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Home My WebLink About182-191age Project Well History File~lver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J_ (~c~_- ~_ ~ ~_ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: D Diskettes, No.. [3 Maps: [] Grayscale items: [] Other, NofType [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: Logs of various kinds NOTES: [] Other BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation BY: BEVERLY BREN VINCENT SHERYL~ LOWELL Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: '/'~'~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~,YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERLY BREN VINCE~ARIA LOWELL (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INOIV]DUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) NO NO IIIIIIIIIIIIIIII ReScanned r~.d~i~,,,,~ ~a~ ~sp~,cia~ a~t~ntior~] ~camd~ completed} RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: QUality Checked '\ STATE OF ALASKA ) ALASKA vIL AND GAS CONSERVATION COMrVII6SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged a Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: DIL I SP I SHCS I GR, FDC I CNL I GR I CAL, CBL CASING, LINER AND CEMENTING RECORD SETT!NQ'D~PTH,Mb' . SETTNGDE~HJ\ÎD' . Hp~r;", Top BoTtoM Top" ,BoTtOM" SttE Surface 79' Surface 79' 30" Surface 2382' Surface 2382' 17-1/2" Surface 10382' Surface 8717' 12-1/4" 10061' 10940' 8423' 9233' 8-1/2" 0 GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 691' NSL, 942' WEL, SEC. 18, T10N, R15E, UM Top of Productive Horizon: 5110' NSL, 2419' WEL, SEC. 18, T10N, R15E, UM Total Depth: 5' NSL, 2428' WEL, SEC. 07, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 696661 y- 5930998 Zone- ASP4 TPI: x- 695054 y- 5935377 Zone- ASP4 Total Depth: x- 695040 y- 5935551 Zone- ASP4 18. Directional Survey 0 Yes a No 22. \ CA$ING SIZE 20" GRAD£; H-40 L-80 L-80 L-80 WT.8ERFT. 91.5# 72# 47# 29# 13-3/8" 9-518" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): None MD TVD MD SCANNED NO"l 8 2004 26. Date First Production: Not on Production Date of Test Hours Tested 27. TUSING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 9325' - 10044' 4-1/2", 12.6#, L-80 10044' - 10117' ACID"FRACTUR£;, CEMENT SQUEezE, ETC. One Other 5. Date Comp., Susp., or Aband. 9/25/2004 6. Date Spudded 11/11/1982 7. Date T. D. Reached 11/23/1982 8. KB Elevation (ft): 77' 9. Plug Back Depth (MD+TVD) 10600 + 8918 10. Total Depth (MD+TVD) 10950 + 9243 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 24. TVD 25. DEPTH INTERVAL (MD) 8946' 9275' 8925' 1b. Well Class: 0 Development 0 Exploratory 0 Stratigraphic a Service 12. Permit to Drill Number 182-191 304-325 13. API Number 50- 029-20863-00-00 14. Well Name and Number: PBU 12-20 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028330 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTINGRECPR[) 415 sx Permafrost 'C' 2100 sx Fondu, 400 sx Permafrost 'C' 500 sx Class 'G', 300 sx PF 'C' 300 sx Class 'G' AMOUNT PUl~ED PACKER SET (MD) 10032' AMOUNT & KIND OF MATERIAL USED Set EZSV P&A wI 82 Bbls Class 'G' Set Whipstock GAs-McF W A TER-BSL CHOKE SIZE GAS-OIL RATIO PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A PRODUCTION FOR OIL -BSL TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BsL Press. 24-HoUR RATE GAs-McF W A TER-BSL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS BFL NOV 1 6 1DDD RIG I N A L Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE NOV] 2004 (gF .28. ') 29. ) FORMATION TESTS GEOLOGIC MARKERS 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". Sag River 10377' 8712' None Shublik 10404' 8737' Top Sadlerochit 10483' 8810' SCANNED NOV 1 8 2004 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~.Q.N\i.l ~ ~ PBU 12-20 Well Number Title Technical Assistant Date lilt l lo<{ 182-191 304-325 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dave Wesley, 564-5153 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only -) ) Well: Field: API: Permit: 12-20A Prudhoe Bay Unit 50-029-20863-01-00 204-166 Accept: Spud: Release: Rig: 09/22/04 09/27/04 1 0/05/04 Nabors 7ES PRE-RIG WORK 09/05/04 DRIFTED TO TOP OF PATCH @ 8664' SLM, WI 4.52" GAUGE RING. RIH TO 8664' SLM LATCH PATCH. BEAT FOR TWO HRS. POOH RETIED RAN BACK. RIH TO 8664' SLM LATCH PATCH. BEATING UP. 09/06/04 JARRING UP ON PATCH. SHEARED GS. REDRESS CUT 100' WIRE. RETIED, LATCHED AND JARRED. 8668' SLM SHEARED. REDRESS. CUT 100' WIRE. RETIED SOCKET. PULLED ECLIPSE PATCH FROM 8664' SLM. DRIFTED TBG TO POINT OF COLLAPSE @ 9399' SLM WI BRUSH & 4.52" GAUGE RING. 09/07/04 MADE DRIFT WITH 2.50" CENT, AND SAMPLE BAILER. UNABLE TO WORK PAST 9,402' SLM. TOOLS SWIVELED OFF. FISHED TOOLSTRING FROM 9,400' SLM. MADE DRIFT WITH 2.50" TAPERED LIB TO 9402' SLM. (LIB LOOKS LIKE POSSIBLE COLLAPSED TUBING 21/8" ACROSS). 09/08/04 RUN 2.25 SWEDGE W/10' SPACER WI TATTLETAIL PRONG TO 9398' SLM. 09/09/04 RUN 2.50 SWEDGE + 10' X 1-1/4 STEM + 1.75 CENT + 1.25 LIB TO 9405' SLM. SIGNS OF COLLAPSED TBG (LEAD SMASHED TO WEDGE). 09/13/04 CUT TUBING AT 9325' W/4 7/16" CHC AFTER STRING SHOT FROM 9312'-9327', SUSPECT GOOD CUT, CHC HEAD HAS EVEN LARGE GROOVE AROUND 75%. WELL SHUT IN. 09/16/04 RAN GYRO FOM SURFACE TO 9200'. STOPPED EVERY 500' RUNNING IN HOLE, AND EVERY 100' WHILE PULLING OUT OF HOLE. GYRODATA TO DELIVER INFORMATION TO PE. SCANNED NO\ll 8 2004 ~) ') Page 1 - BP EXPLORATION Operati.ons Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 Hours Task Code NPT Description of Operations 9/19/2004 20:00 - 21 :30 1.50 MOB P PRE 21 :30 - 23:00 1.50 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 00:00 - 07:00 7.00 MOB P PRE 07:00 - 09:00 2.00 MOB P PRE 09:00 - 00:00 15.00 MOB P PRE 9/20/2004 9/21/2004 00:00 - 14:30 14.50 MOB P 14:30 - 00:00 9.50 MOB P 9/22/2004 00:00 - 04:00 4.00 MOB P PRE 04:00 - 09:00 5.00 MOB P PRE 09:00 - 11 :30 2.50 MOB P PRE 11 :30 - 12:00 0.50 MOB P PRE 12:00 - 13:00 1.00 MOB P PRE 13:00 - 15:00 2.00 MOB P PRE 15:00 - 18:00 3.00 RIGU P PRE 18:00 - 19:00 1.00 WHSUR P 19:00 - 20:00 20:00 - 00:00 1.00 KILL 4.00 KILL P P SCANNED I\IO\i 1 8 200t; PRE PRE DECaMP DECOMP DECaMP Prep Rig floor to lay down derrick, disconect topdrive, bridle up, held PJSM wI Toolpusher, lay down derrick. Blow down pits & disconect service lines. Held PJSM wfToolpusher, Peak. prep pits and rig for move. Move pits away from rig, Pull rig off U-12A & position to allow pits, camp and shop to pass. Move Pits, camp and shop from U-pad to DS-12. Spot camp and shop, position pits to spot on 12-20A. Move sub from U-pad, 9 miles into move at pipeline crossing at the intersection of Spine road and A-pad turn off, the sub broke through the road, 100' before pipe line crossing, were able to back the rig up, filled holes with timbers and matted this section up to the existing matts laid for pipe line crossing, 3 hr delay. Continued moving @ midnight rig was 1 mile from WOA check point. Continue Moving rig from WOA checkpoint. Approximately 1/4 mile past WOA check point rig fell through the road, began cutting timbers and blocking up under tires, lay plywood from in front of rear tires to front tires, lay mats in front of rig. Held PJSM with Peak drivers, utilized Peak truck to assist rig out of hole & up on mats. Shuttle mats around Colleen Lake with three Veco contract trucks, two loaders from heavy equipment, two rig loaders, and support from field engineers Scott Grieve, Mike Calloway and roustabout crew from tool service. Mats will be required for this entire section of road to the turn at 100% pad and on to the pipeline crossing at Baker Fishing shop. At midnight the rig had progressed 1 mile from the point of falling through the road and are currently sitting in front of the water hole at Colleen Lake. Lay mats from the water hole at Colleen Lake to corner at 100% pad, move rig to intersection. Pickup mats and shuttle around rig, lay mats from intersection to turn off to Shlumberger camp. Move rig to Shlumberger camp, continue moving rig to DS-12, utilizing plywood on shoulders as needed. rig on location at 11:30. Position Sub to to move over well. Remove wing valve on tree. (valve woud hit BOP stack) Lay herculite around cellar, spot and level rig over hole. Lay mats for pits, spot pits. Held PJSM wI Toolpusher, raise derrick, pipe shed chute, unbridle blocks and hang bridle line in derrick, RIU topdrive, mud lines and cement line. Take on seawater. Accept rig @ 17:00 hrs 9/22/2004 RIU DSM lubricator and pull back pressure valve, well on vacuum. RIU and test mud line and secondary kill lines. Held PJSM, RIU to reverse circulate taking returns through choke manifold to cuttings tank. Reverse diesel from tubing, took 64 bbls to fill hole, pumped an additional 60bbls, to displace diesel at 3 bpm, 275 psi. RIU and pump down tubing initial rate 5 bpm @ 90 psi, slowed rate to 1 bpm, while getting Printed: 10/11/2004 9:30:48 AM ) ) BP EXPLORATION Operations Summary.Report Page 248 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/22/2004 20:00 - 00:00 4.00 KILL P DECOMP air and diesel back and keep returns from splashing out of cuttings tank. Hole taking 45 bph. 9/23/2004 00:00 - 03:30 3.50 KILL P DECOMP Held PTSM, Continue circulating down tubing, taking returns through choke, until clean seawater at surface, 4 bpm ,130 psi, pumped a total of 655 bbls. Zero pressure on tubing and annulus. Blow down circulating lines and choke manifold. Lost a total of 318 bbls during displacment. 03:30 - 04:00 0.50 WHSUR P DECOMP RlU and install BPV. 04:00 - 06:00 2.00 WHSUR P DECOMP Nipple down tree, inspect lifting threads on tubing hanger, Keep hole full by pumping down 5.5" X 9 5/8" annulus with charge pump. 06:00 - 09:00 3.00 WHSUR N SFAL DECOMP BPV set too high blanking plug will not seat properly, attempt to re set BPV, no go. 09:00 - 10:30 1.50 WHSUR N SFAL DECOMP Nipple tree back up. 1 0:30 - 11 :30 1.00 WHSUR N SFAL DECOMP Rig up DSM lubricator, and pull BPV, 11 :30 - 12:00 0.50 WHSUR N SFAL DECOMP Flush profile in tubing hanger with water hose, berfore re installing new BPV. Losses for past 12 hrs = 451 bbls. 12:00.12:30 0.50 WHSUR N SFAL DECOMP Install BPV. 12:30 . 13:30 1.00 WHSUR N SFAL DECOMP Nipple down tree and install blanking plug. 13:30 - 16:00 2.50 BOPSUR P DECOMP Nipple up BOP and riser. 16:00 - 16:30 0.50 BOPSUP P DECOMP R/U BOP test equipment 16:30 - 00:00 7.50 BOPSUPP DECOMP Test BOP's per testing procedure to 250 psi low, 3,500 psi high, Jeff Jones with AOGCC witnessed BOP test Losses for last 12 hrs = 382 bbls 9/24/2004 00:00 - 00:30 0.50 BOPSUP P DECOMP RID BOP test equipment. 00:30 - 01 :30 1.00 BOPSUR P DECOMP RlU DSM lubricator, pull BPV, RID Lubricator 01 :30 - 02:30 1.00 PULL P DECOMP M/U landing joint, screw into hanger, Back out lock down screws. Pull tubing hanger to floor, broke loss @ 225k up weight = 185K, 02:30 - 04:00 1.50 PULL P DECOMP Circulate Bottoms up @ 500 gpm, 700 psi, lost 58 bbls while circulating. Rig up control line spooler and casing tools while circulating. 04:00 - 04:30 0.50 PULL P DECOMP Lay down tubing hanger, landing joint, break and lay down circulating head. 04:30 - 12:00 7.50 PULL P DECOMP Lay down 5.5- 17# L-80 tubing. Laid down 155 jts, SSSV, recovered 27 control line clamps and 3 55 bands. Losses in past 12 hrs = 636 bbls. 12:00 - 16:30 4.50 PULL P DECOMP Continue POH laying down 5.5" 17# L-80 tubing, laid down a total of 239 jts. plus 19.50' cut off jt. Rig down casing tools 16:30 - 17:00 0.50 CLEAN P DECOMP Clean floor, change elevators and bails. 17:00 - 17:30 0.50 CLEAN P DECOMP Install wear ring. 17:30 - 00:00 6.50 CLEAN P DECOMP PJSM wI Schlumberger, rig up E-line tools, RIH with 8.5- gauge ring junk basket, tag stump @ 9,325', POH with gauge ring and lay down. Make up Halliburton 9 5/8- EZSVand RIH. Losses for past 12 hrs = 519 bbls. 9/25/2004 00:00 - 02:00 2.00 DHB P DECOMP RIH with EZSV on E-line, correlate GRlCCL with previous run, locate collar and set EZSV @ 8,946', POH with E-line, Rig down Schlumberger. 02:00 - 10:00 8.00 PXA P DECOMP MlU Halliburton cement stinger and RIH picking up 4- DP to 3CANNCD NO\! 1. () 200/1 L...;' - \". , Printed: 10/1112004 9:30:48 AM ) ) BP EXPLORATION Operations Summary Report Page 3 - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/25/2004 02:00 - 1 0:00 8.00 PXA P DECOMP 8,925' 10:00 - 11 :00 1.00 PXA P DECOMP R/U and test 9 5/8" casing to 3,500 psi for 15 min. Circulate DP volume, 5 bpm @ 640psi. 11 :00 - 12:00 1.00 PXA P DECOMP M/U Circulating head, change out bails. Losses for past 12 hrs = 78 bbls. 12:00 - 12:30 0.50 PXA P DECOMP Sting into EZSV & establish injection rate, 2 bpm @ 240 psi, 3 bpm @ 520 psi. Pumped 10 bbls seawater. 12:30 - 14:30 2.00 PXA P DECOMP PJSM wI Co Rep, Toolpusher, Schlumberger. Pump 5 bbls water and test lines to 3,500 psi. Pumped 82 bbls 15.8 ppg class G cement, average rate 4.5 bpm @ 900 psi, final rate 4 bpm @ 595 psi. Pumped 10 bbls Fresh water and displace with seawater, Intial rate 4 bpm @ 210 psi, Slow rate to 3 bpm 53 bbls into displacement, pressure 100 psi. Slow rate to 2 bpm when cement at perfs, 77 bbls into displacement, pressure 691 psi. Slowed rate to 1 bpm 91 bbls into displacement, pressure 980 psi. Final rate 1 bpm, 1 ,400 psi. Squeezed 35 bbls cement through perfs. Top of cement @ 9,275' 14:30 - 15:30 1.00 PXA P DECOMP Unsting from EZSV, circulate bottoms up 11 bpm @ 1,420 psi. no cement to surface. 15:30 - 16:30 1.00 PXA P DECOMP R/U and test lower pipe rams and casing to 3,500 psi for 30 min. record on chart. 16:30 - 17:30 1.00 PXA P DECOMP Pump dry job and change bails. 17:30 - 20:30 3.00 PXA P DECOMP POH UD cement stinger. 20:30 - 21:00 0.50 WHSUR P DECOMP Pull wear ring 21 :00 - 22:30 1.50 BOPSUPP DECOMP Nipple down riser and BOP. Bleed 133/8' X 9 5/8" annulus to zero. 22:30 - 00:00 1.50 BOPSUP P DECOMP Nipple down tubing spool, back out lock down screws, while backing out the last screw, casing pushed pack- off out, cutting a groove in the Pack-off, pipe grew 31/2". 9/26/2004 00:00 - 03:30 3.50 BOPSUR P DECOMP Position pack-off over mandrel on casing hanger with running tool, Make up top drive, set weight of topdrive on pack-off, lacked 1" of being seated. UD running tool, P/U BOP's and set weight of BOP on pack-off, ran joint of 5" HWDP through stack and applied weight of top drive, pack off seated RILDS. Pull joint out & set BOP back. Make up new tubing spool and test pack-off to 5,000 psi. 03:30 - 05:30 2.00 BOPSUF P DECOMP Nipple up BOP and riser, Install secondary valve on IA valve. 05:30 - 06:00 0.50 BOPSUP P DECOMP R/U and test Flanges to 250 psi low and 3,500 psi high. 06:00 - 06:30 0.50 BOPSUR P DECOMP Install wear ring. 06:30 - 10:30 4.00 STWHIP P WEXIT Held PJSM, P/U whipstock, milling assembly orient MWD & whipstock, P/U 9 61/4. DC's, surface test MWD, P/U 18 joints of 4. HWDP. 10:30 - 12:00 1.50 STWHIP P WEXIT RIH with whipstock milling assembly to 3,814' 12:00 - 15:00 3.00 STWHIP P WEXIT RIH to 8,879' filling pipe @ 3,814' - 6,680' 15:00 - 16:00 1.00 STWHIP P WEXIT Service rig and top-drive. 16:00 - 16:30 0.50 STWHIP P WEXIT Break circulation & orient whipstock 70L of high side & set trip anchor, top of whipstock @ 8,925', bottom of whipstock @ 8,941. 16:30 - 18:00 1.50 STWHIP P WEXIT Displace seawater with 10.1 ppg milling fluid 18:00 - 00:00 6.00 STWHIP P WEXIT Mill window from 8,920' to 8,936' 2-10k wob, 500 gpm @ 2,480 psi, 100 - 120 rpm, 6,500 ftIIbs torque, up wt = 180k, dn wt. = 150k, rt wt = 165k. Pumped 30 bbl high vis sweep (duo vis, and super-sweep.) Sweep brought back a significant amount of "CAí\NC"- rO\i" p 200;~ 8 .;. ..Jj ~. , 1 0 .- '"i Printed: 10/11/2004 9:30:48 AM 'II' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 4~ BP EXPLORATION Operations Summary Report 12-20 12-20 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 9/26/2004 18:00 - 00:00 From - To Hours Task Code NPT Phase 6.00 STWHIP P WEXIT Date 9/27/2004 00:00 - 01 :00 01 :00 - 02:00 02:00 - 06:00 06:00 - 08:30 08:30 - 09:00 09:00 - 11 :30 11 :30 - 13:00 13:00 - 16:00 16:00 - 17:00 17:00 - 00:00 9/28/2004 00:00 - 00:00 9/29/2004 00:00 - 01 :30 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 4.00 STWHIP P WEXIT 2.50 STWHIP P WEXIT 0.50 STWHIP P 2.50 STWHIP P 1.50 STWHIP P 3.00 STWHIP P 1.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT 7.00 DRILL P INT1 24.00 DRILL P INT1 INT1 1.00 DRILL P INT1 SCANNED NOV 1. 8 20DL( Start: 9/19/2004 Rig Release: 10/5/2004 Rig Number: Spud Date: 11/11/1982 End: 10/5/2004 Description of Operations metal. Mill formation from 8,936' to 8,950', Work milling assembly through window, began packing off when starting mill at the bottom of the slide, working string back to bottom, had 2' of fill. Pump 30 bbl high vis sweep. Continue working Mills from 8,915' to 8,950' rotating string 120 rpm, pumping 500 gpm, 2,410 psi seeing slight drag when working string above window 5K. Did not see an increase in cuttings when sweep came back, circulated an additional bottoms up. 200 Ibs. metal recovered. POH to 8,890', RIU test equipment & perform FIT. Mud weight 10.1 ppg in and out. 8,920 md, 7,409' tvd. pressure achieved 643 psi, EMW 11.77 ppg. RID test equipment, pump dry job, monitor well, POH, @ 8,784' to 8,583' started seeing excess drag 25k worked string down, no further hole problems. Continue POH. Stand back DC's, Lay down milling assembly, (mills were packed off) clear floor of all milling equipment, clean floor. Flush SOP stack, blow down choke and kill lines. PIU SHA, orient and suface test MWD. PIU 57 jts 4" DP from pipe shed. RIH, to 8,890' fill DP every 30 stds. M/U top drive break circulation, orient motor 70L, work assembly through window, (no problem) wash from 8,940' to 8,950' Up wt = 185k dn wt = 145k Directional drill 8.5" hole from 8,950' to 9,061" by sliding. drill string hanging up & stalling motor. DD spending alot of ti re-orienting. Pulled off bottom to orient, with stabaliz t the bottom of the window, saw 25k overpull attemR work back down, set down 40K, work free by rotatin Ing 5 rpm and setting 30k down, saw no packing off ontinued drilling ahead by sliding, 500 gpm, 2,950 psi 0 ottom, 2,800 psi off bottom, up wt = 185k, dn wt = 145 wt = 150k. Drilled to 9,061', pulled stabalizer thro window with no problem. AST = 1.92 AR .52 Direcional 8.5" Intermediate hole from 9061' to 10,230'. Slidin -15K was, 500 gpm @ 3,700 psi on bottom, 3,480 ff bottom. Up wt = 195k,dn wt = 155k, rt wt = 155k. Once the MWD tools past through the window, drill string stopped hanging up reducing the amount of time spent orienting. Torque off bottom = 5K, on bottom = 7.5K. AST = 9.27 Hrs. ART = 6.43 Hrs. Calculated ECD = 10.6 ppg. Actual ECD averaging 10.85 ppg. Pumping Hi-Vis weighted sweep every 300'. Direcional drill 8.5" Intermediate hole from 10,230' to 10,325'. All Rotating w/ 10-15K was, 500 gpm @ 3,700 psi on bottom, 3,480 psi off bottom. Up wt = 2ook,dn wt = 160k, rt wt = 155k. Torque off bottom = 5K, on bottom = 7.5K. ART = 1.16 Hrs. Calculated ECD = 10.6 ppg. Actual ECD averaging 10.80 ppg. Pumping Hi-Vis weighted sweep every 300'. Circulate up samples per Geologist request. Confirmed sandstone cap atop Sag. Printed: 10/1112004 9:30:48 AM li2 -le¡I Subject: Re: 12-20 Revised Application for Sundry From: Winton Aubert <winton_aubert@admin.state.ak.us> Date: Fri, 10 Sep 200415:16:34 -:0800 To: "Wesley, Dave E" <WesleyDE@BP.com> Dave, AOGCC hereby approves changes to your proposed well 12-20i P&A procedure (App. No. 304-325), through Step 9 of "Rig Operations", described in the attachment. All other permit stipulations apply. Winton Aubert AOGCC 793-1231 Wesley, Dave E wrote: Winton, As discussed, the revision to our approach to P&A the 12-20. «12-20i Sundry Application Rev1.ZIP» Dave Wesley, Jr. Operations Drilling Engineer GPB Rotary Drilling 564-5153 office 440-8631 cell 564-4040 fax J~¿-\q, ~o4-~2S 0 bp To: Winton Aubert - AOGCC Date: September 10, 2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: Reference: 12-20i Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20863-00 Approval is requested for the proposed P&A of PBU well 12-20i. Well 12-20 was drilled and completed in November of 1982. In 1989, an injection profile showed over 90% of water entering the 41 P perforations with significant cooling deep into Zone 3, indicating a cement channel down. In 1999 a profile showed 17% going below the plug and the other 83% of injection going into the perforations above the plug, indicating that a thermal fracture or a cement channel down still exists and that most of the injection in this well is still going out of zone into Zone 3. In April of 2003, 12-20 failed a MITIA and was removed from MI service. A caliper survey was run and looked marginal for patching. A leak detection log was run and a leak was found at 8,703'. It was decided to go ahead and attempt to patch the leak. This was done in 9/03. The well failed a pressure test. While performing diagnostics on the failed patch, it was found that the tubing had collapsed at 9,424'. The 12-20Ai sidetrack is scheduled for Nabors 7ES. Current estimates have it beginning as early as September 20,2004, following the completion of the U-12A. