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Home My WebLink About185-302Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. j_ (~ 5- ~ -~(~ Well History File Identifier Organization (done) ~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) ~ Color items: [] Diskettes No. [] Maps: '/Grayscaie items: [] Other, No/Type [] Other items scannable by . large scanner oor Quality Originals~,~~-~-~--~.-~..~-.~-~ ~ - - ~'~' ~' ERSlZED (Non-Scannable) P other: ~ ~0-44/~ - ' ! [] Logs of various kinds [] Other ORGANIZED BY: BEVERLY BREN VINCENT SHERYL~-OWELL DATE: /S/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: (~'~ (at the time of scanning) SCANNED BY: BEVERLY BREN VINC~MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: PAGES: Quality Checked (done) Revi NOTScanned.wpd ~~~ la• PROACTIVE DIAGNOSTIC SERNCES~ INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Gas Lift Survey 2j Signed Print Name: 01-Feb-10 nnpl I Rccn r~5 =3~a ~ ~} 3~ 3 BL / EDE 50-029-2 1 509-0 1 _ _ -_ _^ ~ -, Date . ° ,A~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907?245-8951 FAX: (907)245-88952 E-MAIL : ___:-: s wEBSITE : -, Cs.Doc latent and Setffitgsl~lana R'illiams~DeskYOp'I'rattsmlt BP.docx r~~~11/ • STATE OF ALASKA ~ JAN 0 7 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 4~Ia;Oil ~ Gas Cans. COmm15SI0f~ Anchnrana 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended ~ zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: • ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., o ban 12/7/2008 12. Permit to Drill Number 185-302 308-389 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/29/1985 13. API Number 50-029-21509-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 01/10/1986 14. Well Name and Number: MPB-22 - 183 FSL, 1066 FWL, SEC. 18, T13N, R11 E, UM- Top of Productive Horizon: 970' FNL, 1764' FEL, SEC. 25, T13N, R10E, UM 8. KB (ft above MSL): 59' Ground (ft MSL): 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 1270' FNL, 1908' FEL, SEC. 25, T13N, R10E, UM 9. Plug Back Depth (MD+TVD) 10533' 6930' Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 572144 • y- 6023308 'Zone- ASP4 10. Total Depth (MD+TVD) 10729' 7031' 16. Property Designation: ~~ z55/ ADL 047438 ,~ TPI: x- 569375 y- 6016849 Zone- ASP4 Total Depth: x- 569234 y- 6016547 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: /.rz' 18. Directional Survey ^ Yes ®No i I ni n rin in rm i n r AA 2 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL/FDC/CNL/GR/CAL, G ro/GR/CCL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM .TOP BOTTOM .SIZE CEMENTING RECORD PULLED 1 /8" 4 rf ' ' 1750 sx Permafrost'E' 300 sx Class'G' " 1 9' 1' 300 sx Class 'G' 60 Bbls Arctic Padc 180 sx PF 'C' 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top 8~ Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER SET MD 3-1/2", 9.2#, L-80 10419' 10375' MD TVD MD TVD 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. r- ~y DEPTH INTERVAL MD AMOUNT ~ KIND OF MATERIAL USED 6'' ~' ~°~'°' ~~~'~ ~~ ~~~~ 10400' - 10405' ubin Punch for P8A Cementin 10389' P8A w! 11 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrs Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: ` GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 2a-HouR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? Yes ® No Sidewal l Core s A wired? ^ Yes ®No"' If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. A6a.~dlnr f None $~ ~ ~ ,jGs~ Z~JO~ '~ .,_~ 37 Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE .~J~ l~~//~ ~ ~-~Z'v7 • • 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu Zone C 4920' 3871' None Ugnu Zone A 5352' 4098' Schrader Bluff NA 5770' 4314' Schrader Bluff OA 6045' 4452' Kuparuk D 10056' 6678' Kuparuk C 10338' - 6827 Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / / Q ~t Signed Terrie Hubble ~ Title Drilling Technologist Date ` O7/ ~ ` MPB-22 185-302 308-389 Prepared By Name/iVumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Greg Barber; 564-4330 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. Submit a well schematic diagram wlth each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground Level elevation in feet above mean sea level. 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: Repoli true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. trExl 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only MPB-22, Well History (Pre Rig Sidetrack) Date Summary 10/30/2008 T/I/0=1000/ 1300/380 (Freeze Protect) Pumped 30 bbls 60/40 down IA. Pumped 2 bbls Neat methanol and 10 bbls 60/40 down flowline. Pumped 2 bbls neat methanol and 20 bbls 60/40 methanol down tubing. FWHP=1000/1120/380 Slickline on well upon departure. IA and OA open to gauges. 10/30/2008 WELL FLOWING ON ARRIVAL. DRIFT TUBING W/ 2.53" CENT, TEL, SAMPLE BAILER, LOC TT Cad 10432' SLM (10416' ELM) S/D C~ 10505' SLM (CORK 10489' ELMD, 29' OF MK-2 PERFS COVERED, 1' OPEN) RECOVER SAND IN SAMPLE BAILER. SET WHIDDON C~ 10423' SLM. PULL BK-LGLV FROM STA #6, #8, #10. SET BK-DGLV IN STA #10, AND #8, RUNNING IN HOLE W/ STA #6. 10/31/2008 SET BK-DGLV IN STA #6. PULL EMPTY WHIDDON. UNABLE TO PASS THROUGH NIPPLE WITH A 2.73 CENT, XO, 3.5 BLB, S/D C~ 10418' SLM, MARKS ON BOTTOM EDGE OF CENT. LARGEST OD TO PASS THROUGH 2 75" D NIPPLE WAS A 2.53" CENT_ WELL S/I ON DEPARTURE. 11/2/2008 T/I/O =1340/1500/325 Bled IA from 1340 psi to 0 psi in 2 hr 7 mins, first 25 bbls FP then all gas. T/I/0=1340/0/0 11/2/2008 T/I/0= 1320/300/260 Standby for well techs to bleed down IA Press. Pump 152 bbls dead crude down IA to load for MITx IA. FWHP= 1340/1650/310. 11/2/2008 T/I/O=SSV/1400/340, Temp=S1. PPPOT-T (PASS), Pre CTD, repair leaking gland nuts. PPPOT-T: Stung into test port (0 psi). Functioned LDS (ET style), all moved freely. 6 LDS/gland nuts were out of adjustment (weeping), re-adjusted and torqued to spec. Pressured test void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 11/2/2008 T/1/01300/ 1250/280. Bled IA from 1250 to 360 in 4 hrs, and 11 min all gas. Ending pressures T/I/O 1300/360/260 11/2/2008 (MITx IA / MITx OA) T/I/0= 1320/0/280 Pump 10 bbls diesel down IA. Pressure IA to 3000 Psi. MITx IA =Initial press. = 1320/3000/280. 15 Min. Press = 1320/2980/280. 30 Min Press = 1320/2970/280. MITx lA is a Pass. wing=shut / ssv=shut /swab=shut /master=open / IA and OA open to gauges.) FW H P=3120/0/280 11/4/2008 SSV/200/200 MIT-OA TO 2000 PSI ""`PASSED""" LOST 80 PSI IN FIRST 15 MIN. AND 20 PSI fN THE SECOND 15 MIN FOR A TOTAL LOSS OF 100 PSI IN 30 MIN. BLED OAP TO 200 PSI. FINAL WHP = SSV/200/200 11/12/2008 T/I/0=1300/250/225 RIG UP FOR TUBING PUNCHER. TBG PUNCH BELOW PACKER FROM 10400 - 10405' AT THE TOP OF THE FULL JOINT. JOB COMPLETED. WELL LEFT SHUT IN. SWAB, SSV AND WING CLOSED. CASING VALVES OPEN TO ALL GUAGES, CAP HAS GREEN O'RING AND IS PRESSURE TESTED. 11/19/2008 CTU #9 w/ 1.75" OD CT. MIRU CTU #9. Drift new reel with 1.25" OD ball. Perform BOPE test. MU and RIH with 2.0" OD BDJSN. Kill well w/ 2X vol of KCL. Tag TD C~ 10470'. Correct to E/L tag. PU 10' flag CT. Suspend job due to inability to move diesel transport. 11/20/2008 Re-kill well w/ 2x volume of 1 %KCL. Load backside w/ 70 bbls of diesel. Confirm 1:1 liquid returns at surface. Lay in 11 bbls 17 ppg class G cement, losing approximately one bbl cement to formation. Build_ -650 psi squeeze pressure over static. Drop ball to convert nozzle to JSN, clean out cement to a clean cement top at 10400' MD (the depth of the uppermost tubing punch). Freeze protect wellbore to 2500' TVD with diesel. Trap 500 psi WHP. RDMO CTU. Job complete. 11/23/2008 T/I/0=200/220/180 (Flowline Flush and Freeze Protect) Pumped 4 bbls Diesel C~3 90°F down flowline and 12 bbls 60/40 methanol to flush flowline. FWHP=200/220/180 Page 1 of 2 C. MPB-22, Well History (Pre Rig Sidetrack) Date Summary 11/27/2008 WELL S/I ON ARRIVAL. PULL BPV. TAG W/ OC, XO, 2.74 CENT, SAMPLE BAILER, SD C«2 10371' SLM, NO SAMPLE RECOVERED. 3.5 OK-1 (straight tray, no kick springs), ZERO BOTTOM OF TRAY, SD ~ 10388' SLM (CORK 10393' MD), PULL UP HOLE UNABLE TO LOC STA #1 OR #2, LOC STA #3 8704' SLM (5' CORK TO 8709' MD. 11/28/2008 TAG TOP OF CEMENT W/ OC, XO, 2.74 CENT, SD @ 10384' SLM.(5' CORK TO 10389' MD). LRS MIT-T TO 2000 "''FAIL*" WELL S/I ON DEPART. NO BPV. 11/28/2008 Pulled BPV for Slick Line to tag cement plug. BPV out of the hole till further notice. 11/28/2008 T/110=150!2601180 (MIT Tubing to 2000 psi.) MIT Tbq to 2000 psi. Failed. Lost 240 psi in first 15 minutes & 190 psi in second 15 minutes. Total loss=430 psi. Retest. Failed. In second test tbg lost 210 psi in first 15 minutes & 230 psi in th esecond 15 minutes. Total loss=440 psi. MIT tbg to 2000 psi. Failed. Lost 300 psi in first 15 minutes & 200 psi in second 15 minutes. Total loss = 500 psi. Bleed tbg pressure down to 0 psi. FWHP=0/130/180. 12/3/2008 The Well Support Techs rigged up and set a back pressure valve NOE• The BPV was I well is ready for the rig. Page 2 of 2 BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: MPB-22 Common Well Name: MPB-22 Spud Date: 12/29/1985 Event Name: REENTER+COMPLETE Start: 12/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2008 20:00 - 20:15 0.25 MOB P PRE PJSM on pulling off well. 20:15 - 20:45 0.50 MOB P PRE Pulf rig off of well, tum around for driving off pad. 20:45 - 21:00 0.25 MOB P PRE PJSM with Security and rig crew on rig move. 21:00 - 00:00 3.00 MOB P PRE Leave Y pad for MPB-22 via, Y pad access road to GC2, to GC2 access road, to spine road, to Milne Pt. Rd, to MPU B Pad. 12/5/2008 00:00 - 06:00 6.00 MOB P PRE Continue to move rig down Spine Road towards MPU. Near L pad access ~ crew change 06:00 - 06:30 0.50 MOB P PRE Crew change out. Make rounds. 06:30 - 16:00 9.50 MOB P PRE Continue rig move. Approximately 15 miles of 30 mile move at 0700 hrs (15 miles in 9 hrs) 16:00 - 18:00 2.00 MOB P PRE Arive ~ B pad. Standby for ATP meeting. 18:00 - 19:00 1.00 MOB P PRE ATP meeting with both crews. 19:00 - 19:20 0.33 MOB P PRE Crew change, walk arounds, and PJSM for moving SLB injector. 19:20 - 20:00 0.67 MOB P PRE Move SLB injector off to side of rig floor from where the chains were changed to be able to PU the BOP's 20:00 - 20:10 0.17 MOB P PRE PJSM - on PU and secure of BOP's with blocks. 20:10 - 20:30 0.33 MOB P PRE PU and secure BOP's 20:30 - 20:40 0.17 MOB P PRE PJSM - on spotting rig over well. 20:40 - 22:30 1.83 MOB P PRE Move rig over well. Rig spotted at about 40 deg angle to well rows in order to be able to spot trailer under reel house to load coil. Ri acce ted ~ 22:3 22:30 - 00:00 1.50 MOB P PRE Continue to ready rig. ND tree cap and NU BOP's 12/6/2008 00:00 - 06:00 6.00 MOB P PRE Continue to NU BOP's, change out BOP rams, and ready rig. 06:00 - 06:30 0.50 MOB P PRE Crew change. Make rounds. Discuss plan forward. 06:30 - 15:00 8.50 BOPSU P PRE Test BOPe as era roved well Ian, AOGCC re s and PTD #208-168. Record all data electronically and on AOGCC test form. E-mail test form to AOGCC. Test witness waived by J. Crisp, AOGCC. Continue to rig up equipment. Re-spot office trailer. Rig up flow back tank and line. Lower 2" combis leaking. Replace same. Found damaged ram body. Complete test. 15:00 - 18:00 3.00 RIGU P PRE t r I r fil PV RD lubricator. 18:00 - 18:30 0.50 RIGU P PRE Crew change and PJSM 18:30 - 20:20 1.83 RIGU P PRE Clean up rig floor from SLB chain change, assemble Injector Head, RU to stab pipe, PU tools and motors. 20:20 - 20:45 0.42 RIGU P PRE PJSM for stabing pipe. 20:45 - 22:05 1.33 RIGU P PRE Pull test grapple, retighten. Pull pipe over and stab in to injector. OC wire. 1200 Mohms, 49 Ohms. MU 3 ft lubricator. 22:05 - 23:15 1.17 RIGU P PRE Reverse in water. 23:15 - 23:50 0.58 BOPSU P PRE Pressure test Pack off and outer most inner reel valve. 23:50 - 00:00 0.17 RIGU P PRE Pump slack management 12/7/2008 00:00 - 00:15 0.25 RIGU P PRE Continue to pump slack management. 00:15 - 00:25 0.17 RIGU P PRE PJSM for cutting coil. BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: MPB-22 Common Well Name: MPB-22 Spud Date: 12/29/1985 Event Name: REENTER+COMPLETE Start: 12/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/7/2008 00:25 - 01:35 1.17 RIGU P PRE RU and cut coil. Cut 61.5 ft of coil. OC Eline 1230 Mohms, 48 ohms. RD CT Cutter. Install SLB CTC -pull test to 35,000 #'s 01:35 - 02:45 1.17 STMILL P WEXIT Install BHI Upper Quick Connect. Test connection - +2000 Mohms, 54 Ohms. Press Test to 3,500 psi. 02:45 - 02:55 0.17 STMILL P WEXIT PJSM-PU milling BHA. 02:55 - 03:45 0.83 STMILL P WEXIT PU -Milling BHA #1 03:45 - 06:30 2.75 STMILL P WEXIT RIH with milling BHA. EDC open, pumping min rate and returns to ti er tank. 06:30 - 10:30 4.00 STMILL P WEXIT Tag cement at 10385'. Log tbg RA tag at 10,330'. m'Q~'22R Log GR across DIL log interval from 9450' to 9550'. subtract 8' correction. Log GR again across tbg RA tag. Did not see RA this pass. Log CCL from 10,000' to TOC at 10,379' (corrected) Found GLM # 1 at 10,317' and HB packer on original completion depth of 10,375'. -14' correction from tbg punch log. 10:30 - 15:30 5.00 STMILL P WEXIT Mill cement from 10379'. 