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185-120
Project Well History File Covel~l~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _J ~ _~- J '~ Well History File Identifier Organizing (done) RESCAN I~Two-Sided Color items: [] Grayscale items: [] Poor Quality Originals: Other: NOTES: L.) LJ DIGITAL DATA [] Diskettes, No. Other, No/Type BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other /si Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation L.~ X 30 = /~'~ + '-7 = TOTAL PAGES BY: Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: / A ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ~, NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) III IIIIIIIIIII II III ReScanned (individual page [special attention] scanning completed) RESCANNEDBY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd - , Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-in ~ Current Mechanical Condition of Well2 Possibilities3 Comments iMPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle gas. Possible production after gas expansion project. MPB.08 May-94 E No known problems 3 Futher use as an injector not recluired MPB-13 Jan-86 B GL well that was shut in due to high 3 Weilhouse and flowlines removed water cut. Possible channel into-water zone. MPB-17 Jan-96 E i No mechanical problems. Quick 3 Wellhouse and flowlines removed communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 Weilhouse and flowlines removed Possible frac into water zone MPC-11 Feb-96 E No known problems 3 F~rther use as an injector not required while associated producer shut-in . ~~ Jan-O0 E Fish in h°le, drilling problems 3 Suspended due to drilling problems. 12a MPC-16 Aug-93 A High GOR well, parrs and completion 3 Weilhouse and flowilnes removed abandoned MPC-17 May-O0 D Leak in 9 5/8" casing to surface I Evaluating possible plans for solution ~o problem. MPC-20 Apr-O0 B High water cut well, no mechanical I Evaluating possible plans for solution to problems problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible plans for solution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block problem. Possible alternative uses for wellbore MPD-02/ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well MPE-02 Jun-05 C No known problems 2 Recomplete to upper Kup zone MPE-19 Aug-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities MPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities MPL-21 0ct-98 E High'pressure-block - 5000 psi, no I Possible use-for injectionwhen-pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP, noother_mechanical I Evaluating possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or for it. recompletions *Note - Wells were shut in 100% during 2001 Milne Pt Shut In Wells 2001 .xls __u~.,:_,;~ ~ LOC~.TION CLE~_~_~CE REPORT Review ~he well fils, aud' c=mman: on pluqcjing, well hea~ scacus, ~ !ocaci:n a!e~ce -.p~~ loc. c!e~. cc~e. Loca=ion CLearance: · o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well []Oil [] Gas [] Suspended []Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 185-120 399-149 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21373 4. Location of well at surface ,-----~-------'r 9. Unit or Lease Name 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM ~ ~~..,~ Milne Point Unit At top of productive interval !i~!' 10. Well Number 3208' SNL, 2757' WEL, SEC. 03, T13N, R10E, UM i'l~lli~.~ ~- MPC-12 At total depth ~r~'"~ 1 11. Field and Pool 2739' SNL, 2857' WEL, SEC. 03, T13N, R10E, UM~t Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 52'I ADL 047433 12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or Aband. 115. Water depth, if offshore J 16. No. of Completions 6/14/85 6/26/85 8/12/99 N/A MSL I Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10975 7578 FTI 10801 7492 FTI [] Yes [] No! N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run LDT, CNL, DIL, GR, SP, Gyro 23. CASING~ LINER AND CEMENTING RECORD CASING ' SE'ri'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 48# H-40 Surface 108' 9-5/8" 36# K-55 Surface 6070' 12-1/4" 1625 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 Surface 10956' 8-1/2" 300 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2#, L-80 10173'- 10510' 10242' & 10476' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9551' P&A with 18.4 Bbls Class 'G', 3500 psi 7310' Set EZ Drill Cement Retainer Plug 7076' K/O Plug with 22 Bbls Class 'G' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production i N/A Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs'OIL RATIO TEST PERIOD I Flow Tubing ;Casing Pressure CALCULATE OIL-BBL iGAs-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL O;5 !999 Aiasl~a 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. KA 4720' 3793' MA 5146' 4080' NA 5522' 4332' OA 5753' 4487' Middle Kuparuk 10415' 7289' Laminated Zone 10439' 7302' Lower Kuparuk 10710' 7446' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble '"'~/~. ~ Title Technical Ass is tant III Date I~. '~)~. '?? MPC-12 185-120 399-149 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23; Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 MILNE POINT, ALASKA TO: Bill Hill FROM: Mark O'Malley WELL# IMPC-12 Main Category: I Drlg / Prep Sub Category: IPump Operation Date: 18 / 12 / 99 18/19/99 AFE# 337157 9335-070-780 Drlg / prep / pump DS: $ 8000 Cement - $1000 Diesel Used - 18 Bbls x 42 - $ 756 Objective: Bull head perforations with cement for upcoming side track Operation: DS arrive location RU held pre-job safety meeting. Start down tubing with 10 Bbls of fresh water establish a injection rate 2550 psi @ 2.7 bpm. switch to cement 15.7 emw class G, start down tbg. at 2.1 bpm. 2100 psi. pumped 18.4 Bbls, back to water for 10 Bbls @ 2.7 bpm. 3000 psi. put 18 Bbls of frz. Protection diesel @ 2.7 pressure increased 3100 psi., back to water continue pumping at 2.7 bpm. @ 3100 psi. as cement was at the tail pipe pressure started to increase slowly 3,500 psi. with less then 5 Bbls remaining in the fresh water spacer dropped rate to 1.5 bpm. pressure dropped off but continued to climb. Stopped pumping, est. top of the cement is 10,245 psi. pressure dropped slowly to 2900 psi. the balance pressure for the well with the hydrostatic of the fluid i~ approx. 