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with Intent to plug and abandon Pre-Ria Ooerations: 1. The latest recorded MITOA to 3,000psi passed on 10/18/2002. 2. Conduct an MITOA to 2,000psi. 3. The latest CMIT T X IA to 3,000psi passed on 5/19/2003. 4. An MITIA attempted to 4,000psi failed on 9/11/2003. Pressure reached -3,600psi, then broke over. An LDL run on 10/21/2003 indicates the tubing is collapsed at 9,424'. 5. RIU slick-line and. RIH and retrieve the Eclipse 5 %" tubing patch. (Completed 9/06/2004) 6. Drift the 5 %" tubing to the point of collapse at -9,424'md to confirm clear for upcoming chemical cut. 7. RIU E-line. RIH with the appropriate chemical cutter and cut the 5 %" tubing at -9,300'md. 8. Displace the well to seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 9. Test the 9 5/8" pack-off to 5,OOOpsi for 30 minutes. Function all 9 5/8" casing and tubing Lock Down Screws; repair or replace as needed. 10. Bleed casing and annulus pressures to zero. 11. Set a BPV. Secure the well. Level the pad as necessary. Ria Ooerations: RECEIVED SEP 1 3 2004 1. MI/ RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawak:.osiall TWC. 3. Nipple down the tree. Nipple up the BOPE and test to 3,500psi. Pull TWC. AncÌlo'ü~t .;¡~Ion 12-201 Application for Sundry, Revised 4. RIU. Pull the 5%" tubing from the cut at -9,300' MD and above. 5. M/U an 8 1/2" casing mill assembly. RIH, picking up 4" drill pipe, to the 5 %" tubing stump. POOH. 6. RIU E-line. M/U a HES 9 5/8" EZSV Cementing retainer. RIH on E-line and set retainer at -9,250'md. Set as required to avoid cutting a casing collar, while milling the window. POOH. RID E-line. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record the test. 8. M/U cementing stinger. RIH and sting into retainer. Establish injection. 9. Plug and abandon, with 15.8ppg class 'G' cement. The estimated cement volume required is -80.0bbls. This is based upon 782' of 9 5/8" x 5 %" annulus above the packer, 744' of 5 %" tubing, 73' of 4 %" tubing tail, 483' of 7" liner, and -10.0bbls of slurry to squeeze the open perforations. The cement top should be approximately 9,250'md, at the cement retainer. POOH. 10. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on cement retainer. Shear off of whip stock. 11. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 12. Mill window in 95/8" casing at 1: 8,950'md, plus approximately 20' beyond middle of window. Circulate well bore clean. 13. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 14. M/U 8 %" Dir/GRlRes/PWD assembly. RIH, kick off and drill the 8 1/2" intermediate section tothe top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 15. Run and cement a 7",26.0#, L-80, BTC-M intermediate drilling liner. POOH with liner running tool. 16. RIU, run and cement -6,250' of 7",26.0#. L-80, BTC-M scab liner, sufficient to extend from the top of the 7" drilling liner, at -8,750'md to -2,500'md. POOH and UD the liner running tool. 17. RIU E-line. M/U and RIH with SWS USIT. Log the 7" drilling liner from the float equipment to the top of the drilling liner at -8,750'md. POOH and RID E-line. 18. M/U a 6 1/8" Dir/GRlRes/Den/Neu assembly. RIH to the scab liner float equipment. Test the 9 5/8" X 7" scab liner to 3,500psi for 30 minutes. Record the test. 19. Drill out the scab liner float equipment and continue in hole to the drilling liner float equipment. 20. Pressure-test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 21. Drill out the float equipment and cement down to the 7" shoe. 22. Displace the well to 8.5ppg FIe-Pro drilling fluid. 23. Drill out the shoe plus approximately 20 feet of new formation. Circulate the well clean. 24. Pull up into the 7" shoe and conduct and FIT to 10.0ppg EMW. 25. Directionally drill the 6 1/8" section per directional proposal. Circulate well bore clean, short trip to the 7" shoe. Circulate. POOH. 26. Run and cement a 4 %", 12.6#, L-80, IBT-M solid production liner, extending the liner lap -150' into the 7" drilling liner. POOH laying down drill pipe. UD the liner running tool. 27. RIU and run a 41/2", 12.6#, L-80, TC-II completion, stinging into the 41/2" liner tie back sleeve. 28. Circulate the well to clean seawater and corrosion inhibitor. Freeze protect the well to -2,200'. 29. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 30. Install a TWC. 31. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 32. Install BPV. Secure the well. 33. Rig down and move off. Post-Ria ODerations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: Estimated Spud Date: 09/01/04 09/20/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 12-201 Application for Sundry, Revised 12-20 Pre Rig Revised - 113 3/S", 72#, L-SO, H 2383' I D = 12.347" 1.) P&A 7" above IBP to -10,025' md. Not possible due to collapsed tubing. 2.) Retrieve Eclipse tubing patch. Done 9/6/2004. 3.) Chemical cut the 5 1/2" tubing at -9,300' md. Severely collapsed tubing. I ~~', ~~. ~~S;~" TOPOF 7" LNR 4 1/2", 12.6#. L-SO. f'C.tbg, D = 3.958" 9-5/S" CSG, 47#, L- SO, D=S.6S1" 1 Sand top H 10600' I I Baker bridge plug H 10606' I I~"~~~:SO, Lmer H 10940' I DÐ-t 1 0950' I TREE = FMC GEN 3 wa.LHEAD = FMC ACìUA TOR = AxaSON KB. B.EV = 77' BF. B.EV = KOP= 2700' Max Angle = 47 @ 6600' Datum M) = 10556' Datum TVD = SSOO' SS 2213' H5-1/2" CAMBAL-O SSSV NP, D=4.562" I PffiFORA TION SI.JM\1ARY REF LOG: BHCS ON 11/24/S2 ANGLE AT TOP PffiF: 23@ 10484' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DA1E 3-1/S" 4 10519-10599 S 10/17188 3-1/S" 4 10485-10509 S 10/17/88 3-1/S" 4 10650-10700 S 10/17/88 3-1/S" 4 10630-10640 S 10/17188 3-1/S" 4 10600-10620 S 10/17188 3-3/S" 6 10773-10777 S 10/17/88 3-3IS" 4 1 0660-1 0680 0 11/21/88 3-3IS" 4 10650-10660 0 11/21/88 3-3IS" 2 10630-10640 0 11/21/88 3-3IS" 2 10600-10620 0 11/21/88 3-3IS" 2 1051S-1059S 0 11/21/88 3-3IS" 1 10484-10505 0 11/21/88 18689' - 8712' H51/2" Ea...PSEpatch, Ð=2.441" Minimum ID = 2.441" @ 8689' 5-1/2" ECLIPSE PATCH, 24' LONG 1 1OO1T I 10032' 1 1 0044' I 10105' 1 10116' H5112" Baker PBRassy. H9 5/S" X 5112" Baker SAB packer I H5-1/2" X 4-1/2" XO I 1-14-1/2" CAM NO-GO LANONG NP, D = 3.S12" I H4-1/2" BAKER SHEA ROUT SUB I 110899' HPBID DA1E REV BY COWfÆNTS DA1E REVBY COWfÆNTS 11/30/82 ORIGINAL COMPLETION 09/03101 RNITP CORRECTlONS 9/4-9/7/0 BJM'KK SEr Ea...PSE PATCH 09/10/04 dew Pre rig work (revised). PRUDHOE BAY UNrr WB.L: 12-20 PERMrr No: 1S21910 API No: 5O-029-20S63-oo SEC 1S, nON, R15E, 2426.03' FB. & 5272.94' FNL BP exploration (Alaska) 12-20Ai Proposed Completion 13 3/S", 72#. L-SO, D = 12.347" 7".26#, L-SO, BTC-M scab liner I Cementing Retainer H H I Collapsed tubing. 5112",17#, L-SO, PC-tbg, D = 4.S92" TOPOF 7" LNR 4 1/2", 12.6#, L-SO, PC-tbg, D = 3.958" 9-5IS" CSG, 47#, L- SO. D = S.681" 1 I 2,200' H4 1/2" X-landing nipple, D = 3.S13" 1 TREE - FMC GEN 3 WB..LHEAO = FMC ACTUATOR = AXB..SON KB. B..EV = 77' BF. B..EV = KOP= 2700' Max Angle = 47 @ 6600' Datum r.tJ = 10556' Datum TVO = SSoo' SS 2383' -9250 9405' 10061' 1011T 10382' 9 5/S" X 7" Baker Flex-Lock Nner 2,500' hanger, ZXP liner top packer with Tie Back Sleeve. 9 5/S" X 7" Baker HMC liner hanger, 8,750' ZXP liner top packer w ith Tie Back Sleeve. Baker 9 5IS" w hip stock set on bridge plug 10085' H41/2" 'X' Landing Nip. LO. = 3.S13" 1 10105' H7" X41/2" Baker 8-3 production Pkr I' 10125' H41/2" 'X' Landing Nip. LO. = 3.S13" I 10145' H41/2" 'XN' Landing Nip. LO. = 3.725"1 10,155' H4 1/2". 12.6#, L-SO, TCU col11>letion 1 - 5" X 7" Baker HMC liner hanger, ZXP 10,160' liner top packer with Tie Back Sleeve. ~I 10,310' H7". 26#, L-SO. BTC-MNner Sand top H 10600' I I Baker bridge plug H 10606' 1 I~"~ ~~~:SO, Liner H 10940' I ~ 10950' 1 10,630' H4 1/2", 12.6#, L-SO, BT-M liner I DATE REVBY CONIv'ENTS DATE REV BY CCWI.ENTS 11/30/82 ORIGINAL COM PLETION 09/03/01 RWTP CORRECroNS 914-9/7/0 BJM'KK SET ECLFSE PATCH 09/10/04 dew Proposed col11>letion (revised). PRUDHOE BA Y UNrr WB..L: 12-20 PERMrr No: AA No: 50-029-20S63-01 SEC 1S, nON, R15E. 2426.03' Fa. & 5272.94' FNL BP exploration (Alaska) ~ ~ ~1T~1TŒ (ill~ ~~~~~~ AItA~1iA OIL AlÐ) GAS CONSERVATION COMMISSION / / ¡ / I / í ¡ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 27,2004 ! ~-r Þ~J Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 12-20 304-325 Dear Mr. Crane: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure "j~1\- '<Sf Z-ft;{ZOO4 STATE OF ALASKA ~ DTS ð'/d; /1- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 RE: r" ~~::" I,......... 1. Type of Request: -. "&.;;,u DI Abandon [] Repair Well II Plug Perforations [] Stimulate [] Oth'UG19 200 [] Alter Casing [] Pull Tubing [] Perforate New Pool [] Waiver AI'I&Tt1Ifl~ension ~ [] Change Approved Program [] Operation Shutdown [J Perforate [] Re-Enter Suspended Well A " Cons. COmmisso nchllr..... Ion 2. Operator Name: 4. Current Well Class: 5. Permit To Drilll'4ùmber BP Exploration (Alaska) Inc. D Development D Exploratolj/ 182-191 /' 3. Address: D Stratigraphic II Service 6. API Number: / P.O. Box 196612, Anchorage. Alaska 99519-6612 50- 029-20863-00-00 7. KB Elevation (ft): 77' 9. Well Name and Number: / PBU 12-20 8. Property Designation: 10. Field 1 Pool(s): ADL 028330 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARy Total Depth MD (ft): Total Dep" TVD (ftj~dve Depfu MD (ftj: Effective Depfu TVD (ftj: Plugs (measured): Junk (measured): 10950 9243 10600 8918 10600 None Cá$mg. '.'.'" ,", .«<L /L\ ,1\4[i.~ IL,fV"ID\ c>81i11'St> .< ~trllctllr::ll 79' 20" 79' 79' 1490 470 2382' 13-3/8" 2382' 2382' 5380 2670 10382' 9-5/8" 10382' 8717' 6870 4760 P Liner 879' 7" 10061' - 10940' 8423' - 9233' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 10484' - 10598' 8811' - 8916' 5-1/2", 17# x 4-112', 12.6# L-80 10117' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAB' packer; Packers and SSSV MD (ft): 10032' 5-1/2" Camco 'Bal-O' SSSV Nipple 2213' 12. Attachments: 13. Well Class after proposed work: II Description Summary of Proposal D BOP Sketch D Exploratory D Development II Service D Detailed Operations Program 14. Estimated Date for / 15. Well Status after proposed work: ./ Commencing Operations: September 1, 2004 DOil DGas D Plugged II Abandoned 16. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission ReDresentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name I,þwell Crane Title Senior Drilling Engineer Sianatur~ ~ _....c..e.1 /~ Prepared By Nama/Number: Phone 564-4089 Date K>-J9-OY Terrie Hubble, 564-4628 L/ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~, '~d.tJ D Plug Integrity øBOPTest D Mechanical Integrity Test D Location Clearance T.e-<;.t- Bo P f +0 ~S"OO pÇ.(¡~ , d~c.. du n' V\--"'\ cJy2øv~ þ~ Ç. ~)f}O\/êJ Other: ßOPG te~t- G.veðUk1-~ t "J ~ CW etA. UVLA4' -t-U<.. I ~, '0 _J Su_oont Fo"" R......", ~V~ l RBDMs 8FL AUS 3 0 ?nnh . AppONæ BY( / ~ ~~ APPROVED BY 'i;1 ,-/ COMMISSIONER THE COMMISSION Date 8 z, ñ ð Form 1 0-403 Revis~-I C,/ '-- }ubmit If¡ Dup1icate ORIGINAL ~ ~ bp 0 To: Winton Aubert - AOGCC Date: August 20, 2004 From: Dave Wesley, Jr. - BPXA GPB Rotary Drilling Subject: Reference: 12-2Oi Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20863-00 Approval is requested for the proposed P&A of PBU well 12-20i. Well 12-20 was drilled and completed in November of 1982. In 1989, an injection profile showed over 90% of water entering the 41 P perforations ~ with significant cooling deep into Zone 3, indicating a cement channel down. In 1999 a profile showed 17% going below the plug and the other 83% of injection going into the perforations above the plug, indicating that a thermal fracture or a cement channel down still exists and that most of the injection in th's well is still going out of zone into Zone 3. In April of 2003, 12-20 failed a MITIA and was removed from MI service. A caliper survey was run and looked marginal for patching. A leak detection log was run and a leak was found at 8,703'. It was decided to go ahead and attempt to patch the leak. This was done in 9/03. The well failed a pressure test. While performing diagnostics on the failed patch, it was found that the tubing had collapsed at 9,424'. The 12-20Ai sidetrack is scheduled for Nabors 7ES. Current estimates have it beginning as early as / September 20,2004, following the completion of the U-12A. The pre-rig work for this sidetrack is planned to begin as soon as the attached Application for Sundry is approved. Scope Notify the field AOGCC representative with Intent to plug and abandon Pre-Ria ODeratlons: 1. The latest recorded MITOA to 3,OOOpsi passed on 10/18/2002. 2. Conduct an MITOA to 2,000psi. 3. The latest CMIT T X IA to 3,000psi passed on 5/19/2003. 4. An MITIA attempted to 4,000psi failed on 9/11/2003. Pressure reached -3,600psi, then broke over. An LDL run on 10/21/2003 indicates the tubing is collapsed at 9,424'. 5. RIU and RIH with coil tubing to plug and abandon the well bore above the sand plug/Inflatable Bridge plug set at 10,606'md. Confirm tag at top of sand plug at -1 O,600~. lug and abandon, with 15.8ppg class 'G' cement. The estimated cement volume required. 30 bls. This is based upon 483' of 7" liner, 73' of 4 Y2" tubing tail, 44' of 5 Y2" tubing tail, and -1. bls of slurry to squeeze the open perforations. The cement top should be approximately 10,OOO'md. ./"' 6. RIU slick-line and¡RIH and retrieve the Eclipse 5 Y2" tubing patch. 7. Drift the 5 W tub(ng to the point of collapse at -9,424'md to confirm clear for upcoming chemical cut. 8. Fluid-pack the 5 Y2" tubing and 95/8" x 5 Y2" annulus to surface. Test to 3,000 psi. . 9. RIU E-line. RIH with the appropriate chemical cutter and cut the 5 Y2" tubing at -9,200'md. .../ 10. Displace the well to seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to -2,200' MD with diesel. 11. Test the 9 5/8" pack-off to 5,OOOpsi for 30 minutes. Function all 9 5/8" casing and tubing Lock Down Screws; repair or replace as needed. 12. Bleed casing and annulus pressures to zero. 13. Set a BPV. Secure the well. Level the pad as necessary. / / 12-201 Application for Sundry ~ ~ Ria ODerations: 1. Mil RU Nabors 7ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install TWC. 3. Nipple down the tree. Nipple up the BOPE and test to 3,500psi. Pull TWC. ,/ 4. RlU. Pull the 5Yz" tubing from the cut at -9,200' MD and above. 5. M/U an 8 1/2" casing mill assembly. RIH, picking up 4" drill pipe, to the 5 Yz" tubing stump. POOH. 6. RlU E-line, M/U a HES 9 5/8" EZSV. RIH on E-line and set bridge plug at -8,975'md. Set as required to avoid cutting a casing collar. POOH. RID E-line. I ' 4 7 01/ J 7. Pressure-test the 9 5/8" casin to 3 500 si for 30 minutes. Record the test. 1M-') 10 - 0 J i1.f),:> r o..{, . P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.1 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at:t 8,950'md, plus approximately 20' beyond middle of window.~Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.5ppg EMW. POOH. 12. M/U 8 Yz" Dir/GRlRes/PWD assembly. RIH, kick off and drill the 81/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80, BTC-M intermediate drilling liner. POOH with liner running tool. 14. RlU, run and cement -6,250' of 7",26.0#. L-80, BTC-M scab liner, sufficient to extend from the top of the 7" drilling liner, at -8,750'md to -2,500'md. POOH and UD the liner running tool. 15. RlU E-line. M/U and RIH with SWS USIT. Log the 7" drilling liner from the float equipment to the top of the drilling liner at -8,750'md. POOH and RID E-line. 16. M/U a 6 1/8" Dir/GRlRes/Den/Neu assembly. RIH to the scab liner float equipment. Test the 9 5/8" X 7" scab liner to 3,500psi for 30 minutes. Record the test. 17. Drill out the scab liner float equipment and continue in hole to the drilling liner float equipment. 18. Pressure-test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 19. Drill out the float equipment and cement down to the 7" shoe. 20. Displace the well to 8.5ppg Flo-Pro drilling fluid. 21. Drill out the shoe plus approximately 20 feet of new formation. Circulate the well clean. 22. Pull up into the 7" shoe and conduct and FIT to 10.0ppg EMW. 23. Directionally drill the 6 1/8" section per directional proposal. Circulate well bore clean, short trip to the 7" shoe. Circulate. POOH. 24. Run and cement a 4 Yz", 12.6#, L-80, IBT-M solid production liner, extending the liner lap -150' into the 7" drilling liner. POOH laying down drill pipe. UD the liner running tool. 25. RlU and run a 41/2", 12.6#, L-80, TC-II completion, stinging into the 41/2" liner tie back sleeve. 26. Circulate the well to clean seawater and corrosion inhibitor. Freeze protect the well to -2,200'. 27. Set the packer and individually test the tubing and annulus to 4,OOOpsi for 30 minutes. Record each test. 28. Install a TWC. 29. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. Pull TWC. 30. Install BPV. Secure the well. 31. Rig down and move off. Post-Ria ODerations: 1. Mil RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Re-install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: Estimated Spud Date: 09/01/04 09/20/04 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 12-20i Application for Sundry r" TREE = H/C GEN 3 12-20 WRLHEAD = Ftv'C A crUIHOR - AXELSON KB. ELEV - 77 BF. ELEV - KOP= 2700' Max Ange - 47 @ 6600' Datum MD - 10556' DatumTVD - 8800'SS 13-3/8" CSG, 72#, L-80, ID = 12.347" TOP OF 7" LNR Minimum ID = 2.441" @ 8689' 5-112" ECLIPSE PATCH, 24' LONG 15-1/2"TBG-PC, 17#, L-80, .0232 bpf, ID= 4.892" I TOP OF 4-1/Z' lBG-PC 10061' 4-1/Z' TBG-R::, 12.6#, L-80, .0152 bpf, ID = 3.958" 10117 9-518" CSG, 47#, L-80, ID = 8.681" PERFORA TION SlIv1Mð.RY REF LOG: BHCS ON 11/24/82 ANGLE A TTOPPffiF: 23 @ 10484' Note: Refer to A'oduction œ for historical perf data SIZE SFF INTERVAL OpnlSqz DATE 3-1/8" 4 10519-10599 S 10/17/88 3-1/8" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17/88 3-1/8" 4 10630-10640 S 10/17/88 3-1/8" 4 10600-10620 S 10/17/88 3-318" 6 10773-10777 S 10/17/88 3-318" 4 10660-10680 0 11/21/88 3-318" 4 10650-10660 0 11/21/88 3-318" 2 10630-10640 0 11/21/88 3-318" 2 10600-10620 0 11/21/88 3-318" 2 10518-10598 0 11/21/88 3-318" 1 10484-10505 0 11/21/88 10899' 10940' 10950' . 