3100 psi fs at 1.49 bpm in/out. 100-200 psi mtr work. 1.5k# dhwob. TF: 180 deg. ROP: 20-25 fph. Frequent stalling. Cement is hard. ROP slowed to 10 fph. CHange TF to HS at 10,445'. Mill to 10,452'. Note increased mtr work and some reactive torque. 15:30 - 16:15 0.75 STMILL P WEXIT Back ream with HS tool face into tbg tail. 16:15 - 18:10 1.92 STMILL P WEXIT Pull out of hole. PJSM on LD BHA while POOH 18:10 - 19:00 0.83 STMILL P WEXIT LD Milling BHA #1 and PU window milling BHA #2 19:00 - 19:40 0.67 STMILL N SFAL WEXIT BHA will not pass through well head. Attempted to grind off wear pad but way to hard. 19:40 - 21:30 1.83 STMILL N SFAL WEXIT Wait on Weatherford to bring out 2.5 fixed bend motor with no wear pad. SLB-used the time to off load old injector chains. Nordic-RU slick line unit for pressure deployments. 21:30 - 21:40 0.17 STMILL N SFAL WEXIT PJSM-PU of tools. 21:40 - 22:05 0.42 STMILL N SFAL WEXIT PU -New window milling BHA #2 with 2.5 deg fixed bend motor with no wear pad. 22:05 - 22:25 0.33 STMILL P WEXIT Stab on injector, run final test on BHA. 22:25 - 00:00 1.58 STMILL P WEXIT RIH with EDC open. 12/8/2008 00:00 - 00:45 0.75 STMILL P WEXIT Continue RIH 00:45 - 01:15 0.50 STMILL P WEXIT Log for CCL tie in from 10,225 ft to 10,389 ft. -8 ft correction 01:15 - 01:29 0.23 STMILL P WEXIT RIH and dry Tag ~ 10,451 ft. PU to 10,441 ft. Turn on pumps while setting back down with 0=1.5 bpm Tag ® 10,450.4 ft. PU to 10,449.4 ft and flag pipe 01:29 - 06:00 4.52 STMILL P WEXIT Mill window following BP RP/Well plan schedule. Op=1.46/1.47 bpm ~ 2930 psi Printetl: 1/5/2009 11:19:54 AM TREE: 3 1 /8' - SM FMC w/ 3 1 /I Otis Quids Unbn WELLHEAD: 11" SM FMC w/ 3 12" 'H' BPV pro1Ne. MPB-22A CTD ~ KB Elev. = 59' Nabors 27E GL Elev. = 36' Nabors 27E 13 3/8", 48#, K-55 88, BTRC KOP @ 500' MAX Hole Angle: 61 DEG @ 6375' 9 5/8", 36;K, K-55 6349' - BTRC 3 12" , 9.3#, BTRS, L~0 TUBING DRIFT ID: 2.86T' CAPACITY: 0.0087 BBUFT 7" , 26#, L-80, BTRC Casing DRIFT ID: 6.151" CAPACITY w/ tba:.0264 bpf Top 2 3/8" liner at 10,272` _ Casing RA Tag 10219' Baker'PBR' Seal Assy (3.00° ID) 10360' Baker `HB' Packer (2.as° ID) 10375' Perf @-10385 for tailpipe cementing - Camco 2.750'D' nipple 10413' WLEG 10419' WLEG (ELMD) 10426' PERFORATION SUMMARY (DIL Loq dated //) Zone Size SPF MD' TVD' MK-1 MK-2 5" 5" 12 12 10426' - 10456' 10488' - 10518' 6873' - 6889' 6906' - 6922' 0 17 PP9 cement Camco TRDP-IA-SSA SCSSV 1927' I Note: The Camco TRDP-IA-SSA was locked out of service 6125/00. 1° x 3 1/2" McMurray FMHO w/ BK latch # rnd tvd d9 10 2198' 2111 ` 30 9 3119' 2822' 47 8 4102` 3420' 57 7 5242' 4041 ` 59 6 6196` 4526' 61 5 7150` 5027` 55 4 7945` 5482` 54 3 8709' 5926` 55 2 9504` 6377' 57 1 10331 ` 6832` 58 Cement Ramp Window at 10,460' 2 3/8" Cemented Liner 11, 780' Fill tagged w/ wireline on 2/27/08 at 10533' MD Fish:Calculated top of TCP 10526' - PBTD (~ Ca~ar) 10628' T' 26 # Shos 10729' DATE REV BY COMMENTS MILNE POINT UNIT 1/11/05 Lee Hulme Convert drawing to Canvas WELL MPB-22 12/23/08 Nordic 2 Sidetracked for more oil....... API NO: 50-029-21509 BP EXPLORATION (AK) • . ~~, _ ~ SARAH PALIN, GOVERNOR ~T ALASKA ®II, A1~TD rirAS ,• 333 W 7th AVENUE, SUITE 100 CO1~T5ERQA'1`IOrT C011II1II5SIOPIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. r , ~, , ~ ~t ~, P.O. Box 196612 ~~~"~~~' ~~ ~~ ~ ~~ ~~~~ Anchorage, Alaska 99519-6612 ~~~0 `~ Re: Milne Point Unit, Kuparuk River Sands, MPB-22 Sundry Number: 308-389 Dear Mr. McMullen: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this ~ day of October, 2008 Encl. STATE OF ALASKA • - ~l;V~ i A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL c°~~GCr '~ 2008 20 AAC 25.280 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate i ~ ~isl~oa~~ ~0~ ,, ~~`"ors ~ ,,~.~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Su`~i4~ijQll ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Develbpment ^ Exploratory 185-302 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21509-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPB-22 , Spacing Exception Required? ^ Yes ®No 9. Property Designation: ~i 10. KB Elevation (ft): 11. Field /Pool(s): fSl$ ADL 047438 • 59' Milne Point Unit / Kuparuk River Sands 12• ~~~•~' PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10729' 7031' 10533' 6930' 10533' 10526' 'n Len Siz MD B rst Colla tr r I a 9' /8" 460 In rmedi Pr i n 1 7 7 1 7 4 41 Lin r Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10426' - 10518' 6873' - 6922' 3-1/2", 9.2# L-80 10419' Packers and SSSV Type: Baker'HB' packer; Packers and SSSV MD (ft): 10375" Camco TRDP-1A SSA SCSSV 1927' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 15, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Greg Sarber, 564-4330 Printed Name John CMy le Title En ineerin Team Leader Prepared By Name/Number. Signature • Phone 564-4711 Dated ~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~ ~ ..- ~ c~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity OP Test ^ Mechanical Integrity Test ^ Location Clearance other: 3~~ ~~~~ ~~~ ~..~~.~--, Subsequent Form Required: ~~~ APPROVED BY 6 / ~ 0 A roved B COMMISSIONER THE COMMISSION Date 7- Form 10-403 Rer~ised~6/2006 r~ ~~:9 ? r= ~ 2Q08 ~•.~I`1~~~~a~~ is"3 Submit In Duplicate ~ ice. Z~ ~ ~n~ 113/may/~' • To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: October 23, 2008 Re: Milne Point B-22 Sundry Approval Sundry approval is requested to abandon perforations on well MPB-22 in preparation for a CTD w!~ rtri sidetrack. MPB-22 is a Kuparuk C/B sand producer that is in direct communication with its injector. MPB-22A .~ C~`",~,, (~'t~~,~ will be drilled to a more optimum location for injection support. ~~~~~;~' ~rhh ~ al`f ~ The sidetrack, MPB-22A, is scheduled to be drilled by Nordic 2 starting December 15, 2008. The plan calls for ~.~ Fr ri~ laying 17 ppg cement across the 7" liner to shut-off existing perfs and to prepare for a cement ramp window in ~ ~` ~''~ ~`~ the Kuparuk C interval. Additionally, the 3'/z" tailpipe will be punched just below the production packer to allow ~~~ ~ ~' ~ jf'°'k 17 ppg cement to swap out around the tailpipe to provide mechanical stability. The stabilized tailpipe will then ~`~' rat ui~,~'~ provide aback-up KOP in the event that troubles arise with the cement ramp window. The following describes ~r work planned. A schematic diagram of the proposed sidetrack is attached for reference. 5~ `~ {~~ Pre-CT Rig Work: The pre CTD work is slated to begin about November 15. 2008. 1. MIT-IA. 2. PPPOT-T 3. Slickline tag PBTD at 10,500 ft to confirm volume of cement required. 4. Dummy off all GLM's. ~,,~~ 5. Punch tailpipe at 10,385-87 (2 ft, 4 SPF). 6. Lay 17 ppg cement, minimum 7 bbls, to shut-off perfs and provide for a cement ramp window. ~`~ 7. MIT-T ~ 8: Pull wellhouse, bleed remove and blind flowlines. j Drill Mousehole extension Rig Sidetrack Operations: (Scheduled to begin on December 15, 2008 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 2.74" pilot hole in cement, and cement ramp for window. ~ G! ~ t rf IIt~/?~~A ~ ~ !r iii/~ y/ 4. Mill 2.74" window in 7" casing. 5. Drill build/turn section with 2.70" x 3.0" bicenter bit, and land well. 6. Drill lateral section to 12,875'. 7. Run and cement a 2-3/8" L-80 liner string. 8. Make a cleanout run with mill and motor. 9. Make a logging run with a memory SWS GR-CNL logging tool. 10. Perforate well. 11. Circulate well to KWF brine. FP well to 2000' with methanol. 12. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 13. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design. 4. POP well to a separator (1200' of perforations expected) Greg Sarber CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble TREE: 3 1 B' - 5M FMC '++' 3 tl2^ DI's Quick Urion V,rELLHEA~ i t- 5M FA1C va' 3 1/2" hr BPV ptaifile- MPB-22 13 3/8", 48#, K-55 _ BTRC ~ 88~ 9 5/8~, 36#, K-55 6349' BTRC KOP ~ 500' MAX Hole Angle: Ot DEG >~ 9375' 3 tt2" , 9.3tf, BTRS, L-90 TUBING DRIFT ID: 2.86A CAPACITY: 0.0087 8BL1FT 7" , 2@#, L-80. BTRC Caisirg DRIFT ID: 0.151" CAPACITY w.~ tha .0204 bpf Casing RA Tag 10219' PERFORATION SUMMARY jDIL Log dated ll} Zone Size SPF MD' TVD' MK-1 MK-2 5- 5' 1~ i~ 10429' - 10459' 10489' - 10518` 4873' - 988 4809' - 99:: KB Elev. = 59' Nabors 27E GL Elev. = 36' Nabors 27E Camco TRDP-IA-SSA SCSSV 1927` Note: The Camco TRDP-IA-SSA was locked art of service 6l25lD0. 1" x 3 tl2" McMurray FMHO w! BK latch # rnd tvd d9 10 2198' 2111 ' 30 9 3119' 2822` 47 8 4102' 3420` 57 7 5242` 4041' S9 6 6196` 4526' 61 5 7150` 5027' S5 4 7945` 5482` 54 3 8709` 5926` 55 2 9504` 6377" 57 1 10331' 6832' S8 e: SPM ~1 has a DV w/o a latch. t latch broke off 519/07. 'r 'PBR' Seal Assy ~s_oo~ ID) 10360` ~cer 'HB' Packer lass" lD} 10375' amco 2.750 'D' nipple 10413' WLEG 10419' WLEG (FEND} 10416 99~d w/ sllcklina on 2Y17108 at 10533' ELMD :Calculated top of TGP 10526" PBTD (Float Cc~ar} 10628' 7~ 26 ~ shoe 10729' DAre REV.sY CCatrv~Nrs MILNE POINT uN1T 1111105 Lee Hulme Convert drawing to Canvas WELL MPB-22 02-27-08 JRP ELMD to WLEG, Updated TD tag a. API NO: 50-029-21509 BP EXPLORATION AK ( ) ~~ 1t~„_~ FMC MPB-22A Proposed Completion Md 3 trz' Otss c]uidc union KB Elev. = 59' Nabors 27E GL Elev. = 36' Nabors ?7E WELLHEAQ: 11' SM FMC w' 3 1!2' H' BPV pn~He 13 318", 48#, K-55 ~ __ BTRC 88__ KOP ~ 500' MAX Hole Angle: 61 DEG ~ 6375' 9 5?8", 36#, K-55 6349`_ BTRC 3 tl1" , 9.3~. 13TRS. L-80 TUBING DReFT ~D: 2.807" cApACITV o.~a7 eeLrFr 7" , 20#, L-&7, BTRC casing DRIFT lo: c. ~ e r cnPnclTY W+ +e~- .o2s~a t~f -o~ 2 3; 8" liner at 10 3d-~ --_ Casing RA Tag 10219` ___ Baker'PBR' Seal Assy 13.00• IDi 10360` Baker'HB' Packer 12.ae• l01 10375' Perf x--10385 for tailpipe cementing ---- Camco 2.750 'D' nipple 10413` WLEG 10419' - WLEG (ELMD) 17 ppg cement PERFORATION SUMMARY ;DIL Loy^ dated ;i i Zone Size SPF MD' TVD' - I L1K-t 5' 12 10420' - 10438' 8873' - 11889' SiK-?. 5' 12 10488' - 10518 ~ 8908' - 8922' Camco TRDP-IA-SSA SCSS!~ 1927 I Note: The Camca TROP-tA-SSA Has locked out of service 6!25!00. 1" x 3 1R" McMurray FMHO wl BK latch and tvd d9 10 2198` 2111' 30 9 3119' 2822' 47 8 4102' 3420' S7 7 5242' 4041' 59 6 6196' 4526` 6'I 5 7150` 5027' S5 4 7945` 5482' S4 3 8709' 5926' 55 2 9504' 6377' S7 I 10331' 6832` 58 Cement Ramp Window at 10,440' 2 3J8" Cemented Liner 12, 875' FIII taOgM wJ wlnllna on 2/27!08 at 10531• MO ' FISh:CalculaMd top of TCP 10526' PBTD (Hoot Cdlarl 10628' ~ - T 26 # Shoo 10729' DATE REV. BY CCNdMENTS MILNE POINT UNIT 1/11?05 Lee Hulme Convert drawing to Canvas WELL MPB-22 API NO: 50-029-21509 BP EXPLORATION (AK) e ~V~1fŒ lID~ ~~~~æ!Æ e A)'tASKA. OILAlWD GAS I CONSERVATION COMMISSION / Ted Stagg CT Drilling Engineer BP Exploration (Alaska) P.O. Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 , Re: MPB-22 Sundry Number: 305-349 ~ÇANNEC DEG 1 6 2005 Dear Mr. Stagg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ohn orman Chairman DATED this,Gday of November, 2005 Encl. ~ C1?J;¡'i..~j' . STATEOFALASKA . ALASKA ðr( AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 NOV (I ·'.I'E~%~... '" \ M', ;;n '1" ~ . ····1/·· (/ ,."u Þ :& 1. Type of Request: . Abandon o Alter Casing o Change Approved Program o Suspend o Repair Well o Pull Tubing o Operation Shutdown 0 Perforate 0 Other o Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well o Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: 1m Development D Exploratory D Stratigraphic D Service 5. ..perm. it To ~rill ~~.... er .... V" ' 6. API Number: 50- 029-21509-00- 99519-6612 59' 9. Well Name and Number: MPB-22 8. Property Designation: ADL 047438 10. Field 1 Pool(s): Milne Point Unit / Kuparuk River Sands 11. Total Depth MD (ft): Total Depth TVD (ft): 10729 7031 Len h Effective Depth MD (ft): Effective Depth TVD (ft): 10493 6908 Size MD TVD 88' 6349' 13-3/8" 9-5/8" 88' 6349' 88' 4600 1740 3520 750 2020 10729' 7" 10729' 7031 7240 5410 Perforation Depth MD (ft): 10426' - 10518' Packers and SSSV Type: Perforation Depth TVD (ft): 6873' - 6922' Baker 'HB' packer Camco TRDP-1 A SSA SCSSV Tubing Size: 3-1/2", 9.2# Tubing Grade: L-80 Packers and SSSV MD (ft): 10375' 1927' Tubing MD (ft): 10419' 12. Attachments: 1m Description Summary of Proposal D Detailed Operations Program 14. Estimated Date for Commencing Operations: D BOP Sketch 13. Well Class after proposed work: D Exploratory 1m Development D Service 16. Verbal Approval: Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ted Stag Title CT Drilling Engineer November 14, 2005 Date: 15. Well Status after proposed work: DOi! DGas D WAG D GINJ D Plugged DWINJ 1m Abandoned D WDSPL Contact Ted Stagg, 564-4694 Phone 564-4694 Commission Use Onl Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity ~BOP Test D Mechanical Integrity Test D Location Clearance Other: ~Sò 'CJ ~-::;l . ,'-~\? ~..