1500 psi. over balance. Well balanced out at 2100 psi. Clean up unit. RD DS Conclusion: Cement est. top @ 10,245' md. will tag with slickline in the next few days. & pressure test. SIWHP:2100 IA: 200 OA: 0 Diesel Used - 18 Bbls x 42 = $ 756 BY:BPX-I~OC ; 9-10-99 ;IO:OOAI~ ; MILNE POINT, ALASKA TO: J. Bixby FROM: M. O'Mall~ MPc-12 I' ~Pump, I Slil:kline Pressure t~st / Tag cement 8~16-99 WELL# Main Category: Sub Category: Operation Date: BP×-MILNE POINT~ ~.~,.~_. 907 564 5193;# 2/ ~ 337157 [8 / 16/99 9335-070-780 Drlglprep/W/L HES = 280 x5 = $1400 Tri-plex = $100 Pressure Test / Obj~)ctive: Pressure test cement pl~g for upcoming sidetrack. Operation: / RU to tubing wi~h tri-ple~ Starting pressure was 1{~50 psi. start pumping, pressure immediately increased continue to pressure up tubing to 2500 psi. stop pumping. Approx..5 Bbl of diesel. Blocked In well and ruer tubing back to 1300 psi. Shut in well. Conclusion: Tested cement plug fo~ witnessing of the tag ~ Slickline Objective: TAG TOP OF CEMENT Operation: MIRU.-I-GSM 1.875" T,~ RIH W/QC, 2' 1.875" S' RKB) WORKED DOWN DOWN IN CEMENT. PC RDMO. itor for 30 min. pressure dropped 60 pounds, good test bled 30 min, tested good. AOGCC representative waived the the pressure test. ;~LUG , RS,QC,5',3',OJ,KJ,SSS rEM, X- OVER, 2,62' GAUGE RING TO 9510'. WLM (9545' TO 9516' WLM (9551' RKB) APPEAR TO BE SETrlNG ~OH Conclusion: Tagged top of cement i~lug @ 9551' RKB, while filling up our lubricatar we were able to drop the pressure to 100 psi. that pressure stayed constant during the tag, / SIWHP--800# IA" 120~ OA= Off Diesel Used I NONE Methanol Used I NONE MILNE POINT, ALASKA TO: John Hendrix FROM: Matthew Linder WELL# IC-12 Main Category: IE-Line Sub Category: IJet cut tubin~l Operation Date: 18/22/99 I Objective: SWS will jet cut the tubing around 9400' for an upcoming sidetrack. Operation: Rig up SWS. RIH with 3.5" jet cutter to 9450'. Log six collars. Drop back. Log jet cutter into position. CCL at 9383' and cutter is at 9400'. Pressure up on tubing to 1300 psi. to counter balance the 10.2 brine on the backside. Shot cutter. Saw 200 psi pressure change from tubing into annulus. Log off. POOH. Rig down SWS. Conclusion: Jet cut tubing at 9400'. Good indication that tubing cut do to pressure changes from tubing to the annulus. Rig down SWS SIWHP: 1300 IA:150 OA: 200 Note: All measurements are slickline depths unless otherwise noted. Diesel Used L J Methanol Used [ J Facility Date/Time 14 Sep 99 15 Sep 99 16 Sep 99 M Pt C Pad Progress Report Well MPC- 12A Page Rig Nabors 4ES Date 1 01 December 99 12:00-18:00 12:00-18:00 18:00 18:00-01:00 18:00-01:00 01:00 01:00-03:30 01:00-03:30 03:30 03:30-05:00 03:30-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-12:00 08:30-12:00 12:00 12:00-14:30 12:00-14:30 14:30 14:30-15:30 14:30-15:30 15:30 15:30-05:00 15:30-18:00 18:00 18:00-20:30 20:30 20:30-22:00 22:00 22:00-05:00 05:00 05:00-06:00 Duration 6hr 6hr 7hr 7hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr lhr lhr 2-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr lhr lhr 13-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 7hr lhr Activity Derrick management Rigged down Drillfloor / Derrick Prep rig for move. Equipment work completed Move rig Rig moved 100.00 % move & spot rig on C-12 & Berm & trim rig. raise derrick & slip sand line & scope derrick. At well location - Slot Wellhead work Removed Hanger plug Rig lubricator & remove bpv. & read Pressure. tbg. psi. = 1200 psi. annulus = 500 psi. rig lines in cellar & take on water & spot tiger tank & load pipe shed with drill pipe. Equipment work completed Flow well Monitor wellbore pressures let well U-tube to tiger tank until psi. to O & set twc. bleed back a total of 8-bbl. Observed well static Wellhead work Removed Tubing head spool Nipple down tree. Stopped: To hold safety meeting crew change. Wellhead work (cont...) Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi test waived by aogc Larry Wade. Wellhead work Retrieved Hanger plug Equipment work completed Pull Single completion, 3-1/2in O.D. Removed Tubing hanger rig floor & bolds & work tbg. to get hanger to floor & lay dn hanger work tbg. to 135 k pu wt = 87 k Equipment work completed Laid down 2100.0 ft of Tubing 67 joints laid out Circulated at 7310.0 ft displace well bore fluids with fresh water. Hole displaced with Water - 125.00 % displaced Laid down 10173.0 ft of Tubing recovered all tbg. & seal assy. (tbg. cut was 50 % effective Completed operations 3-1/2in. Drillpipe workstring run Facility Date/Time M Pt C Pad 05:00-06:00 06:00 Duration Ilar 06:00-23:00 06:00-07:30 07:30 07:30-08:00 08:00 08:00-12:30 12:30 12:30-13:30 17 hr 1-1/2 hr 1/2 hr 4-1/2 hr lhr 13:30 13:30-16:00 16:00 16:00-17:00 2-1/2 hr lhr 17:00 17:00-20:00 3hr 20:00 20:00-23:00 23:00 23:00-06:00 23:00-02:00 3hr 7hr 3hr 17 Sep 99 02:00 02:00-06:00 06:00 06:00-06:00 06:00-06:45 06:45 06:45-14:00 14:00 14:00-15:00 15:00 15:00-00:30 4hr 24 hr 3/4 hr 7-1/4 hr lhr 9-1/2 hr 3hr Progress Report 18 Sep 99 00:30 00:30-03:30 Well MPC-12A Page 2 Rig Nabors 4ES Date 01 December 99 Activity Rigged up Drillstring handling equipment clean floor & rig up same to run HOWCO EZ drill Stopped · To hold safety meeting crew change 3-1/2in. Drillpipe workstring run (cont...) Rigged up Drillstring handling equipment Equipment work completed Installed Bore protector Equipment work completed Ran Drillpipe to 5000.0 ft (3-1/2in OD) mu Hes EZ drill cmt. retainer plug. & rih on singles Stopped · To hold safety meeting Held safety meeting safety stand down with nabors & bpa personell. Completed operations Ran Drillpipe to 7310.0 ft (3-1/2in OD) Stopped · At sub-assembly Set packer at 7310.0 ft with 4200.0 psi Set hes ez drill & set dn 25 