2213' 8689' - 871 Z ~ I SAFETY NOTES 5-1/2" CAM BAL-O SSSV tIIP, D =4.562" 5-1/Z' EQIPSEPATCH, ID= 2.441" 10017 5-1/2" BAKER PBR ASSY 1oo3Z 9-518" X 5-1/Z' BAKER SAB PKR 1 0044' 5-1/2" X 4-lIZ' XO 10105' 4-1/2" CAM NO-GO LA f\[)ING tIIP, D = 3.812" I 10116' H4-1/2"BAKERSI-EAROurSUB I 10117 4-1/2" TUBING TAIL I 10101' H ELfvÐ TT LOGGID 07/20187 I 10600' 10606' DATE REV BY COM~NTS DATE REV BY OOM'v1ENTS 11/30182 ORIGINAL COMPLETION 09103101 RNffP CORRECTIONS 9/4-9ntO BJMA<K SET" EeLPSEPATCH / PRUCHOE BAY UNIT WELL: 12-20 ÆRMT f\b: 1821910 API f\b: 50-029-20863-00 SEe 18, T10N, R15E. 2426.03' FEL & 5272.94' FI\l. BP exploration (Alaska) ~ r" 12-20 ~re Rig - 113318",72#, L-80, H D= 12.347" 2383' I 1.) P&A 7" above lap to -10,025' md. 2.) Retrieve Eclipse tubing patch. 3.) Chemical cut the 5 1/2" tubing at -9,200' md. Potential tubing collapse. Î 5 112", 17#, L-80, PC-tbg, D = 4.892" ITOPOF 7" LNR 4 1/2", 12.6#, L-80, PC-tbg, D = 3.958" 9-5/8" CSG, 47#, L- 80, D = 8.681" I Sand top H 10600' I I Baker bridge plug H 10606' 1 1~"~~~~:80, Lmer H 10940' I [2£J-I 1 0950' I TREE - FMC GEN 3 WB.LI.EAD = FMC ACTUA TOR = AXB.SON KB. aEV = 77' BF. aEV = KOP= 2700' Max Angle = 47 @ 6600' Datum t.Ð = 10556' DatumTVD= 8800' SS 2213' H5-1/2"CAMBAL-OSSSV NP D=4.562" 1 PERFORA TION SlJPJMA RY REF LOG: BHCS ON 11/24/82 ANGLE AT TOP PERF: 23@ 10484' Note: Refer to Production DB for historical perf data SIZE SPF NTERV A L OpnlSqz DATE 3-1/8" 4 10519-10599 S 10/17/88 3-1/8" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17188 3-1/8" 4 10630-10640 S 10/17188 3-1/8" 4 10600-10620 S 10/17188 3-318" 6 10773-10777 S 10/17/88 3-3/8" 4 1 0660-1 0680 0 11/21/88 3-318" 4 1 0650-1 0660 0 11121/88 3-3/8" 2 10630-10640 0 11/21/88 3-3/8" 2 10600-10620 0 11/21/88 3-318" 2 10518-10598 0 11/21/88 3-318" 1 10484-10505 0 11121/88 I 8689' . 8712' H 5 1/2" ECLFSE patch, D = 2.441" Minimum ID = 2.441" @ 8689' 5-1/2" ECLIPSE PATCH, 24' LONG I 1OO1T I I I 1"51/2" Baker PBRassy. H9 5/8" X 5112" Baker SAB packer 1 H5-1/2" X 4-1/2" XO I W4-1/2" CAM NO-GO LANDNG NP, D = 3.812" I H4-1/2" BAKER SHEAROUT SUB I 10032' 10044' 10105" 10116' I 10899' HPBTD DATE REVBY COWM:NTS DATE REVBY COOfÆNTS 11130/82 ORIGINAL COMPLETION 09/03101 RfoVTP CORRECTlONS 9/4-9f710 BJMlKK SET ECLFSE PA TCH 07/28/04 dew Pre rig work. PRUDHOE BA Y UNIT WB.L: 12-20 PERMIT No: 1821910 API No: 50-029-20863-00 SEC 18, nON, R15E. 2426.03' Fa & 5272.94' FNL BP Exploration (Alaska) ~ ~ 12-20Ai ProJlosed CompletitJn Potential tubing collapse. I 2,200' H4 1/2" X-landing nipple, 0 = 3.813" 1 TREE = FMC GEN 3 WB.LI-EAD = FMC ACTUATOR = Axa.SON KB. B.EV = 77' BF. B.EV = KOP- 2700' Max Angle = 47 @ 6600' Datum M) = 10556' Datum TVD = 8800' SS 1133/8",72#. L-80, H 0= 12.347" 2383' - 9 5/8" X 7" Baker Flex-Lock finer 2,500' hanger, ZXP finer top packer w ith Tie Back Sleeve. 7",26#, L-80, BTC-M scab liner 9 5/8" X 7" Baker HMC finer hanger, 8,750' ZXP liner top packer w ith Tie Back Sleeve. Baker 9 518" w hip stock set on bridge plug I 10085' H4 1/2" 'X' Landing Np. LD. = 3.813" I I 10105' H7" X 4112" Baker 5-3 production pkr II 10125' H4 1/2" ')(' Landing Nip. LD. = 3.813" I I 10145' H41/2" 'XN' Landing Np. LD. = 3.725"1 I 10,155' H4 1/2", 12.6#, L-80, TCU co~letion 1 I ~~', ~~. ~~~2" I TOP OF 7" LNR 4 1/2", 12.6#, L-80, PC-tbg, 0 = 3.958" 9-518" CSG, 47#, L- 80,0=8.681" 10061' 5" X 7" Baker HMC liner hanger, ZXP 10,160' liner top packer with Tie Back Sleeve. 10117' 10,310' H7", 26#, L-80, BTC-M finer 10382' I Sand top H 10600' I I Baker bridge plug H 10606' 1 1~"~~~~~80, Liner H 10940' I DÐ-I 10950' 1 I 10,630' H4 1/2", 12.6#, L-80, BT-M liner 1 DATE REVBY COYÆNTS DATE REVBY COM.1ENTS 11130/82 ORIGINAL COMPLETION 09/03/01 RNITP CORRECTDNS 9/4-9f710 BJWKK SET EQ.PSE PA TCH 07/30/04 dew A'oposed co~letion Wp08. PRUDHOE BA Y UNIT WB.L: 12-20 PERMIT No: API No: 50-029-20863-01 SEC 18, nON, R15E, 2426.03' Fa. & 5272.94' FNL BP exploration (Alaska) .. ( f 12-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/05/03 DRIFT WEATHERFORD DUMMY PATCH (9511 OAL 4.5411 MAX OD) SET DOWN IN SSSVN @ 21931SLM BRUSH SSSVN WI 5-1/2 BRUSH AND 4.5511 GAUGE RING DRIFT DUMMY PATCH AGAIN AND SET DOWN IN SV NIP BUT FELL THRU WITHOUT JARRING RAN DOWN TO 8820lSLM (PATCH TARGET 8702) - NO PROBLEMS 08/31/03 T/I/O= 400/010. TBG and IA FLls for ElL. TBG FL @ 1890'. IA FL @ 11401. 09/04/03 RIH AND SET LOWER ELEMENT OF 5.5in ECLIPSE PATCH WI CENTER ELEMENT @ 87121 MD. ORIGINAL SET DEPTH IN PROGRAM SHIFTED TWO FEET TO AVOID SETTING UPPER ELEMENT IN COLLAR. NO PROBLEMS RIH OR POOH. DID NOT TAG TD. LEFT WELL SHUT IN. 09/07103 SET UPPER 5-1/2in ECLIPSE PATCH ASSEMBLY. CENTER OF ELEMENT AT 86911. PATCH LENGTH 201 ELEMENT TO ELEMENT. 09/08/03 T/I/O= 530/0/30 (FLs for FIB). TBG FL @ 1650' (38 bbls). IA FL @ 11001 (48 bbls). IA valve has a intragal flange on. 09/11/03 T/I/O=52010/40 MIT IA TO 4000 PSI, FAILED, PRESSURE IA UP TO 3600 PSI WHEN SUDDENLY PRESSURE DROPPED TO 0 PSI, TBG PRESSURE INCREASE FROM 520 PSI TO 700 PSI, TOOK 55 BBLS CRUDE. PUMPED 25 BBLS MORE CRUDE AT 3 BPM, T/I/O=880/450/40. MONITORED PRESSURE FOR 15 MIN. FINAL WHP=70010/40 09/11/03 T/I/O=52010/40 MIT IA TO 4000 PSI, FAILED, PRESSURE IA UP TO 3600 PSI WHEN SUDDENLY PRESSURE DROPPED TO 0 PSI, TBG PRESSURE INCREASE FROM 520 PSI TO 700 PSI, TOOK 55 BBLS CRUDE. PUMPED 25 BBLS MORE CRUDE AT 3 BPM, T/I/O=880/450/40. MONITORED PRESSURE FOR 15 MIN. FINAL WHP=70010/40 10/21/03 LEAK DETECT LOG FROM TD 94241 TO 01. LOGGED BASE PASS DOWN 120 FPM TO TAG DEPTH 94241, NOTE XY CALIPERS READ 4.5" AND 5.5" SUSPECT COLAPSED TUBING. PERFORMED STATIC STOP COUNTS @ 9400', TEMP 151.4 DEGF. PUMPED 85 BBLS 50/50 54 DEGF DOWN IA @ 5 BPM NOTICED POSITIVE SPINNER COUNTS, FLUID MOVING UP FROM BELOW FILLING TUBING, REDUCED RATE 1 BPM PERFORM STOP COUNTS @ 94001 TEMP 145.4 DEGF. 102 BBLS AWAY, LOGGED UP 120 FPM TO 01 AND FOUND ZERO FLUIDS ENTERING TUBING, SUSPECT TEMP ANOMOL Y -3300' RESULTED FROM FLUIDS PUMPED DOWN IA. IA FREEZE PROTECTED WELL SHUT IN. LEAK DETECT LOG FROM TD 94241 TO 01. LOGGED BASE PASS DOWN 120 FPM TO TAG DEPTH 94241, NOTE XY CALIPERS READ 4.5" AND 5.5" SUSPECT COLAPSED TUBING. PERFORMED STATIC STOP COUNTS @ 9400', TEMP 151.4 DEGF. IA FREEZE PROTECTED WELL SHUT IN. Page 1 ( t 12-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/21/03 LEAK DETECT LOG FROM TD 94241 TO 01. LOGGED BASE PASS DOWN 120 FPM TO TAG DEPTH 94241, NOTE XY CALIPERS READ 4.5" AND 5.5" SUSPECT COLAPSED TUBING. PERFORMED STATIC STOP COUNTS @ 9400', TEMP 151.4 DEGF. PUMPED 85 BBLS 50/50 54 DEGF DOWN IA @ 5 BPM NOTICED POSITIVE SPINNER COUNTS, FLUID MOVING UP FROM BELOW FILLING TUBING, REDUCED RATE 1 BPM PERFORM STOP COUNTS 2 94001 TEMP 145.4 DEGF. 102 BBLS AWAY, LOGGED UP 120 FPM TO 01 AND FOUND ZERO FLUIDS ENTERING TUBING, SUSPECT TEMP ANOMALY -33001 RESULTED FROM FLUIDS PUMPED DOWN IA. FLUIDS PUMPED BBLS 80 Crude 454 50/50 Methonal/H20 534 TOTAL Page 2 ,,->- ( TREE = Ffv'C GEN 3 W8...LHEAD = Ffv'C ACfLLA. TOR = AXELSON KB. ELEV = 77 BE ELEV = KOP= 2700' Max Ange = 47 @ 6600' Datum MD = 10556' DatumTVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2383' Minimum ID = 2.441" @ 8689' 5-1/2" ECLIPSE PATCH, 24' LONG 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 10044' 10044' TOP OF 4-1/2" lEG-PC 1 TOP OF 7" LNR I 10061' 14-1/2" TBG-Fe, 12.6#, L-80, .0152 bpf, ID = 3.958" I 1011T 19-5/8" CSG, 47#, L-BO, ID = 8.681" I 10382' PERF ORA 1l0N SLMrvv\RY REF LOG: BHCS ON 11/24/82 ANGLEA TTOPPERF: 23 @ 10484' Note: Refer to A"oduction œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10519-10599 S 10/17/88 3-1/8" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17/88 3-1/8" 4 10630-10640 S 10/17/88 3-1/8" 4 10600-10620 S 10/17/88 3-318" 6 10773-10777 S 10/17/88 3-318" 4 10660-10680 0 11/21/88 3-318" 4 10650-10660 0 11/21/88 3-318" 2 10630-10640 0 11/21/88 3-3/8" 2 10600-10620 0 11/21/88 3-3/8" 2 10518-10598 0 11/21/88 3-318" 1 10484-10505 0 11/21/88 10899' 10940' 7" LNR. 29#, L-80, .0371 bpf, ID = 6.184" 10950' 12-20 (t) 2213' 8689' - 8712: ( I SAFETY NOTES 5-1/2" CAM BAL-O SSSV NIP, () = 4.562" 5-1/2" EQ..IPSEPA TCH, ID = 2.441" 1oo1T 5-1/2" BAKER PBR ASSY 10032: 9-518" X 5-1/2" BAKER SAB PKR 10044' 5-1/2" X 4-1/2" XO 10105' I 10116' 1011T I 10101' 10600' 4-1/2" CAM NO-GO LANDING NIP, () = 3.812" H 4-1/2" BAKER Sl-EAROUT SUB I 44-1/2" TUBING TAIL I 1-1 ELMO TT LOGGED 07/20/87 1 10606' -f BAKER BRIDGE R..UG I DATE REV BY COMrvENTS DATE REV BY COMMENTS 11/30/82 ORIGINAL COMPLETION 09/03101 RNITP CORREC1l0NS 9/4-917/03 BJMIKK SEf ECLPSE PATCH PRUDHOE BAY UNIT WELL: 12-20 ÆRMT f\.b: 1821910 API f\.b: 50-029-20863-00 SEC 18, T10N, R15E, 2426.03' FEL & 5272.94' FI\L BP EIcploration (Alaska) Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 10/31/03 NO. 3017 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-19B ] ~ ~ ~ MEM PPROF 8, IPROF LOG 09/29/03 H-27A ~,/~"~ ~)LZ:~ ~ MEM PPROF & IPROF LOG 10/01/07 O.S. 1-10 ~ ~--~~ PSP LDL 10126103 D.S. 16-23 '} ~ I - I ~ RST G~VEL PACK LOG 07110/03 P1-17 t PROD PROFILE W/DEFT/GHOST 10126103 D.S. 4~2 ~ I ' I~' LDL 1012~03 GNI-02 [~ ~ '~ ~TEMP PROFILEISBHP SURVEY ~0/08103 D.S. 6-16 i~~~ LDL 10/12/07 Pl-18A ~-~~ PROD PROFILE W/DEFT 101~5107 D.S. 5-28A ~1 ~ [~ I LDL 10/14~03 D.S. 12-20 ~1~ ~LDL '" 10121103 2-321SN-~ '[ ~O~ ¥ ~'~, LDL 10125107 Z-39 ~- ~ 10563105 RST-SIGMA 0912~03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. ":"'~i;~ i!:-':'"i i!i'~''''~ i~ '~'~'~! ''[~ ;~-'':; Anchorage, Alaska 99508 '; ':~,~ ~i~,~,,,.~ ", ,.~:" ~ ~ ~. L~ Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 06~05~03 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD W-19AL1 ~ 23099 TIE-IN MGR/CCL 03106103 P2-57A '<-,.~ 23272 MCNL 03115103 D.S. 12-20 ""'-J LDL 06/03/03 D.S. 15L2t A..J PRODUCTION PROFILE 05/15103 B-04 '-~.J PRODUCTION PROFILE/GHOST 05/17103 F-10A "--J L. DL 05/18103 D-30A '~"-J MEM PRODUCTION PROFILE 05/20103 , , D-22B ..~ MEM PRODUCTION PROFILE 05122103 K-01 -~ LDL 05116103 i ,, . , , , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received "~ ' "~ '" JUN RE: 12-20 (PTD #1521910) failed MITIA i Subject: Date: From: To: CC: RE: 12-20 (PTD #1821910) failed MITIA ~(~f/~,~ ~/?~ /x2H Wed, 21 May 2003 16:21:56 -0500 "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> Jim Regg <jim_regg~admin.state.ak.us>, "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us> ~ "Dube, Anna T" <Anna. Dube~BP.com>, "GPB, FSI TL" <GPBFS1TL~BP.com>, "GPB, FSI DS Ops Lead" <GPBFS1DSOpsLead~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "Rossberg, R Steven" <RossbeRS~BP.com>, "Babcock, Dan" <BabcocDR~BP.com>, "GPB, FSI DS12 Operator" <GPBFS1DS12Operator~BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com> Hi Jim and Bob. Attached are 3 MIT forms - the 2 you requested and one for a passing CMIT TxIA against a TTP, conducted 5/19/03. Current plans are to run an LDL to ID the leak point, pull the TTP and POI, and request a variance. Bob - the 2 earlier forms are both failing MIT's, the 5/19 form is for a passing CMIT TxIA. Let me know if you have any questions on the forms. Thanks! Joe 659-5102 ..... Original Message ..... From: Jim Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, May 20, 2003 2:10 PM To: NSU, ADW Well Integrity Engineer Cc: AOGCC Winton Aubert (E-mail) Subject: Re: 12-20 (PTD ~1821910) failed MITIA Please put the test info on MIT forms for each of the failures and 5/2/03) and fwd to me for our records; copy Bob Fleckenstein. (4/25/03 Thanks Jim Regg "NSU, ADW Well Integrity Engineer" wrote: > Hi Win ton and Jim, > After swapping 12-20i from MI to PWI, the well failed a second attempted > MITIA on 5/2/03. > > A recent history of well events is as follows: > > 04/25/03: MITIA Failed 2.6 bpm @ 3500 psi > > 04/27/03: Email to Winton reporting the failed MITIA and swap to water > injection. > > 05/02/03: MITIA Failed. LLR of 1.6 bpm @ 3000 psi > > Our proposed plan of action is as follows: > 1. Stop Water injection. > 2. ,'~a'.~i~3~ the 9~g.-and secure with a TTP. > 3. CMIT T x IA > 4. Based on the results of the diagnostic testing, either patch the tubing 2003 5/21/2003 1:57 PM RE: 12-20 (PTD #1821910) failed MITIA > or apply for a variance for water injection with T x IA communication. > If you have any questions, or would like to discuss other options for this > well, please give me a call. > > Thanks, > John Cubbon > GPB Well Integrity Coordinator > 1-907-659-5102 > pgr. 659-5100, x. 1154 > > <<12-20. ZIP>> > > Name: 12-20.ZIP > 12-20.ZIP Type: Zip Compressed Data (application/x-zip-compressed) > Encoding: base64 Name: MIT PBU 12-20 04-25-03.xls ~i.z v~u ~-~0 04-2~-03.x~sI Xyve: ~i~oso~ ~xo~ Worksheet (~pp~i~tio~n~.ms-~xc~)t tEncoding: base64 ..................................................................... i Name: MIT PBU 12-20 05-02-03.xls [-~MIT PBU 12-20 05-02-03.xlst Type: Microsoft Excel Worksheet (application/vnd.ms-excel) 1 ]Encoding: base64 'I Name: MIT PBU 12-20 05-19-03.xls ~__)MIT PB'U 12-20 05-19-03.xls1 Type: Microsoft Excel Worksheet (application/vnd.ms-excel) t .l, Encoding: base64 2 of 2 5/21/2003 1:57 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS12 05/19/03 Joe Anders / Jimmy Moore P.T.D.] Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. , Notes: Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. 12-20 Type I nj. 1821910 CMIT TxIA against a TTP. Note: Established LLR of 1.8 BPM @ 3000 psi from Tubing into the IA. I I I I ITubing] I ] ] ] Interval Type test I I Test psiI I I Casingl I I I I P/FI Type l~. Type l~. Type I~. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 12-20 05-19-03.xls 12 20 ACTUATOR = AXELSON KB. ELEV = 77' BF. ELEV = K~ = ........... 2700' Max Angle = 47 @ 6600' Datum MD= 10556' t2213' Id5'1/2" CAM BAL'O SSSV NIP' D = 4'562" I Datum TVD = 8800~ SS , I I ' Minimum ID = 3.812"@ 10105' [ i 4-1/2" CAMCO NO-GO LANDING NIPPLE L' ~ ~ 10017, 1--15-1'2" BAKER PBR ASSY I Z: ~ 10032' I-I~-~"x~,.".A~..s^..~. I I .-,,~"T.~.c,~#,.-~o,.o~¢,,~:~.~" Id ~oo~' t~~\ / t ~oo~' H~-~,,x4-,~,,xol I~o.o~ ~"~ H ~oo6~' I~ ~ II t 10105' 1_I4-112"CAUNO-GOC~ND~mN~P,,D--3.812"I ANGkEATTOP~F: 23 @ 10484' Note: Refor to R'oduction BB for historical porf data II SIZE SPF INTERVAL Opn/Sqz DATE I! I 3-1/8" 4 10519-10599 S 10/17/88 3-1/8" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17/88 3-1/8" 4 10630-10640 S 10/17/88 :; .. ~... :. :..:::.:. 3-1'8" 4 10600-10620 S 10'17'88 :. '~.: .: :' :I 3-3~8" 6 10773-10777 S 10/17/88 3-3/8" 4 10660-10680 O 11/21'88~~ 10606' I-t"^~"""~~ I 3-3/8,, 4 10650-10660 0 11/21/88 3-3/8,, 2 10630-10640 0 11/21/88 3-3/8" 2 10800-10820 0 11121188 3-3/8" 2 10518-10598 O ' 11/21/88 3-3/8" 1 10484-10505 O ~ 11/21/88 17" LNR, 29#, L-80, .0371 bpf, ID= 6.184" Id 10940' ~ i · I , [-~-H ~o,~o. , DATE REV BY COIVIVIENTS BATE REV BY COMMENTS PRUDHOEBAY UNIT 11/30/82 ORIGINAL COMPLETION WELL: 12-20 12/15/00 SlS-SLT CONVB;tTED TO CANVAS PERMIT No: 182-191 09/03/01 RN/TP CORRECTIONS APl No: 50-029-20863-00 SEC. 18T10N, R15E 7 2426.03 FEL 5272.94 FNL BP Ex plo ratio n (Alas ka) SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 10519-10599 S 10/17/88 3-1/8" 4 10485-10509 S 10/17/88 3-1/8" 4 10650-10700 S 10/17/88 3-1/8" 4 10630-10640 S 10/17/88 3-1/8" 4 10600-10620 S 10/17/88 3-3/8" 6 10773-10777 S 10/17/88 3-3/8" 4 10660-10680 O 11/21/88 3-3/8" 4 10650-10660 O 11/21/88 3-3/8" 2 10630-10640 O 11/21/88 3-3/8" 2 10600-10620 O 11/21/88 3-3/8" 2 10518-10598 O 11121188 3-3/8" 1 10484-10505 O 11/21/88 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS12 05/02/03 John Cubbon ~ Packer Depths (ft.) Pretest Initial 15 Min. 30 Min. Welil~2-20 I Typelnj. I~ I MD,~I ~0,0a~'I a,a,,' Tubing[ 401 10001 10001 10001 IntervaI O P.T.D.[1821910[ Type testI P I Testpsi[ 20991 Casing[ 275[ 3000'I 3000'I 3000'I P/FI F Notes: *MITIA Failed, evaluate previous failed MITIA. Established LLR of 1.4 BPM @ 3000 psi. WellI Type Inj. P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I N ores: WellI P.T.D.I Notes: Type Inj. Type l~. Type l~. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 12-20 05-02-03.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS12 04/25/03 Joe Anders I Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. We,,112-20I Type,nJ.I ~ I MD/TVDI 10,0321 S,397'1 TubingI 19801 17601 17001 16401 IntervaI O P'T'D'I1821910I Type testl P I Test psil 20991 I CasincjI 19801 35001 NAI NAI P/FI F Notes: MITIA Failed, evaluate high IA pressure. Established LLR of 2.5 BPM @ 3500 psi. WellI Type Inj. P.T.D.I Notes: P.T.~.I NoteS: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type Inj. Type Inj, Type Inj. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU 12-20 04-25-031 .xls 2003-0427_MIT_PBU_12- 20_fai I ed. txt subject: FYI: 12-20 Failed MITIA Oate: Sun, 27 Apr 2003 20:09:08 -0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWel 1 Integ ri tyEngi neer~BP, corn> To' "AOGCC wi nton Aubert (E-mai 1)" <wi nton_Aubert@admi n. state, ak. us> cc: "GPB, FSI DS12 Operator" <GPBFS1DS12Operator~BP.Com>, "GPB, FSi DS Ops Lead" <GPBFS1DSOpsLead@BP. com>, "Babcock, Dan" <BabcocDR~BP. com>, "NSU, ADW well Operations Supervisor" <NSUADWWel 1 Ope rati onsSupervi sor@BP, corn>, "Rossberg, R Steven" ,<,RossbeRS~BP.com>, "Engel, Harry R" <En~elHR@BP.COm>, AOGCC 3im Regg (E-mail)" <]im_Regg~admln.state ak.us>, "GPB, FSi TL" <GPBFSiTL~BP. com> Hi wi nton. well 12-20 (PTD 1821910) failed an MITIA. It is a WAG injector on MI injection. On 4/25/03, an MITIA was attempted and a leak rate of 2.75 BPM @ 3500 psi was established. The well was switched to water injection after the MIT and is currently injecting 7500 BWPD. Current plans are to repeat the MIT with the well on water injection, we'll inform you of the MIT results, then evaluate a plan forward. Please call if you have any questions. 3oe Joe Anders, P.E. /]ohn cubbon well Integrity Engineer, BP Exploration, (Alaska) Inc. work:(907) 659-5102 Mobil: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com Page 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION REPORT uF SUNDRY WELL OPF_rlATIONS ~-. Operations performed: Operation shutdown Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate Olher X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 691' FSL, 942' FEL, Sec 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec 18, T10N, R15E, UM At effective depth At total depth 1' FSL, 2445' FEL, Sec 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 77' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-20 9. Permit number/approval number 82-191J91-288 10. APl number 50 - 029-20863 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10950 feet Plugs(measured) 9243 feet Effective depth: measured 10899 feet true vertical 9195 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 415 sx PF 'C' 79' 79' Surface 2305' 13-3/8" 210 sx Fondu & 400 sx PF 'C' 2382' 2382' Production 10305' 9-5/8" 500 sx CI 'G', 300 sx PF 'C' 10382' 8716' Liner 879' 7" 300 sx CI 'G' 10940' 9233' Perforation depth: measured 10484-10508'; 10518-10598'; 10600-10620'; 10630-10640'; 10650-10680' (isolated) true vertical 8811-8833'; 8842-8916'; 8918-8937'; 8946-8955'; 8964-8992' (isolated) Tubing (size, grade, and measured depth) 5-1/2', 17#, L-80, PCT @ 10044' md; 4-1/2", 12.6 #, L-80, PCT w/tail @ 10117' md Packers and SSSV (type and measured depth) Baker "SAB" pkr @ 10032' md, Camco BaI-O SSSV @ 2213' md 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation MAY 1 5 1992 Nas~ 0il & Gas Cons. ~;0mmissi0n Representative Daily Average Production or Iniection Data ~lt, flCll0fag8 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5767 250 psi 24485 2014 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__. Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 ~.~.' .(:; W~ll~.~./13.C; I=nnr/.I W Pp. ir~.~ Date SUBMIT IN DUPLICATE Dally Report of Operations DS 12-20 11/2/91 Switched from SWI to MI injection. WAG conversion complete. REEEIVED MAY 1 § 199~ Alasl(a Oil & Gas Cons. Comm'tss'~on Anchorage ARCO ~-~-,~., Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-1-92 REFERENCE: ARCO CASED HOLE FINALS 1-4 3-24-92 Prod Profile ?