~~ RBOMS 8Ft J 6 7005 COMMISSIONER APPROVED BY THE COMMISSION Date ORIGINAL e e Obp To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Ted Stagg CTD Engineer Date: Nov. 3, 2005 Re: Prep Milne Point B-22 for CTD sidetrack Sundry approval is requested to prepare MPB-22 for a sidetrack. MPB-22 is a Kuparuk C/B producer that is in direct communication with its injector. MPB-22A will be drilled to a more optimum location for injection support. ~~\ø...~~~\ ~(c..\A \0 't<M.~~~e. ~co~~, The sidetrack, MPB-22A, is scheduled to be drilled by Nordic 1 on or about Nov. 20, 2005. The plan calls for laying 17 ppg cement across the 7" liner to shut-off existing perfs and to prepare for a cement ramp window in the Kuparuk C interval. Additionally, the 3 Y2" tailpipe will be punched just below the production packer to allow 17 ppg cement to swap out around the tailpipe to provide mechanical stability. The stabilized tailpipe will then provide a back-up KOP in the event that troubles arise with the cement ramp window. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sid~ck:-\s-at@çhed for reference. " . '"_.. 2) Re-tag PBTD at 10,500 ft to confirm volume of cement required. 3) Punch tailpipe at 10,385-87 (2 ft, 4 SPF). ~s....;;,\C-'\.c.·\£"\,, Ci.~Cc.À ..x:.\.,j~ ~.( 12 4) Lay 17 ppg cement, minimum 7 bbls, to shut-off pens and provide for a cement ramp window. ( ~ ~~~~:~~""~~,~~kiS slated t?~~~~~~~v. 14. 2~~._________ ...__. ./ . '·-Rie: Work '-'''"'' ," ..-...- ~ 1) MIRV Nordic 1 and test BOPE. 2) Mill 2.80" window in Kuparuk C interval. ~ 3) Drill sidetrack into Kuparuk C and B target. 4) Log open hole with Memory Induction log. 1.....10·· A,. \fC:.,'... . J-\\t....... 5) Run solid liner and cement. .... \ '..L . '" v 6) Cleanout liner and perforate for production. 7) Freeze protect well and RDMO o:zJß;; Ted Stagg CTD Drilling Engineer 564-4694 CC: Well File Sondra Stewmanfferrie Hubble TREE: 31/8" - 5M FMC e wi 3 112" Otis Quick Union WELLHEAD: 11" 5M FMC w/3 112" 'H' BPV profile. 133/8",48#, K-55 BTRC I 88' 1- 95/8",36#, K-55 BTRC I 6349' 1 - KOP @ 500' MAX Hole Angle: 61 DEG @ 6375' 3 1/2" , 9.3#, BTRS, L-80 TUBING DRIFT 10: 2.867" CAPACITY: 0.0087 BBUFT 7" , 26#, L-80, BTRC Casing DRIFT 10: 6.151" CAPACITY~: .0264 bpf Casing RA Tag 110219' I PERFORATION SUMMARY (OIL Log dated II) Zone Size SPF MD' TVD' MK-1 5" 12 10426' - 10456' 6873' - 6889' MK-2 5" 12 10488' - 10518' 6906'" 6922' DATE 1/11/05 MPB-22 REV. BY COMMENTS Lee Hulme Convert drawing to Canvas KB Elev. = 59' Nabors 27E GL Elev. = 36' Nabors 27E Camco TROP-1 A-SSA SCSSV 11927' I Note: The Camco TROP-1A-SSA was locked out of service 6/25/00. 1 'x31/2 MM.rícyFM-ON B<låd1 # md tvd dg 10 2198' 2111' 30 9 3119' 2822' 47 8 4102' 3420' 57 7 5242' 4041' 59 6 6196' 4526' 61 5 7150' 5027' 55 4 7945' 5482' 54 3 8709' 5926' 55 2 9504' 6377' 57 1 10331' 6832' 58 Baker 'PBR' Seal Assy (3.00" 10) 110360' I Baker 'HB' Packer (2.89" ID) 110375' I Camco 2.750 'D' nipple 110413' I WLEG WLEG (ELMO) I 1 0419' I I' I Fill tagged wi wireline on 2/16/02 at 10493' MD Fish:Calculated top of TCP 10526' PBTD (Float Collar) 7" 26 # Shoe 110628' I 110729' I MILNE POINT UNIT WELL MPB-22 API NO: 50-029-21509 BP EXPLORATION (AK) TREE: :3 1/8" . 5M FMC wi 3 1fT 0Iís Quick Unioo KB Eiev. '" 59' Nabors 27E GL Elev. '" 36' Nabors 27E WELLHEAD: 11" 5M FMC wl3 1!Z' 'H' BPV profile. 13318",48#, K-55 BTRC # md tvd 10 2198' 2111' 9 9' 2822' 8 4102' 3420' 7 5242' 4041' 59 6 6196' 4526' 61 5 7150' 5027' 55 4 7945' 5482' 54 3 8709' 5926' 2 9504' 6377' 1 10331 ' 6832' Camco TRDP-1A-SSA SCSSV KGP@500' MAX Hole Angle: 61 DEG @ 6375' 9 5/8" 36#, K-55 :3 112" , 9,3#, BTRS, L-80 TUBING DRiFT ID: 2.867" CAPACITY: 0,00137 BBllFT 7" , 26#, L-80, ElTRC Casing DRIFT 10: 6.151" CAPACiTY~; ,0264 bpf Casing RA Tag Baker 'PBR' Seal Assy (3.0Q" ¡D) Baker 'HB' Packer (2,89" ¡D) WLEG WLEG (ELMD) Fill tagged w!wlrallne on 2116!02at 10493' MD Fi$!I:Calcuiatoo top of TCI> 11)526' PBID (Float Collar) 7" 26 # Shoe BP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (~C4, DATE: May 14, 2002 Chair ..~'~JBJECT: Mechanical Integrity Tests THRU: Tom Maunder J ¢~r¢-¢"'- '- BPX P.I. S u pe rvisol~¢~Ok' ' ~"' -""~>_..~..~...-~3;~)~, MPU B-25, F-41, J- 17, L-34 FROM: John Crisp Milne Point Field Petroleum Inspector Milne Point Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI B-25 I Typelnj. I N I T.V.D. I 7032 J Tubingl 2600 I 2600 ] 2600 ! 2600 l lntervall 4 P.T.D.I 1853020 ITypetestl P ITestpsiI 2000 ICasingI 650 I 20O0 I 19901 1960 I P/F I P Notes: WellI F-41 Type lnj. J N I T.V.D. I 4590 I Tubing I 2700 i 2800 ] 2800 I 2800 I lntervall 4 P.T.D.I 1970950 Typetest] P ITestpsiI 1500 I Casingl 590 I 1510 I 14~0 I 1460 I P/F I Pi Notes: We,,J J-17 I Typelnj. I S I T.V.D. 13432 J Tubing 11250 11250 11250 ] 1250 J lnterval] 4 P.T.D.I 1972080 [Type testI P ]Testpsi[ 1500 l Casing] 360 1154011500114901 P/F I __P Notes: WellI L-34 P.T.D.I 1970800 Notes: WellI P.T.D.I Notes: Typetesq P ITestpsil 1700 I Casingl I 1700 I 1670 I 1660 I P/F / --P IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Tesrs Details I traveled to BP's Milne Point Field to witness MITs. No Failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed:_4 Attachments: Number of Failures: 0 Total Time during tests: 8 hrs. cc: SCANNED JUN 4 2002 MIT report form 5/12/00 L.G. MIT BPX MPU 05-14-02jc.xls 5/16/02 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0'0 DATE: July 12, 2000 Commissioner' ! //o/öc/ THRU: Blair Wondzell, 41~ P. I. Supervisor . ef -r(c(J FROM: ~dt¡ Jeff Jones ..-" SUBJECT: Safety Valve Tests Petroleum'l sp c /r Milne Point Unit B & C Pads JulV 9. 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU 8 Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3)VK.>,- r~-h-':?i- 21 well houses were inspected, no failures. -.----1f' Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaslut Oil anù Gas Conscl~ation COlnnlission Safcty Valvc Systclu Tcst Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/B-Pad Separator psi: 1..PS 140 I-IPS NI A 7/9/00 N -....) N " ." . . .,. ." ,., .. . ..~. . ":"." ... .' '. -.... . ~ ... ',. ~ I"'" .... '. .... " - . i - t ... -" \ \';, - - - '::. $vr :.SSV ~ . ; . :.:" .'.' H'el!:' 'J);pe , '" '1\'ell Data ~ ' ~" I , '"," ...I"P.lt "1..-_.",,,1''''''1. ,.J . ',', " , . " lOS' I 'r r'r, I., ", '\. .. \Vcll Pcrmit Scpar Sct LIP Tcst Tcst Tcst NUlnbcr Numbcr PSI PSI Trip Code Codc Code Oil, WAG, GIN.J, GAS or CYCLE 8-02 1811420 B-03 1820560 140 100 115 P P OIL B-04A 1821000 140 100 95 P P OIL B-06 1850130 140 100 90 P P OIL 13-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 8-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 COlllpOllents: 18 Failures: Failure Rate: 5.5% 090 Day Wells: Remarl{s: Three well SV's recorded slow closing titnes; B-04A(3:20), B-03(3:03),B-06(3 :30). Son1e of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these iteIns corrected. n,-, ,^^ 1 (' 1 ,.f..... 1. 1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 February 14, 1995 David W. Johnston AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Dear Mr. Johnson' BP Exploration requests approval to temporarily convert Milne Point wells MPB-06 and MPB- 22 from shut-in Iow rate oil producers, to gas injectors. Given the ramp up in production from Milne Point over the next few months, and a lack of gas injection capacity until our C Pad IWAG program is completed, we anticipate having difficulty re-injecting the additional gas which the increase in production will bring on. The C Pad IWAG compressor is scheduled to begin injection in May, therefore, our injection deficit will be present between February and May 1. To be specific, within the next month, we anticipate having approximately 17 million standard cubic feet per day (MMSCFD) of produced gas, with 4.4 MMSCFD fuel gas requirements. This leaves us with 12-13 MMSCFD to re-inject. Given that the current E Pad IWAG can only inject 10 MMSCFD, we are left with a 2-3 MMSCFD shortfall in re-injection capacity for 2-3 months. Initially it was thought that our current injection capacity would be sufficient until the C Pad WAG program was in place. However, gas production from the producers offsetting our E-03 gas injector has been higher than originally anticipated. In addition, the C Pad WAG program has been delayed slightly from the originally planned early March startup. The combination of these factors has led us to a short term lack of gas injection capacity. Attached is a more detailed summary of the injection problem and proposed solution. If you have any questions regarding this matter, please call James Royal, our lead reservoir engineer, at 564-5133. · Mine Point Expl~-~tion RECEIVED MAR - ?-- 1~95'~ /~aska Oil & Gas Cons. Commission Anchoraoe /x~~~miss~on Anchora e -- STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMMIS. ,,I APPLICATION FOR SUNDRY APPROVALS 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 __ Variance ~ Perforate __ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 183'FSL, 1066'FWL, SEC 18, T13N, R11E, UM At top of productive interval 1037' FNL, 1744'FEL, SEC 25, T13N, RIOE, UM At effective depth At total depth 1270' FNL, 1909' FEL, SEC 25, T13N, RIOE, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 59' kb 7. Unit or Property name MILNE POINT UNIT 8. Well number MPU B-22 9. Permit number 85-302 10. APl number 50-029-21509 11. Field/Pool KUPARUK SANDS feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' S u rface 6313' Intermediate Production 10695' Liner Perforation depth: 10729 feet Plugs (measured) 7031 feet 10628 feet Junk (measured) 6969 feet Size Cemented 16' cemented to surface 9-5/8 2025 sacks 300 sacks measured 10426'-10456', 10488'-10518', true vertical 6873'-6889', 6906'-6922' Tubing (size, grade, and measured depth)3.5, L-80, 10419' Packers and SSSV (type and measured depth) T.R scssv@ 1919', ret pkr @ 10375' Measured 115' 6349' True vertical depth BKB 115' 4600' 10729' 7104 RECEIVED MAR - 2 1995 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program ~r BOP sketch __ 14. Estimated date for commencing operation February, March 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil y Gas__ Suspended~ Service 17. I hereby certify that the fore~e and correct to the best of my knowledge. Signed ~~ Title ~..~ ~-~f"~ E - ""' FO. co ,,ss,o, o..Y Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test l,""" Subsequent form required 10- Original Signed 6y David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 I Approval No.¢~.