet any further. POOH w/CT. Evaluating options. Weather deteriorating. Made decision to move off well because of Kalubik shale instability. Weather hold. RIH w/CT nozzle & displaced 10 ppg mud over to 12.3 ppg KWF. POOH & FP'd well. Began RDMOL. CTU#4 off location 2300 hrs. Weather hold. 3S on standby. Weather hold. 3S on standby. Weather hold. 3S on standby. RDMOL Nabors 3S. Well 3H-10Ai is currently suspended. Future options are currently being evaluated. Sidetrack Summary Page I Alaska Oil & Gas Cons. Commission Anchorage r BP Amoco ('· Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 1/17/2001 Time: 14:50:20 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 3H-10, True North Site: KRU 3H Pad Vertical (TVD) Reference: 3H-14 Rig 76.0 Well: 3H-10 Section (VS) Reference: Well (0.00E,0.00N,10.00Azi) Wellpath: 3H-10APB1 Survey Calculation Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 GeD Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: KRU 3H Pad UNITED STATES: North Slope Site Position: Northing: 6001657.06 ft Latitude: 70 24 56.740 N From: Map Easting: 498373.50 ft Longitude: 150 0 47.691 W Position Uncertainty: 0.00 fi: North Reference: True Ground Level: 0.00 fi: Grid Convergence: -0.01 deg Well: 3H-10 Slot Name: 501032008700 Well Position: +N/-S-1321.83 ft Northing: 6000335.30 fi: Latitude: 70 24 43.740 N +E/-W 282.31 ft Easting: 498655.50 fi: Longitude: 150 0 39.415 W Position Uncertainty: 0.00 fi: Wellpath: 3H-10APB1 Drilled From: 3H-10 501032008770 Tie-on Depth: 6264.00 ft Current Datum: 3H-14 Rig Height 76.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/20/2000 Declination: 26.15 deg Field Strength: 57413 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction fi: fi: ft deg 0.00 0.00 0,00 10.00 Survey: MWD Start Date: 12/1/2000 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 6264.00 5901.68 Kick off Point 6365.00 5988.33 Projected to TD Survey .............. :~"'-"~='~'ii;;3.'~7T7:~i;;;'-~777'-¥~i ....... :"7~7~'~'~"'-'~"~ .......... ~ ....... ~'~77~.-~'-'7: ......... 7'~';;~;~:'~- ....... 7'-T~-;~;~-'~ ......... :'~'"~i~: .......... i~'"~,-'."7'' .... i...._!..;..., fi:" :.':: :::'" deg '-:L.d.'e:.g_.,.i.......'..~.._..:_._.'_'f! ........... 'i.,.;.i..,:...,..i.,.: !~!~;.,._:~.:_ ...... '.:.i.:_~i::~.::.: .............. ~.~....=._f.t.:...~_i_......._::.__,i...._,',i. '=".?.,:_:.i.,..-..: ........ i.._:.......i...i...'..._ft_~.._..· ................ i_,:.d..e..g:(~l.0:.~{'t-.':_..:........:__ff....!...,__'..~.=_.;i: .... 6264.00 30.92 86.76 5901.68 5825.68 -29.61 1402,43 6000305.44 500057.79 0,00 214.37 6365.00 30.92 86.76 5988.33 5912.33 -26.67 1454.25 6000308.37 500109.60 0.00 226.26 FEE~ 0 ~ 2001 Alaska Oil & Gas Cons, Commission Anchorage BP Amoco WELLPA TH DETAILS 3H-IOAPB1 501032008770 Parent Wellpath: 3H-10 Tie on MD: 6264.00 Vertical Section OrYgin: Slot- (0.00,0.00) Vertical Section Angle: 10.00° Rig: Nabors 3s Depth Reference: 3H-14 Rig 76.00ft REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 3H-10, Tree North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot- (0.00,0.00) Measured Depth Reference: 3H-14 Rig 76.0 Calculation Method: Minimum Curvature ANNOTATIONS IgD Anno~alion 5825.68 6264.00 5912.33 6365.0O Pm~e~edtoTD LEGEND / T I W¢llpalh: {:HI-IO/HI-IOAPBI) 3H 103H_10APB1 p1--1,,7 A Az mu hs o True Norlh I 3~:1o'(3,~10) ' ~T' /~\ Nldagnetic Norlh: 26.15" ! (:reat~a By: Brij I'olnis Date: 1/17t2001 3H-10~B1 / / ~ I / /? Magnclic Ficldl .............. / ~ Slrcugth: 57413nT / f~N Dip Angle: 80-70° I / ~ Dale: 11/20/20001 I -F I .................... ....... ,o . 