~-:~ 3-2 3-19-92 Prod Profile ? ~.. ~.l 3-10 3-20-92 Inj Profile ?~-/°~ 3-17 3-21-92 Inj Profile ~-/z~ 3-22 3-20-92 Prod Profile ~ ~/~? 3-24 3-22-92 Prod Profile 4-1 ~ ~ ~/~- 3-23-92 Prod Profile - 3-23-92 Prod Profile g~--¢~ 9-~ 3-2o-92 Prod Profile ~--do 11-4 3-30-92 Prod Profile ~--~r' 11-12 3-22-92 Prod Profile ~t~-~ 11-24 3-23-92 ' Prod Profile ~-/?/ 12-20 3-23-92 Inj Profile 18-16~?-~/ 3-24-92 PITS 1~11~1 1, 5~' Calico Run 1, 5" Camco Run 1, 5" Camco R~ln 1, 5" Camco Run 1, 5" Camco R'~ 1, 5" Camco Run 1, 5" Camco R-u 1, 5" Camco Rl_~n 1, 5" Camco Run 1, 5" Camco Run 1, 5" Camco R.- 1, 5" ~co R.n 1, 5" Catnco Run 1.5" Camco R-n 1.5" Camco Run 1, 5" Camco Please sign and return thee attached c~gpy as receipt of data~ H v, R [ C E IV E D Sonya Wallace APPROVED ATO-1529 MAY 11 1992 Trans# 9209~7~' ....... Alaska Oil & Gas Cons. Commissiort Anchorage # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # PHILLIPS PB WELL ~ R&D #BPX # STATE OF ALASKA TEXACO # MOBIL STATE OF ALASKA ~ ALASKA"-'"L AND GAS CONSERVATION CC'-"/IISSION Ft tl ~ ~ ~~ L APPLICATION FOR SUNDRY API-'ROVAL"S" 1. Type of Request: Abandon Suspend ~ Operation shutdown ~ Alter casing Repair well Plugging Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM R 8 E P 2- ! 97 alaska Oil & ~as Cons. Commission Anchorage Re-enter suspended well Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 77' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-20i 9. Permit number 82-191 10. APl number 50 - 029-20863 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10950 feet Plugs(measured) true vertical 9243 feet Effective depth: measured 10899 feet true vertical 9195 feet Junk(measured) None Casing Length Size Cemented Conductor 79' 20" 415 sx PF 'C' Surface 2305' 13-3/8" 210 sx Fondu & 400 sx PF "C" Production 10305' 9-5/8" 500 sx CI 'G',300 sx PF "C" Liner 879' 7" 300 sx CI 'G' Measured depth True vertical depth 79' 79' 2382' 2382' 10382' 8716' 10940' 9233' Perforation depth: measured 10484'-10508';10518'-10598';10600'-10620';10630'-10640';10650'-10680'(isolated) true vertical 8811'-8833';8842'-8916';8918'-8937';8946'-8955';8964'-8992'(isolated) Tubing (size, grade, and measured depth) 5-1/2",17 #,L-80,PCT @ 10044'md; 4-1/2",12.6 #,L-80, PCT w/tail @ 10117'md Packers and SSSV (type and measured depth) Baker "SAB" pkr @ 10032'md, Camco BaI-O SSSV @ 2213'md 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: September 1991 16. If proposal was verbally approved Oil Gas Suspended Name of approver Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Sr. Area Operations Engineer Date FOR COMMISSION H~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY · :",q.-~ELL A. DOUGLASS JApproval No. ._,..., u"/ _.-,TON '" ~A ~- ~ Commissioner Date ~ --"~"~O-- ~ ~'~/ Form 10-403 Rev 06/15/88 c: SW SUBMIT IN TRIPLICATE DS 12-20i Summary of Proposed Operations AP1 50-029-20863-00 Permit # 82-191 Conversion from Seawater/Produced Water Injection to Water- Alternating-Gas Injection Service 1) Test surface flowline and valves. 2) Commence Miscible Gas, Alternating with Water on or about October 15, 1991. Note: This well is part of the planned expansion of the Prudhoe Bay Miscible Gas Project (PBMGP). Mechanical Integrity Test of tubing/casing annulus passed and witnessed by AOGCC on 7/16/91. STATE OF ALASKA ALASK,A~r'''-''''l_ AND GAS CONSERVATION C(" 'MISSION REPORT SUNDRY WELL OPI::RATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing ~ Alter casing Plugging Perforate Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory StratJgraphic 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 10950 feet Plugs(measured) 9243 feet 6. Datum of elevation(DF or KB) 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. W~ll/number 1 9. Permit number/approval number 82-191/9-584 10. APl number 50 - 029-20863 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10899 feet true vertical 9195 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 415 sx PF 'C' 79' 79' Sudace 2305' 13-3/8" 210 sx Fondu & 400 sx PF 'C' 2382' 2382' Production 10305' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 10382' 8716' Liner 879' 7" 300 sx CI 'G' 10940' 9233' Perforation depth: measured 10484-10508'; 10518-10598'; 10600-10620'; 10630-10640'; 10650-10680' (isolated) true vertical 8811-8833'; 8842-8916'; 8918-8937'; 8946-8955'; 8964-8992' (isolated) Tubing (size, grade, and measured depth) 5-1/2", L-80, 17#, PCT @ 10044' MD; 4-1/2", 12.6#, L-80, PCT tail @ 10117' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 1003 ' · - / ',', Can3c, o Bal-0 SSSV @ 2213' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached J~UG ]-/~ ]_~0 Treatment description including volumes used and final pressure /~la,s,~(a. 0JJ .& Gas Cons, C0mmissi0 ~nnhnrnn~. 14. Representative Daily Average Production or InieCti°n D~.ta Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure .... 16768 -- 893 Prior to well operation Subsequent to operation 13287 -- 73O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 430 JWS cc: J. Gruber. ATO-1478 SH SUBMIT IN DUPLICATE DS 12-20i DESCRIPTION OF WORK COMPLETED BRIDGE PLUG INSTALLATION FOR INJECTION PROFILE MODIFICATION I 2/7/89: MIRU. PT to 3500 psi. Performed tubing wash. Pumped: 85 bbls 12% HCI w/10% Xylene, followed by, 283 bbls Seawater. Displaced w/Meth-Water. POOH. RD. Returned well to injection. 12/8/89: MIRU. PT to 3500 psi. RIH w/CT Bridge Plug to set at 10,645' MD. Plug did not set properly. Could not retrieve plug. POOH. RD. 12/9/89: RIH w/fishing tool. POOH w/Bridge Plug. RD. Returned well to injection. I 2/29/89: MIRU. PT to 3500 psi. RIH w/CT Bridge Plug to set at 10,605' MD. Plug set properly. Lost plug setting tools in hole. POOH. RD. I 2/30/89: RIH w/fishing tools, and POOH w/fish. Tagged Bridge Plug top at 10,605'MD. POOH. RD. I 2/3 1/89: Made runs w/dump bailer to cover Bridge Plug w/sand to 10,600'MD. POOH. RD. Returned well to PWI injection. 4/15/90: MIRU, and RIH to run an Injection Profile. Log showed 1% of injection going past plug. Tag run indicated plug had moved down to 10,636'MD. POOH. RD. Put well on injection. 4/18/90: MIRU, & PT to 4000 psig. RIH w/CT to 10,635' MD. POOH. RD. Returned well to injection. Pumped 2.1 bbls of Sand Slurry. 4/20/90: RIH & tagged top of sand at 10,635' MD. POOH. RD. Returned well to injection. Perforation Summary_: Open perforations not covered by sand are currently at: 10,484 - 10,508' MD Ref. Log: BHCS 11/24/82. 10,518 - 10,598' MD 10,600 - 10,620' MD 10,630 - 10,635' MD (of the 10,630 - 10,640' MD perf interval). Open perforations that are covered by sand/bridge plug are currently at: 10,635 - 10,640' MD (of the 10,630 - 10,640' MD perf interval). Open perforations that are isolated below the bridge plug are currently at: 10,650 - 10,680' MD Previously squeezed perforations are at: 10,680 - 10,700' MD 10,773 - 10,777' MD ARCO ALASKA, INC~ P.O. BOX i ¢';~]6(']' ANCHORAGE, ALASKA DATE REFERENCE ' ARCO 995i ,~ RECEIVED Alaska Oil & (;as Cons. Commission Anchorage CASED HOLE FIHALS '.-'-:~'? 4-i6-9'2, PRODUCTION PROF'ILE RUN t 6-~ 7 4-9-9,2' F'IT'£ RUN ~ 7-4 4-23-9(.} PRODUCTION PROFILE RUN i 7-i6 4-'23-9,2, INJECTION PROFILE RUN i 7'"'7~3 4-23-9~) INJECTION PROFILE RUN ~ i~-~ 4-'2')-9('}.- ,PRODUCTION, . PROFILE RUN ~ ~-S 4-~8-9~ PRODUCTION PROFILE RUN t ~-~2 4-'i7-9(~ F'RODUCTION PROFILE RUN ~ ~i-2~ 4-2S-9~ GAS LIFT SURVEY RUN ~ ~m-~m 4'-~ '= m(D F'RODUCT!ON PROFILE RUN ~ ~ ~- ~ . . ~2-2~3 4-i5-?(~ ~NJECT~ON PROF'~LE RUN ~ ~3-2& 4/2(~-2~/9,2, TEHP SURVEY RUN ~ ~4-25 4-~-9,2, LE~K DETECT~ON SURVEY RUN ~ ~5-~ ~-~-?~ PRODUCTION F'ROF~LE RUN ~ i 5 i i ~ 9~ - 4-~- TEHP SURVEY RUN i tS-iS 4-i4-9~ PRODUCTION PROFILE RUN i iS-2() 4-ii-9~ PRODUCTION PROFILE RUN i i6-8 4-i5-9(~ LEAK DETECTION SURVEY RUN i i6-i9 4-iS-9~ LEAK DETECTION SURVEY RUN i PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA RECEIVED BY -'T ........ HAVE A NICE DAY! SALLY FtOFFECKER A'TO- i 5'~- . AF'F'ROVED~ I'RANS~ 9 C A H C 0 C A M C 0 C A M C O CAMCO C A M C (] C A M C 0 CAMCO C A M C 0 CAMCO C A M C 0 C A M C 0 CAMCO CAMCO CAMCO CAHCO C A M C 0 CAMCO CAMCO DISTRIBUTION · .- CENTRAL FILES ~-~ F'HILLIF'$ -~: CHEVRON PB WELL F'IL. ES D & M R & D '"' EXTENSION EXPLORATION ~ BF'X ~ EXXON -~ STATE OF ALASKA MARATHON TEXACO ~ MOBIL * THE CORRECTED AF'I~ FOR i5-20 IS 50-029-2it~53. ARCO AL_A~KA, INC, F:'.,O~ BOX t 00.360 Ai'-~C:I-IOI~.:AG E, ALASKA 995t (.) DA"I"E · t -.5-89 R I!': F F: F'.: E N C E ' Al?CO CA,S'ED I"IOI..E FINAl_,? ") '-' ")'7 i 2 '-' ''~ S - r-t 9 rt r) !.. L. A R / F:' E R F: a;. .,,'.. a' t,:.") .-.. ":' "-".,.-. ,, i '::'- 2 ° "- 8 ?,.. , ..... F: 0 i.. I_ A R t 4 - 2 i t,..':.> - ,:.. ''> n,, - 8 c,,, C O L L. A R ,'" P E R I::' t 4-28 t 2'--2':'.:-89 CF'ET i .4 - 28 t,,.') _. .,.':~ 6 - 89 H F' C: ~ 4-'28 i~.'~'-'~ 6- 89,:.. ,~P INNER/ TIEMI:' i 4-28 ~ 2'"-26-89 VERT ]:I..OG F'I..EA,'~E ZIGN AND RETURN THE A'I"TACHED COPY R Ii':: C E: I V E I) B Y _.~~.~_'~._ ......................... :. ..... HAVF A NICE DAY, RECEi'VED ,~,' A I._ I... Y I"IOFFEC:K E:F;: A'ro- s' 9 JhN 1.7 Ii)gO Alaska 0ii '& Gas Cons. Comm~ss-~----'"la /~chomge DISTRIBUTION · ..'"' CENTRAL FILES ~ CHEVRON D & M ~- EXI'ENSION EXFLC. RAFtON 11' ~ EXXON MARATHON ~'- MOBIL AS' IRI::Ci::iIF'I" OF' DATA, AF:'F:'RC)VI~:D (~ .... 'I'RAN~':~ 90Dt 0 F' H I L L ]1P 5' F:'B WEI...L FIL. ES R & D BPX 3TA'['E OF AL.A~'KA TEXACO ARCO AlaSka, Inc.' Prudhoe Bay ,.ngineering Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 6, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-20i, Permit No.82-191 Dear Mr. Chatterton' Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/JMV/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-20i)Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--$132-C STATE OF ALASKA ALASK/~'-'"!L AND GAS CONSERVATION CK-"MISSION APPLICA ,'ION FOR SUNDRY AFPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Vadance Perforate X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well ..~,~,.~ Development.~,,,~' Exploratory StratigraphiCservice 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, TION, R15E, UM At top of productive interval 173' FNL, 2435' FE, Sec. 18, TION, R15E, UM At effective depth At total depth 1' F"SL, 2445' FEL, Sec. 7, T10N, R15E, UM Other X 6. Datum of elevation(DF or KB) 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-20i 9. Permit number 82-191 10. APl number 50 - 029-20863 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10950 feet Plugs(measured) true vertical 9243 feet .J i: . measured 10899 feet ~...~., ~.:, - ~,.,.:~:. ' ' true vertical 9195 feet Junk(measured) i~?:':'.':~ ' '~ ': - ,::.. ;. Length Size Cemented Measured depth 79' 20" 2305' 13-3/8" 415 sx PF 'C' 79' 210 sx Fondu & 400 sx PF 'C' 2382' 10305' 9-5/8" 500 sx CI 'G' & 300 sx PF 'C' 10382' 879' 7" 300 sx CI 'G' 10940' measured 10484-10508'; 10518-10598'; 10600-10620'; 10630-10640'; 10650-10680' True vertical depth 79' 2382' 8716' 9233' true vertical 8811-8833'; 8842-8916'; 8918-8937'; 8946-8955'; 8964-8992' Tubing (size, grade, and measured depth) 5-1/2", L-80, 17#, PCT @ 10044'; MD; 4-1/2", 12.6#, L-80, PCT tail @ 10117' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 10032' MD; Camco Bal-O SSSV @ 2213' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1989 16. If proposal was verbally approved II ,. X Name of al)prover Date approved Service 17. I hereby.certify that the foregoing is true and correct to the best of my knowledge. Signed ~/'. ~,~~'~'~ Title Operations Engineering Manager I15. Status of well classification as: ~as Suspended FOR COMMIS.~ION LISI= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner I Approval No. 7_~-~ Approved Copy Date ((O(~/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 12-20 Non-Rig Workover Application For Sundry Approvals . 3. 4. 5. 6. 7. 8. Perform a slickline GR/dummy gun run to verify PBTD and ensure wellbore is free of obstructions. If necessary, perform a tubing wash and/or FCO. MIRU service company. RIH with through-tubing retrievable (TYR) bridge plug. Locate top of bridge plug at 10640' MD. Set TI~ bridge plug. Release from TFR bridge plug. POOH with setting tool. Place approximately 10 ft of bridging agent on top of TTR bridge plug. POOH. RD equipment. Return to injection. Test inJectivity and verify Well Information Current Status: Injecting (100°/6) Expected Static Bottomhole Pressure: 3900 psi @ 8800' SS Expected Static Bottomhole Temperature: 80 °F Expected Fluid in wellbore at time of workover: seawater profile. 6 2 COILED TUBINt~ UNIT BOP Ei)U l PHENT~ 1. 5000 PSI 7" WELLHEAD OONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" tJYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS IS.5000 PSI 4 1/1~B" STUFFING BOX 2 H]RELINE BOP EOUIPHENT 1. 5000 PS, I ?" W£LLH[.AD CONN£C10R FLANGE 2. 5000 PSI WIRELIN£ RAMS (VARIAEiL[ SIZE) · 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-OFF ARCO ALAS.'KA: INC. p._.Fl BO¥:.. i (_'-) (-) 3 6 ,.'3 ANCHORAGE DATE' i-2S-89 REFERENCE' ARCO. CAZED HOLE FINALS i-.~ i -4--89 PRODUCTION F'ROFILE i-6 i -5-89 PRODUCTION PROFILE i-J4 i-9-89 PITS t-2i i -7-89 PRODUCTION PROFILE i-22 i -8-89 F'RODUCTION PROFILE 3-t t2-29-88 PRODUCTION F'ROFILE 3-i(3 i2-29-88 INJECTION PROFILE 3-25 i2-:5i-88 F'RODUCTION PROFILE 5-3 i-5-89 PITS 5-i2 i-2-89 PRODUCTION F'ROFiLE 9-4 i2-S0-88 PRODUCTION PROFILE 9-Si i2--3~-88 PRODUCTION PROFILE i i - i =~' '-" ~' i~-°8-88--- LEAK DEi'ECI'ION ii-iS i-i-89 LEAK DETECTION i2-9 i-7-89 F'RODUCI'ION PROFILE i2-2G i-8-89 INJECTION PROFILE iS--6 i-6-89 INJECTION PROFILE i S-S,'-J i -i i -89 PRODUCTION PLEASE SIGN AND RETURN THE ATTACHED COPY AS RUN i , 5" RUN i , 5' RLJN t, 5 RIJN t , 5' RUN t .. 5 R~JN t , 5 · RUN t RI. JNi , :S" RUN i , 5" R~JN i , 5" RUN t, 5" RUN t, 5 R. UN i , '2 RtJN i , RUN RUN i, 5 RUN i, 5 RtJN i, 5 RECEIPT OF DATA. · # · CAMCO CAMCO CAMCO CAMCO t.,r4MUU CAMCO CAMCO CAMCO ;:]:AMC(] CAMCO CAi'iCO CAMCO CAMCO CAMCO CAMCO CAMCO $CH RECEIVED BY___ HAVE A NICE DAY! SALLY HOFFECKER AT0-t~29 TRAMS ~89~4~ APPROYED -'~1~--- DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D SAF'C STA'T'E OF ALASKA TEXACO ,'~ N ''-' H !? ~'-.: -:'] c' F_.' ¢'~ L :q ,? K ¢i DATF_ - i i .--3(!:~--. 88 F.:EF'EF.:EN'E:E ' AR'-'.'.'q:,_ r:A2ED.., HOLE FINALS' ARCO ALASKA, INC P.O. BOX i86'S60 '~ ANCHORAGE, ALASKA 995',~ DATE' t8-2t-88 REFERENCE' ARCO CASED HOLE FINALS t -~'~ t6'-8-88 ,.%." "2-i 4 t 8-5-88 :5-7 9- t 8.-8(3 :5-t 5 t 0-7-88 7-5:5 9-2S-88 9-i 9-i 6-88 9-9 t 6'-t 7-88 9-i:5 9-2t-88 o-")7 9-25-88 i.-"~- '~ ;":~-",, i 0-8-88 t 75-"~A,. t 0-6-88 i 5-9 t 8-7-88 i ~-i '~ i 8-7-88 t 5-'~'-',_.-t6'-6-88 t5-25 t8-t3-88 PWDW2-i 9-i 8-88 PERF RECORD COLLAR/F'ERF INJECTION PROFILE COLLAR/PERF COLLAR F'RODUCTION PROFILE F'ERF RECORD F'RODUCTION PROFILE PRODUCTION PROFILE COLLAR/F'ERF' PRODUCTION CNL-GAMMA COLLAR/F'ERF COLLAR/PERF COLLAR/PERF TEMP PLEASE SIGN AND RETURN THE ATTACHED COPY A37 RECEIP'I' OF RUN i, RUN i, RUN i , RUN t , RtJN i, RUN t , RtJN i, RUN t , RtJN i, RUN i, RUN I , RUN t , RUN t, RUN t, RUN i , RUN i, DATA. 5' 5' 5" 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' SCH ATLAS CAMCO ATLAS' CAMCO CAMCO $CH CAMCO (]AMC(] Al'LAS $CH ATLAS ATI_A~' ATLAS' ATLAS CAMCO RECEIVED BY HAVE A NICE DAY! 3ALLY HOFFECKER A'i'O-i 5"':'9.- TRAN~ ~886t8 /~ AF'PROVED Anchorage DI$I'RIBUTION '$ CENTRAL FILES' $ PHILLIPS ~~ CHEVRON F'B WELL FILES D & M R & D. ~, EXTENSION EXPLORATION ~ - SAPC -'" EXXON ~ 5'TATE OF' ALA3'KA - MARATHON ~ ~ TEXACO ~ MOBIL ** THE WRONG AF'I ~- IS PRINTED ON THIS LO(;;. I"HE CORRECT ~: IS 50-()":29-':20~'24-6'i. ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 17, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-20 Permit No. 82-191 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 12-20)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--8132-C STATE OF ALASKA ALAS,.,~ OIL AND GAS CONSERVATION COM~,,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~. Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 77' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM 7. Well number DS ~2-20 8. Permit number 82-191 9. APl number 50-- 029-20863 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10950 feet 9243 feet Plugs (measured) Effective depth: measured 10899 feet true vertical 9195 feet Junk (measured) Casing Length Size Structural Conductor 79' 20" Surface 2382 ' 13-3/8" Intermediate Production 10382 9-5 / 8" Liner 879 7" Perforation depth: measured 10484-10508', 10518-10598', 10600-10620' true vertical 8811-9011' Tubing (size, grade and measured depth) Cemented 415 Sx 210 & 400 Sx 500 & 300 Sx 300 Sx Measured depth 79' 2382' 10382' 10061-10940' ~ue Verticaldepth 79' 2382' 8716' 8422-9233' , 10630-10640' , 10650-10700' 51 ,, ~r ~ ~ , ~-ou, 17¢~, 10117' MD Packers and SSSV (type and measured depth) £~.7~,,,'r,..~ ,~' ~ .- .,. Baker SAB Packer @ 10032' ~, Camco Bal-O SSSV ~ 2213' ~" ........ U,~.7: ;';:'7-; :;,'~:':. ;':, ~:~':~':':- i*~, ;. ~ .......... 12.Attachments Description summary of proposal ~ Detailed operations program ~ ~BOP'~'; sketch 13. Estimated date for commencing operation 4/1/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~,,f,~/~,,w'-~_.~,~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance -~pproved Copy Returned - ORIGINAL SIGNED ElY Approved by LONNIE C. SMITH Commissioner IApprOvalNO' ~P-- /¢~ by order of the commission Date Form 10-403 Rev 12-1-85 WELLS/27 T. A. Billingsley, ATO-1506, 265-6871 Submit in triplicate DS 12-20 PWI CTU CEMENT SQUEEZE PROCEDURE 1. RIH with coiled tubing. With well on injection, clean out sand from rathole and place in channel. 2. Shoot squeeze perfs: Ref. BHCS 11/24/82. 10773-10777' 4 spf 3. Perform acid wash to clean up perfs and channel. 4. Pump cement through coiled tubing, squeezing existing perforations. 10484-10508' Ref: BHCS 11/24/82 10518-10598' 10600-10620' 10630-10640' 10650-10700' 5. Pressure up on squeeze and hold for 1 hour. 6. Contaminate cement in wellbore. Leave well shut in overnight. 7. Jet out contaminated cement. Leave well shut in. 8. After at least 2 weeks, test for injection. 9. Reperforate: 10484-10508' Ref: BHCS 11/24/82 10518-10598' 10600-10620' 10630-10640' 10650-10680' 10680-10700' Limited shot density. 10. Return well to injection. 11. Run injection spinner/temp log. TAB2/162 6 5 4 2 1. 5000 PS1 ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PS1 4 1/16" PiPE RAMS 3. 5000 PS1 4 1/6" HYDRAULIC 5LIPS 4. 5000 PSI 4 1/6" SHEAR RANIS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1. ~>000 PSI 7" WELLHEAD CONNEC'I'OR FLANGE 2. 5000 PSI WIRE:LINE RAU$ (¥ARiABL[ SIZE:) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUB[ PACK-OFF H]RELINE BOP EOU]PMENI I II I ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 100360 Anchorage, Alaska 99510=0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 17, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-20 Approval No. 7-141 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 12-20)W1-3 detailing work ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ,'-". STATE OF ALASKA ---. ALAS. OIL AND GAS CONSERVATION COM, ~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 77' RKB Feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 691' FSL, 942' FEL, Sec. At top of productive interval 173' FNL, 2435' FEL, Sec. At effective depth 18, TION, R15E, UM 18, T10N, R15E, UM Attotaldepth 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM 7. Well number DS 12-20 8. Approval number 7-141 9. APl number 50-- 029-20863 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10950 feet Plugs (measured) 9243 feet Effective depth: measured true vertical 10899 feet Junk (measured) 9195 feet Casing Length Structural Conductor 79 ' Surface 2382 ' Intermediate Production 10382 Liner 879 Perforation depth: measured 10484-10508' , 10518-10598' true vertical Size Cemented 20" 415 Sx 13-3/8" 210 & 400 Sx Measured depth True Vertical depth 79' 79' 2382' 2382' 9-5/8" 500 & 300 Sx 10382' 8716' 7" 300 Sx 10061-10940' 8422-9233' , 10600-10620' 10630-10640' 8811-9011' ~bing(size, grade and measured depth) 5~', L-80, 17#, 10117' MD ~ackers and SSSV(type and measured depth) Baker SAB Packer @ 10032' MD, Camco Bal-0 SSSV @ 2213' MD , 10650-10700' 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure -- 12500 inj. -- 12500 inj. ~bing Pressure 1100 1150 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. , hereby certify that the foregoing is true and correct to the best of my knowledge ..S~ ~.