k & psi. test to 4200 psi. ok. Packer set at 7310.0 ft Circulated at 7310.0 ft displace well bore fluids with section milling fluid. & spot 10-bbl. of 18.0 ppg. Hole displaced with Water based mud - 120.00 % displaced Pulled Drillpipe in stands to 0.0 ft Completed operations BHA run no. 1 R.I.H. to 7060.0 ft Make up Baker NO. 5-section mill with ..572 TFA +bit sub+jars+8-4.75" dc's At Top of new hole section · 7060.0 ft Made up BHA no. 1 locate collar @ 7073' & begin section milling @ 7060' Initial cut out =l-Hr. Monitor well (stable) first cuttings to surface in 45-min 4720 strks, mill csg. 7060-7064' 15-# of iron recovered. Stopped · To hold safety meeting crew change. BHA run no. 1 (cont...) Serviced Mud pumps Equipment work completed Milled Casing at 7084.0 ft mill 7" csg. F/7064' to 7084' Observed 25.00 klb drag on connections Worked toolstring at 7084.0 ft circ. 7& work tool string Completed operations Milled Casing at 7110.0 ft mill ssection F/7084' to 7110' Completed operations Circulated at 7110.0 ft ~,~. & tu,, ~ ~vio~ of~,~v ...... v,~:~ & t_:m_v,~..:~ ~":~,mu to Facility Date/Time M Pt C Pad 03:30 03:30-06:00 06:00 06:00-09:00 06:00-08:00 08:00 08:00-09:00 09:00 09:00-06:00 09:00-12:45 Duration 2-1/2 hr 3hr 2hr lhr 21 hr 3-3/4 hr 12:45 12:45-16:30 3-3/4 hr 16:30 16:30-18:00 18:00 18:00-19:00 19:00 19:00-19:45 1-1/2 hr lhr 3/4 hr 19:45 19:45-21:00 1-1/4 hr 21:00 21:00-02:00 5hr 19 Sep 99 02:00 02:00-06:00 4hr 8hr 1/2 hr 6hr 1/2 hr Progress Report 06:00 06:00-14:00 06:00-06:30 06:30 06:30-12:30 12:30 12:30-13:00 13:00 Well MPC-12A Page 3 Rig Nabors 4ES Date 01 December 99 Activity clean section for sidetrack plug. Rec. total of Hole swept with slug - 300.00 % hole volume Pulled out of hole to 1329.0 ft on trip out of hole have only had one spot that had 15k over Stopped: To hold safety meeting crew change. BHA run no. 1 (cont...) Pulled out of hole to 321.0 ft & lay dn section mill & drill collars & jars. At BHA Pulled BHA BHA Laid out 3-1/2in. Cement stinger workstring run Ran Drillpipe in stands to 7110.0 ft rih & break circ. to confirm drillpipe not plugged. Observed 25.00 klb resistance Washed to 7118.0 ft circ. & wash with kelly in to csg. stub. & would get down as much as 30 ' plus and was unable to keep · set mule shoe @ 7118' & prepare to set plug. Observed 35.00 klb resistance Batch mixed slurry - 22.000 bbl set plug. 5 bbl. h20+test +20 bbl. h20 +22 bbl. cl. g. 17.0 ppg.+6-bbl, h20 & put in place with 32 bbl. mud & sht dn pump & use C pump to pump 3.75 bbl. mud to balance plug. cemtn in place 1738 hrs. 9/18/99 Completed operations Pulled Drillpipe in stands to 5700.0 ft Completed operations Circulated at 5700.0 ft circ. 2-bottoms up @ 6.5 bpm 1100 psi. Hole displaced with Water based mud - 200.00 % displaced Injectivity test - 3.000 bbl injected at 800.0 psi Perf. hesitation sqz. in 200 psi. increments to 800 psi. & hold 1-hr. & bleed back 2 bbl.s Unable to inject fluid Circulated at 5700.0 ft Circ. & wait on cmt. to build compression strenght for top tag. & test. Obtained req. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6949.0 ft run to 6450 ' in stands & start single in with slow pump looking for cmt. top observed increase in pump @ 6750' & pumped bottoms up & observed no cmt. single in to 6949 & found hard cmt. & set compression to 15 k & increase of 400 psi. indicate good t Observed 15.00 klb resistance 3-1/2in. Cement stinger workstring run (cont...) Circulated at 6949.0 ft Hole displaced with Water based mud - 125.00 % displaced Laid down 6949.0 ft of 3-1/2in OD drill pipe 234 joints laid out Removed Bore protector Equipment work completed Facility Date/Time M Pt C Pad 13:00-14:00 Progress Report Well MPC- 12A Page Rig Nabors 4ES Date 14:00 14:00-19:00 14:00-17:00 17:00 17:00-18:00 18:00 18:00-19:00 19:00 19:00-20:30 19:00-20:30 20:30 20:30-21:00 20:30-21:00 21:00 21:00-22:30 21:00-22:30 22:30 22:30-06:00 22:30-23:30 23:30 23:30-00:00 20 Sep 99 00:00 Duration lhr 5hr 3hr lhr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 7-1/2 hr lhr 1/2 hr 4 01 December 99 Activity Serviced BOP stack Wash iron out of bop stack Equipment work completed 3-1/2in. Surge string workstring run Ran Tubing to 2015.0 ft (3-1/2in OD) ran 65-jts. tbg. for kill string. At Setting depth: 2015.0 ft Installed Tubing hanger Tie-down bolts energised Serviced Multipurpose tool repair rilds Equipment work completed Nipple down BOP stack Removed BOP stack set twc & rig dn bop's Equipment work completed Wellhead work Serviced Hanger plug Change out 4-RILDS & test. Equipment work completed Wellhead work Installed Xmas tree Install tree & test same to 5000 psi. & pull twc & set bpv. Equipment work completed Fluid system Freeze protect well - 75.000 bbl of Diesel Completed operations Cleared Circulating head FLlush out & blow dn lines & secure tree & cellar. Equipment work completed Rig Released @ 0000 hrs. 1/19/99 Facility Date/Time 31 Oct 99 M Pt C Pad Progress Report Well MPC- 12A Page Rig Nordic3 Date 1 30 November 99 02:01-06:00 02:01-06:00 06:00 06:00-08:30 06:00-08:30 08:30 08:30-09:00 08:30-09:00 09:00 09:00-14:00 09:00-13:00 13:00 13:00-14:00 14:00 14:00-16:00 14:00-15:00 15:00 15:00-16:00 16:00 16:00-17:30 16:00-17:30 17:30 17:30-18:00 17:30-18:00 18:00 18:00-21:00 18:00-21:00 21:00 21:00-21:30 21:00-21:30 21:30 21:30-22:00 21:30-22:00 22:00 22:00-23:00 22:00-23:00 23:00 23:00-01:30 23:00-01:30 Duration 3-3/4 hr 3-3/4 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 5hr 4hr lhr 2hr lhr lhr 1-1/2 hr 1-1/2 hr 3hr 3hr lhr lhr 2-1/2 hr 2-1/2 hr Activity Move rig Rig moved 100.00 % Move rig f/MP L-16A to MP C-12A. Rig accepted @ 0600 10/31/99. At well location - Cellar Move rig (cont...) Rig moved 100.00 % PJSM waite on pad operater w/Unit permit. Move rig over C-12Ai. Bearm liner arouuund rig. At well location - Cellar Wellhead work Removed Hanger plug Equipment work completed Fluid system Fill pits with Fresh water Completed operations Circulated at 2020.0 ft Displace diesel with water. Hole