59 nn--~.:" 1200 1400 1600 1800 2000 =- i West(-)/East(+) [200flJin] ..-. . . . ~ .... ~ : : .- ~ . . ~ ; _ ~ · 6100-4) a~.~o tzH-~mF ~. ......................................... 200 300 400 500 600 700 800 900 1000 1100 Vertical Section at 10,00° [100ft/in] Plot 1/17/2001 2:57 PM Subject: Re: CTD BOP stack for KRU wells Date: Wed, 27 Sel~,','~' 30 14:37:12-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Mark O" <JohnsoMO~bp.com> Mark, I re-read your original E-mail. We accept these changes for the 5 wells you listed. Thanks for including the PTD numbers. That makes our life a little easier. Thanks, Blair Wondzell, 9/27/00. "Johnson, Mark 0" wrote: Blair, I could not save the visio drawing in xls, pdf, or txt. I saved it in jpg which I think you will be able to open. I also faxed over a copy. Thx MOJ 240-8034 Good Morning Mark, We can read the attached vsd file. Can you please send it in xls, pdf, . doc, .txt. or a paint brush file or fac to me at 276-7542 or both. Thanks, Blair Wondzell "Johnson, Mark 0" wrote: > Blair, > > We would like to make a change to the BOP stack configuration in five (5) > KRU CTD drilling permits. The drilling permits were approved by AOGCC in > 3/00. Please approve this change for those drilling permits listed below. > > A drawing of the proposed BOP stack is attached. > > The primary difference in this stack compared to what is in the KRU drilling > permits is how the ram type BOPs stack up. We want to put the 2" coil > tubing pipe rams below the mud cross. In the unlikely event of a mud cross > leak, this configuration would allow .us to isolate the leak by closing the > pipe rams on the coiled tubing during the drilling.phase. > > A risk assessment was performed on this BOP configuration and results were > favorable. > > The five sidetrack wells will be drilled with CTD using the dynamically > overbalanced drilling technique, as per the permits. The wells and approved > drilling permit numbers are as follows: Well Permit ~ # 1R-O3Ai 200-021 3K-22Ai 200-026 3H-IOAi 200-041 3H-14A 200-020 3H-16A 200-022 <<KRU BOP Stack.vsd>> FYI, a new drilling permit request for the sidetrack of 1R-O1Bi will also include this BOP stack. Thanks, Mark O. Johnson 564-5666 (office), 240-8034 (cell) > > Name: KRU BOP Stack.vsd > > KRU BOP Stack.vsd Type: > appl i ca t ion~x-unknown -con ten t- type-vsd_a u to_f il e {' ( C:\TransferkKRU BOP Stack jpg.jpg (local) - Microsoft Intemet Explorer Page 1 of 1 KRU C:TD:BOP Detail . . · ' ' ' 'tor He~ _~.~. Stullring..Box (Pack-Off) 1:0,'000 . . : '~ . 7''· Riser: Methanol'InjeCtion' ~ I ~- :~'.bhnec~tis"'7'"' ' LA, Quick. I' ...... " I :Annular BOP. (H:ydril)',7-~l/l'6? :ID 5000 psi'working pressure 7,:1:/!'6 .::ID, 5000.:p Working:.pressure .:~ .~. .Ram.TyPe,.Dual Gate BOPE . :,.,.. .... ' ........ ,..,. . : Ma.nU:.al..0v~} Hy.dra'ulic Hydr. i'i, ~ Mod'el':'B'~ ....... i' I 23/8, Slips I ~F]an'.ge.d.!F]re :Resi'sta nt HCR. 