~--(~- Signed ~~,~~?~.~~,..~~' Title Operations Engineering Manager Date Form 10-404 Rev. 12-1-85 Submit in Duplicate ~LLS/27 T. A. Billingsley, ATO-1506, 265-6871 DS 12-20 SAND PLACEMENT FOR PWI CHANNEL SHUTOFF 7/10/87 7/13/87 Run spinner/temperature log. Lower perfs taking 72% of injection and channel detected 90' below perfs. Pumped sand through coiled tubing in two stages. 2600 lbs 12/20 mesh sand 2600 lbs 20/40 mesh sand 1600 lbs 100 mesh sand 800 lbs silica flour 7600 lbs total sand Minor injection pressure response that was only temporary. 8/5/87 Ran spinner survey; 82% of the injection entering the lowest perfs. 11/15/87 Pumped 6000 lbs sand in four stages. 2000 lbs 12/20 mesh sand 2000 lbs 20/40 mesh sand 1000 lbs 100 mesh sand 1000 lbs silica flour 6000 lbs total sand Minor injection pressure response that was only temporary. WELLS/27 STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMi,...~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon © Suspend ,~ Operation Shutdown [] Re-enter suspended well F~ Alter casing [] Time extension ~ Change approved program ,~ Plugging ~ Stimulate [] Pull tubing [] Amend order ~ Perforate ,~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 77' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth l' FSL, 2445' FEL, Sec. 7, Ti0N, RL5E, UM 7. Well number DS 12-20 8. Permit number 82-191 9. APl number 50-- 029-20863 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth:, measured true vertical 10950 feet 9243 feet Plugs (measured) Effective depth: measured 10899 feet true vertical 9195 feet Junk (measured) Casing Length Size Structural Conductor 79 ' 20" Surface 2382' 13-3/8" Intermediate Production 10382 9-5/8" Liner 879 7" Cemented Measured depth True Vertical depth 415 Sx 79 ' 210 & 400 Sx 2382' 79' 2382' 500 & 300 Sx 10382' 8716' 300 Sx 10061-10940' 8422-9233' Perforation depth: measured i0484-i0508', 10518-10598', 10600-10620', 10630-10640' true vertical 8811-9011' Tubing (size, grade and measured depth) 52" L 2 , -80, 17#, 10117' MI) Packers and SSSV (type and measured depth) Baker SAB Packer @ 10032' MD, Camco Bal-O SSSV @ 2213' MD 12.Attachments Description summary of proposal [] Detailed operations program Q BOP sketch 13. Estimated date for commencing operation 4/1/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed ~¢~/~~~~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Notify commission so representative may witness Q Plug integrity [] BOP Test [] Location clearance .Approved Copy Returned .~ ~ Commissioner Approval No. by order of the commission Date Form 10-403 Rev 124-85 WELLS/27 T. A. Billingsley, ATO-1506, 265-6871 Submit in triplicate DS 12-20 PWI CTU CEMENT SQUEEZE PROCEDURE i · RIH with coiled tubing· With well on injection, clean out sand from rathole and place in channel. 2. Shoot squeeze peris: Ref. BHCS 11/24/82. 10773-10777' 4 spf 3. Perform acid wash to clean up peris and channel. 4. Pump cement through coiled tubing, squeezing existing perforations. 10484-10508' 10518-10598' 10600-10620' 10630-10640' 10650-10700' Ref: BHCS 11/24/82 5. Pressure up on squeeze and hold for 1 hour. 6. Contaminate cement in wellbore. Leave well shut in overnight. 7. Jet out contaminated cement. Leave well shut in. 8. After at least 2 weeks, test for injection. 9. Reperforate: 10484-10508' 10518-10598' 10600-10620' 10630-10640' 10650-10680' 10680-10700' Ref: BHCS 11/24/82 Limited shot density. 10. Return well to injection. 11. Run injection spinner/temp log. TAB2/162 5 4 3 2 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/"16" PIPE RAUS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 1 ii 1. 5000 P.~I ?" W£LLH[.AD CONNECTOR FLANGE 2. 5000 PSI WIRELIN£ RAUS (VARIABLE SIZE) .3. 5000 PS~ 4 1/6" LUEIR~CATOR 4. 5000 PS~ 4 1/6" FLOW TUBE P^Cz-Orr N]R£L]NE: BOP EOUIPHENT Ill I I I I ARCO A£aska, Inc. P.O, Box tOOS60 Anchorage, Alaska 995~0 DATE: Augus~ 34, t~87. REFERENCE: ARCO Cased ~-29 8-8-87 -Prod. Profi[e Run ~, t-SO 8-9-87 Prod. Profi [e Run t, t--~ 8-.~-87 F'rod, F'rofi le Run ~, ~-~2 8-~8-87 F'rod. F'rofi Le Run ~, t.-SS 8-9-87 Prod, I::'rofi Le Run ~, S-9 8-~6-87 l'emp. Log Run ~, S-~2 8-8-87 In j. Profi[e Run ~, ~-~8 8-6-87 Inj, Profi[e Run ~, S-27 8-~-87 F'rod. F'rofi Le Run ~, 3--30 8-1~-87 GR/Temp/F'rod. F'rofi le Survey Run t, 4--3 8--i6-87 Prod. F'rofi le Run i, 4-.6 7/~i.-8/i/87 Leak Def./Temp/FlowmeCer Run i, 4--27 8-6-87 Inj~ Profi le/Temp~/f:'lowmeCer Run i, 4-32 8-t6-87 F'rod. Profile Run t, 5'-2 8/i-2/87 Leak Det'/Temp. Log Run i, '7-2~ 8-t2-87 Flowmefer Run I , 9.-~ 8-i7-87 X-Y Caliper Run i, 9---3 8-t3-87- F'rod. F'rofi le Run t, 9-8 8--7-87 Inj. Profi le/Temp./Flowme¢er Run i, 9--t8 8-7-87 In j. F'rofi le/Temp./Flowmefer Run t, 9-.-31 7-':29-87 F'rod. I::'rofi le Run i, _ ~ 8-5-87 Inj. Profi le Run t, I:'l. ea~e sign and return ~he alT. ached copy as rec:eip~ of da Ro,'anne ~ek ~hOil ~... z ~ ~..~,. & Gas Cons Co :~ .... ~'.. . ~' . . ,lo ..... Anchorage Approved ..... .~ . . 5 ' 5' 5' $. 5' 5' 5' 5' 5' 5" 5' 2' & 5' 5' 5' 2' & 5' 5' 5' 5' 5' 5' 5' 5' C a flit 0 C a m ~ o Ca ~c o Ca flIC 0 Camco C a ~mIc o Ca fflc o C 8 fli (S 0 Ca ~flc o C a m c o C8 fll~ o C~co C a mC o C a ~ o C a mc 0 ' C 8 ~ c o Camco ~ ... ;;Icl 0 99'3~ 0 Run 2, Run 'l , Run '1, R u ~"~ 'i , I::' I. ea:.:.:e ~' i g'r'~ avid 'r'e't u,.i"'n//~:hel~C:Ei/~(EIDc~¥ @.'¢ i".ec:e ip'l: Fk'e(::: e i red B ';,,' ..................... ~'i' ......................... H A V E: A N I C E D A Y ! x,~[las~ OX & Gas Oens, Anchomga of da'l:a, · ,,-"" f".'en+~-a_.. . L F:'i Le~' ~ Ch ev'r o'n E x '1' e n.-:.:: i o 'n E x p L o'r' a 't i o n ,.11. ~,. E x x o ~'; i"l a r a '1' h c.', n ....-,. f'iob i L -..~" F' h i I. Lip .~' F'B kl e t L F i / (.:.-, s' R & D ,.... o J') i o__. ARCO Alaska, Inc. P. O, Box t Anchorage, ALa.ska 995t0 D~TE: June 29, t987 REFERENCE' ARCO Cm~ed Hole r;;na[ ~.-7 6-~ 5-.-87 9-4 6-t 0-87 t 2-20 6--t 0-87 t 4-"~ 7 6-t 3-87 t6-24 6-t t-87 Xtep Ra~e In j, F'rofi [e Run t, 5" Camco F'[ow/Water Ho[d-up/GR Run t, 5" Camco Inj~ F'rofi [e/'femp, Run ~, 5' Camco Temp,/F'[uid Den . /W~ 't er Ho[d-up Run ~, 5' Camco GR/FLowmeter Run t, 5' Camco F'[ease sign arid ret~urn r Re~c::ei red By Hi~¥~ iq W I¢~ DAY! Ro_sn nne Peek A'FO- t 5'~9~ 'f'RAN~ ~87332 App roved the a'ttached copy a.s receipt of da'f~. /JUL- 1.,87 ( Oil & Gas Cons. Commission Anchorage DISTRIBUTION Cen'~ral. Fi te.s ~ F'hi [Lips: ; ..... "[ ('.? .S' Chevron ,. ,:.~ M R & I) E× ten.s i on E×p[orat ion ~ ~ohio Exxon .. ~'tate of Ataskm Mob i ~ ARCO Alaska, Inc. Prudhoe Bay ~-.]gineering Post Office Box '!00360 Anchorage, Alaska 99510=0360 Telephone 907 263 4248 Donald F. Scheve Operations Engi.eering Manager March 5, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-20 Permit No. 82-191 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work on the above-referenced well. Very truly yours, D. F. Seheve DFS/TAB/jp Attachment Standard Alaska Production Company PI(D8 12-20)W1-3 REC. EIVEO A,q _ 6 1987 Alaska Oil & Gas Cons. Comrnisslan WELLS/54 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-". ALASK,, OIL AND GAS CONSERVATION COMM,_31ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 77' RKB feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM At effective depth 1/~t total depth FSL, 2445' FEL, Sec. 7, T10N, R15E, UM 7. Well number DS 12-20 8. Permitnumber 82-191 9. APInumber 50-- 029-20863 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 10950 feet Plugs (measured) 9243 feet Effective depth: measured 10899 feet Junk (measured) true vertical 9195 feet Casing Length Size Cemented Structural Conductor 79 ' 20" 415 Sx Surface 2382' 13-3/8" 210 & 400 Sx Intermediate Production 10382 9-5/8" 500 & 300 Sx Liner 879 7" 300 Sx Perforation depth: measured 10484-10700' 8811-9011' true vertical ~bing(size, grade and measured depth) 5½", L-80, 17#, 10117' MD Packers and SSSV(ty~e and ~easured depth) Baker SAB Packer @ 10031' MD, Camco Bal-0 SSSV @ 2213' MD Measured depth ~ue Verticaldepth 79' 79' 2382' 2382' 10382' 8716' 10061-10940' 8422-9233' RECEIYED AP, ' 6 1987 Alaska Oil & Gas ConS. Commission 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation 4/1/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~certify treat the fg. regoing is true and correct to the best of my knowledge Signed ,~¢.-~,¢.~Z~~..~.~ Title Operations Engineering Manager Date Commission Use Only approval Notify commission so representative may witness ~ Approval Conditions of No. ~ Plug integrity ~ BOP Test .~,,.Location clearance~ ~'~., :~;, :~.:} ......... ~..% ........ ~,,.. L, .-,? ., by order of Approved by Commissioner the commission Date~-~- Form 10-403 Rev 12-1-85 WELLS/27 T. A. Billingsley, ATO-1506, 265-6871 Submit in triplicate DS 12-20 SAND PLACEMENT FOR PWI CHANNEL SHUT-OFF PROCEDURE 1. Run pre-treatment spinner/temperature survey. , RIH with coiled tubing. Tie in with tubing tail locator. (TT at 10117'). Tag PBTD. (Last PBTD was 10877 on 5/8/86.) 3. Reduce injection rate to ±3000 BWPD. . Set CT nozzle at 10640'. Start pumping gelled sea water with approximately 2 lb/gal sand. Pump 6000 lbs 12/20 mesh sand followed by 1000 lbs 100 mesh sand. 5. POH with CT and return well to normal injection (~10,000 BWPD). Note new pressure and rate. 6. Tag top of sand in wellbore. 7. Run post-treatment injection spinner/temperature survey. TAB/60 I! 1. 5000 PSI 7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICA'TOR 4. 5000 PSI 4 1/6" FLOW 'TUBE PACK-OFF Gas Co~s. c~mm'ts$ion klIRELINE BOP EOUIPHENT 6 5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 5. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX . · , . · , . CO ! LED TUB ]NG UN ] 1' BOP EOU ] PHENT ARCO P':a:ka, inc. F" C: ~ ...... ~ 0036¢, ~.--J~.~,_ho':-.-~qe, Al.-' -":'" ~ ::o :..: 9'?5: DATE' Jur:e 2:. '!996 ARCO Cas'et .-!..:La :':naJ. S p, -': ~ T .:-.--.. :~': p ~ L o.:::. R -':.: '.,-: ': 5 ~ ":'" :" ~.~ ~i' V '"-- c ......-:' ,~-~ ? ..... _~::j _. :. : ~_:, .. F-:..'21'~ i ~:~ i 'n j--'--~, .. 't i :: 'n ~'':-:.. .... ~-~:- :' ::~- -'---: u 'ni _.:'.' ' Te:~'.:F-:-:::".sts:"e .".Turvac:' f;:u'n : 5-' '-' j e c + .'. :, r.-: ? r o i-: [ .s. F:: u n ~ -'cT. ' ~ ' ~'. -- ~ :-. .- r-, · . . -- :, . _.:- ]: '~":. j e c i. i o n F: r o f: i..:=.. F-~ u r:! 5 ' ....... ~ F'ro" rS:un i 5:" · '--:p i'n. i_c,.:] .... .... ~ ~ Sp: ":'nar :':Survey Run i S' lr, j:--.,_t i o'r,: ,-'rof~ .._: R~'..".~i lr, jec~ior, P'-:-of: :e Run i S' ?rod J -. o., , ~ :_.._,~!. ."?e'.:--¥ice£ ~,~n ~ ~" F:J. ea_:e :--.igrJ a~d :..-e'+ur'.,~ !he 6 ':- 'f .:.- c: ~ E: d copy a~. 'receip+.. of data, Re:ca i red By F!AYE A Nc-CE ~:: C"-:-': Y2c-' T-'.:-: A N L--: :.:-::8630'? DZSTRZBU7: O ...-,:' _ ,. ARr'O A~aska Inc.~ P.,O,. Box i0'3S6() Anchorage., ALaska DATE' December 2t , 1984 REFERENCE' ARCO Pre.s.s-ure Data D.,Y... 9-6 16,-1i-84 PBU Survey ' DA D ,u , . , .~.,...., ~: ~- Sta4. r..- · 4. ,..-.,i 2-.4. I '~-~¢--°z-' : i c ~.,-, ad ~ en: Camco I),$, 12-8B 11-26-84 3:i'ati'c r..;radient Camco:, O. $, i 2-2,3 i i -26-84 Y-tm tic C..rad i eh'? Camco D 2 I"~-":-'i I t-%,:-;-84 £;tatic E--rcdien-I' Camco D, $.. -~ ~~.:.. I -- I -84. Y't'at i c g-tad i en't Cam,'-'o... r, ,'-' d 4. r'. , , .. --.., -- ,a ,. ic 6ra le:,r~: ,...~lil'lr'o D.,,~,. 12-26 4,2-3-84 Static G'radier,'t' Camco .... · ~ 2-.27 i~_'"' S 84 ~;-i.'at i cGrad i e'n4., r':amr'r; .... D Y ,i '-., - --., o I '-'- ' 4. .... '~ -84 34. , o .,:...~ .. : a -!.. i c 6- r a d i e ~"~, C a m c ,_ -- .o¢~ .':..'+ 4-lc Gradien+ Camco D,,:"-..:, i 3;-x i I -i ;-,. ..... a . . D,.$.~ 13-4 11-i7-84 Y.-.ta!'ic Gradient Camco D,.~;. i3;-6 ii-.-Ic,'-p..,'~., ~,. ,.,":',l:,atic Graclien*: Camcc, [:.,., 5:.. i S- ,7-' t I -! '7-84- Stat i c Grad i er~'t.' Camco -. ..... a4.ic graf.; i ent Camco ~',_;,$.i3-14 ii-19-84 $'i:atic E,-radien't' Camco D.£',. i4-i2 ii-i6-84 £'tatic C. radier, t Camco ~.,.. $,I ¢.:,-'~ , I -84 F'D;...', Survey Camcn 'r:,,2, i 6-6 9-22-84 PBU .?urvey 6-6) D,.$. to-9 c,-i 9-84 ~4. . . · -" .,.,at ir- Gradien+ 0-i: i..'-: ...... 84 ,.,. 4. grad'_. * Camr'o D,2.~ to-ii o-~-,,- ¢,a: ic ~'.','~'~,. -, '" ' --' ~' , _ Cail'ir'n L:,. Y....'~ ,--..., 9-26-84 Pt:-;U. Yurvey .... D,. ~.,' , i '7 -- 5 7.', - i '':~, _ .....° 4 ?-: 't' a t i c 6 ~- a d i e n 4.,. C a m c o F"t. ea~e sign and re'!.'u.r'n the attached copy as receip't' of data.. Received By 2EAYONY GREETiN6Z~ Kel. Ly Mc:Far La'nd ATn '~ :~F Alaska Oil & Gas Cons. 6ommiss!or, Anchorage i.':'. I ~]'R i BUT I ON Ch e¥'~' o '.,'i El :----.: p ~. c.:,'.,'- a 'f i o r~ 3 e r v i c e s E:' :~:.' ":,.' =._. , ,.:. '~'" ;, o 'n E ..'~' r-:' ~l o r a 4.,. i o 'n 6ei' ~. y i'-iob i I. ?iobi L ,.'-' & i::' Phi I. I. i ps Pruc!hoe Bay Wel. t F;.: & D :?oh ir.:, · '*.' -I. 4. . ,;.:a:e o'~' F:'i Les ARRN A ~ ' ...... · :z:~:k8, II]c, -... F',. (]~ Ii-,'(::, x i 0036~ ' A'r',chc, rag(-z,, ALa..gka 995t0 ...'f) F'.] ';", :... :c- 0 c: -I-. c) b (-.'.~, i" 2 (i), i ~.i;' ',iii 4 ,'.c'P"r'-r"r' 'r"'"'"~F:'- 'r' ,:.,"..,::.,..: ...c. ARC:O Ca ..':i:(ed Ho [ 6> Fi'ha. L '.7 }7., ~; ~ .3 .... 1 9 ~ '~ ....... -.~- 6', m p (-:..', 'c ...'..'~ t: u ¥' ,::, L.. c) g ._13 ~ ,_.?, '7-4 ~ i 0-' -,'"" _o._,...,.,,, ,'!?p i 'nner Log i),. S _. '::.--"":>., ,_, i ;::,, .... ..':'.,--..-'-::::4 F'.I::',':..::/,?F', inner D., ;il, 9-i 2 ~' i ¢--6-84 CFL'..",.'£'F, i r'~n(.:-:r 'q .? .c.., .....-.:, ,.'>, ~ ~ ,"; ............ ? .... ! '7'"" :iii', 4 'i" e:' m P (-:-'.' ;" a t.- u 'r' e ...... ,::j ;'"' S i 2"--20' '"' " : , , :-~'ml-, ....... i 0--0---'04 D' i '""';: '"". ....... i5 S i "':' .... :':'- 0 -'~ 4 ~:, _ 6 .... ., .-, ~. r.:' -:', .-' -::, .. .... · ':.. ~'- --' : '---' ' ,::.', '-';' L: ,-': D 3 i ,5 ..... i "i ~' 5 "'-;"- ':::'""""::" 4 · ............... ;.:--,- C F:' ;~-." / R p r,. ::..::! 4-28 / ' .,.,' .-. ?'"' 26"- :_-'!: 4 :0 ~ '~' ';: ';- ........ ~' · I ! I ~';' III[ ~. .... ;~: i 6- ;i!; .'" 5- .... -i ! "- {:::.':~- ", ~:r';- t:~_. ! (3 ':-3 ;'" ': ....... :'- ~ 'il;:-..- 2 ,-'"-.--" Fi -'% ".¢' ,.., .... :-,. 'I ~ ....-;' . T'E' !...O':J n :.ii: i '7 ..... i ~:, ~'~' ':..:;'-... 2 'i .... '::> ,'! .... "', ' -,. ....... :.:--? i- [ U. icl s...-(..'~ '.,] .S- ] : '::.-" '.5" !5" '.15" !15:" C a .,'n (:: (:.', C a m c ,:::, C;. C) C'.: a m ,'.': (;.; CI Cf 0 3' ,::: I", Cl. 0 Ch er',- on I) & M ExpLoration Service:s E'xt'en~'ion Expl. oration Exxon Get'~y H a r a t h o n Hob i I. :'"~"" I. "" ?'., F:' FI ,...~ ,j i t::. .. Phi t I. i l::'.s' F:"~" u. cl h ,::, e B a y 1.4 6:' I. I. R & D S'oh i o State of Ata.s-ka ARCO Alaska, Inc. '~-"-. Prudhoe Bay ~ ,,,neering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments CC: Sohio Petroleum File Pi(DS 12-19)Wl-3 File PI(DS 12-20)W1-3 RECEIVED JUL 2 3 ]984 Alasl~a 0il & Gas Cons. C0mmissl0n Anchorage ARCO Alaska, Inc. I! a Sublldlary of AllantlcRIchfleldCompany STATE OF ALASKA ALASKA-~L AND GAS CONSERVATION cr~{MISSION SUNDRY I ,OTICES AND REPORT , ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER~ 2. NameofOperator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell (surface) 691' FSL, 942' FEL, Sec 18, T10N, R15E, UM (Producing Interval) 173' FNL, 2435' FEL, Sec 18, T10N, R15E, UM (Total Depth) 1' FSL, 2445' FEL, Sec 7, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB I 6. Lease Designation and Serial No. ADL 28330 12. 7. Permit No. 82-191 8, APl Number 50- 029-20863 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing ~ Stimulate [] Abandon [] Stimulation [] Abandonment Lr--I Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing r-] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each coml~letion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any propo~d work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 12-20 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10600 - 10620' MD (20') 10630 - 10640' MD (10') 10650 - 10700' MD (50') Ref: BHCS 11/24/82 RECEIVED JUL2 1984 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby c//~/y that the ~)e,~ing is true and correct to the best of my knowledge. ",~~~/./"~ / /_~/f~ Regional Engineer Signed Title The space below for Commission use r Conditions of Approval, if any: Approved by IRIGIliAI SIGNED I~T L9111(1£ C. SalTll _i~pproved Copy ~eturned By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" ~n/Tr,pl~cate and "Subsequent Reports" in Dupl,cate ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 8, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned well. V~~truly your~s, '- D. F. Scheve DFS/JCD/lmi Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska. Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ...---, STATE OF ALASKA ..-~ ALASKA iL AND GAS CONSERVATIONC. IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL I~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20863 4. Location of Well 691'FSL, 942'FEL, Sec. 18, T10N, R15E, gM (Surface) 173'FNL, 2435'FEL, Sec. 18, T10N, R15E, UM (Top Prod) 1' FSL, 2445'FEL, Sec. 7, T10N, R15E, UM (TD) 5, Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. 77' RKB I ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number DS 12-20 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other []X Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105~170). ARCO Alaska, Inc. has converted Drill Site 12-20 to a water injection well. F',, 1 14. I hereby,c, ertify that th,~nforegoing is,true and correct to the best of my knowledge. ~~.~~~ Regional Engineer Signed ....... Title The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office"-"'"x 360. Anchorage .... aska 99510 Teiephone 907 277 5637 January 6, 1984 Reference' ARCO Pressure Data D.S. 7-18~~- 12-8-83 D.S. 7-20f' 12-7-83 D.S. 7-20-~- 12-7-83 · D.S. 7-21 '~'" 12-11-83 D.S. 12-15-" 12-8-83 D.S. 12-16'~- 12-8-83 D.S. 12-20- 12-7-83 D.S. 13-4" 12-8-83 D.S. 13-18 / 12-12-83 Static Survey GO Static Survey (8700 - 8800) Camco Static Survey (8600 - 8900) Camco Static Survey GO Static Survey Camco Static Survey DA Static Survey Camco Static Survey DA Static Survey Camco ~ P1/~ease~sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 005 D & ~ Dallas Drilling ~xxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips Prudhoe B~v_.. /33 ' '. Caroline Smith State of Alaska ARCO Alaska, lnc, Prudhoe Bay ~-ngineering · Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 23, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/lmi Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 DS 12-19, 12-20 ARCO Alaska, Inc. Is a Subsidiary of AllanllcRIchfleldCompany ,~*~ STATE OF ALASKA ;,.-~ MISSION ALASK, -)IL AND GAS CONSERVATION C_ (.,/D~ '~. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Water Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20863 4. Location of well at surface 9. Unit or Lease Name 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM DS 12-20 At Total Depth 11. Field and Pool 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 77' RKBI ADL 28330 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. ND. of Completions 11/11/82 11/23/82 12/9/82[ N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10950'MD, 9243'TVD 10899'MD, 9195'TVD YES d( NO []] Nipple @ 22f~,t MD 1800' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ZO" 91.5# ~-40 Surf. 79' 30" 415 sx Permafrost C 13-3/8" 72.0~ L-80 Surf. 2382' 17½" 210 sx Fondu & 400 sx Permafrost C .., 9-5/8" 47.0~ L-80 Surf. 10382' 12~4" 500 sx Class G & 300 sx Permafrost C 7" 29.0~A L-80 10061' 10940' 8½" 300 sx Clas G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) !0484-10508' MD 8734-8756' SS 4 spf 5½" 10116' 10031' 10518-10598' MD 8765-8839' SS 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Ref: BHCS 11/24/82 - DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Water InjectionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A I TEST PERIOD I~ Flow Tubing :Casing Pressure CALCULATED. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CDR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. JAN2 51984 Alaska 0ii & Gas ColTs. Anchcrage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS Base Sadlerochit NAME i MEAS. DEPTH ii TRUE \_':ERT. DEPTId Top Sadleroch~ t 1048z~ ' i! 8733' O/W Contact i! 10805' 9030' No t Reache~ 3i LIST OF ATTACHMENTS I hereby certify That the ~:oregoing is true and correct to the best of my knowledge 30. FORMATION TESTS Include interval tested, p,-essure data, ~;I; flu~d~ ,~;(:~v(:~td i~n,,i cl~:i~ ,'y. GOR.and time of each phase N/A 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 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 (multit)le completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separatelv produced, showing tl~e data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". * ORIGINAL . : /-'"" STATE OF ALASKA ALASKA ..;L AND GAS CONSERVATION C,. ,VllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILYl~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] - 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20863 4. Location of well at surface 9. Unit or Lease Name 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UN '~' Prudhoe Bay Unit At Top Producing Interval I VERIFIED 10. Well Number 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM F~ 12-20 ISurf. At Total Depth ! B. H, E~ 11. Field and Pool 1' FSL, 2445' FEL, Sec. 7, T10N, RISE, UM ' Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 77' RKBI ADL 28330 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. Nc. of Completions 11/11/82 11/23/82 1 2/09/82I N/A feet MSLI 1 17'T°talDepth(MD+TVD) 18' Plug Back Depth (MD+TVD)19. Directi°nalSurvey ~2;~D;P~h~2hle~efSeSe~l~l~t [ 21'Thickness°fPermafr°st 10,950'MD,9243'TVD 10,899'MD,9195'TVD YES ~] NO [] i 1 1800' (approx) 22. Type Electric or Other Logs Run DIL/$P/BHCS/GR, FDC/CNL/GR/Cal , CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 79' 30" 415 sx Permafrost C 13-3/8" 72.0# L-80 Surf 2382' 17-1/2" 2100 sx Fondu & 400 sx Pe'mafrost C 9-5/8" 47.0# L-80 Surf 10382' 12-1/4" 500 sx Class G & 300 sx 'ermafrost C -7" 29.0# L-80 10061' 10940' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 10116' 10031' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date F~irst Production Method of Operation (Flowing, gas'lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-QILRATIO TEST PERIOD II~ I F'low Tubing Casing Pressure ICALCULATEDI~ OIE-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. ' ,24-HOUR RATE '"~ 2'8. CORE DATA I~ ~'_ ¢" I-~ ~! None .JAN t 4 i983 Alaska 0il & Gas Cons. C0mmissi0r~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC3 CONTI N UED ON REVERSE SI DE 29. NAME Top Sadl erochit O/W Contact Base Sad]erochit GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovere(I and ( GOR, and time of each phase 1048q' 10805' Not Reached 8811 ' ii 9108' N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct To the best of my knowledge Signed , ~-'~ Title Area Dri ] 1 i ng EngineeDate INSTRUCTIONS Genera' 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 only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" DS 12-20 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1530 hrs, 11/11/82. · Drld 17-1/2" hole to 2395'. Ran 58 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2382'. Cmtd 13-3/8" csg w/2100 sx Fondu and 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10,395'. Ran 252 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 10,382'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tested csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,950' TD (11/23/82). Ran DIL/SP/BHCS/GR f/10,942'-10,382',FDC/CNL/GR/Cal f/10,950'-10,380' cont w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 21 jts 7" 29#/ft, L-80 BTC csg f/10,061'-10,940'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10,899' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/10,895'-9950'; good bond. Ran 5-1/2" completion assy w/tail @ 10,116' & pkr @ 10,031'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2213'. Secured well & released rig @ 0015 hrs, 11/30/82. Gyroscopic survey ran 12/09/82. JG' sm 12/17/82 GRU1/DH6 .JAN ~. Gas Cons. Commission A. nchorage ~~ l Eastman i 1 A PETROLANE COM~ REPORT of SUB-SURF,4CE DIREC TIONA L SURVEY ARCO ALASKA, ~NC. COMPANY DS 12r Well Number: 20 WELL NAME Prudhoe Bay, North Slope, Alaska lOCATION JOB NUMBER TYPE OF SURVEY Directional Single Shot DATE 12-Nov-82 SURVEY BY Controlled Drilling Consultants (Hendrix) ~3as Cons. Anchorage ~'.:~ L A SI< .¢..~., 'f N L-:. :2., WELl.. Nr): '7.:0 O'.?-E:/-['~LECO (C:OC) TELE:C:O., O-IO:B:B.I MO T.'~'...:.:'._::, .1. O9:~;0 MD., [)R-r. LLER: 1-~ HENDRIX SURVEY F'I:-::OVI OE:]:) BY COI',ITRC~LLED DF<It_L IFIG C:F~N:-'";I_ILTANT."=_;. F(EC:("IF~[) OF SURVEY F'RI_I]]HOE BAY, NORTH SLOF'F.., hLASKA ( C: D C ) C 0 I'1F' LIT A'r ! 0 N T I ME DATE 1:3: :38: 25 :2." 9- N 0 V - E: 2 F'AGE NO, I TRIJE MEASURED DRIF:T DRIFT r-:OUR'.=:E VERTIC:AL VERTICAL SUBSEA R E C: T A N O U L A R C L O S U R E DOGLEG DEF"I-H ANGLE DII:~EC:TIC$1 I_EI',IG1-H DEF'TH :=: [= C: T I O Iq 'I"VD C FI 0 R D I N A T E :3 DISTANCE DIRECTION :2;EVERI1-Y F EE-"r P I'1 D M F[=_'ET FEET FEE:T FE:ET FEET FEET D M DO/100F-[ O, c) o 0 23'.=/5. ('~ c) 0 0 2511. I 0 N '.:.:'o () W · :;:.'/-./-.'-:>_ _.. ,_,':' 4.2 N :::P;_ _ c). W 2792. 12 6 N :2'.1 0 W 2778. 2C) 42 N 2..:/=. 0 W :3104. 24 18 N 2.:"? 0 W :2:2:/=. 1, 28 4.'.2 N 2 :=_': 0 W :=::'::!--, 3 . :3 t 1:2 N ....'-'._, .... o. 14 :F.:4'7.6. :E:4.0 N ".!: i 0 W C). ('). 25:'? 5, '2:2:95. (') 1 t/-.. 251 (-). '?'? 158. 266:=:. :2:1 1 '-:":' 27:2:.? 27 C). 00 .-- 77. OC) O. 00 2:=: 18.00 C.), :--', 2 24:2'.:2:. '.-.-~9 9.56 2591 · :2:1 31.04 271 '..-._'. 27 186. 2967.54 1:26. :2:0:2:3.9:2: 157. :2:224.40 92. 3:2:(.")4, 10 123. :3407.72 82.6, 9 2890. 54 1:30. :30 3006.9:3 199.27 3147.4(.]) :24. 4. '74 :3'.::' 2'7. 10 :2:10 · 79 3:3:2:0.72 70.64 N 49.52 W 86.27 N 35 2 W 4.68 l 1:3, 4.0" N ......... 7'1; 7:=:' 174.94 N 105.20 W 204.14- N 5::1 .1 W 2.82 216.04 N 125.69 W 249.94 N 30 11 W 3.1'7 277,02 N ! 51'~ 57-"W .......... i~ii'~]"'?'~i'~'N'"-~:~i-'21i'""'W ........... ~!': '87' :2:6:2:(). :3'i> 4.2 N :2C) 0 W 1154 . :2:5:2:0. 'P() . 'I0:3 05 "'" ='"''-''' '" " '-' . ' .:,4.,-,.:,, ~)0.:,:' .:,63.50 N 1.~:3,'.90 W ' : ;' ' ' ;";'.': '""~z 4.1.2Zl. 4.2:30 Iq 20 30 W 494, :3'F.¢0:3, 1,.:: '727.;, 61';:;.E:82/=.~iI.'2,-'jr6./:.8.~ 1.4:"N ..... ,:~.'z:,c.,,;. W 4/-'~1 4:3 0 N 21:2:o W .~i ''~ '* "4.290 !1 !o' ~[,':¢S:" ~ '~' _. ............. ,,'.. . ..8. .._. 4.2!:3,!! ..:..?!0:2,10/N ]i~424,4.9 N :::;174 43 54 N 20 4.8 W ~'="':' ' 4. /=, 6'? '. 7 '.=.¢ .1.,144.'27i' /t'=;°'='~::'~';'/::;::': t':'g9 C~='' . . , _, .... '-=.,f ¢,...., '.! i-' '-",, · '-"-~ 'N ¢'.;;~,~,.Zt 0'7 W ..... · _ .~,......~ ' f .~: y<...,..~=r ii ~ ~. 56'?6. 4.5 6 N !9 6 W 5:2';=:. '' 5042, 10 tF:lO:: Ot!; ":'4965.'10'~':': 168t"~ 4'5 'N :;;;'"¢:&:,';7:9. 09 14 407.:37 N 26 50 W :=:.72 730.89 N z3 55 W ........ ~i.'; ..... 10:38.:30 N 22 57 W 0.16 1447.:2:4 N 22 31 W 0.20 181..:,.'~'-'~'l' .... N ":s'"'=-;...-..- o w v)": ii:. . ;>.. .... ./.':.';:' ]. 4- ...................... Zl 6 42 N 1 :iii: (') W ::'~ 1:2: ?: 40'2 :=;7 21 °1 c.¢::: '=;'="--'R._ ._, .... .... 57 2O34 (')9 Iq 797 43 W ..':'"' 1 ,:,4, 6:2 N ~ 1 24. W o, 34 ./- ':-?:'";'4'7 12 Ixl .1. '7 ! :2: W 308 561 '...2 ':'":' '24.0'7. (")ii' "=="""-' ":":'48 .'.57 iq '-'/' ~ ' / ')'' i.i ;5:4'~id~"'Z~: ........ iq'"',~;¥ ........... .-, "i:i .............. l:.,'".~,.=; ....... :.. .............. : .......... '._'..=,..-'. |.'"i|2 ".-,:.. . ,",".= ...... % / ~'/ -' "r . :: · -, .... ,"1 .-' .I..:,w ....,: ..... , ...... ~':;- '-"- .......... =" 94.5,60 W 2677.70 20 O, 24 /- r::,-} 1 4./... ! ',=: N 1 '7 1 :=: W .369 58/=,5,65 2./:,75.7:2: ._ ?,:,.:,./= .... ~._,,.,._,. t :2: N N 4 ! W ... 72:2::::: . 46 .':.24 I',1 1 ',F: 0 ..... W 5: :Fi: 7, 6098 27 2'? 1 ':¢ 55 6021 :27 2'7:2:7 .... .., ._._4 W l ...... ..,.:: N W 1 75:2::=:. 45 F,4 N ! 7 4.';.:' W :.=.:05.63O'.=/. 57 :=:13'.:.~. 49 6:.-'":.B2..57 7'7:!::5. 4:;.:.' 24. N 18 42 W 7906, 39 ::::./:, N 18 2:4 W 8C) 5'?, .'2:4 4.:F: N 19 6. W :i::4. 16, 2::2: E~.-. N 2C) 6 W :2: 9:=:4. 5::L :36 Ix.I 21 :=:0 W '72:38. 30 :.36 N 21 54 I,,I ":~ ..... : 4:2 .. :2.4. W 7.-' ..... 2'7 N 1'::' I0062, 24 42 N 15:36 W 10:':::31. 2:2 !54 N 8:30 W :.:_:(::),I-, '7/- ':.?.=:;. 4:=: ....... 4. 1';i::3. ()A 7/:18,4.:3 :2::2:72 , '::'.~;~... N .1. ,.'1.21 .20. W 4124 , ,_,~.o-:, N 20 '9. W ().. :2:4 4:37. :.=: 12C). '7 ! 4:7.'.60.07 804:3.71 /!.09,.~..t E: N ' 11%04.84' W 4.:2:'.).:. i'":-".-7;'i~i ......... ~"'-~i~i"":['j~ '-"~ ............ i~i ~'"~,'5"' . . 4~:,.:,:, 04 N 17'149.5'7 W 4,510.57 N 2C) 6 W 1 C) 2 :3:.37 :=:4=.::.3 ()F; /1508,79 :2::2:4.6,05 '-"-'/ , , ......... '=-'7 '- ..... ':"-' ...... R .... ' . . . '2/',':P. :,_=:/-, 69 16 461 ./: .... ~ ,:,.._, .-..e.. 1/-, 4:342'. 1 'R N 1 ._ ?,..:. ";":.2 W 4618 C) ! N 1 ':) 54 W 1 26 ......................................................................................... .1. C)'~.)5C) MD IS DSS '.BLiRVEY. DS 1:2, ~.JEI_L Nr-i,", 20 EI'._qS:/TEL. EC:O F'RUI;)HOE £qqY.: I',IORTH '.BLI-IF"E, ( C O I-: ') T ~ HE DATE 13: 3 8: 2 .S 2 '.~ - N 0 V - E: 2 ]'RLIE P'IEA'.--_;LIRE[~ E~RIF-T DRIFT C:~-~I_IR'.-_-;E VERTICAL VER'rlC:AL L=:UBSEA R E C T A N G U L A R C: L 0 S U R E DOGLEG. DEF'TH ANGLE DIREC:TION LENGTH DEI.~'TI-t SECTION TVD L-: 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY FEET D I~1 D M FEET FEET FEET FEET FEET FEET D M DG/lOOF'r 1 (')'? 50 · '.7::':;_' 0 N :_R ' 0 W F I BIP~L i-:[.O'.::;I_IRE -- rll REIZ:T I fiN: D I '._=;TANIZ:E: N i'F¢ DEG.'=_: 20 MINS '.75 SEC:S W 484'P· 75 FEET DRIFT CHART'S RELATED DATA FILE ' ARCO ALASKA, INC. --'DE:--I"~'~ ..... WELt--NO PRLIDHOE BAY, NORTH SLOPE, ALASKA SURVEY FILE NUMBER 1463 BOTTOM HOLE ASSEMBLY VALUES USED FOR DEPTH ARE MD DEPTH DESCRIPTION 1.31_9,, O0 JETTI'NO ASSEMB~ , ............. .......... 6990.00 3678,00=853¥~0.1 -- 10. O0 O0 - ......................... ...................... LO'~'F-ED--ASSEMB ANGLE LOCKED LOC-;KED---' DROP ASSE MBL~'~III~~ A~.;,E MB,,!~'.~.'":'- :3976. O0 LOCKED ASSEMBLY A PETROLANE COMPANY 103S.,'5. O0 LOCI<ED ASSEMBLY DR ILL I NO DAYS VA L4J E S -U S E[-~R--BEP-T-H-A RE--MD ................ DAY .......................... DEPTH ................... 1 ............. 1-C41~9. O0 23?5.00 2395.00 3~00. 5653. O0 6962. O0 .;zE:20.~AO 8 8769.00 '~ 9362.00 !-0 10-1-1-7-.~0 11 10395 · 0 12 1A'P50. O0 WEIGHT ON BIT WE~U~ ~ r~, p~ I~0n POUNDS VALUES USED FOR DEPTH ARE MD DEPTH WEIGHT 1319.00 60.00 3678.00 60.00 ,, .... ~ c,.~. 00 ....................................... 60.00 .)6990. O0 65.00 8110,00 70.00 ......... 899~,00 ........................ ~0,.00 10395.00 50.00 REVOLUTIONS PER MINUTE VALUES US DEPTH R.P.M. 1319.00 200.00 ...... 3578,00 .............................. 140..00 ......... 5390.00 140.00 6990.0(3 140.00 - ..~-- 110. 00 1.40.,<)0 Whipstock A PETROLAIVE COM~NY 8996.00 120.00 10395.00 80.00 i 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 ! t I I ~ I i f ~ , ....... !ii i !~ ~IlI iill ~lil ii!1 ~11~ III~ !!Il illl Il [ i i II I '11I I It !111 I1!! iI~ i~i itli Ilil ~t~ i1~1 i~i !Iii III~ iIll ii i ~ I I! I ifil I 1! il!l ii1' ............ iii' ii ! ~ ! I! i !~!I i i! 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'" :~ llJi !Iii ii . fiji lltl [ili lll! ii! i!li ilfi tiil ~i! :[:~ iii :Ii! ill 'i! i Ii I ii11 ilrl illi !lil i111 jill iiil i!il !111 iii iii ilil lJ!i {!il . i i i i i : i i i I ~ ~i.i iZ :~i j~i.~ ,~i .ii i,j. i: ~ ~ I .i i I~ i [ ! i I J i [ i i : ~ i I i: i i : i ........... i:: iiii !!ii jif: ii;; ,.' · i. i'iij jilt iiii ~iii ifil iii: iili llil [:Li :IL: i!i! ;il: :::] *ii ,il: :iii !!jill il:; iiii i!ii ii!! liii il]i Ifil till !lJ iiil iii: .Iii ]Iii ;~:: '"i :, ~ iit~ t,~i,I~1,, iii~.ilil ~ii*.'ili ili; .;~,. ;ii i,i'. ,~' ~ ~",.~ !ii j iii! fill !iii iili iiiJ illi j i' i! 'i ir:; : ~; it, ii: .::i ii: !!i! ::i! : :Ill iill jlii !iiI iili illi !!!~ .: ! ii; ~ii :; : i~ROO-~^L^SK^-,--tNC,-t- ....... i .... f ......~ ...... -i- --i ~IOR'.IiZONTiAL PROJ~CT[ON. D~'_-:Z:2;-----~ELL::~O ~::L-201- ' DSS/-.TErECoL-: i.:::--LLJrL-::'::: ~ ' t--: :':: ~C^~'E i~ t~. i= 'SO01 FE:ET i ' : ' )~']~H,,f~OE~ ! :ASK'~ ! ~ --I ...... DEPTH IT t, ID'I CATOE,,~TVD ...... .... ~ ...... ~ - ~ - ! .... i - '~:.- T~_22_-~~_ 2' .__-_: ~ i . ~ ..... i ..... ~ ......I .... ~ ' ' 1, .... ' ..... i i ...... ..... 7 .... .... i' .... ~ ..... ,:. ::~----i':::-': :. · ............ ~. .... I ' - -1 ' - ] ...... i .... - } ....... ] --- ...... Ji ..... i , - - _ ~ .... ! -i ..... ~ ...... + ~ ..... i ........ ; -- i .... .... i" ..... 1 - · ~ . : +~+ - . ! . .. · . ~ ~ ............... · ..... t.'" ::::[:::_:: ..... .:-:: ii! "'' . · , ~ -' .~ ............r ~ - . . ~ ..... .... ~ - : .... ..... ! i ' .-.! ..... .... , - :.. --- ~ . ! .... ~ ~ __.~__.t '- . .... ' I'' ' i ! i - i ----~ ....... - ' .... : ! i -[ i .~ ..... ~ . .......... l ....... :-::-[ I ..... -t ....... ~ ........ 1 ......: .... ' A.R ¢o ALASKA., iNC. ; 4 T L EO Teleco Oilfield Services/nc. 220 A Center Court Anchorage, Alaska 99502 December 14, 1982 ARCO ALASKA ROWAN 26 DS 12 #2O JOB 191AK O. Attached please find a copy of the computer calculated survey for the above mentioned well. On behalf of Teleco, I would like to thank you for the opportunity to serve you. We at Teleco realize the importance of good service and hope that you will continue to use our MWD. services in the future. Please feel free to contact me if you have any questions. Enclosures SB-ck Sincerely, ~ Steve Billeaud Field Service Supervisor T L EO - Teleco Oiifield Services Inc. 220 A Center Court Anchorage, Alaska 99502 JOB 191AK ARCO ALASKA ROWAN 26 DS 12 #2O FSE Colby Colomb arrived at drill site 12 at 1100 on 11/13/82. Tool 277-20 and surface gear 137 arrived later that afternoon. This 8~ collar entered the 12k hole at 0630 11/14/82 to deviate it from vertical at a depth of 2450' A jetting assembly was to be used to accomplish this task. One proposal was to build to 40° of angle in a direction of N18°30'W. 0800 11/14/82 to 0800 11/15/82 rotary drilling and jetting started at a depth of 2450 with 1° of angle being present. At the end of our kickoff 1229' of new hole was made with 39.7 of angle being built. Our direction at this point was a N20.1W. 0800 11/15 to 0800 11/16 drillimg with a packed hole assembly started at a depth of 3679' and continued -this day to a depth of 6279'. Angle 7° built to 46.7 or a increase. 0800 11/16 to 0800 11/17 again this day rotary drilling with a packed assembly was used to drill to a depth-lof 6963'. Angle this day dropped from 46.7 to 46.3 in 684'. -- 0800 11/17-to 0800 11/18 drilling this day netted 988'. A 30' pendulum assembly was used to drop the angle to 39.6. Our direction this day went from a N17.7W to a N19.1W. 0800 11/18 to 0800 11/19 rotary drilling with a packed assembly started at a depth of 7951' and continued to an ending depth of 8998'. Angle for the day went from a 39 6 to 31.6 or a loss of 8° _ 0800 11/19 to 0800 11/20 rotary drilling with a packed assembly netted us 302' of new hole. During the day of drilling showed a drop in angle, which is now 30.6. 0800 11/20 to 0800 11/21 starting at a depth of 9300' with 30.6 of angle. 826' of new hole was made. At a depth of 10126' 24.7 of angle was present with a direction of N19 4W. 0800 11/21 to 2300 11/21 269' of new hole was made during this final day of drilling. At a depth of 10395' the 9 5/8 casing point was reached with 22.9 of angle being present. At this time our direction was at a N8.5W. At this time our closure distance was 4621.42' with a closure angle of N19.87W. DIREGTIONgL CUSTOMER I ARCO LOCATION I PRUDHOE BAY, ALASKA WELL PAD i D8-12 NELL NO. I DRILLING CO. ~ ROWAN CUSTOMER JOB NO. I TELECO JOB NO.. a '191-RK MAGNETIC DECLINATION RIO NO.~ 26 PLANE OF PROPOSED DIRECTION 18 ! N 18.7 W , DRILLING SURVEY REPORT TELEco OILFIELD SERVICE8 OF nLnstm, INC. 6110 NIELBON WY., ANCHORAGE, ALASKA, 99682 PAGE DATA REDUCED pY RADIU8 OF CURVATURE HETHOD TYPE OF SURVEY , HAONETIC 8TART DATE I 11t13/82 FINIBH DRT~ I ~1/22/82 REPORT PREPARED BY ! COLBY COLOMB MEASURED DRIFT TRUE VERTICAL DRIFT DEPTH ANGLE VERTICAL 8ECTION DIRECTION DEO MIN DEPTH OEO HIN 2606 E.~8 2685.76 3.98 2667 8.42 2666,22 '11.66 2792 12.~6 2789.17 33.53 2918 18.:42 2918.65 66.45 2978 28~2 2967.13 86.49 5104 2~18 3085.54 154.14 5261 28.&2 3224.85 283.17 5476 3~.08 ......... 3487.38 314.65 3630 . 39.~2 353~.62 ~06.97 i , 4124 ~. 42.58 3982.88 731.~5 4E51 45.00 4289.86 1888.85 5174 45.54 4669.55 1448.18 5696 ~5.06 5841.87 1813.88 6214 46.&2 5482.35 2185.87 6522 &?.12 5612.68 '2418.89 6891 &6.18 ' 5865.45 2679.54 7228 &6.24 6898.85 2923.33 7~53 45.54 E~89.3~ 3143.27 7785 A2.24 6490..16 3318.79 7986 59.56 6~81.48 3398.18 8049 54.48 6695.38 5484.63 8728 32.38 7253.73 3856.61 893~ 31.~6 7435.12 ~970.03 38.88 W 35.88 W 31.88 W 27.08 W 26. E)0 W 29. ~8 W 28.08 W 26.80 W 21.88 W 20.08 W 21.88 W 22.8~ W 21.08 N 19.88 N 18.88 N 17.88 N 17.~8 W 18.~ W 18.88 W 19.88 N~ 1~.88 W 19.88 W 28. ~8 N 21.88 W 22. ~ N TOTflL COORDINATE8 CLOBURE8 DIGTflNCE ;iNGLE DD HH 27.69H 22.79 W 35.86 N 39 27 15 W 75. e6 N Aa. a3 W 89.11 N $2 37 mB ~ DO0 - LEO SEVERITY ~DEO/188 FT. 3.664 2.779 5.382 3.388 117.83 N 78.38 H 137.28 N 38 49 19 N 2.998 179.39 N 1~3.73 W 287.22 N 38 ~2 14 W 2.817 228.31 N 124.58 W '253. i8 N 29 29 i8 W 2.926 281.89 N 1~1.88 W 319.~8 N 28 14 42 W 3.157 367.59 N 183.35 N 418.78, N 26 38 31 N 3.722 671.77 N 297.87 W 734.53 N 23 51 22 W 8.582 1884.61 N 428.18 W 1892.~ N 23 ~5 ~4 W 8.168 1339.26 N ~68.~8 W 1~51.63 N 22 &t 31 W 8.217 . 1683.87 N 685.14 W 1817.18 N 22 89 88 W 8.353 2835.84 N 883.18 W 2188.54 N 21 31 48 W 8.339 22~8.&9 N 878.86 W 2567.52 N 949.44 W 2748.~7 N 1822.76 W 2949.26 N 1~98.73 N 3115.72 N 1146.~3 W 2413.11 N 21 89 16 W 2681.24 N 28 44 18 W 2924.73 N 28 28 ~7 W 3144.49 N 28 17 ~5 W 3191.8~ N 1171.61 W 3399.29 N 28 89 ~8 W 5272.99 N 1199.~5 W 3485.71 N 28 87 12 W ~467.~4 N 1267.91 W 5691.98 N 28 ~5 ~7 W 3622.74 N 1325.97 N 3857.77 N 28 86'11 W 3728.39 N 1~67.59 W 3971.38 N 28 ~8 55 W 8.287 8.217 8.16A 1.416 2.377 3.383 8.~61 8.488 ~) 0 DIR~TIONgL D R :[- LL 'Ir HI3 ~URVEY REPORT PROE 2 JOB NUMBER s 191-FIK CUBTOMER ~ RRCO PAD ~ DB-12 HELL NO. ~ 20 ' HEABURED DRIFT TRUE YERTICRL DRIFT TOTRL CQQRDINRTEB C L O 8 U R E B DOG - LEa DEPTH ANGLE VERTICRL SECTION DIRECTION DISTRNCE RNGLE 5EVEEITY DEG MIN DEPTH DEQ MIN OD MM S8 DE~/100 FT. 972~ 27.&2 812a. 74 4353. ga N tg.a~ H BOTTOM HOLE CLOBURE; A62~.4 FEET AT N 19 4a ~B ~REPRRED BY RBRCUB COHPU~ER 8ER¥ICE 82~ N. 718T. AVE, ENTIRE CQNTENT~ COPYRIGHT .