displaced with Fresh water - 100.00 % displaced Wellhead work Installed Hanger plug Install BPV and test to 1000 psi from bottom Equipment work completed Rigged down Xmas tree ND tree Equipment work completed Nipple up BOP stack Rigged up BOP stack NU BOP 11" 5000 psi BOP Equipment work completed Wellhead work Retrieved Hanger plug Pull BPV and install TWC Equipment work completed Nipple up BOP stack Tested All functions Test BOP 250/3500 Ann 25/2500 Test TPR 250/5000 Witness waived by AOGCC Chuck Schieve Function test completed satisfactorily Planned maintenance Serviced Top drive Service top drive and replace saver sub Equipment work completed Wellhead work Removed Hanger plug Pull TWC. PU landing jt. PU tbg hanger to rig floor. Up wt. 35k Equipment work completed Fluid system Circulated at 2020.0 ft Circ. 70 deg fresh water to warm up wellbore Hole displaced with Fresh water - 150.00 % displaced Pull Tubing, 3-1/2in O.D. Laid down 2020.0 ft of Tubing LD 65 its Facility M Pt C Pad Date/Time Duration 01 Nov 99 01:30 01:30-02:30 01:30-02:30 02:30 02:30-06:00 02:30-06:00 06:00 06:00-05:30 06:00-06:30 06:30 06:30-09:00 09:00 09:00-10:00 10:00 10:00-13:00 13:00 13:00-14:00 14:00 14:00-14:30 lhr lhr 3-1/2 hr 3-1/2 hr 23-1/2 hr 1/2 hr 2-1/2 hr lhr 3hr lhr 1/2 hr 14:30 14:30-15:30 15:30 15:30-16:00 lhr 16:00 16:00-20:00 4hr 20:00 20:00-23:00 23:00 23:00-03:00 02 Nov 99 03:00 03:00-05:30 3hr 4hr 2-1/2 hr 05:30 05:30-06:00 Progress Report Well MPC-12A Page 2 Rig Nordic3 Date 30 November 99 Activity Repair Completed operations Wellhead work Installed Wear bushing Loading 3 1/2" DP in shed, change out tbg tongs. RU DP spinner Equipment work completed BHA run no. 1 Made up BHA no. 1 PU BHA and load/strap DP in pipe shed BHA no. 1 made up BHA run no. 1 (cont...) Serviced Top drive Service rig, block, crown & top drive Equipment work completed Singled in drill pipe to 4005.0 ft P/[J DP RIH to 4005' Stopped: To circulate Circulated at 4005.0 ft Circulate out Milling fluid with SW at 4 bpm. Obtained req. fluid properties - 100.00 %, hole vol. Singled in drill pipe to 6863.0 ft Continue P/U 3.5" DP Stopped: To circulate Circulated at 6863.0 ft Circulate out Milling fluid w/SW Obtained req. fluid properties - 100.00 %, hole vol. Drilled cement to 6950.0 ft C/O cement stringers f/6863 to 6950' Completed operations Tested Casing - Via annulus and string Test bottom pipe rams to 250/3500 psi. Bled off change to top pipe rams & test 7" csg to 4500 psi f/ 30 min O.K. Pressure test completed successfully - 4500.000 psi Held drill (Kick (well kill)) D5 drill 39 sec AMAS 1 min 2 sec Completed operations Drilled cement to 7076.0 ft Continue to C/O Firm cmt f/6863' to 7076' 9' below top of 7" section. Completed operations Circulated at 7076.0 ft Pump Hi-vis sweep 30 bbl. Change oover ff Sw to Drlg fluid @ 5 bpm. Up wt 105K, Dn wt 70K, RT wt 95K Hole displaced with Water based mud - 120.00 % displaced Pulled out of hole to 805.0 ft POOH stand back 65 stands of 3.5" ~'~ ' E C E ] V E At BHA .; ~ .. ~ : Singled in drill pipe to 3041.0 ft PFU 93 its of 3.5" Dp RIH ~-, r., 03 199[ 93 joints picked up ~ ...... - Aj~aka Oil & Gas Cons. C~r~mmi~i~ Anchorage Facility Date/Time M Pt C Pad Duration 1/2 hr 05:30-06:00 06:00 06:00-11:00 5 hr 06:00-07:00 1 hr 07:00 07:00-11:00 4 hr 11:00 11:00-06:00 19 hr 11:00-14:30 3-1/2 hr 14:30 14:30-15:30 1 hr 15:30 15:30-20:30 5 hr 20:30 20:30-01:30 5 hr 03 Nov 99 01:30 01:30-02:30 1 hr 02:30 02:30-06:00 3-1/2 hr 06:00-01:30 19-1/2 hr 06:00-23:30 17-1/2 hr 23:30 23:30-00:00 1/2 hr 04 Nov 99 00:00 00:00-01:30 1-1/2 hr 01:30 01:30-06:00 4-1/2 hr 01:30-02:00 1/2 hr 02:00 02:00-02:30 1/2 hr Progress Report Well MPC-12A Page 3 Rig Nordic3 Date 30 November 99 Activity Repaired Drillstring handling equipment Repair tong line Equipment work completed BHA run no. 1 Serviced Top drive Service top drive, blocks, and crown. Equipment work completed Pulled out of hole to 0.0 ft POOH. L/D bit and B/S. At top of check trip interval BHA run no. 2 Made up BHA no. 2 PFU bit, motor, and MWD. Oreint motor and MWD and test same. OK. Conitnue GIH with BHA. BHA no. 2 made up Held safety meeting Hold pre-spud meeting with all personnel associated with well. Completed operations R.I.H. to 7076.0 ft Finish GIH with drill pipe and tag cement kick-off plug. On bottom Drilled to 7350.0 ft Orient motor and kick off of plug (3 1/2 hrs). Detected casing stub with resistivity tool after getting kicked off. Continue drill/slide to 7350'. Top drive failed - Pull back to shoe Serviced Top drive Top drive saver sub started leaking. Change out same. Equipment work completed Drilled to 7400.0 ft Continue to drill/slide from 7185' to 7400'. BHA run no. 2 (cont...) Drilled to 8834.0 ft (cont...) Continue to drill/slide from 7185' to 7400'. Stopped: To circulate Circulated at 8834.0 ft Circulate hole clean. MW at 9.6 ppg Hole swept with slug - 100.00 % hole volume Drilled to 8933.0 ft Observed well flowing while taking SPR after making connection. Well shut in. In 0.08 hr had 12.000 bbl Gain - closed in well Well control Monitor wellbore pressures Well shut in on the annular Observed pressures - string: 630.000 psi, annulus: 860.000 psi Bit depth 8933' MD 6943' TVD Estimated top of Kuparuk D Shale 8942' MD Cleared Kelly/top drive hose Begin weighting up to KWM 11.6 ppg. Attempt to Facility Date/Time M Pt C Pad Duration 3-1/2 hr 02:30 02:30-06:00 24 hr 3-1/2 hr 06:00 06:00-06:00 06:00-09:30 5hr 09:30 09:30-14:30 1-1/2 hr 14:30 14:30-16:00 1/2 hr 16:00 16:00-16:30 lhr 16:30 16:30-17:30 12-1/2 hr 05 Nov 99 06:00 17:30 17:30-06:00 Progress Report Well MPC-12A Page 4 Rig Nordic3 Date 30 November 99 06:00-13:15 06:00-06:30 06:30 06:30-07:00 07:00 07:00-08:30 7-1/4 hr 1/2 hr 1/2 hr 1-1/2 hr Activity Began precautionary measures Cleared Standpipe manifold Close upper / lower kelly cocks to remove kelly hose. R/D kelly hose. Begin thawing kelly hose. Equipment work completed Well control (cont...) Cleared Kelly/top drive hose Finish R/D kelly hose and start