-~ O/~ ...... ~,.'ea Copy SUBMIT IN TRIPLICATE Attachment I Given the ramp up in production from Milne Point over the next few months, and a lack of gas injection capacity until our C Pad IWAG program is completed, we anticipate having difficulty re-injecting the additional gas which the increase in production will bring on. The C Pad IWAG compressor is scheduled to begin injection in May, therefore, our injection deficit will be present between February and May 1. To be specific, within the next month, we anticipate having approximately 17 million standard cubic feet per day (MMSCFD) of produced gas, with 4.4 MMSCFD fuel gas requirements. This leaves us with 12-13 MMSCFD to re-inject. Given that the current E Pad IWAG can only inject 10 MMSCFD, we are left with a 2-3 MMSCFD shortfall in re-injection capacity for 2-3 months. Initially it was thought that our current injection capacity would be sufficient until the C Pad WAG program was in place. However, gas production from the producers offsetting our E-03 gas injector has been higher than originally anticipated. In addition, the C Pad WAG program has been delayed slightly from the originally planned early March startup. The combination of these factors has led us to a short term lack of gas injection capacity. (~ne option to mitigate the problem is to shut-in our high GOR wells, to reduce 3 MMSCFD gas production, which would result in the loss of approximately 980 barrels per day (BOPD) oil production. There is already approximately 300 BOPD shut-in as a result of gas re- injection limitations. We are hoping to minimize the impact on production. Other than reducing gas by shutting in wells, our short term options for expanding gas re- injection are very limited. Since there are only two high pressure gas injection lines, only E and C Pad wells can be used for gas injection. Given that the C Pad IWAG program will not be in place as early as planned, E Pad is the only outlet for high pressure gas. Again, due to compressor limitations E Pad can only take 10 MMSCFD. Adding additional E Pad injectors will not add capacity unless there is a significant drop in injection pressure (i.e. injecting into a depleted reservoir block). Hence, a new E Pad IWAG injector, E-05, will not add overall gas injection capacity since it will inject into a reservoir with the same, or higher, static pressure. The other option, which we are proposing, is to use the existing gaslift injection lines to supply injection gas to wells which have highly depleted reservoir blocks. With this option, gaslift gas would be supplied at maximum rate and pressure, but the well's tubing would be shut-in, forcing the gaslift gas into the formation. Since the gaslift system can only supply gas at 1300 psi maximum, the wells chosen for injection would to need to meet several criteria allow injection. First, the wells chosen must be currently on gas lift. Second, the reservoir pressure would have to be below 1300 psi, and third, oil production from the wells would have to be sufficiently Iow so that we wouldn't miss the production. Finally, there should be no long term loss in reserves, or recovery, related to this shod term disposal option. We feel that only two wells meet these criteria, MPB-06 and MPB-22. Both wells are shut-in as Ii_g~~figures 1 and 2). Each well is in a severely depleted fault block with the latest static pressures measured at 1179 psi (10/94) and 811 psi (10/94) respectively (figure 3). Neither well appears to be receiving any type of injection support. However, based upon the need for support, a WAG injector is planned for September, 1995, which will provide injection support for both B-22 and B-06. Since we anticipate significant production increases after injection is established, the gaslift injection gas forced into these wells should be viewed as a temporary means of storing gas until the C Pad WAG is in place. RECEIVED After establishing C Pad gas injection, B-06 and B-22 would be brought back on line as producers, benefiting long term from the new injection support. This method of storing gas had been accidentally tested previously at Milne Point on well B-06 on December 7, 1992. B-06 was shut-in due to excessive flare volume. While "gas packing" the well for freeze protection, it was noticed that the flare decreased dramatically. The gaslift controller was set on maximum and the well continued to take gas at about 1.4 MMSCFD. During a 20 hour "pilot" gas injectability test injection rate climbed from 1.1 to 2.0 MMSCFD. No oil production decrease was noted after B-6 was brought back on line the next day. In conclusion, we request that B-6 and B-22 be temporarily converted to gas injection service. We anticipate 3 months of service with each well taking a maximum of 1 to 2 MMSCFD. Total gas storage for the two wells is anticipated to be 270 MMSCF. We anticipate producing this gas back again after a nearby injector is drilled, the B-6 and B-22 reservoirs are re- pressurized, and the C Pad IWAG is brought on line. RECEIVED ~ska Oil & Gas Oons. Commission Anchor~ - I ()()()(X) '~r i, r I ()()()(I ) .......... I( Oil, GOR, 'Wc,"MPR, cKIN & APi"GRXV I i()() ' , + .. I ! ~.~g4 ! · · (;i'i~ss l"luici · · 'VUalcr 14ntt m · ( )il (-,~ ....... (-) \Valcrcu! ,,',:, · '5 ~ x ('ill,kc , ' ._.ices (.:3 ....... (-) (;()R · · Manifold Pressure + .....+ Gas l,ift Rate 56%,808 578,0a8 ~8,' 5,080 RECEIVED ~ ~ .~ w~ & Gas Cons. Commission ~nchor~ , / ,/ MPC-iS tStg3 \ \, \ \ \ MPR~ 10 MP%18 ~,~ + 2/80 MPE-83 -4- MPB-~3 3801 ~2792 MPB-O? 1454 12/92 MPB-09 ,4- lO?g 1/9~i ,\ MP8-1 1 '1887 1/9'~ MPB-O~fl !359 2/80 MPB-08 MPB-08 x \ MPB-03 ,,4.- MPE-02 2189 ~, MPB-12 + [~ ~1889 , ," MPB-O1 "MP0-20 2526 4/9e '1 l MPB-I6 -f- 2602 MPB-1S -L 1 B-06 10000 -~:::::::.::::: Oil Rate (Calendar Day) (bbls) .............................................................................................................................................................................................. -i .............................................. i .................................... : .................................... : ................................... i .................................. ........................... (c y)( ) i ........................ ::::::::::::::::::::::::::::::::::::: -~ .............................. . ............... Water Rate alendar Da bbls ................. ~ .............................. :: ................................... :: ......................... --~ ................................................ : .................................. : .................................... : .................................. : ............................... : ................................. ' ~ c~s oi ira ti o ( sc f/bbl )s :: :: ~ ................................ , ....................................................... , ................................ ~ .................. ,..,.....* .................. ........... ............................... ........................................................................ : ..................................................................................................................................................... ~ ........................ ~ ................ ~ ......................................................................................... . ~ . ~ ~ · ~ · 1000 ................................................... ' ........................................................................................................... ' .............................. *"': .................................... ' ....................... ' ...... ~ ................. ~'~ ......................... ~ .................................. : .................................. · ................................... · ................................... · ................................. - ..................................................................... · .................. 7EEEZEE'EE..ELE,.. ..................... ~ ...... ~ * ,::,::~*~*~~* ::~ .......................... ~ .................... ,...., ....................... ~ ~ ~ .................................. ~: ................................. .......................... .................................................. .............. ::.::.:..:: :::::::::::::::::::::: :::: :::. ::::::: :::::: ::::::' : ........ ..::::.:. .:.:: ~ ........................ ~ ...................... : ~0 - '~ ':::~ .... ::::: ...... . .... " " . . ' ' '. ..... ~ ...... ::': ~ ...................... i ........ . ........... . ......................... . ........... . .............. . .............................. ~ ~ ....... ~ . ..... . ..... , ...... ~ ........... : ...... . .... · ................ . ~ ..................... ~ ............................. : ................................................ ......................................... . ....................... ~ ............... ......................... ~ .............. II Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 December 23, 1987 bls. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well histories" from Conoco's Milne Point Unit XVells No. C-17, C-19, B-20, B-21 and B-22. If .you require additional information concerning this ~veli history, please contact Mike Zotzky at 564-7623. Yours ~'er.x' truly, · E. D. XVilson Sr. Administrati~'e Coordinator C-17, C19, B-20, B-21, B-22 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point B No. 22 - CONFIDENTIAL (10,729'-Kuparuk River) AFE 10-61-1155 API No. 50-029-21509. Ak. Permit No. 85-302. Elevation: 59' KB. Location: 183' FSL, 1066' FWL, Sec. 18, T13N, RllE, U.M. 12-30-85: NU Tanko system. RU diverter & mix mud. PU & strap BHA. MU bit, inspect 8" Navidrill. PU 1st NMDC. Repair rig, skate, & Hydril. Test diverter. Orient MXVD & replace transmitter valve. Drlg from 88' to 500'. Repair rig - hydraulic pump. Drlg from 208' to 500'. Navi drlg from 500' to 614'. 12-31: Drlg from 615' to 1161'. Perform single shot survey; agrees with ~IWD. POOH to PD 9 1/2" Navi. LD 8" Navi, PU 9 1/2" Navi & change BHA. RIH to 1161'. Drig from 1161' to 1767'. 01-01-86: Drlg & Navi drlg from 1767' to 2405'. MWD erratic, drop single shot, single shot stuck in O sub, break slickline ~ tool head & POOH. POOH to return single shot & change electronics in MWD. RIH to 2405'. Drlg & Navidrill from 2405' to 3190'. 01-02: Drlg from 3190' to 3354', poor ROP while sliding. Max only 300 psi, suspect radial bearing in motor failed. Pump slug. POOH from 3354'. Change motors, PU 8" DTU MI, orient MWD. RIH to 3354'. Drlg from 3354' to 3635'. MWD giving erratic surveys. Double check surveys, run single shot. Drlg from 3604' to 3671'. Re-survey, poor results. T.F.O. feature also giving erratic data. POOH from 3671'. LD MWD, PU backup, inspect & orient. RIH to 3671'. Drlg from 3671' to 3850'. 01-03: Drlg & Navidrlg from 3850' to 5877'. Hole shows tendency to turn right ( 2°/100.) and build slightly. 01-04: Drlg from 5877' to 6377'. Circ & pump slug. POOH for short trip from 6377' to 3680'. RIH. No tight spots. Circ & cond. POOH slow. Continue POOH. LD MWD & Navidrill. RU & RIH w/G.O, triple combo, tools would not fall below 5190'. Work for 45 min, no success. POOH, LD G.O. RIH, tag bridge @ 5042'. Ream clean. Hit bridge ~ 6005'. Ream to bottom. 01-05: Ream to 6377'. Circ & cond. POOH from 6377'. RIH w/DIL, GR, CNL, FDC to 6090'. Logging tools would not fall below this depth. Sinker bars flex joint & stand off w/hole finder installed. RD G.O. & RIH to 6377'. No obstructions. Circ & cond. Pump slug. POOH from 6377'. LD BHA & clear floor. RU & begin running 160 jnts of 36 lb/f t, K-55 csg w/btrs thds. 01-06: Finish running 159 jnts of 36 lb/ft, K-55 csg ~v/btrs thds. Shoc ~ 6349'. F.C. ~ 6268'. 80 total centralizers used; full displacement returns. RU cmt head. Attempt to recip pipe. Hanger dragging on well head & diverter - land same. Circ 667 bbls of 9.6 ppg mud. Pump 40 bbl Zeogel preflush @ 11 ppg. Pump 5 bbl H20. Test lines to 3000 psi; drop bottom plug. Pump 10 bbl H20, pump 613 bbls of 12.3 ppg Permafrost, Type E w/5 lb/sk Gil- sonite. Pump 56 bbls of 15.8 ppg Class G w/3% NaCI & 1% CFR-2. Drop plug; pump 5 bbls H20. Pump 480 bbls 9.6 ppg mud. Bump plug w/1500 psi; 130 bbls cmt to surface - full returns. ND, wash bag, NU, torque speed to 14,000 ft/lbs. Test upper & lower pipe rams & blinds to 5000 psi. Test bag to 3000 psi. Test choke manifold, floor valves, upper & lower Kelly cock to 5000 psi. Test approved by B. Foster. PU BHA. _. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point B No. 22 - CONFIDENTIAL (10,729'-Kuparuk River) AFE 10-61-1155 API No. 50-029-21509. Ak. Permit No. 85-302. Elevation: 59' KB. Location: 183' FSL, 1066' FWL, Sec. 18, T13N, RllE, U.M. (cont'd.) 01-07: Install wear bushing, PU BHA, orient MWD. Repair rig, found frozen mud discharge line; thaw same. Slip & cut 105' of drlg line. RIH, tag F.C. @ 6262'. Drill plugs, cmt & shoe. Drlg from 6377' to 6385'. Perform E.M.W. test - 12.4 ppg. Repair rig, replace brake pad. Drlg & Navidrlg from 6385' to 7500'. Slides set to drop angle & turn left. 01-08: Drlg from 7500' to 7893', bit bailing. POOH from 7893'. LD RP13, PU R419. Inspect MWD & chg batter.x'. RIH to 7893'. Drlg & Navidrlg from 'z803' to 9083'. Setting in order to hit NW quarter of target. 01-09: Drlg from 9083' to 9243'. Navidrlg from 9243' to 9303' in order to hit 1/4 size target as directed by WlO's. Drlg from 9303' to 9719'. Navidrlg from 9810' to 9749' to hit 1/4 size target as directed by WIO's. Drlg from 9749' to 9939'. Navidrlg from 9939' to 10049' in order to hit 1/4 size target as directed by WIO's. Drlg from 10049' to 10263'. Mix slug & circ, POOH to chg bit & BHA. 01-10: POOH from 10262'. LD Navi & bit, PU new bit. RIH to 10262'. Drlg from 10262' to 10690'. Survey, circ& cond. Short trip from 10690' to 10249'. RIH. Circ & cond to logs. POOH, SLM from 10690' for log run. 01-11: Finished POOH & LD MWD. RU Gearhart. RIH to 6463', couldn't get any deeper. POO w/W.L., RD. PU tool pusher logging tools, test tools. RIH to 10019'. PU side entry sub. RIH w/W.L, latch up to logging tools. RIH, logging dwn from 10090' to 10690'. POOH, logging from 10690' to 10310'. RIH to 10690'. POOH, logging from 10690' to 10090'. Unlatch W.L. POOH w/W.L., RD side entr.v sub. Pump pill. POOH w/DP & logging tools. 