~9B3 ABACU~ COMPUTER BERVICE 43~E. 96 N 1~6~.91 W ~62~.41 N 19 48 38 W 0.805 RNCHGRRGE, RLRGKA (907) ~44-0761 ) , ,) ................... AR£~E~--AL"ASk~A, .... INC'. DS 12, WELt. NO: 20 GMS dOB NO: A1282RO342-NG PRUDHOE BAY, NORTH SLOPE, ALASKA , GYRO NO: 631, CAMERA NO: 1507, 5-90 OEO A/U NO: 1566 FORESIGHT: N 13 33 E ............... :~URiVE¥~-~AKEN-i~RO~,-WELLHEAD A PETRO/.ANE COMPANY ............................................................................................................... REE. ORD-..-E F..-.=.UR-VE¥ ~ RADIUS OF CURVATURE METHOD ..................................... ;~"~- ARCO ALASKA, INC. "D'.~-I'2'; ....... WELt '-'-'NO : ....... 20 ....... GMS ............ F'RUDHOE BAY NORTH oLCFE, ALASKA COMPUTATION P~GE NO , ,,, £)8: 15: 33 16-DEC:-82 MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R.E C T A N O U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TUD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY ........... FEET D H D FEET FEET .....................F,EE~ ................................. FEE~. .FEET .... FEET D .... M .... DG./19OF~ O. 0 0 0 O. 0.00 0.00 -77.00 0.00 0.00 0.00 0 0 0.00 ................. t'00'; ............ 0"':'"0 .......................... 0 ................................... t'00~ .................... t'00'~'-00 ....................... 0-~'00 .............. -2.3.:,00 ................. ().-:-00. £~,00 ~.00 ....... () 0 ~,--00--- 1000, 0 0 0 900, 1000, C)O O, O0 923, O0 O, O0 O, O0 0, O0 0 0 0 · O0 1100. 0 15 .c.; 9 W 100. 1100.00 -0.19 1025:.00 0.21 S 0·03 W 0.22 S 9 0 W 0.25 ....... t"200'~ 0 ..... t5 '~9'"W 1'00~: ................. t"200'~'"00 ...................... 0-~'54 .......... 1'i'~3",-00 .......... 0-~-'~"~--'~-- .............. O~40-'W ............. 0.-~5 ~--1 ~ 40 W 0~-0~ ............ 1300. 0 15 S C) E lOCi. 1300.00 -C).DC) 1223.00 1.04 S C).28 W 1.08 E: 15 12 W 0.' ~i ........... t400'~ ...................... 0 ........ t"5 ~: '" ' , ~,~ ~ - ~ ~ ~_ ~ t6 W 100~ t400~ 00 ....... t-~-~.. -- t ~.';~3 .- 00 ........ t-.-4-?--S ..... O~-:~-W - 1-.-~5! ~, ~~-,, 0,.~,., - 1500· 0 0 0 100. 1500.00 -1·47 1423.00 1·68 S 0.40 W 1.73 S 13 30 W 0.25 1800. 0 0 0 300. 1800.00 -1.47 1723.00 1.68 S 0.40 W 1.73 S 13 30 W 0.00 ...... t"~00: .................. 0--'80 ....... S'--2t'."E ......................... t00~ ..... t900.~,--00 ......... 1-~-.90 ...... t.82~,~-0(; ....... ~-~-0~--~ ...........O~-2~W ..... ~t-[~ ~~W ........... 0~~ ........... ::~t'00~ 0~ 45 .......... S.--52.,. E 209~. 2200. 0 30 S 3~ E 1 21~9. :~:s=~,,~:~ ~ : ~~.:~,~ 1:~:~,~ :~2~. :~c: :. ~ S ~~0~~ __ E 3.31 'S 38 20 E O. 31 2300. 0 35 34 E C).16 ~ PETRO~E 2500. 0 15 S ~5 ~ 100. 2~9~.$~7 -5.7~ 2~22.97 5.2~ S 2.~3 E 5.7~ ~ 2~ 50 E 0.6~ ......... ~600', .............. 5'45 N'-"40"N ................... iOOf' .......... ~'~99"~"79 .................... 4'.'08 ............ ~22',--79 ............. ~-...0~ .......... ~-2-.-W : ~.~5t- S~~7--W 5.78~ 2700. 9 30 N 35 W 100. 2698.89 8.46 2621.89 5.48 N 10.29 W 11.66 N 61 58 W 3.80 2800. 12 0 N 33 W 100. 27~7.13 26.43 2720.13 20.~4 N 20.72 W 2~.46 N 44 42 W 2.53 --~900 ~- ..... t--~-'80 ..... N-'--~7'-.-W ..... t. 0(~- ..... ~893.~-7C~ ........ ~-1-~--~C~81-6~~,.~N ~ ~ ~ ~... .... .~-. ~ .. 5. ~ ) :3000. 20 45 N 27 W 100. 2988.26 83.76. 2911'.26 72.16 N 48.31 W 86.84 N 33 48 W 3.2o ..... :3100, ......... 23 · 4~ .....N--.-29--W .................. 100,- ....... ~080,-80 ......... 1-21.,0S~ ........ 3003,-80 ........ 105-~ N--~,~)~ ~ ~~~~2 3 N 3~ 09 __ 3200, 2Y 0 N 29 N 100, 3171,14 163,22 3094, 1~ 1~3,06 N 86,86 N 167,~7 N 31 16 N 3,25 3300, 2Ex 15 N 29 N 100, 3259,33 209,57 3182,33 18~,29 N 109,71 W '21~,48 N 30 ~6 ~ 2,25 .... 3~00, .... ~2 -- 0 .... N --26--N ............... 100,. ...... :~3~,.37 ........ 25~, 87 ..... 326~,-37 ....... :22~,-~.--N ,, I~~N 2~~ N -30 ~ N 3 :3500. 34 15 N 21W 100. 3429.12 314.29 3352.12 279.56 N 155.01W 3&O0, .... ~7--45 ......N--2-1-.--.W .............. 100, ....... 3510.,.01 .......... 373,.O0--~433,-Ol~--~31~G-C~-N-. ~7-/.~.07 W :3700. 41 30 N 21W 100. 3587.02 436.70 3510,02 3~3.96 N 198.93 W 3800. 41 45 N 21W 100. 3661.77 503.06 3584.77 455.~7 N 222.73 W ~15~04.~2---0 .... N--2.1....W ............. 100, ......3736,-23 .......... 56~.~75 ...... 365~.~3 ..... 51.8,~ N 2~6=65 W 319.66 N 29 0 W 3.54 377=95 N 27 ~6 W 3.50 441.33 N 26 47 W 3.75 507.46 N 26 2 W 0.25 5~3~9~ N 25 27 W 0.25 _ ARCCI ALA:_:;KA, INC. D S--1-,2-, ..... WE hE,-,-,,,,N O: ..... ,20 ........... G M ~; PRU13HOE BAY, NORTH :sLCFE, ALASKA COMPUTAT I ON T~I~IE DATE 08: 15: 33 16-DEC-82 PAGE NO. 2 MEASUREI] DRIFT DRIFT COURSE VERTICAL VERTICAL 8UBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY ....... F:,EET .................... D ......... M IL ................. FEE,T- ........... E.,E.E-~ ....... E.E.E,~ E,E~ FEET FEFT r~ M oB / 100F.~.' 4000. 42 15 N 21 W 100. :3810.3~ 636.76 3733.3~ 580.~1 N 270.6~ W 640.88 N 24 5~ W 0.25 .............. 41.( (. ................ 4~ ....... 1.~, .......... N.,.,.-~,1 ....... W ................... 100.. ........ ~¢,~,4....4,~ .... -70~...-~-.~O.~...~.~---~.~N ......... ~4.7R W - 7o7. ¢]7 N ~4. RAW O. 0~.~ 4200. 42 30 N 22 W 100. 37¢.58 29 771 23 3881 2~ 706 3~ N 31~.~8 W 775 28 N 24 20 W 0 72 4300. 42 30 N 22 W 100. 4032.02 838.67 3~55.02 76~.03 N 344.7~ W 842.78 N 24 ~ W 0.00 . . o " ,~ ~ ~ o~ ~ ' · ~7 .......... 44t:)0. ............ 42 ........ 0 ........... ........... ~ .................... lo0 ............. &.,tO6.,,.08 .............. 05~.~---4,0~,,~.~,~3~~ ! 06 W o I ~, ~0 N 24 4 w 1.43 ......... 4500. 42 45 N 22 ~ 100. 417~.~ ~72.87 4102.~1 8~2.~5 N 397.39 N W77,38 N 23 59 N .-4~00, 42 45 N 22 l:)O ~'~ ~' ~ ~ l~ .................. ~ ...... N ............ ,, .. ........... 4~., :¢,,,o5 ........ ~040,~,63-~.1.7~35 ,55~,=, N .... 82 :: H ~-~~~~~ O- ~, 4700. 42 45 N 22 N 100. 4326.78 1108.38 424~.78 ~018.82 N 448.25 N 1,113;07 N 23 45' N 0.00 4800. 4:3 15 N 22 ~ lO0. 4399.71 1176.45 4322.91 1082.06 N 473.80 N 1181.25 N 23 3~ N 0.50 .............. 4,9,00,. ............. 4:¢-.-30 ........ N-:22-W ................. 1-00.-~,~.~,~.:~5.~~3~-&0 , l-l~,~~ - 4~9, ~ ..... ~.49 ~ 8~: N 23 33 H - . ,.~ ~(',(',0 .... 43 0 N ~=~" W 10~4545,4~~~~¢~~ 120~,26,N,, ....... ~25,19 W 1318,39 N 23 29 W 0,50 ' , c: . ' ,"86 W 1386=8~~4 w ............ ~,..1-(~, ......... 4c,--.c,0 ......... N.---~---W 4 · .. O, 50 ' "4~, ),~-- ~~~,-~1~;51- 1887, i~N ~"20 W 1456,00 N 28 19 W 0,85 ........... 5400, ............ 4¢.-,.45 N--..19.---W 10'~ 15~~ ~~~~~ ~",~8 W 15,~,49 , N 23 !" A PETRO~NE C~PANY 5500. 45 0 N 19 W 100, 4904,48 1661,04 4827,48 1535,12 N 646,~5 W 1665,88 N 22 51 W 0,25 ............ ~600, ............ 45-.---1.~ ........ N.-19---~ ......... 1.00, ..... 4~7~.,4)~ .... t-~..~..,~8~8¢~~.0~1~ ~~~36,59, N ~ 42 ~.. 0,25- 5700. 45 15 N 19 W 100. 5045,44 1802,~2 4968,44 166~,28 N 6~3,15 W 1807,47 N 22 83 W 0,00 5800, 45 15 N 19 W 100, .5115.84 1873,93 5038,84 1736,43 N 716,27 W 1878,35 N 22 25 W 0,00 ......... ,=~00., ..... 4¢-¢0 .... N-~8--W 14K~ 5~~~4~ ~! 09. O? ! ~03.92- ~! 738. ~5 ¥~ ! 749.37 N 22 ! ~. ¥~ O. 7% ) 6000 46 15 N 18 W 100 ~ . .... ;-,-~.71 2016.88 5178.71 1872.19 N 761 03 W 2020.96 N 22 7 W 0.7o ........ /_~t00-. ..... .4t.-.--1.~ ..... N--tS--W 400. 53-24~8~(~42 .52~~0.89 N 7~W~l~.1 5~~~ 6200. 46 30 N 18 W 100. 5393.85 2161.50 5316.85 200~.73 N 805.72 W 2165.23 N 21 51 W 0.25 6300. 46 45 N 17 W 100. 5462.53 2234.18 5385.53 207~.06 N 827.58 W 2237.71 N 21 42 W 0.77 ........ /.~400.---- 47 .... 0 .... N--1-7-W--- 100~-.--5530~89 ~0~14 5453 ~8.9 2.148.~85 N ~8.9~W .... 231.0~~~~W 6500. 47 0 N 17 W 100. '5599.09 2380.25 5522.09 2218.79 N ....... /_,/_*00,- ..... 4-7 ..... O----N--t-7--.-W ................ 100r----56~7,-29 24~?.4-,-~A_- 5~-~0,-27 2-288. 73 N /-',700. 46 45 N 17 W 100, 5735, 65 2526, 32 5658.65 2358.53 N 6800, 46 45 N t/_-, W 100. 5804.17 2599.1 t 5727, 17 2428, 36 N ...... /_-.~00, .... 4~:..--45 ....... N---1.7--.W ....... 100, ~872,68 267-1-,-90 5-7-~-&--.8 24~--'-. 20--N - 870.30 W 2383.37 N 21 25 W 0.00 8~1.~69 ~ 245~;~.-30 N-24--1-7J 913.02 W 2529.08 N 21 10 W 0.25 933.71W 2601.68 N 21 2 W 0.73 954~.-z1~ ~ 267-4-.~ N 20-55--W.- 0~73.~ PRLIDHOE BAY, NORTH SLOPE, ALASKA COMPUTATION PAOE NO. 08: 15: 33 16-DEC-82 3 MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY ........... FEET ................. D .......... M ............. -D FEET FEE-T ......... FEE~--- FEE'f' FEET FEET .ri ...... M .r-16/4-OOF-T, 7000. 46:30 N 17 W 100. 5941.36 2744.57 5864.36 2567.71 N 975.65 W 2746.82' N 20 48 W 0.25 ............ 7-1,-O0~-~--46-4.-5---N--1-7--W l.£~e-.---~et-or3s .... 28~b.-~m-599~.-35 26--3~N 99.5'-8.1--W 2~8.t~.(~--~2~4~2-W 7200. 46 15 N 17 W 100. 6079.51 2889.14 6002.51 2706.01 N 1017.93 14 2891.1 7300. 46 O, 'N 17 W 100. 6148.82 29611.20 6071.82 2774.95 N 1039.01 W ..... --Z400-~- .... 46---90 ........... N-~-I-,~-W .......... t-.0~-~.--.~5-~1,-7~.-,.~7 ..... -3--0-3~.-~--~-40--,-~7 2~4~. 03. N IO&O,-1-8--W--~O~-W 750(). 46 0 N 16 W 100. 6287.12 3105.60 '6210.12 2913.29 N 1080.64 W 3107.26 N 20 21 W O. -~6'00;-~45--"45 .... -N--t-6---W .... iO~.~-6-35~4---3-1-7-7-~-.-3z2~---b2-7~.-74--~i¥-2~N ..... 1100~3--W 317~3 N. 7700. 44 0 N 16 W lC)O. 6427.60 3247.81 6350.6C) 3050.11 N 11 I?. 88 W 3249.20 N 20 10 W 1.75 m~ ') ' i m , 7,:40 42 15 N 16 W 100 6500.57 3316.10 6423.57 3115.82 N 1138.72 W 3317.38 N 20 5 W 1.75 ,:,000. 37 0 N 16 W 1 :06o4-1~~~~~~ 0 W 3445.08 N 17 55 W 3.00 s3 t5 N t6 W i ;27 W 3558 26 N . 3& 8300 33 0 N 16 W 10~~e02.~.8._~ -,,:: 33 W c.612.7~ N 1~ 45 W ~~0'25 ........... 8400, ............. :aa,.--se ...... N----1.6-W, I ,:-~ W 3667.50 ~ N 1-~-W A PETROLANE C~NY .=,~,.K~ 33 30 N t6 N tO0 7Obi. bO 372t 83 6~2.b0 350b,20 N ~250.bb N ~722,58 N ....... 8600',- ..... ~9 ....... 0 .... N--t'6-W t~~59'~ 22 ~7~&'~-t~ ~ ~7&-~-2-~'8~~ ' ~ 2~, 77 ~'J 3777.90 8700. 32 ~0 N ~7 N tO0, 7237.33 3830.b8 7t60.33 3bt0,78 N ~28t.t3 ~ 383t.32 N t~ 32 N 0.74 8800, 32 t5 N t7 N tO0, 732t.78 3884,20 7244,78 3bbt.98 N ~2~b,7~ ~ 3884.82 N t~ ~0 N 0.25 ) ~000. 31 0 N 18 W 100. 74~2.19 3~88.88 7415.1~ 3761.68 N 1328.70 W 3~8~.45 N 1 .... ~ )' ~' ~ ~ . 0~. 750-~~~(~~4, 5~ W -., t..( V., ............. o0--4~, N.-18--W ..1 757~2 4~0, t 9 4~--19 2~-J.% 9200. 30 15 N 18 W 100. 7664.19 4090.95 7587.19 3858.76 N 1360.24 W 40~1.4~ N 1~ 25 W 0.50 9300, 30 15 N 19 W 100, 7750.57 4141.32 7673.57 3~06.53 N 1376.23 W' 4141.86 N 1~ 24 W 0.50 9500. 29 0 N 18 W 100.. 7924.10 4240.75 7847.10 4000.96 N 1407.37 W 4241.27 N 19 23 W --~¢600-.---28--45--N--l~-.W ~00.. ~1-1~7 42~9.03 7934.67 404~-.-0-1--N 142!.89 N 4289;53 N !9 22 W 9700. 28 0 N 16 W '100. 8099.65 4336.52 8022.65 4092.58 N 1435.39 W 4337.00 N 19 20 W ~800. 27 0 N 15 W 100. 8188.35 4382.64 8111.35 4137.07 N 1447.73 W 4383.07 N 19 17 W 'Pg(K)..,----2G-iS---N--t4.-W.-' I£~).. 92::17-7.75 4427.34 8°=00.75 41~<),4&~ F! !458,95.Y 4427,73 N !~ !4 W 1. O0 O= 54 O. 89 1.10 ARC:O ALA'.=:KA, I NC. PRUDHOE BAY, NORTH SLOPE, ALASKA COMPUTATION PAGE NO. 4 TIME r,~E 08: 15: 33 16-DEC-82 MEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG~ DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERITY F,-E,E-~ .......... D M ..... ~ f,~ .......... F.E,E-.T, .............. FE,E;,T FF, ET FEET FEET D M DC/! 10000. 25 45 N 13 W 100. 8367.62 4471.01 82~0,&2 4223.08 N 146~.18 W 4471.35 N 1~ 11 W 0.66 10200, 24 0 N 8 W 100, 854~,34 4553,76 8472"34 4305, 12 N 1484,78 W 4553,77 N 17 2 W 1,33 10300. 23 15 N 5 W 100. 8640.95 45~2.~6 8563.~5 43~4.~3 N 148~.32 W 45~3.0~ N 18 ~=~ W 1.42 / 1.04, O. ...... ~--.-4-~ ........ N .... ~.-~ .... 100, 87~.~0,0 ~6 ............. ' ~0500, 22 30 N 2 N ~00. 8825.3Z 4667.77 ~748.31 4422.34 N ~493.72 ~ 4667.79 N ~8 40 ~ 0.~ '] 10700. 22 0 N 3 W 100. ~010.58 4740.27 8~33.58 44S~7,58 N 14~7.34 W 4740,28 N 18 25 W 0.00 10800. 21 45 N 4 W 100. ~103.38 4776.26 ~026.38 4534.76 N 14~.61 W 4776.2~ N 18 18 W 0,45 ,: 10~'._0. 21 4S N 4 N 5 ':P2 2,7 '= 4!5~0,.21 N~ 1.503,49 N 4830 17 N 18 8 N .0,00 F I NAL C:LOSUF{E - DI REC:T I 0 ' N 18 · pEG , ' ' A ~TRO~NE ~NY .............. ARCO'-A~A~WAs .... ~N~..- i i DS 12, WELL NO: 20 GMS JOB. NO: A1282RO342-NO PRUDHOE BAY, NORTH SLOPE, ALASKA GYRO NO: 631~ CAMERA NO: 1507, S-~O DEG A/U NO: 1566 FORESIGHT: N 13 33 E SURVEY'-TA'KEN-'-FRSM-WEEkHEAD A PETROLANE COMPANY ARCO ALASKA, INC. DS,--1-,2~-- W ELL.-, -N 0:--~20 ........ GMS, PRUD~OE BAY, NORTH :SLOPE, ALASKA COMPUTATION ' ~AGE NO. 1, TI. ME rd~TE 08:17:57 16-DEC-82 MARKE~ ............ ~ ...... ~RU~ SUB$~A CODE MEASURED VERTICAL MD-TVD VERTICAL R E C T A N G U L A R C L 0 S U R E VERTICAL' NAME DEPTH DEPTH DIF~ DEPTH C 0 0 R D I N A T E S DISTANCE DIRECTION THICKNESS E, EE.T ......... EEE.~ ......... E,EEI ...... FEEl' FE~T F~T .O M TOP SAG RIVER 10383.00 8717.36 1665.6 8640.36 4377.28 N 1491.58 W 4624.43 N 18 49 W " I ~' '" ~. ~. ~ ~ ~m~ .......... ~.~ ........ TOP SHUBLIK B 10425.00 8756.08 1668.? 867?.08 4373.51N 1472.47 W 4640.0? N 18 46 W TOP SHUBLIK C 10443.00 8772.70 1670.3 86?5.70 4400.43 N 1472.77 W 4646.74 N 18 44 W ......... ~OR,,-,SADLEROCHIT ...... 10484.00 ....... W 466!~8B N ~8 4! W TOP ZONE 3 10725.00 ?033.78 1671,2 8956.78 4506.87 N 1477.?0, W 4747.28 N 18 23 W HO~ 10734.,.,00 ......... ~042,.-13.---1.~.~,~ .... 8~/~5,-1,3~SZ,O~22::N1478~1!,~,,,,,,W 4752~52 N!8 22 W 'TOP ZONE 2 10777.00 ~082.04 1~75.0 ?005.04 4526.21N 1499.0~ W 47~8.00 N 18 20 W O/W CONTACT 10805.00 7108.03 1677.0 7031.03 453~.~1N 147~.74 W 4778.08 N 18 18 W .......... PB,TD 108~,~....00 S~1..?15.~3--1.703.~.7-~1~-8.~.3~5~!~~~7 ~ ~8~!~.,.84 N!8 1-1.--W TD A PETROLANE COMPANY 4830.17 N 18 8 W · ALASKA, INC. -tO-R-'['ZONT',AL PROJECT[ ON- ' . ::)S 12. WELL NO: 20[ Olds ....... SCALE!I - ~RUDHOE BA'f'-, NORTHi SLOPE. ALASKA ''-: ........ DEPTH --- '. : - ! · ~ -~---i- -'t ....... ,~ ....... [ ! ....?-'-:-:- ......... *'. ..... : ~..7o-~¥o i, 'ii',' , , , , i,-, SURFACE LOCAT'[ON:~ 591-NSL, 942 '~EL .... t . i SEC. 18. TION. RISE' U.i'11 t .... ~ - '- Suggested form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. Operator, Well Name and Number Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Yes /--/~. .Well___ History. ....... Yes /--' //7~--~ ~--~ ~. 't~.. _Samples _. ~ ,x~-:/'~i ... ~./ Mud Log C°r~-"'D~- scripti°n~. Registered Survey P.l~at X:.--~ X~ Inclination Survey ~/~ ' -- Drill St~ Test Reports J/.~.~/'e- ,, ,, . .-. Production Test Reports.N~-~ "~~ -~ Logs Run- Yes .., i ~ ~ 3~- ~ ~ ::'-.ii.~ Digitized Data y ~_..~_~ ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 14, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Attached are Intention Sundry Notices for conversion to water injection Wells for the above-mentioned drill sites. Sincerely, Donald F. Scheve Regional Engineer DFS:la CC: J. C. Dethlefs J. R. Schuyler D. SmileY Sohio Alaska Petroleum Co. Well File, DS 12-19 & 20 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA --. ALASKA ,.,~L AND GAS CONSERVATION C~..IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETEDWELLxEk OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-191 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM (Surface) 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 1' FSLr 2445' FEL~ Sec. 7r 5. Elevationinfeet(indicateKB, DF, etc.) 77' RKB 12. TiON~ RlSE¢ I]M (mD) I 6. Lease Designation and Serial No. ADL 28330 8. APl Number 50-029-20863 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert Drill Site 12-20 to a water injection well. This well is within the Flow Station 3 Injection Project area, and it is scheduled to begin receiving water in late December, 1983. SuBsequent' Wort< Reportecl 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~.~~_. ~../~ ~-~,¢,~. · Title Reaional. En(J~neer. The space below for Commission use Conditions of APproval, if any: Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office.'~'"~ 360 AnchOrage. .,ska 99510 Telephone 907 277 5637 October 17, 1983 Reference: Arco Pressure Data D.S. 4-5 9-7-83 9-7-83 D.S. 4-11 7-24-83 D.S. 4-15 8-11-83 b.S. 12-15 9-24-83 D.S. 12-16 9-24-83 D.S. 12-17 9-24-83 D.S. 12-18 9-25-83 D.S. 12-19 9-25-83 D.S. 12-20 9-26-83 D.S. 15-12 9-21-83 9-21-83 Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Build-up Pressure Build-up Data Sheet Camco Otis Sch DA DA DA DA DA DA Otis ~P~~lease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 578 Chevron D &M Dallas Drilling Exxon Getty Marathon MobiI DISTRIBUTION North Geology Phillips Prudhoe Bay R&D Caroline Smith Sohio $~ate of Alaska ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 3, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 30bl Porcupine Drive Anchorage, AK 99501 Re: D.S. 12-15 D.S. 12-16 D.S. 12-17 D.S. 12-18 D.S. 12-19 D.S. 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Attached are "Subsequent" Sundry Notices detailing work on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS:la cc: Sohio Petroleum Co. File 100.0 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieldCompany ~--~ STATE OF ALASKA ~--~ ALASK. :).[LAND GAS CONSERVATION ~ ~',IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20863 4. LocationofWell 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM (Surface) 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 1' FSL, 2445' FEL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 7, T10N, R15E, UM (TD) 12. I 6. Lease Designation and Serial No. ADT, 28330 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating 25 September 1983. RU perforating unit, pressure test surface equipment. RIH with gun #1, shot 10579'-10599' MD, 4 spf. Flowed to tank for clean up, monitored rate and took shakeouts. POH, all shots fired. RIH with gun #2, shot 10559-10579' MD, 4 spf. RIH with gun #3, shot 10539-10559' MD, 4 spf. RIH with gun #4, shot 10519-10539' MD, 4 spf. RIH with gun #5, shot 10485-10509' MD, 4 spf. RD. Secured well 25 September 1983. All depths referenced to CBL 28 November 1982. Flowed to tank. Flowed to tank. Flowed to tank. Flowed to tank. POH, all shots fired. POH, all shots fired. POH, all shots fired. POH, all shots fired. 14. I hereby c~tify that the foregoing is true and correct to the best of my knowledge. S, n 0 .,.,e The space below for Commission use Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARcO A~'aska, inc. ~ Prudhoe Bay ~ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 12, 1983 Mr. C. V. "Chat" Chatterton Alaska. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 12-15 DS 12-16 DS 12-17 DS 12-18 DS i2-19 DS 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Enclosed are "Intention" Sundry Notices'detailing work proposed on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, and 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/la Attachments cc: Sohio Petroleum Co. Well File 100.0 ARCO Alaska, Inc. la a Subsidiary of AtlanllcRIqhlleldCo'mpany STATE OF ALASKA ALASK, )IL AND GAS CONSERVATION £ VlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL1~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-20863 4. Location of Well 691' FSL, 942' FEL, Sec. 18, T10N, R15E, UM (Surface) 173' FNL, 2435' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 1' FSL, 2445' FEL, Sec. 7, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 77' RKB I ADL 28330 9. Unit or Lease Name Prudhoe Bay Unit 12. 10. Well Number 12-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work; for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes'to perforate selected intervals within the Sadlerochit sand from the Prudhoe Bay unit.. Upon perforating, the well will be flowed to a tank for cleanup. The perforated intervals will be given in the subsequent report. All wireline work will be done'throUgh a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed'perforated Intervals: 10484-10508' MD (24') 10518-10598' MD (80') ref: BHCS 11/24/82 · 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .'~,.