'Kelly.~H0se':t0 DUa'l~ .. ....... :~ . . :' ...[.. :.Manual ~a!~e~ .," : ' ' ,',,' ,' ' ,,, : ......... ' ............ : "KI ..... .,~ ~, ,~ , ' ~,~ ,.~Oh o kc, Manifold:'. ......... ' ..... ,[ : .................. ,,, 7'~t;/~B'~',:iO'~::,, ,,:,,,~ ..... ,5000,~.,psi:working'pressure..,.. :,';:..... : ~:~::o,~,:" ."" ......... '" ~:" .ManualOver Hydraulic I: ':': '1~'fl ' 'I. ~ . I'. ,~,1 2" Combi :ort%:necessary ~. / ,~: .:.; .., .... , .... ,single.or:DOUble M, anUal,:Mas:ter Valges,' ~.. ~ . 7" AnniU!Us ':9':5/B;" Annulus: :9/i6~0! J. THA. 9/27/00 2:26:24 PM ALASKA OIL AND GAS CONSERVATION CO~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Bruce E. Smith, P.E. AAI Coiling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re7 Kuparuk River Unit 3H- 10Ai ARCO Alaska, Inc. Permit No: 200-041 Sur Loc: 1320'FNL, 4997'FEL, Sec. 12, TI2N, R8E, UM Btmhole Loc. 621'FNL, 3653'FEL, Sec. 12, TI2N, R8E, UM Dear Mr. Smith' Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 A.AC 25.035; and the mechanical integrity (Mil) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sin~, ,,~ , Robert N. Christenson, P.E. Chair BY ORDER OF T~E CO'MMISSION DATED this I~ ~ day of April, 2000 rill/Enclosures cc: Department of Fish &Gamc. Habitat Section w/o cncl. Department of Environmental Consen'ation w/o encl. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Ddll D Redrill r~ I lb. Type of well. Exploratory D Stratigraphic Test Re-entry D Deepen DJ Service r'~ Development Gas D Single Zone [~] Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 76 feet 3. Address 6. Property Designation Kuparuk Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25531 /ALK 2657 Kuparuk Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1320' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM Kuparuk Unit Statewide At top of productive interval 12. ~ 8. Well number Number 1349' FNL, 3555' FEL, SEC. 12, T~'~I, R8E, UM 3H-10Ai #U-630610 At total depth 9. Approximate spud date Amount 621' FNL, 3653' FEL, Sec 12, T12N, R8E, UM May 1,2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'IYD) ADL 25631, 3653' @ TD feetI No Close Approach feet 2560 7894 MD / 5976 TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) i Kickoff depth: 6230' MD Maximum hole angle 106° Maximum surface 2850 psi~ At total depth (TVD) 3450 psi~ @ 6043' 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~ Weight Grade couplinc, I Len~h MD TVD MD TVD /include stac, le dataI 3" 2-3/8" 4.6 L-80 FL4S 1894' 6000' 5674' 7894' 5976' 10 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 6785 feet Plugs (measured) Tagged PBTD @ 6526' MD on 8/09/1998. tree vertical 6345 feet Effective Depth: measured 6526 feet Junk(measured) tree vertical 6126 feet Casing Length Size Cemented Measured depth True Vertical depth CONDUCTOR 115' 16" 225 Sx AS I 115' 115' SUR. CASING 2948' 9-5/8" 1300 Sx AS III, 100 Sx AS I, & 300 Sx Class G 3024' 3023' PROD. CASING 6687' 7" 450 Sx Class G & 2OO Sx AS I 6763' RECEIVED Perforatlondepth: measUred 6348'-6356'; 6362'-6390'; 6416'-6450'; 6480'-6510'. MAR 1 5Z000 Alaska Oil & Gas Cons, Commission tree vertical 5974' - 5981'; 5986' - 6010'; 6032' - 6061'; 6087'- 6112'.Anch0mge 20. Attachments Filing fee [~] Property Plat ~] BOP Sketch [~] Dive,er Sketch D Drilling program ['~ Ddlling fluid program Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements 21.1 hereby certify th~eforegoing~rrect to the best of my knowledge Questions? Call Dan Kara @ 263-4837. Signed ~ ~ ~ Title: AAI Coil Tubing Drilling Supervisor Date / Z.