01-12: PU BHA & RIH to 1600'. Cut and slip drlg line. RIH to 10690'. Tight 9235' to 10000'. Drld from 10690' to 10800'. Pump pill, short trip 10800' to 7900' to 10800'. circ & cond hole. POOH, LD BHA & DP. Change rams, RU csg crew. 01-13: RU to run csg. Ran 276 jnts 7", 26#, L-80 btrs csg w/no returns for last 140 jnts. RU cmtng head, circ 300 bbls mud w/no returns, pump 40 bbls 12 ppg spacer. Drop bottom plug, test lines to 3000#, pumped 300 sks Class G cmt w/l% CFR-2 & 0.3% Halad-24. Dropped top plug, displaced w/408 bbls 9.6 ppg brine. Bumped plug to 3000#, tested csg to 3000 psi for 30 min, checked floats, O.K. RD landing jnt, pull pack off, repair packoff. Rerun packoff, tested packoff to 5000#, O.K. RU loggers, orient Gyro, RIH w/Gyro, CCL & GR. 01-14: Finished running Gyro from surface to 10628', found PBTD 59' short. Rerun GR-CCL from surface to 10628'. 6 X up to 9500', CCL to surface found 275 jnts 7" instead of 276 jnts. Ran G-ring and junk basket from surface to 10628', RD Gearhart. RU to run 3 1/2" tbg, PU Vann guns & PKR. RIH w/327 jnts 3 1/2", 9.2#, L-80 EUE tbg. RU Gearhart, run correlation log. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point B No. 22 - CONFIDENTIAL (10,729'-Kuparuk River) AFE 10-61-1155 AP1 No. 50-029-21509. Ak. Permit No. 85-302. Elevation: 59' KB. Location: 183' FSL, 1066' FWL, Sec. 18, T13N, RILE, U.M. (cont'd.) 01-15: RD Gearhart. Space out & make up tbg hngr. Test control line to 5000# for 15 min. Land tbg, cir 15 bbls brine, close VCV. Set pkr by pressuring up to 2500#, shear out of PBR @ 46000# over tbg wt. Displace tbg w/100 bbls diesel. Test SSSV to 1000#, U-tube 5 bbls diesel to backside. Test backside to 1500#, back out lndg jnt, install 2-way check. ND BOP, NU tree. Test tree to 5000#. Pull 2-way check, install BPV. RELEASE RIG. Tom Painter Division Manager cono_co_) Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conser~,ation Commission 300i Porcupine Drive Anchorage, Alaska 99503 Dear w. Chatterton: Yemporary Shut-in of Production and injection Wells Wq*~-_~,~, the Milne Point Unit .~= you are aware, Conoco et al has filed an application with the Department of Natural Resources to temporarily discontinue production ¢.oerations at Milne Point. The attached sundry notices are intended :o se_--ye as notice of the pending temporary= ~ shut-in of all wells located within the Miine Point Unit. active and 5 inactive ~roduc*i~n~ we!ls at Milne Point ACTIVE: 5-3, ~-~=,'' ~-6,_ B-s~, B-10, x i~, 5-!3, x ';~, 5-'6,- ~-!, ~ o C-3 C-4 C-5A, C-7, C- - ~-_, , , ~, C- 3,~-~ ~, C i6 ~_~_~: -- .... ~ctzve zr~duction wells will be freeze prc. tected ~v displacing the ~cp 360~' cf the tubing with a 1:3 diesei:c~! mixture. %he annular =~'~ levels will be monitored =or 'eaking gas lift valves, if necessary the production casing annulus will be displaced with a d~esel:cil mixture to at least 3000'. Once the £hut-down operation is completed, pressure surveys will be run in all production wells. After the surveys are run BPVs will be installed and all SCSSVs and we'!head valves will be closed. %he inactive production wells have been adequately freeze protected with diesel across the permafrost. -_inere are currently ten active and six inactive water injection wells in :ine .,_..~,~ Point Unit. !-x _ -. , '~ - ~ ACTIVE: B-G, B-12, B-14, B-17, B-18 C-8, C-Ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPYs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. %hough only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wells have been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. 7ne wei!bore is filled with natural gas so that freezing is not a concern, tut :o prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used ~o~--rry ~he inhib~tcr.~ -..-' vou lna-.-e ar.v cuesti.r.s~ cn the _=ln,,rdo~._. prc-edure ~iease cent=-ct Don Girdler ~: =6~-7637 Yours very tru!v, ~/ ?ainte- ~/~vi~ ion Y_anager - STATE OF ALASKA ALASt OIL AND GAS CONSERVATION COMk SION 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 b~~-- 2. Name of Operator 5. Datum elevation(DF or KB) Conoco Inc. 59' KB feet 3. Address 6. Unit orProRerty name 320! C Street, Ste. 200, Anchorage, Alaska 99503 Milne Point Unit 4. Location of well at surface 183' ESL, 1066' FWL, Sec. 18, T13N, RilE, U.M. At top of productive interval 1037' FNL, 1744' FEL, Sec. 25, Ti3N, R10E, U.M. At effective depth At total d pth 1270~ FNL, 1909' FEL, Sec. 25, T13N, R10E, U.M. 7. Well number B-22 8. Permit number 85-302 9. APl number 50-- 029-21509 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 10729 feet 7031 feet Plugs (measured) Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor 80' 16" To Surface Surface 6313' 9 5/8" 2025 Sxs Intermediate Production 10695 ' 7" 300 Sxs Liner Perforation depth: measured 10426'-10456'; 10488'-10518' true vertical 6873'-6889'; 6906'-6922' Tubing (size. grade and measured depth) 3!~'', L-80, 10419'' Packers and SSSV (type and measured depth) Measured depth !i5' 6349' 10729' %.R. SCSSV @ 1919'; Ret. Pkr. @ 10375' ~ue Verticaldepth 115' 4600' 7104' 12.Attachments Description summary of proposal/b~ Detailed operations program BOP sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved 15. I heret~y-~,ertify.that the foregoing is true and correct to the best of my knowledge Signed ~k_~ ~', ~{'j,_ Title Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. - Plug integrity _-- BOP Test _- Location clearanceI '~ (-~ ~ Approved by -- ,,,,.~I£ ~. ,~!~ Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate John R. Kemp Division Manager Warren J, Hairford Division Operations Manager Gordon A. Hitching$ Division Projects Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 March 31, 1986 Harold Hedlund State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hedlund: Attached are the originals and one copy of each of the Sundry Notices required to remove the suspended status from currently active wells. Should you need additional information or have any questions, feel free to call Lynn Alexander at 694-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/vv RECEIVED Alacka O. c. ~,,., c.. .... u,.,i..lli$SJOI1 A~chorage STATE OF ALASKA ALASKA( AND GAS CONSERVATION CO. IlSSION SUNDRY NOTICES AND RE, PORTS ON DRILLING WELL-- CO,MPLETED WELL OTHER _ 2. Name of Operator 7. Permit ~;o. CONOCO ZNC. 85-302 3. Address ~. ~P~ ';umoer 3201 "C" Street, Ste. 200 /Anchorage, Alaska 99503 ~0- 02921509 4. Location of Well 185' FSi, 1073' ~¢L, Sec. 18, T13N, RilE, Umiat Meridian 5. Elevation ~n feet (~ndicate KB, DF, etc. I 59' KB Lease Designation and Serial No. ADL 47438 3. Unit or Lease ~ame Milne Point Unit 10. '.'~'eil "qumoer B-22 I 1. F-:eld and Poor Kuparuk River Field 12. Check Aopropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Tripiicate) ISubm~t ,n DuD,,cate} Perforate ~ Alter Casing ~-' Perforations .~ Aiter,nq Cas~nq Stimulate ~ .Abandon ._~ Stimulation _ Abandonment Repair Well ~ Change Plans ,~. Repairs Made -" Other Pull Tubing L_~ Other '~ Pulling Tubing __ (,",Jote. Report mult~ole completions on Form 10-407 ,.-vitn a submitted Form 10-407 for each completion I 13. Describe Prol:)osea or Completed Ooeratlons (Clearly state all pertinent c~etalls an(:] gt~e pertinent dates. ~nclud~n,q. est~m.atec] date of startl"tg an,,' proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on 2-28-86, and its suspended status should be removed. 14. I hereby certify that the foregoing ~s true and correct to the best of ,my knowledge. Title _ The space b/~t~ for Commission use Cono~tlons~oof A[:)pro'~al ~f any: 8¥ O'c:e¢ of .AoDroved by CO~.I~%llSSIO.%~ER 'ne C©mm,ss,on Form 10-403 Rev 7-1 GO .~uDm,t 'Intentions '~n Tr D~cate and "Suuse~luent Reports ' ~n r.],~Dl~cafe , Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 February 24, 1986 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Well Completion or Recompletion Report and Log Attached for your information and file are the original and one copy of each of the required reports referenced above. If you should have any questions please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/vv Att. STATE OF ALASKA - ALASK. .,IL AND GAS CONSERVATION C.~./IMISSION WELL COMPLETION OR RECOMPLETIr)N REPORT AND LOG · 1. Status of Well Classification of Service ~?JelJ OIL ~ GAS _-- SUSPENDED X~ ABANDONED ~ SERVICE _-- 2. Name of Operator 7. Permit Number Conoco Inc. 85-302 3. Address 8 APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 5o 029-21509 i 9. Unit or Lease Name Milne Point Unit 4. Location of well at surface 183' FSL, 1066' FWL, Sec. 18, T13N, RllE, U.M. At Top Producing Interval 1037' FNL, 1744'FEL, Sec. 25, T13N, R10E, U.M ,~_T_o.T, ¢2_~_h].t~::~z0atD~_NL' 1909' FEL, Sec. 25, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc./ ~i 6. Lease Designation and Serial No. 59' KB ~ ADL 47438 12. Date Spudded /13. Date T.D. Reached i 14. Date Comp., Susp. or Aband. 12-29-85 t 1-10-86 I 1-14-86 ' Total Depth (MD~-TVD) 18.Plug Back Depth (MD-TVD)'~ 19. Directional Survey 'TV p TV ) _= 10. Well Number B-22 [ 11. F.eld and Pool [ Kuparuk River Field 15. Water Depth, if offshore ~ 16. No. of Completions /A feet MSL I 20. Depth where SSSV set 21. Th,ckness of Permafrost 1919' feet MD 1800 I-+ 22. Type Electric or Other Logs Run DI L-FDC-CNL-GR-Cal, G.vro-GR-CCL 23. CASING SIZE 9-5/8" 11 CASING, LINER AND CEMENTING RECORD WT. PER FT. 36# 26# GRADE K-55 L-80 SETTING DEPTH MD TOP t BOTTOM 0 6349' 0 t10,729, 24. Perforations open to Production IMD-TVD of Top and Bottom and HOLE SIZE i CEMENTING RECORD AMOUNT PULLED 12z'" ,~1750 sx. Permafrost F. 275 sx. Class G 8½" 300 sks. Class G ;60 bbls. Arctic Pak+180 sx. Permafrost C 25. TUBING RECORD PACKER SET tIklD~ interval, size and number) MK-I: 10,426' - 10,456' MD 6873' - 6889' TVD MK-2: 10,488'- 10,518' MD 6906' - 6922' -TVD- All shots SPF, (7 phasing 2-5/8" SI~E ] DEPTH SET ,\ID) 3½ ,9.2#,L-Su 10,419 10,375 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL IMD) AMOUNT & KIND OF ,MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation fFIowing, gas lift, etc.) Date of Test Hours Tested PRO6UCTION FOR OIL-BBL GAS-MCF WATER-BBL ' CHOKE SIZE ! GAS OIL RATIO TEST PERIOD ~' I , ' Flow Tubing Casing Pressure !CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl ~corr~ Press. ! 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ~*,ate r. Submit core chips Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS KA MA NA OA NAME T/Kup. Interva' Middle Kuparuk MK-1 M.K-2 MEAS. DEPTH 4920' 5350.' 5770 6045' 10,117' 10,425 10,487' TRUE VERT. DEPTH 3871' 4097' 4314' 4452' 6710' 6873' 6905 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~ ~- ~ T,tl~Producti on En§r- DaTe 2/14/85 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 (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 we 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 In jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~,07 Eastman Whip q£ (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Jan 30, 1985 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two copi~,of the Gyro Multi-Shot survey run for Conoco Inc. on ~~,, Well No: 22. This is to be considered ~al letter of transmittal. The data herein, is to con. }%d strictly confidential. A copy of this letter ng sent to Conoco's represen- tatives, Mr M. Bradsha Mr S. Davies. Should you have any ions regarding this survey data, please refer all questi, s to CONOCO INC. TOM ~gNE[f ~ Dis~ Technical Coordinator cc: M. BRADSHAW S. DAVIES DirectionaJ Drillers/Sub-Surface Surveyors/Instrument & Tool Renta[s/Sa~es/Worldwicle Eastman Whipstock A PET~OLANE COMPANY REPORT of SUB-SURF,4CE DIREC TIONA L SURVEY CO:NOCO, !r. '. COMPANY . . LOCATION JOB NUMBER 45p--,nn~ TYPE OF SURVEY DATE _. SURVEY BY B RECEIVED F E B 0 5 1986 OFFICE Alaska Oil & Gas Cons, Commission ;"-: :~' ;~ o :- n,: e, Anchor.?e Eastman W ipsto .ck A PETRO~E CO~PA ¥ (907) 563-3650 P. ©. Box 4-1970 Anchorage. Alaska 99509-1970 Date: January 30, 1986 Conoco, Inc. 3201 C. Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad B, Well No: 22 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 13-JAN-86 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: 450-006 Attn: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multishot survey run on the above mentioned well. To date, the following distributions have been accomp- lished: A. 1 Copy delivered to drilling in-house distribution. B. 9 Copies noted for oil company representatives. C. 3 Copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the furture. Sinc,~re ly, TOM D i s ~/.i~t Technical TJ/pdh cc/file coordinator RECEIVED F E B 0 3 1986 Alaska 0il & Gas Cons. 6ommission Anchorage cc: Kathy McGill O.G. Kiel - P.E.S. Reservoir Sect ion Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco Wi] liam Van Allen - Alaska Oil & Gas Conservat ion Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. San Ramone Jim Laws - Champlin Petroleum Co. C.E. Seery, Jr. - Reading & Bates Petroleum Co. Neil Buttram - Cities Service Oil & Gas Corp. O~rectional Drillers/Sub-Surface Surveyors," Instrument &Tooi Rentals/Sales,Worldwide EASTMAN WHIPSTOCK, INC. RECARD AF SI_IRVEY F 0 R * OPERA'f-FIR : C:ONr-lE:O., I NC:. * * STRIJE:TURE : F'Af"~ B * * WELL : 22 SLF~T : 22 * * LOCATION : MIL. NE F'r-~IN]'., NORTH '.-Z;LOF'E-, ALA'.BI'::;A * ,_lOB NUMBER : /y"~o - 0.,:::2 f.... -~ * RIG : /(.~ ~oZ_~ 27- ~ * * DEC:LINATION : 30.50 E * * RKB TO :_=;EA : 59.0 * * PLANE OF VERTIC:AL SECTION * DIRECTION : S 24 0 W * EW DISTRIC"r : ANE:HORAGE, ALASI<A Eastman Whipstock CC~NnC:O, INC. PAD B i'I!LNE F'fllNT, NORTH :--;LOPE SLOT : 22 WELL : '-."--' .... F'BHL : :::; 24 0 W DATE F'RINTED : .3C~-._IAN-:::/:, Al IR REF NO : '-'"'='"='=- 7C0 -- -- m . ._--, It..I._1 ~ ._! ._1 · dOB NUMBER : F'AGE NO. MEA:E;URED [,RIFT [,RIFT C,ziI_IR'._--;E TRUE VERTICAL :---:I_IB::;EA R E C T A N G I_1 L A R C: L F, S U R E DOGLI DEPTH ANGLE D IRECI'Ir-IN LENGTH VERTICAL '.::EC:TIE~N TVD C 0 c~ R D I N A T E S D I'.BTANCE D IREC:TION '.:-;VRT D M D M D E P '¥ H D M 0.00 0 c) N 0 0 E 0. C) 0 101.0<) 0 C) N 0 0 E 101.c_')0 202.00 0 0 N 0 0 E 101.c)0 :F.:03.00 0 0 N 0 0 E 101.0o 404.00 0 15 S :36 c} W 101.00 0.00 0.00 -59.00 ¢]D.00 N 0.c) 0 E lOl.00 0.00 42.00 0.00 N 0.00 E 202. C)0 O. 00 14:--:. 00 O. 00 N 0.00 E :_--:0:::. o0 0.00 244.00 0.00 N c). o0 E 404.00 c). 1 ~'-D :34.5. o0 0.02 ::; 0.2:2 W O. o0 :::; '.-.-,'0 0 E 0.0, o.00 :E; '?(') 0 E 0.0 0.00 S '70 0 E 0.0, 0.00 :--; 70 0 E c).0 (-)_ 'T.' ]:, .-,":' :'--1/-, (') W (') '-" · .,-. 4_ 50A. O0 0 15 :E; /_-,6 (') W 102.00 6(]7.c~0 2 0 :-7 37 0 W 101.00 70:E:.00 5 0 ..E: :2::-.: 0 W 101.0(} ff:O'?.(])O ::3 0 S 29 0 W 101.00 5)].0.00 10 () '.---; :30 0 W 101.00 :::;o/._ _ _. C)CD. . ,:-)...-,o'-"-' 447· 00 0. 12 '.:; ('D_./_-5 W /:, 0 ./:,. ':? :3 2. 12 547.9 E i. :34:3 2. 1 :E: W 707.78 E:. 17 /:,48.7:--: /-.. :39 S .=J;. 72 W :_::0:3. 1 1 19. =_; 1 7.4 9. 1 1 1/-,. 1 ';/ 'm:; 1 1. 6 1 W 9 o 7. :3'7 :_:: 5. ':.]: 4.[34 :::. :B 7 "2 9.9 4 '.B 19. :':','.:.:.' W 0.66 5:.; 7':-.' 17 W o.0 '-' F,/-, '-' 5:~ 7 -" ..... :, 24 W 1. 8.5::: '."-'; 41 49 W 2.'P 9.5)'2 '.:; :35 3:-':--; W :'::. :5./:,7 S :32 5 5 W 1.9 lc-D12.00 1::3 4.5 rE; 2'P (') W 1C) 2.00 1007.4,7 1 1 ]. :'::. 0o 1 .'.5 :]i',0 '.:; :2'.0 () W 1 o 1.00 1 l c);q. :39 1214.CD0 16 :::0 :---; 31 C) W 101.0() 12(:)2.48 1. :_71.5 ("DC'D 1-7 :'::0 '.:-; .-.,o 0 W 101 c)c) 1 .';,,:.),7) · . . ,, ..... _,.. _ . . ~ ~ ,.~., .... · . .. 141/'-,_. c')('D1 :--:1· ='', !'_-'; :':::.5', ('}W 101 . c')_ c}_ 1. ._,... _ .':":" 5 1 :"'-~: 4:3.5-2I ::i: 29.72 W 7(). 40 :il; 4. 2. :;3:::: W '74.:-::'? S 5&,..q-i W 119 ,, 5/_-, '.E; 71. :.'-5:3 W 1 45.71 !5; ::5::?. 4'.?l.'J :[51:'-_-:.00 l:iii:4.5 S :7.:4 0 W 1(_-)2.00 1.45.)1.91 1619.0c) 19 4.5 S :34 0 W 101.00 1587.27 '~ 720. Oep 2.2 15 '.::; :2:4 0 W 101.00 1681.55 :321.(:}0 24 0 S :2::.5: c) W 1ol.00 1774.4:2: 192'5'.(i0 2.=, :30 '._:; :2:4 0 W 101.00 l:i:':.&,. 15 20 ].. 0'2 :143:2. '5:.' 1 :'-23 ::::', ':'"':' :l..~'~'5'::: ..... : ....... :27 26'.-7.46 ] 6, 22.5:5 :30 :':-:. 5 :~!t 715.43 :350.28 1_ ',.'-'.i:()7. 15 ]. 7 :;-2.70 S ]. ':)/:,. :35 W 2C) 0. :3 2:2:0.31 ::-'; 1 26 :-::. :3 :B :7_; .1. 6,'7. 10 W '29::3.64 :_:; 190.44 W :202. :::2 :.:.i; 3 1 :_-{:::'~: W (.'. '5: 2::_:.:b. C,'"':3 :.31 !5::.'-.': W O. '?' 2'75;!:. ';.2-7:~:;:':: 2 1 4 t.,J 2. Zl.: :':: ]. ]. . 'P 2 S :32 24 W 1.7: :Z:.54.. 20 :E: :3'2 ::::2IA 1.5. 2024.(-)0 26, :30 S :32 0 W 102.00 1'757.::3::.3 .,:_"~125.0('}__ 2o.. o_ S :.7.:1 0 W 101.00 2047.20 2226.00 :.5:1 0 S :7:0 (;} W 10l.(;}c} 21:.34.67 ';'-'327.00:3:':: 0 '._=; 31 0 W 101.00 2'220. :.5:2 242:5:. 0(3 :34 4.5 S :31 0 W 101.00 2:2:04. 17 :.5:94.44 1 ::J:'? 8. :3:3 441. cz}/_-, 19:3:5:. 2.':0 49. 1 .23 207 ._, = ./_-, 7 544-. 41 -';:.' 161 . ._,'--' '":'.... /: ()0.2:3 2245. 17 "::/5:::CD. 00 36 15 S :.5:2 0 W 102.00 23:E:7.21 26:_::1.00 ..'2_-::_:: 45 :S; :3:.5: (:} W 101.06 2467. :.5::_:: 27:32.('}0 40 4.5 ::: 32 0 W l('}l oo ...'-' =._,44.98 2:E::2:::3.00 42 :--:0 :_.:; 2'? 0 W lOl.00 2620.47 29:::4.0("). _ 45 15 ~.c' 30 0 W 101.00 2 /_- . ' -7 :-: :. _. 2:'7 CONTINUED ['_'iN NEXT F'AGE ... 659 00 '?':"?'::' 91 719.80 2408. q:: -- .--j ,.-., r-- 78:3./-,'7 ..' 4.:: ..... 9 ::: ,--, I" - ,: .... 0.:32 256,1.47 5> 19.99 2/_:,:'-': 4. '..-.'.7 5/:, 4.61 ::.-: /-,1/-, 4,'_-, '-' -- -- · ._-, ,.S 70.5:':3 '.;; 72:.5:. 7:_.5: !::: 7 :::: 9.65 ::; C:F. NOC:C~, !NC:. PAf'~ B I'I!LNE F'AINT, NORTH '.-:;LOF'E, AL~SK~ SLOT : 22 WELL : '.F"2 F'BHL : S; 24 0 W DATE F'RINTFD : :30-,JAN-86 I-Il_IR REF. NI-I. : '-'"': ""-~-- 71-:t-I -- .'-, I,.! ._1 ~ ._1 ._1 · _ ,_lOB NI_IMBER : PAGE NO. :." MEA:E;I_IRED I-JRIFT 13RIFT CCII_IRF;E TRUE VERTIL-:AL '.2;I_IBSEA R E F: T A N G I_l L A R F: L 0:3 I_l R E Dr-.3LE DEF'TH ANGLE DIREF:TII3N LENGTH VERTIF:AL :_:;EL-:TION TVD E: 0 n R Ii I N A T E rE; DI:E;TANF:E 13IRECTION SVRTt D M D M DEF"¥14 D M :30:'::6.0C> 4.5 45 S :30 0 W 102.00 27/=.4. '7'7 '?92. :=:5 '.-/'705.77 :_=:52.65 :--; .:, 1.2:7 AO 47 15 o 29 0 W 101 O0 282:4 '.~"--,' 1 ,F } ,/- , .'=; 27 2775 ':-"=,~ ':" 1/-,. 41 c. · . ._, . · · .a.... . _ _ · · ~ .. .. _ 32:2::_>, . O0 47:2:0 '.3 :E:O (3 W 101 · O0 2'.P02./=,:=:: 115 9.24 2:34:3.6:5: 'P::.:.: 1. (:>9 ,S ._'=:q'--:"-~ ._ ... 00. 48 1.=,._ c'_, :::0 O. W 1(>1 . (>('1. _' .:' c~ 7 cl.. . . 43 1212: .74 ._'.="-711.. . 4:2: lO45. .97 c..:, 440. O0 49 45 5; :::0 0 W 101. CpO :2:0:36.69 1'289.55 2'.7.'7'7./=.9 1111.9:=: ~':; :'::542. O0 52 30 '.E; 31 0 W 1(:>2. O('D :2:100.7(:> 1:3/=,:E:. '1:2: :2:(:141 · 70 11 :::0. :39 '.-=; :364:::.00 54 0 S :E:l 0 W 101.00 :31/=,1. 1::: 144:::.7.5 :::102. 1:3 1249. 76 :3:; :2:744.11) 0 54 30 '.E; :E:l ('> W 101.00 :E:220. 14 1.5:E:O. 11 :316,1· 14 1:'".:20.02: S :3',345.00 =l.=, 45 :--; :30 C> W 101.00 :3277.:39 16,12.44 :7:21:3.:=:'? 1:3'?1.41 S =:' c- :=:0 0 W 1 (:} 1. O0 :2::2',:34. :2:7 1/-,'-?-=, 71 :E:277] :2',7 1. '1 ~- 5: 0'=: ~" :3'.=..' 4/=,. (:1 c> ts 6 1 ....................... :, ._,-.'4·71 W lOC>l. 17 :--; .:,""1:3/-,_ W 0.45 5/_-,(i>. 79 W 1074. :=:8 ,._=; :E,, 1 2:-=: W 1.6,~. 5'77.:3:3 W 114:3.66 '.E; :31 20 W c).75 634. :---:4 W 122.2:.55 E; :31 15 W ('11.7z 6,72.'.T'~ W 1"::99.75 S :31 1 1 W 1.45 71:E:.25 W 1379. 15 S :2:1 9 W 2.:=:( 754.95: W 146,(->. 0'7 5; :31 :3 W 1.45 7':.~7. 14 W 154- 2. o 4 ::.'; 5:1 ::3 W (11..5 ( .9:=:'P. 20 W 1624. :ii::'F' S :31 /", W 1.4:'-' :3:31.. ('}6.W 17Q::i:. &, 1 S :!:: 1 2 W 0.5( 404:3. O0 5'7 (:} :2; :2:(:> 0 W 102. OC> :3:=:'F*O. 4:3 17:30.42._'::'>"::1 .._,._ 4::'_, 1._,.:,'-~'../-,':.-> ...... S 92:::./-,ffq W 1 vo'::., ..._ 7::::_ S :31. 0 W O. 7/. 4149 O0 .~/-. :::0 c. :::0 .--:A W 1(:}1 O0 3445 '-"- l:3/-,4:3.9 · .... . .-_ .... _ . _ _ _ 1/-, i C> /-,/-, ':'..., '?&,6 .20. _ W 1 :!:7:'-": ...":":'._, :':;:('1 W ('} · _ -- -- ,_, · · 4250.C>C) -r57 1.5 S ::':'2 0 W 101.00 :=:5C)1.05 i'P4::_::.'P'F~ :3442.05 16::::2.':=~7 S 101C>.0.9 W 1'P62.:}::::2 !:; :'::() 50 W J..4-~ -- -- v-.- r~'_. . · '-~ ~ ~:' . - · _ ._ ., · 4351. O0 5;F., 1._, .., :2:1 0 W 1(->1 O0 .- ...... &,. 4:3 2Q:--:2 0:=: ='-' ..................... 5:2: ........... : ..... 4 1:32'7 C}'2 :=: 10'i?/::,./=. 5 W "21 :'::<") I:::; : :: 0 W I. 1 l 44._,..' C)C) 55:2:(:) '.3:30 ("D W 101. Oep :361:3. (-)':) 211 .~] (')':.? ""55 . ('>':~ ":"::' 4554. 00. ,. , ::',/-, .... 15 F; 2'.-? 0 W 102. CDC).. :'::6,7(i>. :31 21':~':?.. . . 14 :=:/.,1 .... 1 . 31 I':~QO...., =;1_ c.._.,]. 1:=::3 .2:3 W 221 !':; .........'::":~ 5:; :=:(I .... ='~,=, W 1 . lC. ~ '==' 7 '~1, ":, ,11, "::, 41-___. ..... 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PAD B MILNE F'OINT, NORTH SLOF'E, ALASKA SLOT : 22 WELL : 22 F'BHL : '.E; 24 0 W DATE F'R!NTED : :':-:C)-,JAN-:::/_-, I_-I I_1R R E F, N I_-I, : :~; (') 5 4 r., .~,. 7 I'-: El ,_lOB NUMBER : 4/-~o-d}o G F'AGE NO. :z MEASI_IF~ED DRIFT DRIFT E:OI_IRSE TRUE VERTIE:AL :::;I_IBF;EA R I--- E: T A N G U L A R E: L O '._:; LI R E DOGLE DEF'TH ANGLE DIRECTION LENGTH VERTICAL SEF':TION TVD C: 13 O R D I N A T E S DISTANf-:E DIREC:TION '.E;VRTN D M D M DEF'TH D 'P108.00 55 15 S 21 0 W 102.0C) 6156.78 59'77.50 60'F.'7.7:E: 5470.4:--~ S 2458.64 W 5'?'77.54 S 24 12 W O.OC 'F'20S,. ¢)(') ~';.~ (] c. ~,~, ¢) W 1 (] 1 c)(') /_-,214 F;::: /-,¢):::c) 29 /;, 1 ?].~l .~:;'.--': 554.7 =]3 c. 4~,9 ...... = ..... 2 ,=,.. (]1 W /-,cD:::O :_::2 '.:"; 24 1(] W ¢) F:~ ...... · . · · ...., _ . - · . . · ':~'~, 1 C) C)C) ~7 1.5 S .-,c, (') W 101 AO /-,276) :::2 Y-. 1/-,4 c)':', y',':m? I 1 :=:") '=A'?'-- 27 '--' '-- '--' C ........ :" --' S -4 '-' - - .".-,-".) 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'7~ :~ 2'"L'"/~J--~' · '?(:) W '?~'~.1'~. F'-,'X.~ .... '.L--.j I ~, ::', (') (') ..... . c)c)_ .~]':)._ .. c)_ c-._, ~":":',_, 0 W 11:3. (-)0 76~6,-7_ . F, 9_. 7421 . 17 '7(")('):::.. _. ,qo._. ~ 67',36. :30 S :2,00'3, :37 W 7,i21 . 1':.-' '.!ii; '? :::", F;?_ _ W CLOSURE - DISTANCE : 7421.1~ DIREC:I'ION : S 2:':: 52 W REPORT UNITSFeet SI_IRVEY CAL. Fi:I_ILATICIN METI.40I] : Radius c,F ,:,Jr'vatur. e SLIRVEY RLIN INFORMATION GYRO MULTI-SHOT SURVEY, 0-10/_-,2.5, MD SURVEYOR: B ,JAHN, DATE RUN: I:3-,JAN-:3/:, CAMERA NO: 1572, GYRO NO: 621, ?0 DEG A/U NO: 1135 ,_lOB NO: 450-006 NOTE: 10687-108C)0 MD ARE F'RChJEE:TED ONLY C:ONOCO, INC. PAD B WELL: 22 SLOT:22 MILNE PT. · NORTH '.3LOF'E, ALASKA GMS· 0-1(~/:..26 P1D· '.-}URVEYOR: B ._IAHN, BATE RUN: 1:]-:-,_lAN-8/_-. FILE: 3 0 5:':: REVOX FROM SPUDD RECORD OF I NTERF'OLATE/~ '.--;I..IRVEY _.__Eastrnan ,~ Whipstock C:ONF,_-:F~, F'AI) ~ NELL:-.°2 KA KB KC: KD LA ~_B MA MB MC: NA NB Nr: ND NE NF' OA 9 5/8" LCU M k r- 19 T/ME-1 B / M K. - 1 T/MK-2 B/ME-2 PBTD TD '~ I N C. MARKER ....... C:ODE NAME CSr:~ Int. MEASLIRED DEPTH FEET 4 920.00 4988.00 5054.00 5174.00 5207.00 5244.00 5350.00 5493.00 5600.00 5770.00 5822.00 58/-,6.00 58 ? 0.0 (]D 5 9920.00 5996.00 /-,045.0o /-, 349.00 9661.00 9::: 1/-,. 00 10117.00 0425. On 0458.00 0487. CDC) C~526.00 0729.00 10800.00 TRUE VERT I F:AL DEF'TFI FEET .:,o70.93 :3 ? n 7.5:3 :3942.50 4<-)<_')5.25 4022.49 4 CD 41.82 4097.21 4172.00 4227· 19 4313. :5:0 4 :--: 40. :':: 9 43/-, 2. :E:8 4 :--.: 75.00 4:3 ? 0. 11 442:3. 10 4452.2:3 460(') ""= · .-' ._1 64/_-,:3.50 /-,550.27 6710. 34 /-,L::72.5:-:: /:,889.95 6?05.21 6925.7:2: 7031.02 7067.59 SI_IBSE A VERT I CAL DEPTH FEET 3 E: 1 I. '? :3 :2::348.53 3 E:83.5 n :394/-, '-'= 396:z:. 4'F',' :2:9:32. 4 O:IBE:. 21 411:3.00 41/-,8. 1'? 4254. ::::0 42 :::: 1. :::9 4 :?. 0 :'3.88 4:2:16.00 43:_--,' 1. 11 43/-,'?. 10 · '"', m~I '--m · 4.:,;.:, 22 4541 · '25 /-,4C)4.50 6491.27 /-,/.:,51. :_.:4 /-. 81:3.5 :.3 6:_::30.95 ,/_-,:::4/-,. 21 /-,:366.7:3 6972.02 7008.59 COMPI_I'¥AT I ON T I ME DATE 15: 39: 17 :30-,_mAN-:B/-. PAISE NO. R E C T A N G U L A R C tel 0 R D I N A T E tS; FEET 2170.84 S 1281.7/-, W ? ?.p..-., ..c, 9 '-' ,:),c: .... :, 120A. W 227:3.01 S 1330.6:3 W 2:366.84 ;; 1271.:2:6 W · ::,'::o2 oo c. 1._,':',_,':'~ ~' 1:3 W 2421.?:3 S 1:3'94.20 W 250/-,.20 '.--; 142/-,.'.:.)/-, W '26'.-'.'0 8<') ts; 14 :,,:,. 42 W 27<]7. ./-,2: c.._, 1497.7:3 IAI 2:346.51 ;; 1543·75 W .-.),c::::::: 6:3 ts; 1 F,'"i o ,/.,/_, W .,,.-- -- -- · ~_li _ - 2:'724. 2::3 S 1571.29 W 294 :'-':. :31 '.:; 1578.20 W 2'? 6:E:. 24 S 1 F,_ :36. ,:,.'-' =_, W 3030.47 .S; 1/-,0:E:. 26 W :3<')71.0::: :_--; 1621.44 W :3:::2 :--:. 7'P :_--; 17<:D2.76 W .... :, .-.~,:,. 47 '.5; 2627:32 W A¢)1© 77 '.--'; 2/-,72 :--:CD IAI -- o 1., · · - _ /-.-.,pl"z 49 ;; 276,1 ="-' -'~.-.- ! i · - - ~: .... 00. 1,_,':' ':'._, 2:3 5 ?. A_ .5 W .... · ~,o- . 2'.-.-~ /-,~2.=; 71 '._:; .... 71 W 654:3. 15 '.:_:; 2:3:31.51 W 6,.578. :31 S :2::: 9.5.32 W 67:32.56 '.E; 2974.81 W 6. 786.29 c-.., :'::_ ('). t'). 3 . :38 W C: L 0 S U R E [i I STANCE If I REC:T I ON FEET [I M '2521.00 $ 30:2:4 W 2578. 1:3 .2~' :3 ¢). 2:lB W 21-,3~ :::5 c- 20 21 W 27:3.5.4:2: '.:;:--:0 5 W 27/-,::: ':"-" '.=;:'::0 1 W 2794.60 S 2'? 