~, '~ L~~H Title Regional Engineer The space below for Commission use (~ Date Conditions of Approval, if any: COMMISSIONER Approved Copy Returned _ -_ ,_ By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. · ' Post 'Office ~;~?7360 . ~ Anchorage,. Alaska 99510 Telephone 907 277 5637 March 31, 1983 Reference: Arco Directional Data D.S. 12-20 11-13-82 Magnetic Survey Teleco sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 252 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON .- M 0 B I L D & M DALLAS CAROLINE SMITH ARCO:Alaska, Inc. i'-'" Post Office ~ ,360 Anchorage, Alaska 99510 Telephone 907 277 5637 .January 13, 1983 Mr. C. V. Chatterton commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are.monthly reports for December on these drill sites' 1-24 13-14 1G-7 2~I'1 13-98 1G-8 '7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-iOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be 'submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 a~d 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28'llm Attachments JAN' q Oil & Gas Cons, Col'nmis~ion AFmhc, r~L~ ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany Post Office Box 360 Anchorage, ~z.~ka 99510 Telephone ~ 77 5637 January 3, 1983 RE: ARCO Directional Surveys D.S. 1-23 11-11-82 D.S. 7-16 11-18-82 D.S. 12-20 ' 11-12-82 Directional Single Shot Directional Single Shot Directional Single Shot . ease sign and return the attached copy as receipt of data. Becky Benedict AFA - 403 'E/W E/W Trans. #003 DISTRIBUTION NORTH~GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS Alasks Oil & Gas Ou,: ,,nmissior, ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompan.¢ ARCO Alaska, Inc. Post Office?'~,, 360 Anchorage. ~ka 9951 Telephone 907 277 5637 December 22, 1982 RE. ARCO Open Hole Finals D.S. 12-20 11-24-82 D.S. 12-20 11,24-82 D.S. 12-20 11-24-82 D.S. 12-20 11-24-82 D.S. 12-20 11-24-82 CPL/Cyberlook Run 1 5" SCH DIL/SFL/GR/SP Run 1' 2"& 5" SCH BHCS/GR Run 1 2" & 5" SCH FDC/CNL (Raw) Run 1 5" SCH FDC/CNL (Poro) Run 1 5" SCH Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA - 403 Trans. #670 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA Alaska Oil & Gas Cons. Commission_ Ap. ch0rage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany Post Otfice Box 360 Anchorage~--'-"~ka 99510 Telephone.. z77 5637 December 22, 1982 RE' ARCO Cased Hole Finals D.S. 1-12~ 11-25-82 D.S. 1-18~ 11-24-82 D.S. 1-23 ~ 11-27-82 D.S. 2-6J 11-27-82 D.S. 4-11 f10-17-82 D.S. 12-4/ 9-26-82 D.S. 12-8B ~11-25-82 D.S. 12-20~11-28-82 D.S. 13-18~ 9-28-82 D.S. 14-14~ 9-3/4/5-82 D.S. 16-12~ 10-14-82 C}( CNL Run 3 5" CH CNL Run 3 5" CBL/VD Run 1 5" CH CNL Run 3 5" Spinner 5" Spinner 5" CH CNL Run 2 5" CBL/VD Run 1 5" Spinner 5" Spinner 5" Spinner 5" ~' P~eIease sign and return the att~c, hed copy as receipt of data. SCH SCH SCH SCH Camco Camco SCH SCH Camco Camco Camco Becky-Benedict AFA - 403 Trans. #671 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY D&M STATE OF ALASKA DALLAS - A I',l~i~,<,?i ARCO Alaska. Inc. is a Sul3sldlar¥ of AtlanticRichfieldCompar~v AHC~ A~as~a, Posl ~ Anch~rag ,ka 99510 Telephone ~,,J7 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton- Enclosed are monthly reports for November on these drill sites' 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 lC-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 Also enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F-7 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information, on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV:JG-sm Attachments GRU1/L3 ARCO Alaska, Inc. is a subsidiary of AllanlicRichfieldCompany . ,.~_.. STATE OF ALASKA -ALASK~~ L AND GAS CONSERVATION C MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wellXl~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-191 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20863 9. Unit or Lease Name FEL, Sec. 18, TION, R15E, UM Prudhoe Bay Unit 4. Location of Well 691 ' FSL, 942' at surface 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 77' RKB I ADL 28330 10. Well No. 12-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of November ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ~ Spudded well (~ 1530 hrs, 11/11/82. Drld 17-1/2" hole to 2395'; ran, cmtd & tstd :. 13-3/8" csg. Drld 12-1/4" hole to 10,395'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 10,950'; ran logs; ran, cmtd & tstd 7" csg. Ran CBL & 5-1/2" completion assy. Secured well & released rig @ 0015 hrs, 11/30/82. SEE DRILLING HISTORY 13. Casing 20", 9 13-3/8 Permaf 9-5/8" 7" , 29 SEE DR or liner run and quantities of cement, results of pressur9 tests 1.5#/ft, H-40, weld conductor set @ 79'. Cmtd w/415 sx Permafrost C. ", 72.0#/ft, L-80, BTC csg w/shoe @ 2382'. Cmtd w/2100 sx Fondu & 400 sx rost C. , 47.0#/ft, L-80, BTC csg w/shoe @ 10,382'. Cmtd w/500 sx Class G. .O#/ft, L-80, BTC csg f/10,061'-10,940'. Cmtd w/300 sx Class G. ILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR f/10,942'-10,382' FDC/CNL/GR/Cal f/10,950'-10,380' CBL f/10,895'-9950' cont w/CNL/GR to 13-3/8" shoe. RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data N/A DEC 1 ~ .',-.~ ~j ~. 0il & Gas Cons. Commission 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED '~"~a~'~~~~ TITLE Area Dril 1 ing Engineer DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU 1 MR8 Submit in duplicate DS 12-20 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well Ia 1530 hrs, 11/11/82. Drld 17-1/2" hole to 2395'. Ran 58 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2382'. Cmtd 13-3/8" csg w/2100 sx Fondu and 400 sx Permafrost C. ND 20" Hydril & diverter. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 10,395'. Ran 252 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 10,382'. Cmtd 9-5/8" csg w/500 sx Class G. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tested csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,950' TD (11/23/82). Ran DIL/SP/BHCS/GR f/10,942'-10,382',FDC/CNL/GR/Cal f/10,950'-10,380' cont w/CNL/GR to 13-3/8" shoe. Arctic packed 9-5/8" x 13-3/8" annulus. Ran 21 jts 7" 29#/ft, L-80 BTC csg f/10,061'-10,940'. Cmtd 7" lnr w/300 sx Class G. Drld cmt to 10,899' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/10,895'-9950'; good bond. Ran 5-1/2" completion assy w/tail @ 10,116' & pkr @ 10,031'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel. Dropped ball & set pkr. Nipple for SSSV @ 2213'. Secured well & released rig @ 0015 hrs, 11/30/82. JG:sm 12/07/82 GRU1/DH6 RECEIVED DEC 1 Oil & Gas Cons. C;ommJ$sion Anchora§~ Post Office Box 360 Anchorage,--~-~ka 99510 Telephor~ .77 5637 December 9, 1982 RE: ARCO Magnetic Tapes 12"\ \~/~'7,, ---"~D.S. 1-23 11-23-82 D.S, 12-20 11-24-82 ECC 1532 Open Hole #66117 D.S. 13-13 -11-24-82 Open Hole #66120 D.S. 7-15 11-10-82 Open Hole #66037 D/A SCH SCH SCH Run 1 Run 1 & 2 Run 1 Please sign and return the attached copy as receipt of data. Becky Benedi ct AFA- 403 Trans. #651 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS EXPLORATI~)I~ A '~ I- ~'-r. I';;-., . · ;..I ~ . ~ ~-!~ ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany M EM O R/ N D'U M Sta e of Alaska TO: T HP%~: FROM: ALAS~ O!~ ~3~D GAS CONSERVATION COMMISSION ' DATE: November 22, 1982 erton .~ FILE NO: 108A/J Lonnie C. Smi th~ ~/(~-'JO~/ TELEPHONE NO: Corem± ssioner Ben LeNorma n Petroleum Inspector SUBJECT: Witness BOPE Tests on ARCO's DS 12-20 Sec. 18, T10N, R15E, UM Prudhoe B.ay Unit ~uesdaY, November 9, 1982 - I departed my home at 12:20 p.m. for"a 12:50 p.m. showup and 1:50 p.m. departure via Alas~_a D~rlines flight #61 for Deadhorse arriving at 3:30 p.m.- Weather: -21"F, clear, light wind. ~ednesday, _~7ovember 10~ 198_2 ~- BOPE tests on Sohio's B-20 ~re completed, the subject of a separate report. ~_OPE tests on ARCO's DS 1-23 were completed. The subject of a separte report. 1982 -BOPE tests on ARCO's Kuparuk Thursday, Novemb~. r !.1, 1E-25 W~re completed, the subject of a separate report. Friday, November t2, 198.2 - Standing by on DS 13-13. Saturday, .November 13, 19~_2 - DOPE tests on ARCO's DS 13-13 were completed, the subject of a separate report. Sun~..a.y,._.November 14,, 1982 - DOPE tests on ARCO's DS 12-20 began at 2:00 a-~. and were completed at 4:30 a.m. DOPE insPection report is attached. I departed Deadhorse ~a Alaska Airlines flight #66 at 9:45 a.m. arriving in Anchorage at 11:25 a.m. and at my home at 11:55 a.m. In summary, I ~tnessed successful DOPE tests on ARCO's DS 12-20. 02-00lA{ Rev.10/79) ' O&G #4 4/8i STATE OF ALASKA ALASKA OIL & GAS OONSERVATION CCMMISSION B ,O. P .E. Inspection Report . Date Operator. /~ C~~ Representative Well ~ ~ / ~- ~ _ . . Permit #. ~,~ Location: Sec / ~> T/~;~R/~'~M ~_F~ /~ ./..~asing Set Drilling Contractor /~. ,~z;~ -%; Rig '~-~ Repre se ntat ire Location, Genera~ Wel 1- Sign Ceneral Housekeepin9 Reserve pit' Pig BOm Stack Annular Preventer Blind Rams Choke L~ ne Valves H.C.R. Valve. Kill Line Valves Check Valve . Test Pressure Test Results: Failures.. / ACCUMULATOR SYSTEM Ful 1 Charge Pres sure ~ ~ ~ ~ ps ig Pressure After Closure /~-~--~ psig -- Pump incr. clos. pres. 200 psig mind, Sec. Fu/ll Ch,~a~e Press~re Attained: ~ min ~ sec. N2/~/~~/~_ ~/~ psig Controls: Master o~ Remote O~ Blinds switch cover~- ~ Kelly and Floor Safety Valves · Upper Kelly Lowar Kelly. ~ail ~pe Inside BOP Choke Manifold Va es Test Pressure. Test Pressure ~~o Test Pressure Test Pressure Test Pressure No. flanges ~O Adjustable Chokes / Hydrauically operated choke / Test Tin~.'~_/~/~- hfs Repair or Replacement of failed equipment to be made within days and Inspector/Ccmmission office notified. Distribution orig. - AO&G~C cc - Operator cc - Supervisor Inspector ARCO Alaska, Inc. Post Office B_.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 16, 1982 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - DS 12-20 Dear Elaine: Enclosed is an as-built location plat for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:llm Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany RECEIVED NOV I ? i.-982 A~k~ Oil & AnohomD~ L ilo · 17 J~ 2O VICJN MAP WELL #12/20 Y = 5,930,998.26 : X = o696,661.20 LAT = 70_12'56.548" LONG = 148024'49.042'' N.W. COR. CEL'LAR BOX ELEV. = 41-3' ! HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF~_,/ . _ RECEIVED NOV 1 ? ]982 Alaska. 0il & Gas Cons. Commission Anchorage. !iovember 8, 19~-~ o2 ~a~; A' Major .Area Drilling Engineer ARCO Alaska, Inc. anchorage, Alaska 99510 Re-: Prudhoe Bay Unit DS t2-20 ARCO Alaska, Inc. Pe~it 31o.oz"~-I9! Sur. Loc. 691'F£L, 942'FEL, Sec. 18, T10?I, Btmhole Loc. 96'FSL, 2508'FEL, Sec. 7, T10U, !~lSE, U?i. Dear Mr. Ma~or: Enclosed is the approve~ application, for permit to drill the above referonced well. if coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttinf~s and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing t!~e digitized log infor~ation ~hali be subt~itted on all log~ for copying except experin, ental logs, velocity surveTs ' ' dip =~=~- rzvera in Alaska and their drainage system_s have been classified as important for t~e _spa.,.~..ing or migration of ~n. adro~u~ fish. ~n _ .... ~ ~ ...... =tions in thes~ areas are subject to AS 16 05 o~ and the regulations proraulgated thereunder (Title 5, Ala~ka Administrative Code). Prior to co~encing o~e~ations =o,~ may be contacted, by the Habitat Coordinator' ~~ ne~a ~mont of ?i8b ~nu Ga~e orate is prohibited by AS 46 Pollution of any waters of the °- ~ , ~.,,~=~.t~r~-~ 3, 'Article_ 7 and the regulations. ~ro.~t,.ulgat~d. ~ thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the t-e~e~a! Water Pollution Control Act, as ~t~ended. Prior to c~2~encing operations YOU. ~a'~'. be contacted by a representative of the Depart~ent of ,~n~ro ...... ~,:~=I Conserva.~ . To aid us .n scheduling field work, please notify this ofF.lee 2A hours pr~ ~ ~ ~ ',~ ~'~ ins . ~ *o~ to ~o~.~.e.c~,~g _. ta~lation _ the olowout Mr. Mark A. Majox Prudhoe Bay Unit DS 12-20 -2- November 8, 1982 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly youths_, -C. ~. Chatterton ~hairman of BY ORD~q Alaska Oil and Gas Conservation Co~ission Enclosure Department of Fish & Game, Habitat Section w/o encl. Departm~ent of Environmental Conservation w/o encl. CVC:be ARCO Alaska, Inc. Post Office B. J60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 5, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Dear Mr. DS 12 -20, Permit to Drill Chatterton' is our application for Permit to Drill DS 12-20 and the Enclosed required $100 filing fee. Attachments to the application include. a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a discussion of nearby wellbores; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we estimate spudding this well November 9, 1982, your prompt approval will be appreciated. Sincerely, M. A. Major Area Drilling Engineer MAM/JG: sm Enclosures RECEIVED NOV 0 5 1982 Alaska 0il & Gas Cons. Commission Anchorage GRU2/L26 ARCO Alaska. Inc. is a subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA (J~L AND GAS CONSERVATION CO~v, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~]( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE D~]X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 691' FSL & 942' FEL, Sec. 18, TION, R15E, UN (as-staked) At top of proposed producing interval 220' FNL & 2401' FEL, Sec. 18, TION, R15E, UM At total depth 96' FSL & 2508' FEL, Sec. 7, TION, R15E, UM 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 12-20 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 77' PAD 41' J ADL 28330 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed Deadhorse 0 4139 feet 2-12 well @ 3930' MD = 95 feet 16. Proposed depth (MD & TVD) 10932'MD, 9223'TVD 19. If deviated (see ?0 AAC 25.050) KICK OFF POINT' ~Z~-'~C) feet. 21 miles 17. Number of acres in lease feet 2512 20. Anticipated pressures MAXIMUM HOLE ANGLE 4el o (see 20AAC25.035 (c) (2) Proposed Casing, Liner and Cementing Program 18. Approximate spud date 11/09/82 3429 psig@____ Surface 4131 psig@. 9223 ft. TD (TVD) SIZE Casing 20" Weight 91.5# 13-3/8" 72# 9-5/8" I 47# 7" 29# CASING AND LINER Grade Couplingl Length H-40 Welded 80' L-80 Butt I 2564' L-80 Butt / [0i~7~ L-80 Butt / 95~? Hole 2-1/4" ~-1/2" 22. Describe proposed program: SETTING DEPTH MD TOP TVD 36' I 36' 36' I 36' I 33' ~ 33' I 99g~o' ! 84 ~/°::'' MD BOTTOM TVD 116' I 116' 2600' 2600' 1.O~ ~gO' I 18721 ' 10932' 19223' I QUANTITY OF CEMENT (include stage data) 2000 # Poleset 2300sx Fondu + 400 sx PFC 500sx Class G 1st Stage 300 sx PFC 2nd Stage 400sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 10932' MD (9223' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing, packer, and gas lift mandrels will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud and at least daily thereafter. See attached well crossing analysis. RECEIVED 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commf~io~/0se Cons. Corragio. TITLE Area ~-~l IVI i~l CONDITIONS OF APPROVAL Directional Survey required APl number J~YES []NO sEE COVER LETTER FOR OTHER REQUIREMENTS Samples required Mud log required I-lYES ~_NO []YES [~-NO Permit number Approval date f~.~/ ~ .~.1A-~08/82 .~., Form ~ 0-401 GRU2/PD16 ,COMM ISSl ON ER DATE by order of the Commission November 8, 1982 ~'~ Submit in triplicate DS 12-20 PROXIMITY ANALYSIS The only well within 200' of DS 12-20 (as planned) in the directional portion is DS 12-12. The minimum distance is 95 ft. at 3930' MD on DS 12-20. At this point, Well 20 is below (TVD) Well 12. In reality Well 20 will be led to the left of what is proposed. This will increase the distance between the wells as Well 12 is further below Well 20 the further Well 20 is led. The Teleco Drill ~Collar will be used throughout this interval and frequent surveys will be taken. GRU2/PA12-20 RECEIVED NOV 0 5 5982 Alaska Oil & Gas Cons, Commission Anchorage ANNULAR PREVENTER ) ( · ) -~~RILL!NG SPOOL . NOV 0 lgB2 Al~s~ 011- & G~s Cons. Co~mtssion krmhorags 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 1. Check and 'fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultane- ously and record the time and pressure remaining after all units are closed with char!)ing pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing 1 iquid. 2. Check that all hold down screws are fu.lly retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Ru~ in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a 250 psi low pressure test for a minimum of 3-minutes, then test at the hi. gh pressure. 5. Increase presure to 3000 psi and' hold for a minim~n of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe r~ms then close bottom 'set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and bold for .at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to ze6o. Open bottom set of pipe rBms. ' 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. · 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey p~np. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC. ~ I0" HYDo OPR. BALL VALVE /~-,--'-V~,L,L BORE (SEE DETAIL) / /.~.-'--IO HYD. OPR, BALL VALVE // f/"' ~ ALL 90° TURNS ARE "TEE" ' ~ I OUSHZON I I~LL RESERVE PIT AREA NOTE' FLO~ INE DR ILL lNG RISER F l 20" 20O0 PSI ~ ANNULAR PREVENTOR Valves on diverter lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE IO" HYDRAULIC OPERATED BALL VALVES "DETAIL" 2026010203 CHECK LIST FOR NEW WELL PERMITS Company r~C~ Lease & Well No. ITEM AP PROVE DATE (1) Fe ~'~ ....... ~, / : , ~.~ '~ (2) Loc (/2 thru 8) le mo 3. 4. 5. 6. 7. 8. (3) Admi.____~n " , . f~.,.,~_~. 1I-~-~-~-~ 9 (9 thru 11) 10. 1t. (4) Casg ru 20) (2i thr~ '2-~ Add: 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is Is Is Is Is well located proper distance from property line ..... ' .... well located proper distance from other wells ........... Sufficient undediCated acreage available in this pool ... Is well to be deviated and is well bore plat included . Is operator the only affected party ................ Can permit be approved before ten-day wait YES NO Does operator have a bond in force ..................... , ............ ~'L-_, Is a conservation order needed ...................................... ~'~ Is administrative approval needed ................................... R~4ARKS Is conductor string provided .' .......................... ' ......... %".~ Is enough cement used to circulate on conductor and surface ..... ~...~ Will cement tie in surface and intermediate or production strings'i..~ Will cement cover all known productive horizons ................. ~.~..~~ Will surface casing protect fresh water zones ................... ~...~ Will all casing give adequate safety in collapse, tension and burs.t*..~ Is this well to be kicked off from an existing wellbore ......... ~...~ ~~ Is old wellbore abandonment procedure included on 10-403 ........ ~'.... ~ · Is adequate well bore separation proposed ....................... ~..~ diverter sys required ' ~/ ~ Is a tem . .... ,.........,,......... .... ..,.. .... Are necessary diagrams of diverter and BOP equipment attached .~ Does BOPE have sufficient pressure rating - Test to ~7~ ;~i~2 .~.~. Does the choke manifold comply w/API RP-53 (Feb.78) ......... ........./ ~ Additional requirements ............................................. Additional Remarks: o Geology: Engineering: fVA ~. JKT~ RAD ~-~ -- tf' :ev: 08/19/82 INITIAL GEo. UNIT ON/OFF' POOL CLASS STATUS AREA NO. SHORE 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. ~1~'~] I~ l!l iil ii:] l_t.' [:-I i ,.. {.. i'113 .... ,( ( ~'-"1~ I'11 ~ I l i1 iI;t i/.~ [;t ~ _ ~NE~ S~RvlCE: SERVICE u~!iT ~.PI APl AP:]. APi FILE )E PT ~FL L', ! IL [Lb 0 0 0 1,2 4e ,( EP7 10973.0000 t:' - !o9.9 ~ ? 5 G Phi -999.2500 DP~¢ -999 'Cf, L -999.2550 C.¢i ~ .c~, b~g -999. 2500 t,,~ P~, i -99~ ~EPT 10800°0000 SF't,U ;P -1 g3. P,'! 50 tJ< IPfl I 26. 1230 DRhO . ~ . .. 19.3594 Ib~ lO.70ba IbP 2 ,~. 562 b !.-'! 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