~ Bruc~ E. Smith, P.E. Prepared b~/ Pau/ Rauf 263-4990 Commission Use Only Permit Number I APInumbor I Approval dat.%/ j(~ ISee cover letter '~-~)~) -- (~)/"'// 50- /~:)::~ -- ~"~'~~7-~)/' q'~uire/d/..;.~/l ~ Ifor other requirements Conditions of approval Samples required r-] Yes ~] No Mud logre r~ Yes ~ No Hydrogen sulfide measures [~ Yes [~r i~1o Directional survey required [~ Yes [~] No Required working pressure for BOPE r-12M;[~] 3M; r'l 5M; [~] 1OM;D [~]3500psiforCTUV'"' Other: ORIGINAL SlGNEDaYRobert N. Chri f~ e by order of Approved by ----s.-n,~on Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate KRU 3H-10Ai CT Sidetrack and Completion Intended Procedure Objective: P&A well with 17 ppg cement. Mill window from cement plug. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: · P&A existing perfs with 17 ppg cement. Mill window from cement in 7" casing at 6230' md. Drill 20' of formation and perform leak-off test to 12 ppg, 0.5 ppg above the highest anticipated equivalent mud weight. Directionally drill a 2-3/4" (3" bi-center) well using dynamically overbalanced drilling techniques. Planned TD is 7894' md. · Run 2-3/8" blank liner to TD, cement in plaCe. · Perforate, place on production. Drilling fluids will be injected into disposal well 1R-18. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use -10 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. At least two times hole volume of kill weight fluid will be on location as a contingency. Frequent monitoring and rolling of the kill weight fluid will .be done to ensure proper weight distribution. March 14, 2000 Kuparuk 3H-10Ai Potential Drilling Hazards POST ON RIG No H2S production is anticipated. BHP: 3450 psi @ 6043' TVD (11 ppg EMW) estimated pressure. Reservoir frac gradient is estimated at -0.75 psiIft or 14.4 EMW, 4550 psi Plans are to drill with less than kill-weight fluid, or dynamically overbalanced. 10 ppg mud will result in a hydrostatic pressure that is -350 psi less than reservoir pressure. Maintain at least 350 psi WHP for well control when not circulating. Pressure loss associated with circulating (ECD) is expected to be -600 psi so applied WHP is not necessary while circulating. Monitor return-line flow rate and pit volume continuously. If crude enters the pits, take all returns to an outside tank first. Have on location at least two times wellbore volume, 11.5 ppg Kill Weight Fluid. Frequent monitoring and rolling of the kill weight fluid is required to ensure proper weight distribution. Maximum anticipated WHP w/ full column of gas: -2850 psi assuming 0.1 psi/ft gas. gradient. However, no gas saturated intervals are anticipated. March 13, 2000 KRU 3H-10J ?ROPOSED CT HORIZONTA' SIDETRACK ~SSSV @ 1793' 9-5/8" Shoe @ 3024' 3-1/2",9.3#, J-55 Production Tubing to Surface Top of 2-3/8" Liner @ 6000' (proposed) 3-1/2" x 7" Baker FHL Packer @ 6168' CUT 3-1/2" Tubing Tail 6195' Mill