56 W 28:::2.'77 S 29 :::9 W :::(:)<])4. 14 '.S 29 16 W · '3(}'-74 ':"'--~ S '"'" 57 W . . · .,.- .. .~. ,-, :':: 228. 17 S 2 :.--:: 2 :_--: W 22 :'_4,'-'. :32 ,z.._, ~.°,-,'-' ..':' 1 W 2:319.69 S 2:i:: 15 W :3:'::40. 17 '.E; 2::: 12: W :_--:2/-,5.79 ~--; 2:!'-: 8 W .) ? 24 :::0.7',:: '.Ei; 27 ':'- W 71 CD 1 4 <"D ':: ..... ' 5 ..... , ,-.z,4 W 7129.46 :--;2:3 4.5 W 7154. 12 '.E;2:3 4.5 W 7187.2:3 S 22 4.5 W 72,/-,<'1 4 ':/ '.3 .... "-' 5(] W .... · .. ~% C' _ 74.21. 1'? S 2:3 52-": W [-/-7 Eastn n /' Whipstock CONOCO. PAD B WELL, 22 EASTMAN WHIPSTOCK. [NC. SLOT'22 VERTICAL PROJECT!ON SCALE 1 !N. - 2000 FEET 0 506 1012 2000 4000 6000 2024 3036 4048 5060 6072 7084 8096 91 08 10120 8000 I' I I 2000 4000 6000 VERTICAL SECTION 'i 8000 CLOSURE 7421,19 S 23 52 21 W CONOCO, !NC. PAD B ~/ELL s 22 EASTI~ WHIPSTOCK, [NC. SLOTs22 HORIZONTAL PROJECTION SCALE 1 IN. - lO00 FEET DEPTH INDICATORs TVD :,58?' O1 4210 4713 276 FINAL STATIONs DEPTH 10800 MD. 7067.59 TVD SOUTH 6786.29 WEST 3003.38 CLOSURE 7421.19 S 23 52 21 W Suggested form to be inserted in each "Active" ~ell folder to check for timely compliance ~ith our regulations. · · Reports and Haterials to be received · .. Date ReqUired /~a~:e ieCeived Remarks Completion Report ~ ~o~, ,.~~ ~ ~ '~---, . ' ..... .d ~, Incltna~lon ~urvey ~rill Stem le, t Reports ~J~_ . - ,... , , .. ~ ~r~ ' ....... ~/~ / L.FJ.04 STATE OF ALASKA -- ALASKA L AND GAS CONSERVATION C~ MISSION 1. DRILLING WELL -- CO,%1PLETED',";ELL ~ 2. ,Name of Operator 7 Pe,m'.t "to. Conoco ]:nc. 85-302 3. Address S..:,Pi 7~um~er 3201 C Street, Suite 200, Anchorage, Alaska 99503 ~0-029-21509 OTHER _ 4. Location of Well 183' FSL, 1066' FWL, Sec. 18, T13N, RllE, U.M. ~. L~N,T Or LeaSe Name Milne Point Unit iO ',',ell Number B-22 · 1. F ,e!d amc POOl Kuparuk River Fietd 5. Elevation in feet (indicate KB, DF. etc.~ i ~. Lease Designation and Serial ,No. 59' KB ' APL 4743R 12. Check AoOrol:)r~ate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit ~n Triplicate) ~SuDm~t ~n Oup~cate) Perforate ~ Alter Casing ~--~ Perforations Z Aiter~ng Cas,nq S~,mulate ~' .,~ banclon "--~ St~mu'atlon -- ~ Abandonment Repair Well ~.~ Change Plans ~ Repairs ;Jade ~ Other __ Pull Tubing '--' Other ~ Pull~ng Tuo~ng __ (Note Report multiple comDlet~ons on Form 10-407 with a submitted Form 10-407 for each comm~et~on ) 13. Describe Proposed or ComDleteCI ©oeratlons (Clearly state ali pertinent details and g~e Pertinent dates, ~nclug~nr] estimated cate of start,nc] any proposed work, for Abandonment see 20 AAC 25.105-170). Approval is requested to allow Milne Point Unit B-22 Well to utilize the high-low pressure pilots and safety system lines in conjunction with the MPU B-4A Well. This is necessary to operate surface and subsurface safety valves while temporarily producing B-22 14. I hereby certify that the forec!Qjng ,s true and correct to the Des! of my knowle...age. Th;s;a;e~Z for Corem,ss,on use ~ono~t~O~~ APproval, ~i any. Amoroved by CO:..iMISSIOY';E~ tee Ccmm:ss~on Form 10-403 Rev. 7-1~0 Suom~! 'In!ChitOnS ,n Tr lDl~cate and "Subsequent i~elDorfs ',n El.~ol~ca!e PERMANENT SAFETY SYSTEM INSTALLATION TEMPORARY INSTALLATION NOT£: There are no additional valve, /'n the flow or injection Hne$. RECEIVED ,,..o ~,,o, FEB 1 9 ~86 . Surface Surface Safety Valve Safely Regulator v~,~, ' WELLHEAD SAFETY . .O PANEL to SSV' _ _ Hi -Lo Sensor Return Oil Pilot ~ , Hi - ko Sen~or] ~ Sub-surface Safety Valve ~s Iniec~ion kine ~ ~ ~ho~ to Inie Cellar 4500 psi Lin .., . ":IT INDUSTRIES. INC FIELD KUP~RUK Type of Logs Distributed Date Job Ran 1-4-R6 ~TT._ County NORTH SLOPE State A/~AgKA 8 . . . WFT..~'fif'_/C~c:;.p&W - - Blue Line Sepia Pre-Fold Rolled Logs mailed to: CRRR] PRINTS MAILED FROM DISTRIBUTED BY GFARHART T'I~I")TL~'T"PTFq !NC T'FLqqTF I.-fO'B__N~R_F¢_.K 2' & 5' LOGS ARE COMBINED INTO ONE PRESENTATION 2"/100' TOP DEPTH BOll'OM DEPTH TYPE C~ POROSITY 4900 6090 CDL/CNS RAW ~OOO 6090 DIL ~ 1 1 ~nan 5"/100' TYPE 5non 6000 Please dat~a//nd sign and return in the enclosed self-addressed envelope and return to Conoco. NO. OF LIS TAPES 13.~ E,~s! 51sl SL, Suite 702 P.O. Box 102436 An£horaoe. AK -09510 T~lpnhnn~ Ic~.o7J KF:9.9~qm STATE OF ALASKA ~,f'~/~. ALASKA ....,_ AND GAS CONSERVATION CC, ..MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS !1. Drilling well ~ Workover operation ~ i 7. Permit No. i2. Name of operator ! Conoco ]:nc. , 85-302 i3. Address 8. APl Number 3201 "C" Street, Anchorage, A]aska 99503 s0 029-21509 14. Location of Well ~ 9. Unit or Lease Name atsurface Milne Point Unit 185' FSL, 1073' FWL, Sec. 18, T13N, R11E, U.M ~O. WeI, No. · B-22 5. Elevation in feet tindicate KB, DF, etc.~ 59' KB 6. Lease Designation and Serial No. ADL 47438 For the Month of December ,19 85 11. Field and Pool Kuparuk River 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date' 12-30-85 Depth at end of month' 1767' MD 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None RECFIVED ,'. ...... i ~ '.--a-- :' tiS."uC~iiFrl"~$$iOfl hereby certify that the foregoing is true and correct to the best of my knowledge. F~?C~i0.3¢¢ · ,~ C~aTnEd R~O'otnsO~rvtah~:ofnO(~r~Lri:sqi~inrebdyf~hree¢,~hCc~le~dea:u~cOe~hi ,ngremgaorndi~:LnOle::~)ts~;tr~s;fd~/e;;;~ns, and must be f,led in dupl,cate ,,,,th the Alaska Fnrm 1N4N4 g~,hm~: ~n rt~nlm~;p MEMORAI UM Stat, of Alaska ALASKA OIL z~,~ GAS CO~SERVATION CO~'R'iISSi~ TO: C. V~/'-~' ~'ttDrton DATE: January 7, 1986 Chaii~anTM THRU: Lonnie C. Smith Commissioner FROM: Bobby D. Foster Petroleum Inspector FI LE NO.' TELEPHONE NO.' D.BDF. 3 SUBJECT: BOPE Test Conoco's - I. IPU B-22 Pemit No. 85-302 Milne Point Field Monday, .J. anuary 6, 1986: The BOPE test began at 2:30 A~q and was concluded at 6:00 AM. As the attached BOPE test report shows, there were no failures. In summary, I witnessed the BOPE test on Conoco's B-22. Attachment O&G 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date / - Operator ~ ~ ~.,~ R%presentative Location:'~ec Z ~- 'T/~Ri/: M ~ ~ Casing Drillin~ Contractor ~.A~Z~ Rig ~~Representat~ve Location, General. ~//~ Well Sign General Housekeeping ~/~Rig /?/~ Reserve Pit f3/~ - Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures dP ACCLrMULATOR SYSTEM Full Charge Pressure_~O psig Pressure After Closure_/~~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained:. / Controls: Master Remote~~Blinds switch cover Kelly and Floor Safety Valves Upper Kelly [ Test Pressure Lower Kelly / Test Pressure ~"~ O Ball Type / Test Pressure Inside BOP / Test Pressure Choke Manifold L z~ Test Pressure ~ No. Valves No. flanges Adjustable Chokes Hydrauically operated choke Test Time3 7Z- hrs. min~_~sec. min_~ e c. Repair or Replacement of failed equipment to be made within days and Inspector/ Commission offic~ notified. . Remarks: f~,,J~,~/ ~.~t"P/ ~/'~] ,/'~C p"fP'~l~/,-'~p~/°.4~ ~/,~3,'t f4/~/m/Pfj~ 7~-~~~ Distribution orig. - AO&GCC cc - Operator - Supervisor Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 February 12, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Monthly Report of Drilling and Workover Operations Attached for your information and file are the original and one copy of each of the required Monthly Reports of Drilling and Workover Operations conducted during January 1986. If you should have any questions, please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/kss Att RECEIV g FEB 1 1986 ~aska Oil & Gas b~,,~ ,, ....... ~slon Anchorage STATE OF ALASKA ALASKA ,...__ AND GAS CONSERVATION CO,..,,41SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well X~_ Workover operation ~ i2. Name of operator i Conoco Inc. 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 I 7. Permit No. 85-302 8. APl ,Number 5o 029-21509 i4. Location of Well at surface 185' FSL, 1073' FWL, Sec. 18, T13N, R11E, U.M. 5. Elevation in feet /indicate KB, DF, etc./ ! 6. Lease Designation and Serial No. 59' KB ADL 47438 9. Unit or Lease Name Milne Point Unit 10. Well No. B-22 11. Field and Pool Kuparuk River Fi eld For the Month of January .19 86 1 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date- 12-30-85 Depth at end of Month' Footage drilled' 9033' 10,800' 13. Casing or liner rgn and quantities of cement, results of pressure tests Ran 159 jts. of 36#/ft., K-55, 9-5/8 casinq w/BTRC. Float shoe 9 6349'. Pumped 613 bbls. of 12.3 ppq Permafrost Type E and 53 bbls .3f 15.3 .);]q Class G w/3% NaCi and 1% CFR2. Ran 276 jts. of.-°5#/ft. L-SO 7" casing w/BTRC. Pumped 300 sks Class G cement w/1¢~: CFR2 and .3% Hal ad 24. 14. Coring resume and brief description None 15. Logs run and depth where run Dual Inductionl Laterolog Compensated Neutron - Compensated Density Dual Induction- Laterolog Compensated Neutron - Compensated Density 6,090' to 111' 6,090' to 4,900' 10,690' to 10,020' 10,685' to 10,020' 1 6. DST data, perforating data, shows of H2S, m 10,488' - 10,5~' 10,426' - 10,456' (4 SPF) and (4 SPF) 1 7. I hereby certifv that the foregoing is true and correct to the best of my knowledge. ? / / / " c2 .. NOTE Re¢~/~/on this form is required for each calendar month, regardless of th~/statUs of operations, and must be lied in duplicate w,th the AlasKa Oil and Gas'-'Conservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10~.04 Submit in duplicate SIMP. ' LAGOON Anchorage SEC. 18 SEC. ( 0 _ CONOCO I~ILNE POINT UNIT IrXIETING DEVELOPMENT I, STATE PLANE CO ORDINATES ARE ZONE 4. 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.O. 1927. OFFSETS TO SECTION LILIES ARE COI~PUT£D BASED ON PPOTRACTED Vz~LUES OF THE SECTION CORNER FOSITIONS. 4. LOCATED WITHIN SECTION )~J 8, 19, Tt3 N,~IE,UiM,AK LOCATION IN SECTION STATE PLANE CO-ORDS. GEODETIC PDSITION , FROMS. Li%'dFRC:~W' UNE NDRTHINGS lASTINGS LATITUDE LONGITUDE DATE ICtlECP'(ED IrlELD B-21~l ~8' ~G~' G.oz4.1Zo. g,a ~?!.931.'9;' 70t2gL~Z7o 14~:z4'-~.~7 II.~.gS L.o. ., CERTIFICATE OF SURVEYOR : I WEREB¥ CERTIFY TH,~1 I ~M PROPERLY R[GI$1ERED AND LICENSEO lO PRACTICE LAND SURVEYING IH 1HE STATE OF ALAS~ AND 1HAT THI~ PLAT REPRESENTS A My ~UPERVISION. ~D 1HAT A~L D~MENS~ON$ · ND OTHER ~TAIL~ ARE CORRECT. I I B PAD WELL LOCATI DN CO NOCO l" · 4OO' I 3 OIr 3 CO~I-~ [ NT$ m D'MENSION THUS'I' FR~a ' N. LINE ~[CT. 19, ALL ~HE~S FROM S LINE December 20, 1985 Mr. Kent J. Stolz Production Engineer Conoco Inc. °~05 C Street, Suite ]00 Anchorage, Alaska 99503 Re: ~filne Point Unit No. B-22 Conoco Inc. Permit No. 85 30° Sur. Loc. 183'FSL, ]066'~.~.,, Sec. 18, TI3?1, RIlE, I~. _ 2029'FE!, Sec 25, T]3F R]0E, IN. Btmhole Loc. 14~'F~, , · , -- Dear '~' ~z. Sro!z: Enclosed is the approved application for permit to drill the above referenced well. %q~e permit to drill does not indemnify you from the probable need to obtain additional permits required b~ law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notifv this off~.ce 2& hours prior to commencing installation of the blowout 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. !.~here a diverter svstem ~s required, ~lease also notify this office 24 hours prior to commencin~ -~uioment installation so that the Commission may witness test~_n~ ~ - ~ ' I ' ~ _ · .for~ drzl~zn~ below the shoe of the conductor DiDe ~v~-~trvl~y.o~rs, .__l C. v. ~hatterton Chairma~ of Alaska 0]~1 and Gas Conservation Conmmission BY OR~p._ © =, 2VHE COi~iISS=O.~* ~ Enclosure cc: Departmen't of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o epcl. Mr. Dou~ L. Lowerv Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 December 6, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-22. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Kent Stolz at 564-764]. Very truly yours, Rogers J. Francis Manager - Engineering KJS/pab cc: B-22 Correspondence File RECEIVED - STATE OF ALASKA ALASKA O~- AND GAS CONSERVATION COM,v,,SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL I lb. Type of well EXPLORATORY -- REDRILL _ DEVELOPMENT OIL __ -- DEEPEN _ I DEVELOPMENT GAS SERVICE _ STRATIGRAPHIC _ . SINGLE ZONE MULTIPLE ZONE _ 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, AK. 99503 4. Location of well at surface 183' ESL, 1066' ~,%, Sec 18, TZ3N, RILE, U.M. Attop ofproposed producinginterval 1290' FNL, 1940' FEL, Sec 25, T13N, RiOE, U.M. At totaldepth 1488' FNL, 2029' FEL, Sec 25, TZ3N, RIOE, U.M. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. KB 59' to MSL I ADL 25518 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and or number 8086-15-54 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse miles 1940' at target feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10~801' F~)* (7059')TVD fept 1,920 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 54.7 (see 20AAC25.035 Icl 15. D~stance to nearest drilling or completed well B-17 4] feet 18. Approximate spud date 12/25/8~ -- 3230 psig@~oo]:___ Surface ~o~n psig~ __ft TD (TVD) __ ~vv 7059 ' Proposed Casing, Liner and Cementing Program SIZE Hole Casing l~'' ]3 3/8" 1 2~ , 9 5/8" CASING AND LINER Weight ~ Grade i Coupling Length 48 H-40 PET.p 80 ' 26 L-80 . BTR$ . 