thawing out same. R/U 2" high pressure circulating hose to top drive and test to 4500 spi. OK. Equipment work completed Cleared Kelly/top drive hose Attempting to thaw out top drive and top drive kelly cock valves. No success. Weight up mud in pits from 10.6 to 11.6 while thawing out. Equipment work completed Cleared Kelly/top drive hose R/U HB&R and attempt to pump methanol thru frozen lines / valves while continuing to attempt to thaw lines with steam. Equipment work completed Held safety meeting Perform a risk anaylsis regarding the forward plan(s) to thaw out the top drive. Completed operations Cleared Kelly/top drive hose R/U and pump 3 bbls mud down annulus. Pump in at 13.6 EMW. Equipment work completed Cleared Kelly/top drive hose No success with steam thawing operations. Shut down same. Remove 2" high pressure hose and re-fill with fresh neet methanol vs the 50:50 blend. Install air ducting around drill pipe from rig floor to elevators. Equipment work completed Wrap visqueen around from elevators to the top of the top drive. 2 portable tioga heaters and 1 rig floor heater are supplying the hot air. By 0600 hrs the 2 kelly cock valves are thawed out and open. Continue pumping heat and attempting to pump methanol Well control (cont...) Cleared Kelly/top drive hose Top drive actually thawed out at 0530 hrs. SICP 930 psi. SIDP 630 psi. Equipment work completed Held safety meeting Hold PJSM on well kill. Review procedure and define responsibilities of crew. Completed operations Circulated closed in well at 8933.0 ft Begin circ 11.6 ppg KWM thru the choke. ICP 1580 psi. Csg press 930 psi. The initial circ press was Facility M Pt C Pad Date/Time 08:30 08:30-09:00 09:00 09:00-11:30 11:30 11:30-12:00 12:00 12:00-13:00 13:00 13:00-13:15 13:15 13:15-06:00 13:15-14:00 14:00 14:00-14:30 14:30 14:30-16:00 16:00 16:00-17:30 17:30 17:30-18:00 18:00 18:00-19:30 19:30 19:30-21:00 21:00 Progress Report Well MPC-12A Page 5 Rig Nordic3 Date 30 November 99 Duration 2-1/2 hr 1/2 hr lhr 16-3/4 hr 3/4 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr Activity taken with the kelly hose, and the well kill was done Began precautionary measures Stopped to weight up surface system. Unable to keep up with a 2 lb (9.6 to 11.6) weight up while circulating. Monitor wellbore pressures SI well at 4317 stks to wt up surface system to 11.6 ppg SIDPP 470 psi SICP 510 psi Freeze protect top drive Observed pressures - string: 470.000 psi, annulus: 510.000 psi Circulated closed in well at 8933.0 ft Continue well kill. Circa total of 2 btm up. Unable to ever get 11.6 MW out. Max circ rate of 2 bpm lose returns. Experience barite sag. MW out ranged from 11.3 to 10.4. Began precautionary measures Monitor wellbore pressures Shut well in to monitor pressures Observed pressures - string: 210.000 psi, annulus: 280.000 psi Circulated closed in well at 8933.0 ft ICP 520 psi. Csg press 10 psi. Shut down and bleed off pressure. No flow. Stopped: To flowcheck well Monitor wellbore pressures Observed well static BHA run no. 2 Pulled out of hole to 8840.0 ft Rig down thawing equipment. Break out stand and stab TIW. Blow down top drive. PU single. Shorten the 2" hose being circulated through to allow movement of the top drive. Began precautionary measures Held safety meeting Hold PJSM on opening the well and moving the pipe. Completed operations Circulated at 8873.0 ft Pipe free. Initial up wt. 140k. Down wt. 95k Hole packing off while circ. Locate free point and circ. staging pump to 45 SPM Began precautionary measures Pulled out of hole to 8255.0 ft Stopped: To circulate Circulated at 8255.0 ft Hole was taking the correct amount of fill, but began u-tubing back up the drill pipe side. Pump 25 bbls. Flow up drill pipe stopped. Broke circulation Pulled out of hole to 6800.0 ft Pull into casing. Hole in good condition. Hole taking correct fill. At Window: 7076.0 ft Circulated at 6800.0 ft Circulate and condition mud. Attempt to increase rate to reduce barite sag. 108 bbls lost. Broke circulation Facility M Pt C Pad Date/Time 21:00-22:30 Duration 1-1/2 hr 22:30 22:30-01:00 2-1/2 hr 06 Nov 99 01:00 01:00-03:00 2hr 03:00 03:00-04:00 lhr 04:00 04:00-06:00 2hr 06:00 06:00-08:30 06:00-07:00 07:00 07:00-08:30 08:30 08:30-04:30 08:30-12:30 2-1/2 hr lhr 1-1/2 hr 20 hr 4hr 12:30 12:30-14:30 2hr 14:30 14:30-15:00 1/2 hr 15:00 15:00-04:30 13-1/2 hr 07 Nov 99 04:30 04:30-06:00 04:30-05:30 1-1/2 hr lhr Progress Report Well MPC- 12A Page Rig Nordic3 Date 6 30 November 99 Activity Flow check Monitor well. Constant rate of influx 0.6 bbl/5 min. Well is "flowing or breathing" not sure which. Lost 108 bbls lost while attempting circulate 11.6 mud around. Observed 7.500 bbl gain in annulus in 1.00 hr Pulled out of hole to 3481.0 ft POOH slowly monitoring well. Next 20 stds gained 17 bbls. Hole started taking mud at 1.6, 0.8, 2.1 bbls / 5 stds respectively. At top of check trip interval Circulated at 3481.0 ft Circulate 11.6 mud around at 4 bpm with no losses. Initial MW out was 10.4. Obtained clean returns - 100.00 % hole volume Rigged up Kelly/top drive hose R/D 2" high pressure circulating hose and R/U kelly hose. Able to trip and rack back drill pipe much easier with kelly hose. Equipment work completed Pulled out of hole to 882.0 ft Continue to POOH. Hole taking inconsistant hole fills. Monitor well each 5 stds pulled. No gain/loss. At BHA BHA run no. 2 (cont...) Pulled out of hole to 882.0 ft Finish POOH to BHA. At BHA Pulled BHA Download MWD/PWD and rack back BHA. Completed operations Run Liner, 4-1/2in O.D. Installed Well control Pull wear bushing. Change top rams to 4 1/2". Set test plug and test rams to 250-3500 psi. OK. Pull test plug. Set wear bushing. Well static. Equipment work completed Rigged up Casing handling equipment Clean rig floor area from wet trip. R/U 4 1/2" casing tools. Well static. Equipment work completed Held safety meeting Hold pre-job for running 4 1/2" liner and well control issues. Completed operations Ran Liner to 8924.0 ft (4-1/2in OD) P/U 