Window in 7" Casing from 17 ppg Cement Plug @ 6230' ELM 2-3/8" FL4S 4.6# Liner Cemented & Perforated 7" Liner & Perfs P&A'd with 17.0 ppg Cement 3" Open hole TD @ 7894' -65' of 3-1/2" Cut & Dropped Tubing Tail 7" Shoe @ 6763' PCR 3/07/2000 ARCO Plan.xlt 5400 t 5500 t 5600 t C' 5700 1 . >. . ~ 0000 - . V 61o0- , , , , , , 500 200 100 0 ARCO Alaska, Inc. Structure: Pad 5H Well : ;SH-IOA Plan, 50-105-20087-01 Field : Kuparuk River Unit Location : North Slope, Alaska Eas~ (feet) -> ......................................... 200 o 200 40° .~ ~ ,~ ,~oo ,.oo ,.o ,.oo ~o, oo ~0o 2400 2~,00 2600 ~ooo ! i i i i I i i i i i i i i i i i i i i I I i i i i i i i 'Fie-in Point Kick-off Point t0^ -r~ 3H--IOA 1'2 (R) 100 200 TD ~ . 3H-10A T3 eR) 7 i , , , , , , , , , , , , , , , , , , , , , , , , , , , , , 500 400 500 600 700 ~00 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 Vertical Section (feet) .> Azimufh 2.00 with reference 0.00 $, 0.00 £ from 5H-10 A 8oo I Z 0 600 :3- 400 2OO Prepared by BHI 3/13/00 3H-10Av4npd.xls Company: Well: Calculation Method: Vertical Sect. Plane: Measured Depth from: MD 6100.00 6125.00 6150.00 6175.00 6200.00 6225.00 6230.00 6250.0O 6275.00 6300.00 6325.00 6350.00 6375.00 6400.00 6425.00 6450.00 6475.00 6500.00 6516.00 6525,00 6550.00 6575,00 6600.00 6625.00 6650,00 6675,00 6700.00 6725.00 6750,00 6761,89 6775.00 6800,00 6825.00 6850.00 6875.00 6887.87 6900,00 6925.00 6950.00 6975.00 7000.00 7025.00 7050.00 7060.66 7O75.O0 7100.00 7125.00 7150.00 7175.00 7200.00 7225.00 7250.00 7275.00 7300.00 7325.00 7350.00 7375.00 7400.00 ARCO Alaska Inc. 3H-10A Version#5 Minimum Curvature 2.00 RKB 76.00 Azi 86.39 86.47 86.54 86.62 86.69 86.72 86.72 85.22 83.61 82.24 81.05 80.00 79.06 78.21 77.43 76.70 76.03 75.39 75.00 73.75 70,32 66,94 63.61 60.33 57.09 53.89 50.73 47.59 44,47 43,00 41.25 37,90 34.53 31.13 27.69 25.90 24.24 20.84 17.49 14.16 10.87 7.59 4.32 2.93 0.75 356.96 353.16 349,35 345.54 341.71 337.87 334.02 330.15 326.26 322.35 318.42 314.47 310.51 TVD (BRT) 5760.68 5782,21 58O3.72 5825.23 5846.72 5868.20 5872.50 5889.43 5909,86 5929.4O 5947,97 5965.52 5981,98 5997.27 6011.36 6024,17 6035.67 6045.82 6051.58 6054.62 6062.71 6070.22 6077,15 6083.45 6089.10 6094.09 6098.39 6102.00 6104,88 6106.00 6107,24 6110,17 6113.80 6118.14 6123.16 6126,00 6128.67 6133.59 6137,71 6141 .O2 6143.50 6145.14 6145.92 6146.00 6145,92 6145.43 6144.48 6143.07 6141.22 6138.94 6136.22 6133.10 6129.57 6125.67 6121.40 6116.78 6111.85 6106.61 TVD (MSL) 5684.68 5706.21 5727,72 5749.23 5770,72 5792.20 5796.50 5813.43 5833.86 5853.40 5871,97 5889.52 5905.98 5921.27 5935.36 5948.17 5959.67 5969.82 5975,58 5978.62 5986.71 5994.22 6001.15 6007.45 6013.10 6018.09 6022.39 6026.00 6028.88 6030.00 6031.24 6034,17 6037.80 6042.14 6047.16 6050.00 6052.67 6057.59 6061,71 6065.02 6067.50 6069.14 6069.92 6070.00 6069.92 6069.43 6068.48 6067.07 6065.22 6062,94 6060.22 6057,10 6053.57 6049.67 6045.40 6040,78 6035,85 6030.61 499974.15 499986.84 499999.54 500012.27 500025.01 500037.78 500040.34 500050.95 500065.29 500080.76 500097.30 500114.85 500133.36 500152.74 500172.92 500193.84 500215.40 500237.54 500251.97 500260.12 500282.62 500304.82 500326.64 500347.99 500368.79 500388.98 500408.46 500427.18 500445.05 500453.23 