10769' SETTING DEPTH MD TOP TVD MD BOTTOMTVD ~5' ' 35' 115' 115' 33' i 33' 10802' 7059' QUANTITY OF CEMENT linclude stage data) +!00 cf Cm..t · 17~g ~k~ Pr~nFr~t "F" ±300 sks Class ±180 sks Perma 22. Describeproposed program: Conoco Znc. proposes d~±11~ng the subject ~ell as a producLng ~ell in the Kuparuk RLve~ ££eld. The mud syste~ ~ill be lo~ sollds, non-dispe~sed ~Lth a minlmu~ mud ~eight !n sur£ace hole o£ 9.0 ppg to a max~mu~ o£ 9.8 ppg. Hud ~e~ght at ~.D. ~11 be 10.4 ppg. A 20" 2000 ps~ d~erter ~11 be ~nstalled on the 13 3/8", 5000 ps~ RSRRA BO?g stack ~11 be used on the sur[ace cas~n~. ?~essuTe tests ~ill be performed as pe~ State regulations. ]]O?~s, choke man££old, gppe~ and Lo,er Ke1!¥ ~£11 be tested to 500 psig and 5000 ps,g, the Hyd~l to 350 psig and 3500 psLg. Caslng ~11 be pressure tested to 1500 psLg. Ha×~ do~,mhole pressure is based on initial ~eservo~r pressure. Na×Lmu~ sur£ace pressure ~s based on an unexpanded gas bubble, temperature taken Lnto account, the closest we llbore is B No. 17 ~hLcb is 41* ~es~ o[ B-22 at 1720~ ~%rD. The ~ell ~ill be £1o~ tested a£ter the r~g Ls released. A~ctic ?ack ~111 be placed in the 7' × 9 5/8' annulus a£ter dLspos~ng o£ test oil and excess d~111Lng [luids. 23. I hereby certify that the foregoing is true and correct to the bes~ of my knowledge SIGNED -' TITLE Fn~n~r The space belov~o~'dom~n' ' "' ,~slon use '~ DATE D~¢¢mher 6, !985 CONDITIONS OF APPROVAL Samples required Mud tog required Directional Survey required _YES _~-NO _YES ~NO ~YES _NO APl number 50 C L'/-~ ! 0~ , Permit numbe~ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS 1985 ,COMMISSIONER DATE December 20; by order of the Commission , Submit ~n triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. B-22 Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 I. CEMENTING PROGRAM Ae The 13 3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. B. The 9 5/8" surface casing will be cemented with ±1750 sacks of permafrost cement followed by ±275 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±300 sacks of Class "G" cement pumped around the casing shoe (estimated ±1250' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type "C" cement followed by ±60 barrels of Arctic Pack pumped do~m the 7" X 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand ~ ./~. sequences. Estimated base of permafrost at 62 1700 '. ~ 4500' - TD Predominantly shale until the Kuparuk Sands - r~o~.~%~ expected at +6700 subsea TVD. --~ ~ III. ~ORMATION EVALUATION A. Wireline logs for the 12~" hole (from TD to Permafrost) will include: Dual Induction log; Spherically Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. B. Wireline logs for the 8~" hole (from TD to ±1000' above the Kuparuk interval) will include: Dual Induction log; Spheri- cally Focused log; Litho Densitv log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. A low solids non-dispersed gel/water mud system will be used from 1000'-Surf. Csg. Pt. Low solids lightly dispersed mud system 6500'-T.D. Ve DIRECTION PROGRAM The B-22 well will be drilled to a proposed KOP of 500', then build angle in a south 24° west direction at a rate of 2.5°/100'. The closest that the proposed B-22 well will come to another wellbore is at 1720' TVD, where the proposed B-22 path will be &l' east of the existing B-17 well. Well B-2 was drilled as a straight hole, with a maximum angle at 4700' TD of 2.6°. A gyro survey was not run on B-2; however, assuming worst case that the well drifted towards the B-22 proposed path, the two wells would have a closest distance of 57' at 1500' TVD. B-22 will also run paral!e] to B-6 with a closest distance of 182' at 1420' TVD. Other wells which paths are crossed are B-3 and B-4A. Closest distances on these two wells are as follows: B-3 (155' at 1440' TVD) and B-LA (360' at surface). Extreme caution will be taken and an MWD tool will be run while drilling for surveying purposes. Final hole angle is estimated at 54.7°. The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300' . , a Sundry Notice will be submitted. SIMPSON N L~GO08 $C~t.£ iN ~,U/..S CONOCO SEC. ~alL NI: POINT UNIT JIll;TING DE ¥£LOPId t' NT S£C. ~ 8-2 B-4 B 5A B'6 1~.9 8 .10 HOTEl;: ALL GEODETIC POSiTiONS ARE BAS[D ON OffSETS TO SICT~O~ L~N(S ~R[ C0~PUT[D BAS[D O~ P~OT~CT(D V~LUES OF 1H[ S(CTlON C0~(~ ~0S~T~0NS. LOCATION I~1 SECTION tRO~' S LINdfR'C..d W LINE 212' ~ 978' 2' 910' 49'~' 1129' 165'.1' II 5t~' 68' III0' 115' 877' 581' 760 ' 697' 731' 348' 819' 232' 848' STATF PLAN[ CO'ORDS. GEODETIC ,.6.' 023,238 24 6, 023 , 702.33 LOCaTEO WITHIN SECTICt~ ~8 8, i9, TiSN,RIIE,UM ,AK. 571,955.56 POSITION NDRTH~NGS FASTINGS LATITUDE LOIJGIT UDE D£.T£ CHIC,ED f I[ Lr~ BOON 6,022,911.70 5]'2,056 98 70° 28'22.367"N. 149024' 41 176" W. 3.6, 82 L.K. 09'82 6,023,121.62 571,989 81 ?O°28'24.438"N. 149~24' 43.149" W. 6 2,85 J. BS. 21-85 6,025,077,00 572,209.10 70= 28'23 9]'8"N. 149°24'36 ?~4"W. 4 22,87 L.K. 09-82 6 ,022 ,960,76 572,239.11 70° 28'22.832"N. 149024. 55 865' W 4.22,82 L.K. 09-82 6 ,023,193.25 572, ~78.88 7~ 28'25.12 4"N. 14 9°24' 37 570" W. 6. 2,85 J.B.S. 21 6, 02],, 818 63 70028. 25.588 "N. 70° 28' 30.16 4" N 700 28' 31.311 "N. 834.16 57 I ,804. Z'~ 14902 4' 44.12 9" W. 149024' 47.561"~ 149°24' 48.408" W 6,023, 470.52 571 ,894.74 70° 28' 27878"N. 149°24'45.84~"W. " " 6,023 , 354 3q 57 I ,925.13 70° 28' 26.733"N 149°24' 4.4 98§"W .... Cl RIIFIC,-T[ Of SURV(YOR : I H(kIU~ CfNIII¥ 1HAl I A~a ~ROf'(RLy I B PAD AS. BUILT WELL LOCATI01~ CO NO¢O SCALE. : $1i([T ' I' · 400' I O~ :3 CO~[NTS , O,.a(~S~g~ It*uS'4' ~N~a N LiNt ~EC. ~B SEC. RJLOCiTION I, S~CTION 790' 920' 979' ~ 0I 1037' IOOg ' 933' 814' B-IZ 882' TO2' ~,73' RECEIVE N.A D. 1927 ~;I'AT [ PLANE: COOn'DS. 6 , 023,586.20i 571,864 47 6 ,OZ3,SB8.~6 J 6 ,023,656 07 I 6 ,023 ,772.39 ] 6 , 023 , 42425 6 , 023 , ~ 40.,4.4 6 ,023,0t3.B6J 6,0Z3, 935.01 j 6 , 024, 004 84 I ~. oz4- ogLo~l 57l, 9~2l 42 ~.T2 ~72,022.59 §72,1i3.60 $72,C93.38 572,013.88 57f,7'~J.46 571,961.74 67~ .743.,~1. OFFSETS TO 5[CTmON L I ~-'[ S ARE COMPUTED BASED 0h/ Pn0TR.~CTED VALUES Or THE SECTION COn~[ gl POS,TION5 4 LOC.".T~O .~lT~tN 5ECT~C~ ~ ~ ~9. T~ N. c) IIE,UM ,AK. GEODETIC POSITION Le-TITuOE ?c? 2e' 3f 98,"~. o ?0 29' 2g 688'N 7'0°29' 30 B3§"N. 70°28' 27.40Z'N. i C f. ,q / ~FIC A I' ~:' OF' SURV[ ¥01~ : A~C~S1E~O a~O L~C[~ISED I0 LA~O ~t~vJ~G I~ THE 5T~T[ O~ ALASKA A~O oTH[R [~ta~L~ ~R~ CO~N~CJ. 70°2B' ZS. 548 'ri 7'0o26, 23. 376"N. 70028. 33 I27'lN. J I --~'- zg'- 33.L.c~ N.I 140024' 4G. 70]' W 149~24'42.854'w. 149~24' 41.146"'# 149°24' 42 1001l' W. 149°24' 42.472"W. ! 149024, ~49.280"W_ 14~° 24'43. 723 ~4g; Z4'-SO. I~o DOTE 6.2,85 6.2, 8.5 I0 23,B5 JB $. JB.S. J. BS. B.T. 21 - 65 21 21-B§ 39 -B$ I0 23.B5 B.T 39- 65 I0 23,85 B.T. 39 - 85 L.O. L.O. 1012,8~ II 15 ,85 L L) 39-85 'B' PAD A SI BUILT WELL LOCATION S~l'eefeO fo," CONOCO I; LOCATION I'~ EECTION S lthPSO" LAG N SEC. HOTEgt I. STATE PLAflE CO OIqDINATEI; .~RE ZO~',~E 4. Z. ALL G£ODET~C POSITIO~;S AFl[ BASED C;~ N.A.D. 1927. OFFSETS TO SECTION LIt:ES ARE COHPUT£D 13ASED Cfi FPOT~£CT£D %'~LUES OF TJI£ SECTION £OR~;[ R POS ITIO t,'S. 4. LOCATED WITHIN c~ECT)ON ~8 Rlg, r 13 N, R lIE ,UM.,AK $ T,I,T E PLANE CO-O RDS. GEODETIC POSITION NDRTHIhtGS LASTINGS L:,TITUDE (,.oT_4.~Z~.F~a ~?l.9~l.eZ 70: ~$L ~7o G,. o ~-3. 7~o8.0Z. c07-Z.143.71 LONGITUDE . -- ~9:24'n4 14 ,g'- 24'- ~S D~TE ii. z,~. $5 II. £~.55 CHECKED FIELD BOOK CE RTIFICAT[ OF SURVEYOR I N(pEEIY CERTIFY TH/~T I .AM FROPERLY REGISlERED aND LICEtJSED ~O PRACTICE LOCATION SURVEy MaDE BY ~[ OR UNDER ENGJNEIr RS AND L~,ND ~JRV[YOI~ 'B' PAD ~~1' b T ~[LL LOCATION ~.Ur Il ~'l IJ for CONOCO 1" · 400'I 3 OF 3 COulJENT$ i D'I~ENSION THUS'~ FRC~'I N. LINE ~ECT. 19, ALL olrHER$ F~OIH 8 LI~,IE .... HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET CONOCO, INC. PAD B. WELL NO, 22 PROPOSED MI LNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. z 1000 1000 200O 3000 4000 5000 6O0O 7O0O 4000 3000 I WEST-EAST 2000 1000 I I S 24 DEG W 7592' (TO TARGET) TARGET TVD-6920 TMD=10560 DEP=7392 SOUTH 6753 WEST 3006 'TENTATIVE' TD 1000 I SURFACE LOCATION, 183' FSL. 1066' FWL SEC. 18, TI~N, RllE SURFACE TARGET LOCATION' 1290' FNL. 1940' FEL SEC- 25. T13N. RIOE CONOCO. INC. PAD 8. WELL NO: MILNE PT.. NORTH 22 PROPOSEu SLOPE, ALASKA - EASTMAN WHIPSTOCK. INC. 0 ..... SURFACE 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ 8000 _KOP .... TVD=500 TMD=500 DEP=O .......... $ !o 20 25 ~0 so EOB BUILD 2.$ DEQ ..... PER 100 FT TVD=2370 TMD=2688 DEP=967 _ 5/8'-CSG PT TYD=4611 THD=6565 DEP=4131 /"% I 1000 AVERAGE ANGLE . 54_DEG__.42 MIN TARGET TVD=6920 TMD=10560 DEP=7392 'TENTATIVE'-TD TVD=7059 TMD=10801 I I i I 2000 3000 4000 5000 -- - VERTICAL SECTION , ,.L,~ DEP=7589 I I I 6000 7000 8000 2OO lO0 0 100 2OO ~00 400 ~00 '00 O0 ,uU ~00 I ! 2OO I lO0 I 0 lO0 i 2397 400 2881 1 389 400 / / / / / / 1 284 ! I 400 liil5 2363 / / / / / / / / /"2121 / / 3OO / / / / 1892 6 400 / 1 731 / / 2OO 100 129 3769 94 3391 REvEIVE~, 3857 2OO I I _ 2OO lO0 100 200 300 400 500 6OO 7OO CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 13 318° CONDUCTOR (~) FILL-UP LINE · ~ FLOW LINE SPOOL TBG SPOOL 2~ APl 5000~ SIDE OUTLETS U/ ~ r~ ANNULAR PREVENTER APl §OO0~f- RAM BOP 13 5/8 " APl 5000~* RAM BOP 13 5/8 " APl §O00~ --3" - APl 5000 SIDE OUTLETS 135/8" APl 5000 '~ RAM BOP 135/8" APl §OOO:~ x II" II" APl 5000~' 3' APl §0OO~ SIDE OUTLETS CSG ( SPOOL WELD-ON CONNECT 3/l" CAS I NG 13 (2) (3) (4) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. RECEiVErJ (5) Choke and kill manifolds shown separately to meet APl 5000 d A?[ R? 53 class 5M requirements. CONOCO, INC. MILNE POINT UNIT DIVERTER ...STACK FOR 13 318'" CONDUCTOR FILL UP L::iE % MCR VALVE L.~.__ VALVE LINE _ 5" REL;E? VALVE 20" ~Pt 2000 p'~ A,NNUL,t,R 2. qE','ENTE~ 21VERTER ~UIC, KC3,",INE.ST SAVER SUg ASSEMBLY HEAD =eljer lines from the drilling s?ool '.'i'~ be re . ., .. uted for do'.m,~ind diversion e H,;draulic control system will be in accordance '~ith AP1 specifications and =OGoC regulations. . Both HCR valves will open ~hen the preventer closes, then either one may be closed. ,~." OT E: Depending on rig contracted, the t~o 6" relief lines may be replaced by a single 10" line with a do~znstream tee. '.~3TE · ~-~ULIC CZ. NTI:~3L S,TSTEU FO~ BC,.P ST, ACK i~-"N:FCLD TO iNSLL,;~.5 ~ STATi~,N CC.~,TROL LS-~-'T.?D ~E~OTEL? WiTH .~C,O0 PSi ~.C~',IULATCR ~T~L TO BE ~ATED CN RIG FLCOR. ~u s~s. ~ K:LL M~NIF~D S~ZE-RAT;NG ~'- 5000 4 CH2KE ~NIFO~ SIZE - RATING ~"- REV, OTE P~ESS'J~E 3-,~3£ ~E';S~ ./ ~r~OTE n~r~ D~ILLING SPCOL HYDRAULIC ¢_.,C;IT RSLLED '~ R~-M. OTE C, PLRATED ,,'AR~BLE ~ r i] C~CKE ,~.C~i J CCNT"ROL ~ I I RECEIVED ELr~D LINE TO ATMOSPHERIC TO PiT MUD/GAS SEPARATCR -, ~. CHOKE MAN:FCLD Oil & Ga..-. Cuns. tJOiii~i!~u,. TO SH~IF SH~'KER CHOKE 8 KILL MANIFOLDS FOR ClS/$" & 7" OD CASING BOP STACK BOP I,IANIFOLD LAYOUT - CONOCO, INC. ; ITEM APPROVE _ DATE , ,. ® 3. 4. 5. 6. 7. (3) Admtn / "'"¢ ' l "1,. ~'~~''. 9. (~gzzt~r~;,. 12) 10. (10 and 12) 12. (4) Casg/~.~¢~ ]~_-/~-~ (13 thru 21) (22 thru 26) (6) Add: 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. YES NO Is the permit fee attached .......................................... , Is well to be ,located in a defined pool ............................ . Is well located proper distance from property line ................. Is well located proper distance from other wells ................... Is sufficient undedicated acreage available in this pool ........... Is well to be deviated and is wellbore plat included ............... Is operator the only affected party ................................ Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... REMARKS Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings . Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter.system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~,~ Does BOPE have sufficient pressure rating - Test Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: ! o ~z H o t'rl m Geology: Ensineering: HWK ~ LCS BEW ~ WVA~_ lqTlq/~ HJH rev: 03/13/85 6.011 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. ' i : GEARHART GEARHART 15'F.4RHART GEARHART GEARHART GEARHART GEARHART GEARHART ~'F_AR/4ART GEARHART GEARHART GEARHART 1~11~4~i/~ ~'F_AR. HART 3 $ GEARHART GEARHART