52 its 4 1/2" 12.60g L-80 IBTMod liner and run on 3 1/2" D/P. TOL 6751'. Shoe 8924'. Tag btm 8926'. Full returns running inside 7" csg. Lost 26 bbls running liner in open hole. Well static. while running liner. On bottom Cement · Liner cement Circulated at 8924.0 ft Facility Date/Time M Pt C Pad Duration 05:30 05:30-06:00 1/2 hr 06:00 06:00-09:00 06:00-09:00 3hr 3hr 09:00 09:00-09:30 09:00-09:30 1/2 hr 1/2 hr 09:30 09:30-13:00 09:30-13:00 3-1/2 hr 3-1/2 hr 13:00 13:00-00:00 13:00-21:30 21:30 21:30-00:00 llhr 8-1/2 hr 2-1/2 hr 08 Nov 99 00:00 00:00-01:30 00:00-01:30 1-1/2 hr 1-1/2 hr 01:30 01:30-02:00 01:30-02:00 1/2 hr 1/2 hr 02:00 02:00-04:00 02:00-04:00 04:00 04:00-06:00 04:00-06:00 06:00-06:30 06:00-06:30 2hr 2hr 2hr 2hr 06:30 Progress Report Well MPC- 12A Page Rig Nordic3 Date 7 30 November 99 Activity 0.4 bpm at 2900 psi. Pressure broke back. Continue Obtained req. fluid properties - 15.00 %, hole vol. Mixed and pumped slurry - 23.600 bbl 15 bbls 12.1 B45 spacer. Batch slurry 113 sks, 23.6 bbls, Wt 15.8, Yield. Displace with 11.6 mud at 4.6 bpm 1800 psi. Bump plug with 3200 psi and set hanger. 50% returns during job. Pressure to 4200 psi to set liner top packer. Check BPV. OK. Tail cement pumped Cement: Liner cement (cont...) Circulated at 6751.0 ft Release from hanger and circulate out. No cement in returns. Got back oil wet barite. Continue to circulate till clean with 11.4 in / out. Obtained req. fluid properties - 200.00 %, hole vol. Perform integrity test Tested Liner Pressure test liner top packer to 2000 psi for 15 minutes. Test OK. Pressure test completed successfully - 2000.000 psi Fluid system Circulated at 6751.0 ft Swap well out to corrosion inhibited seawater. R/D liner swivel and blow down lines. Obtained req. fluid properties - 200.00 %, hole vol. Pull Drillpipe, 3-1/2in O.D. Laid down 6350.0 ft of 3-1/2in OD drill pipe POOH amd L/D drill pipe used for running liner. Baker liner running tool OK and intact. 198 joints laid out Laid down 882.0 ft of Drill collar L/D BHA out of derrick. Completed operations Run Drillpipe, 3-1/2in O.D. Ran Drillpipe in stands to 2900.0 ft Run 30 stds drill pipe back in hole for freeze protect. On bottom Perform integrity test Tested Casing Test 7" and 4 1/2" casing strings to 3500 psi for 30 minutes. Test OK. Pressure test completed successfully - 3500.000 psi Fluid system Freeze protect well - 85.000 bbl of Diesel RFU HB&R and freeze protect well with 85 bbls diesel (2200' MD). R/D HB&R. Completed operations Pull Drillpipe, 3-1/2in O.D. Laid down 2900.0 ft of 3-1/2in OD drill pipe POOH and L/D drill pipe. Pull Drillpipe, 3-1/2in O.D. (cont...) Laid down 2900.0 ft of 3-1/2in OD drill pipe (cont...) POOH and L/D drill pipe. 93 joints laid out Facility M Pt C Pad Progress Report Well MPC- 12A Page Rig Nordic3 Date 8 30 November 99 Date/Time 06:30-09:00 06:30-09:00 09:00 09:00-10:00 09:00-10:00 10:00 10:00-12:00 10:00-12:00 12:00 12:00-17:30 12:00-17:30 17:30 17:30-18:30 17:30-18:30 18:30 18:30-06:00 18:30-20:00 20:00 Duration 2-1/2 hr 2-1/2 hr lhr lhr 2hr 2hr 5-1/2 hr 5-1/2 hr lhr lhr 11-1/2 hr 1-1/2 hr Activity Fluid system Freeze protect well - 15.000 bbl of Diesel Toped off well with 15 bbls disesel. Used test pump to diesel. Pulled wear ring Completed operations Wellhead work Installed Tubing hanger Install tbg hanger w/T.W.C inplace. Equipment work completed BOP/riser operations - BOP stack Removed BOP stack N/D 11" BOPE Equipment work completed Wellhead work Installed Xmas tree N/U Adapter flange, Test pack off. No good remove and clean rings. Reinstall Test to 5000 psi O.K. Thaw out tree and install test 500 & 5000 psi O.K. Equipment work completed Wellhead work Rigged up Hanger plug Pull T.W.C and install BPV Equipment work completed Move rig Rigged down Drillfloor / Derrick Move rig off well. Pick up pit liner & clean around well cellar. Release rig @ 2000 hrs 11/8/99 Equipment work completed · MPC- 12 Sundry Subject: Re: MPC-12 Sundry Date: Tue, 10 Aug 1999 10:55:30-0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Triolo, Mike T" <TrioloMT~BP.com> Mike, Your request to "bull head" cement down the tubing to kill MPU C-12 as an alternate to circulating in place with coil tubing is an insignificant alternate and is hereby verbally approved. Blair Wondzell 9~a~ ~ ~ ~- f~ 10 August 99 "Triolo, Mike T" wrote: > Blair, I would like to request an alternate procedure to be added to the _> > MPC-12 pre rig abandonment work. We would like the option of bullheading > the cement from surface using HB&R. Thus the Pre Rig Work procedure would > be outlined as follows: 1) Test Packoff. 2) RU HB&R to bullhead cement for the abandonment of the perforated intervals: bullhead cement from top fill to a minimum of 100' above the top perfs @ 10,416'. 3) RU slick line to drift tubing and tag top of cement. Plug tag to be witnessed by AOGCC representative unless they choose to waiver the requirement. 4) RUE line and RIH and cut the tubing in the middle of the 1st full joint above the GLM @ 10,173' with Jet cutter. 5) Set BPV. Pending verb~ro¥~ w~ would like to begin pre rig work on C-12 tomorrow afternoo!L,-3, q~PL-16 pre rig WOrk h'as peen pushed ba~K to' Friaay--o~ ~ >~~~7~/99 - 8/14/99) depending on CTU availability, so no immediate >~rush on that S,~dry. Sorry for the confusion on L-16. Please do not hesitate to call me at 564-5774 with any questions or concerns you may have. Thank you, Mike Triolo Michael (Mik) Triolo BP Amoco/SSD Drilling Engineer >MB5-1 900 East Benson Blvd. Anchorage, Ak. 99508 Work phone: 564-5774 Pager: 275-9875 1 ofl 8/10/99 10:56 AM "-"' STATE OF ALASKA ALASKA ,.,IL AND GAS CONSERVATION COh,,.,/IISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [~]Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 52' [] Exploratory 7. Unit or Property Name 3. Address [~]Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [~Service 4. Location of well at surface 8. Well Number MPC-12 496' NSL, 2027' WEL, SEC. 10, T13N, R10E, UM 9. Permit Number At