500461.99 500477.81 500492.42 500505.77 500517.80 500523.46 500528.48 500537.87 500545.97 500552.73 500558.12 500562.12 500564.72 500565.40 500565.86 500565.37 500563.22 500559.43 500554.02 500547.01 500538.43 500528.33 500516.75 500503.75 500489.39 500473.73 500456.85 500438.84 6000300.35 6000301.14 6000301.91 6O00302.67 6000303.41 6000304.14 6000304.29 6000305.04 6000306.45 6000310.80 6O0O313.73 6000317.15 6000321.05 6000325.40 6000330.20 6000335.43 6000341.07 6000344.88 6000347.16 6000354.45 6000363.13 6000373.17 6000384.54 6000397.18 6000411.05 6000426.10 6000442,27 6000459.50 6000468.O5 6000477.73 6000496.86 6000516,80 600O537.48 6000558.81 6000570.01 6000580,72 6000603.36 6000626.64 600065O.47 6000674.75 6000724.21 6000734.84 6000749.18 6000774.16 6000799.04 6000823.71 6000848.04 6000871,92 6000895.23 6000917.88 6000939,75 6000960.73 6000980.73 6000999.66' 6001017,42 6001033.93 Page I of 2 [ 3H-lOAv4npd.xls t', MD 7425.00 7450.00 7475.00 7500.00 7525.00 755O.0O 7575.00 7600.00 7625,00 7650,00 7675.00 7700.00 7725.00 7750.00 7775.00 7800.00 7825.00 7850.00 7875.00 7894.10 Inc 103.03 103.58 104.07 104.49 104.84 105.12 105.32 105.46 105,52 105.50 105.83 106.10 1 O6.29 106,40 106.44 106.40 106.29 106.10 105.84 105.59 Azi 306.52 302.51 298.49 294.45 290.39 286.33 282.25 278.17 274.09 270.00 266,03 262.05 258.06 254.06 250.06 246.06 242.06 238.07 234.08 231.05 TVD (BRT) 6101.11 6095.35 6089.38 6083.21 6076.88 6070.41 6063.85 6057.21 6050,53 6043.85 6037.O9 6030,21 6023.24 6016.20 6009.13 6002,06 5995.03 5988.05 5981.17 5976,00 IT VD (MSL) 6025.11 6019.35 6013.38 6007.21 6000.88 5994.41 5987.85 5981.21 5974,53 5967.85 5961.09 5954.21 5947.24 5940.20 5933.13 5926.06 5919.03 5912.05 5905.17 5900.00 5O0419.77 5OO399.73 500378.82 500357.14 500334.80 500311.89 500288.52 500264.81 500240.86 500216.79 500192.75 500168.85 500145,21 500121.93 500099.12 500076,88 500055.32 500034.52 500014.58 499999.98 6001049.12 6001062.90 6001075.22 6001086.02 6001095.25 6001102.86 6001108.82 600111'3.10 6001115.68 6001116.54 6001115.71 6001113.22 6001109.08 6001103.31 6001095.93 6001086.97 6001076.49 6001064.51 6001051.11 6001039.94 71~.27 728.05I 740.37I 751.17 760.39 768.001 773.95 778.23 780.80 781.66 780.82 778.33 774.18 768.40 761.02 752.06 741.56 729.59 716.17 705.00 1764.29 15.75I 1744.25115.75I 1723.33115.75I 1701.65115.75I 1679.301 15.75I 1656.381 15.75I 1633.011 15.75I 1609.301 15.75I 1585.351 15.75I 1561.281 15.75I 1537.23[ 15.35I 1513.331 15.35I 1489.691 15.35I 1466.411 15.35I 1443.601 15.35I 1421.36! 15.35I 1399.801 15.35I 1379.001 15.35I 1359.061 15.35I 1344.461 15.351 'SEC I 775.41 I 788.48I 800.07I 810.10I 818.54I 825.34I 830.47I 833.92I 835.65I 835.67I 834.00I 830.67I 825.70I 819.11/ 810.93/ 801.20/ 789.97/ 777.27/ 763.17/ 751.49/ Page 2 ~ 2 ARCO Alaska, Inc. Kuparuk 3H-10 3H-10 APl: 501032008700 Well Type: INJ PBTD: 6,785 ftKB SSSV SSSV Type: Otis Series 10 Ori_q Completion: 12/6/87 TD: 6,785 ffKB Annular Fluid: Last W/O: Max Hole Angle: 33 de~ ~ 4700 TUBING Last Tag: 6531 Last Tag Date: 4/24/93 Angle @ TS: 31 deg ~ 6361 PROD. CASING Rev Reason: New Schem Last Update: 3/15/98 An~le {~ TD: 32 deg ~ 6785 Elevations Grd 134 fl I Original Rig RKB J31 fl Gas Lift Casing String - CONDUCT OR Mandrel/Dummy Valve 1 Item I Btm 115 Jnts Wt6 Ord I Thd SUR. CASING 16.000 in CONDUCTOR 2.50 H-40 · Casing String - SURFACE Item Btm 3,024 Jnts Wt36.001 Oral I Thd Gas Uft ~ 9.625 in SUR. CASING J-55 Mandrel/Dummy Valve 2 Casing String - PRODUCT ION Item Btm I Jnts Wt26.00 Oral I Thd 7.000 in PROD. CASING 6,763 J-55 Tubing String - TUBING 3.500 in TUBING 31 6,226 .30 J-55 BTC AB MOD Mandrel/Dummy Valve 3 Perforations Interval Zone Status Feet SPF Date Type Comment 6,480 - 6,510 A-5,A-3 30 12 12/13187 5" Csg Gun 120 deg. phasing 6,348 - 6,356 ' UNIT D 8 12 1/11188 2 118" Silver Jet Zero deg. phasing. Gas Lift 6,362 - 6,390 C-4 28 12 1111188 2 1/8" Silver Jet Zero deg. phasing Mandrel/Durnrny Valve4 6,416 - 6~450 C-4 34 12 1111188 2 1/8" Silver Jet Zero deg. phasing Gas Lift MandrelsNalves ' Stn MD TVD Man Mfr ;Man Type Mfr Type Latch Port ' TRO Run 1 2,242 2,242 Camco '3 1/2 X 1 KBUG DV BK2 0.000 0.0 6/1189 2 3,630 3,619 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 ' 6/1/89 Gas Lift 3 4,427 4,318 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 12/13187 Mandrel/DurnmyValve5 4 4,797 4,628 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 611189 5 5,138 4,920 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 611189 6 5,477 5,219 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 12/13187 7 5,820 5,518 Camco 3 1/2 X 1 KBUG DV BK2 0.000 0.0 6/1189 Gas Lift 8 6,127 5,7841 Otis 3 112 X 1 1/2 LBX Merle DV RM 0.000 0.0 12/22/87 Mandml/Durnrny Valve 6 Other (plugs, equip., etc.) - JEWELRY ~ Depth Type Description ID 1,793 SSSV Otis Series '10' 2.813 6,172 PBR Baker 2.992 6,186 PKR Baker 'FHL' 2.992 Gas Lift 6,224 NO GO Camco 'D' Nipple 2.750 Mandrel/Dummy Valve 7 6,256 SHEAR OUT Camco 2.992 6~257 TUBING TAIL 2.992 Fish - FISH ' Depthl Descripti°n I Comment 6,64211 112" DV Empty Pocked; DV dropped in Rathole " Gas Lilt Mandrel/Dummy Valve 8 PBR ~ , SHEAR OUT TUBING TAIL , Perf Perf ., " Pelf Perf C T Drilling BOPE ~ CT Injector Head ~ I ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure _ Methanol Injection -- 7" Riser Otis 7" WLA I I Quick Connect----I I Annular BOP (Hydril),7-1/16" ID 5000 psi WP Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE ~ Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold Cutters or Combination Cutter/Blinds Slip/Pipe Rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold ri Inner Annulus Outer Annulus t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ion xAPPLICATION FOR SUNDRY APPROVALS · Type of request: _ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_ RKB 76 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 1320' FNL, 4997' FEL, Sec. 12, T12N, R@E, UM (asp's 498655, 6000335) 3H-10i At top of productive interval 9. Permit number / approval number 1349' FNL, 3555' FEL, SEC. 12, T13N, R8E, UM (asp'$ 500098, 6000312) 187-113 At effective depth 10. APl number 50-103-20087 At total depth 11. Field / Pool 1331' FNL, 3322' FEL, Sec. 12, T12N, RSE, UM (asp's 500330, 6000324) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 6785 feet Plugs (measured) Tagged PBTD @ 6526' MD on 8/09/1998. true vertical 6345 feet Effective depth: measured 6526 feet Junk (measured) true vertical 6126 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16' 