top of productive interval 85-120 3208' SNL, 2757' WEL, SEC. 03, T13N, R10E, UM ,10. APl Number At effective depth 50-029-21373 2885' SNL, 2826' WEL, SEC. 03, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 2739' SNL, 2857' WEL, SEC. 03, T13N, R10E, UM Sands 12. Present well condition summary Totaldepth: measured 10975 feet Plugs(measured) P\~CE~VED true vertical 7578 feet Effective depth: measured 10801 feet Junk(measured) true vertical 7492 feet Casing Length Size Cemente(~ask~ 0it & Gas C-o~s. ~0t''q'q'~'S~'~0~ knch0r~M D '1'VD Structural Conductor 80' 16" To Surface 115' 115' Surface 6034' 9-5/8" 1625 sx PF 'E', 250 sx Class 'G' 6070' 4703' Intermediate Production 10922' 7" 300 sx Class 'G' 10956' 7569' Liner Perforation depth: measured 10416' - 10438', 10708' - 10732', 10750' - 10796' true vertical 7290'-7302', 7445'-7458', 7467'-7490' O~IGiNA / Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 to 10510' ~,, Packers and SSSV (type and measured depth) Camco TRDP-1A SSSV at 687'; BOT HP Retrievable packer at 10242'; BOT 2B Permanent packer at 10476' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: August 10, 1999 16. If proposal was verbally approved [--I Oil I--I Gas [] Suspended Service Water Injection Name of approver Date approved Contact Engineer Name/Number: Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 17.1 hereby cedi.fy t___~ the~rego~ true and correct to the best of my knowledge Char,es mallary ~ Title Senior Drilling Engineer Date Commission Use Only Conditions of Approval: Notify Commission so representative may witness I ApprovalNo. Cjo~,,j Plug integrity ,/" BOP Test ~ Location clearance _~Oqe~ ,,A Mechanical Integrity Test Subsequent form required 10- /~O7~ ix~e~:;~~~l~ ORIGINAL SIGNED. BY ApprovejJJ;~dcderF(x,~[~0_40§ Rev. of 06/15/88the Commission Robert N. Chdstenson Commissioner DatesubmijC~ i?(riDhca~C-).,cj t e re.d nll ng To: From: Blair Wondzell - AOGCC Michael Triolo Subject: MPC-12i Application for sundry permit - P&A for Sidetrack Operations Date: 5 August 1999 Reference: APl #50-029-21373 C-12i was drilled and completed in 1985 as a C sand gas hft producer. Within 2 months the well was converted to a frac'd A and C sand water injector. In 1996 it was determined that the well did not support production. A BPV was installed and the well has remained shut in ever since. The well will be sidetracked South of it's current location to provide injection support and reserves sweep to C-03, an ESP producer. The MPC-12i decompletion is currently scheduled for Nabors 4ES following the MPL-16 decompletion. The rig is expected to finish operations on MPL-16 on the 25~ of August. The pre-rig work for the MPC-12i decompletion is planned to begin around August l0th pending Sundry approval. Pre Rig Work: 1) Test Packoff 2) CTU abandonment of the perforated interval, spot cement from top fill to a minimum of 50' above the top GLM of the straddle completion. 3) Punch holes in tubing above PBR @ 10,288' 4) Freeze protect 5) Set BPV RWO Scope of work: 1) Pull BPV with lubricator 2) Circulate well 3) Set TWC 4) ND tree, NU and test BOP 5) Test Casing 6) Pull and LD tubing, inspect for NORM 7) Install bowl protector 8) RIH with bridge plug. Change well over to milling fluid and set BP at 7,310'. 9) RIH with section mill, mill 50' section of 7" casing from 7,060' - 7,110'. 10) Circulate and condition mud. POH 11) RIH open ended and lay cement kick off plug from 100' below section to a minimum of 100' above the section. 12) AOGCC to witness plug placement and testing. 13) Freeze protect 14) ND BOP, NU tree and release rig. KOP = 500' Max hole angle = 60.2 @ 10,876' Orig. KB - SL = 52' (Alaska United #3) Orig. KB - GL = 35' (Alaska United #3) Top of cmt, 100' above window (6,960') 10.4 ppg mud from top PBR to BP. Top of cmt, 100' above top GLM (10,250') MPC- 12 FMC Tubing hanger w/3-1/2" 'H' BPV profile Tree: FMC 3-1/8" 5M with 3-1/2" 8rd treetop connection k 9-5/8", 40# L-80 Btrs @ 6,090' Mill 7" casing from 7,060' - 7,110' Bridge plug @ 7,310' BOT 'HB' retreivable packer (2.89"1D) I 10,242' Camco ~/V-I' selective nipple (2.812"1D)110,280' Camco 'MMG-2' GLM valves Blast j~' length), 4.25"/3.00" OD/ID o.,. ss. I I Perforation Summary **All shot on 4-27-85'* Gun SPI Interval (TVD) 5" 12 10416-10438 7289-7301 5" 12 10750-10796 7466-7489 2-1/8" 4 10708-10732 7445-7457 BOT '2-B' Perm. packer (5.875"OD, 4.25"1D) w/millout extension (5"OD, 4.43"1D) I 10,476'I Camco 'D' nipple (2.75"1D) I 10'501' I PBTD Wireline tag I ~0'~' I 7" 26# L-80 Btrs (6.276"1D, 6.151"drift)l 10,958'I Date Revised by Comments 8/2/99 Mik Triolo Proposed decompletion by 4ES Milne Point Unit WELL: C- 12i APl #: 50-029-21373-00 Proposed Decompletion WELL No. C-12 COMPLETION SKETCH MILNE POINT UNIT (!) APl No.: 50-029-21373 PERMIT No.: 85-120 COMPLETED: 7/51/85 LAS'[ WORKOVER: 10/21/89 NOTES: ALL MEASUREMENTS ARE FROM KDB OF ALASKA UNITED #3 KDB-SL = 52' KDB-G~ = 35' F,VIC TUBING HANGER W/ 5 1/2" 'H' BPV PROFILE ~3 1/2", 9.2# L-80 BUTTRESS TUBING (2.992" I.D., 2.867" DRIFT) 2. MAX. Z_ = 60.2' @ 10,876' MD - ~68T CAMCO JRDP-IA SSA SSSV (2.812" ID) 3. K.O.P. = 500' 4. SLANT HOLE: YES 5. MIN. /_ = N/A 6. TREE TYPE: FMC 3 1/8", /Ol 5000# WITH 3 1/2" 8 RD. TREET0'- CONNECTION. 7. MIN. RESTRICTION IS CAMCO 'D' NIPPLE @ 10,501' (2.750" ID) COMPLETION FLUID: 10.2 PPG NoCI-NoBr FRAC JURE STIMULATION: -7-19-85 MIDDLE KUP 75,000 LBS 16-20 iSP 9-5-85 LK-2 40,000 LBS 16-20 ISP (SCREENED OUT) ~10,173' 3 1/2" CAMCO KBUG GLM - 'i0,22'8' BOT PBR, SEX[- ASS'EMBLY PERFORATION DATA 12 SPF. 120' PHASING, 5" GUNS (ALL DEPTH_q FROM DIL LOG 4-27-85) MIDDLE KUP 10,416'-i0,458' MD 7289'-7301' TVD LK-2 10,750'-10,796' 7466'-7489' TV5 4 SPF, O' PHASING, 2 i/8" GUNS (ALL DEPTHS FROM DIL LOG 4-27-85) LK-1 10,708'-i0.732' MD 7445'-7457' TVD i0,242' BOT 'HB' RETRIEVABLE PACKER (2.89" ',D) ~lC:.2LflO' CAMCO 'W-I' SELECTIVE NIPPLE (2.812" ID) _~~10,.5.45' CAMCO 'ML:-'.-2' GAS LIFT MANDREL 2.920" ID, '.5" VALVES 10,396'CAMCO 'MMG-2' GAS LIFT MANDREL 2.920" ID, 1.5" VALVES 10,404' BLAST JOINT (39.54' TOTAL LENGTH, 4.250" o~.. 