225 SxAS ~ 115' 115' SUR. CASING 2948' 9-5/8' 130o Sx AS "k 100 Sx AS ~. & 30( 3024' 3023' Sx Class G PROD. CASING 6687' 7' 450 sx c~ass G & 200 Sx AS ~ 6763' 6327' Perforation depth: measured 6548'-6356'; 6362'-6390'; 6416'-6450'; 6480'-6510'. ~'~,~CE~VED true vertical 5974'- 5981'; 5986'-6010'; 6032'-6061'; 6087'- 6112'. MAP, 1,5 2000 Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 Tbg @ 6257' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' Packer @ 6186' MD. OTIS SERIES '10' SSSV @ 1793' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X 14. Estimated date for commencing operation 15. Status of well classification as: March 31,2000 16. If proposal was verbally approved Oil__ Gas __ Suspended _ Name of approver Date approved Service Water Injector 17. I hereby certi,~at the foregoing is t~j~correct to the best o! my knowledge. Questions? Call Dan Kart @ 2~3-4837. Signed ~ ~~,'~ ~//~ Title: AAI Coil Tubing Drilling Supervisor Date Bruce E. Smith, P.E. Prepared b~/ Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity _ BOP Test _ Location clearance _ -" Mechanical Integrity Test __ Subsequent t'orm required 10- ! __ Approved by order of the Commission Commissioner.. Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT P.O. BOX 102776 ANCHORAGE, AK 99510-2776 ,~UNT PAGE 1 OF 1 FEBRUARY 2, 2000 TRACE NUMBER: 225126822 CHECK NUMBER: 225126822 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION CO~I 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 AMOUNT PAID : $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES:(907) 263-4422/4988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 O I "28.."O,'; v';,O 128OOSdDO5A YltgPOOO1SdD $1OO.OO $O.00 FILING FEE FOR PERMIT TO DRILL NSK SIDETRACK 31~'-1OA $1OO.OC PI.!: ~%.' Di";.,( I~ lii.I ()R! .)1 I~().';ITING CHECK .... ,nt : P::.O. , ~.::,:," :..; ..AnCh 1~:0~'27 7;6. PAY TO THE ~:,. ...... .:~:;~:ORDER OF~ ::':,::',, :.. ~.. ~, :~"? ,.~ ~:~'"=' ~.,'": ~x~~ T~e' ~'i';~ Na~io,a~ B'a'~'~=' ~i'"'=~'k~caeo~6}~6 ..... WELL PERMIT CHECKLIST COMPANY .-"'//~'~ WELL NAME-..~/~-'/(_.~ PROGRAM: exp __ dev /' redrll sen/ ~' wellbore seg __ ann. disposal para req __ FIELD & POOL INIT CLASS ,/- /C,)//r-/-/ GEOL AREA ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE ~/'~ ¢..._ y~ N 14. Conductor string provided ................... Y 15. Surface casing protects all known USDWs ........... Y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ Y 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 abandonment been approved... Y 22. Adequate wellbore separation proposed ............. (~) 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 3,~(,.~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. UNIT# ON/OFF SHORE ~,/7 N N N Y{~ GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ Y N 31. Data presented on potential overpressure zones ..... ~ Y N 32. Seismic analysis of shallow gas zones ........... ,~/,,/~ Y N 33. Seabed condition survey (if off-shore) ..... i i ~ i-.---.. Y N 34. Contact name/phone for weekly progress reports,rexploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQ~Y.~ ENGINEERING: UIC/Annular TE~~fI~ COMMISSION: Comments/Instructions: Z -I =r- c:\msoffice\wordian\diana\checklist (rev. 02/17/00)