3. oo" ~D) 3 1/2" 9.2#, L-80, BTRC TBG 10,475' BOT C.L. SEAL ASSEMBLY 10,476' BO7 '2-B' PERMANENT PACKER (5.875" OD, 4.25" ID) WITH MILLOUT EXTENSION, (5.0" OD, 4.4.30" ID) __ 10,5CI' CAMCO 'D' NIPPLE (2.750" ID) 10,510' TUBING TA!L .1--'" 10,8~:' PBTD O,~RELINE TAG) . ._ ~ 10,9.,:."-' T' 26#. L-80 BTRS (6.276" ID, 6."~''', DRIFT), CONOCO INC. ,', ~, ,vn,'-:.u,_.. DIVISION APPROVED BY: HDS DATE: 03/i DRAFTED BY: Sd;-,' CAD FILE: WCOC12 SCHLUMBERGER WELL SERVICE A DIVISION OF SCHLUMBERGER TECHNOLOGY CO,-~rORATION HOUSTON, TEXAS 7725 1 -2175 SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-006 Attn: Bernie/Shelley Conoco, Inc. 3201 "C" Street, Suite 305 Anchorage, AK 99503 Attention: Dorothy Bourbeau Gentlemen: ~--'~ J2J~) Enclosed ore 2 BLprintsofthe Injection Profile, Run 1, 10/28/93 Company Conoco, Inc. ~1' ~0_:~© ~ 10~0 Well MPU C-12 on: Field Milne Paine Additionaiprintsore being sentto: 1 BI,prints Conoco, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 EPT 1BLprints Conoco, Inc. 1OOO South Pine Ponca City, OK 74602-1267 Attn: Janet Webb, 1239 EB ERS ,'~rints, 1RF Se~p~ \ -/Alaska Oil & Cam Con~erva 3001 Porcupine Drive Anchorage, AK 99501 Attn: Larry Grant z/ tion The film is ~.eturned to Conoco,. Dorothy Bourbeau We appreciate the privilege of serving you. County North Slope State Alaska 1BL prints, 1RF Sepia Chevron Production Company 1301McKinney Houston, TX 77010 Attn: Gary Forsthoff 713/754-5618 1BL prints, 1RF Sepia OXY U.S.A.. Inc, 6 Desta Drive~ Suite 6002 Midland, TX 79705 Attn: John Corral ~prints prints Very truly yours, SCHLUMBERGER WELL SERVICES $W$-- t 327.F CH (7 BL/3-RF) Raymond N, Dickes OISTRICT MANAGER ':- STATE OF ALASKA . ' AI..~S,, . OIL AND GAS CONSERVATION COMMIS5lO~'I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well m Plugging m Time extention Stimulate __ Change approved program __ Pull tubing X Variance Perforate X Other 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 ,5. Type of Well: Development Exploratory Stratigraphic Se~ice X Datum elevation (DF or KB) 59' KDB 7. Unit or Property name Milne Point Unit 4. Location of well at surface 8. 496' FSL, 2027' FEL, Sec. 10, T13N, R10E, U.M. At top of productive interval 3208' FNL, 2757' FEL, Sec. 3, T13N, R10E, U.M. At effective depth 2885' FNL, 2826' FEL, Sec. 3, T13N, R10E, U.M. At total depth 2739' FNL, 2857' FEL, Sec. 3, T13N, R10E, U.M. Well number C-12 9. Permitnumber 85-120 lO. APInumber 50-029-21373 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 6034' Intermediate Production 10,922' Liner Perforation Depth: measured 10,975' feet Plugs (measured) 7578' feet 10,801' feet Junk (measured) 7492' feet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size Cemented Measured depth 16" TO Surface 115' 9-5/8" 250 sx Class G 6070' 1625 sx Permf E 7" 300 sx Class G 10,956' True vertical depth 10,750'-10,796'; 10,708'-10,732'; 10,416'-10,438' 115' 4704' 7576' 7466'-7489'; 7445'-7457'; 7289'-7301' 3-1/2", L-80, 10,510' CAMCO TRDP-1A SCSSV @687';BOT HB Pkr @10,242', 2B Pkr @10,476' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation January 1991 16. If proposal was verbally approved 15. Status of well classification as: Oil Gas Suspended Date 12/08/90 Name of alpprover/ Date approved Service Waterflood Injector 17. I hereby c~rtify th~ the foregoing is true and correct to the best of my knowledge. Signed (,_~d~ ~ J.H. Andrew Trtle Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity B~P/Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Oi~It~INAL SIGNED B'~ " Approved Copy Approved by order of the Commission mmissioner Form 10-403 Rev 06/15/88 I^""r°w'"°' qO feet .-...~ I~PU C-12 Workover - Reperforate to Access LK-1 Injection Zone Procedure Sun,nary 1. Monitor SITP to determine reservoir pressure. MIRU workover rig on well. Kill well with NaBr/NaC1 brine (density determined by SITP). ND tree, NU and test BOP's. e PU to release from Brown Oil Tools PBR assembly at 10,228'. Circulate hole full of kill weight fluid. POOH and LD 3-1/2" production tubing. e TIH with overshot/grapple BHA to Brown Oil Tools PBR above HB retrievable packer at 10,242'. Latch PBR stinger and release packer. POOH and LD PBR stinger, packer, and isolation tubing. Be PU packer milling/pulling BHA and TIH to Brown Oil Tools 2B permanent packer at 10,476'. Latch packer and mill slips. POOH with packer and tailpipe assembly. e 0 GIH with 5" perforating guns and reperforate the LK-1 sand 10,710'-10,730' CNL. Add perforations to the L-8 lobe at 10,522-10,528' and L-9 lobe at 10,561-10,569'. TIH with full bore retrievable packer on drillpipe and set near 10,650' (below L-9 perforations). Circulate down source water and establish injection into LK-1 and LK-2 sands. Allow injection to stabilize. 1 RU electric line. GIH with production logs while injecting source water and confirm LK-1 is taking fluid at an acceptable rate. NOTE: Additional perforations will be added if measured injectivity is insufficient. 9. Kill well. Release retrievable packer and POOH. 10. PU permanent packer and 3-1/2" tailpipe with wireline nipple and re-entry guide. GIH on electric line and set packer at 10,640'. POOH with setting tool and RD electric line. 11. PU isolation assembly for MK/L-8/L-9 perforations consisting of production seals, 3-1/2" gas lift mandrels, and wireline nipple below retrievable packer/PBR assembly . TIH on 3-1/2" production tubing pinned to packer PBR. 12. Sting into permanent packer at 10,640'. Space out, land hanger. RU wireline and set tubing plug in nipple below packer. Set retrievable packer near 10,220'. 13. ND BOP's. NU and test tree. 14. RU slickline. GIH and pull tubing plug and dummies from isolation mandrels. RD slickline. 15. Return well to waterflood injection service. /~ILNE POINT UNIT £-12 :..~ .... :. 'COAPLETE0 ON 10-23-89 I<I]B - ~. ,52' l~-6L , 35' AAX. N~ ,GB.2 ti lt~.876' F~ 3 I/~' API ~ V/3 !/'2' B TREEI'~ D]N~£TI~ APl ND' 58-~-21373 COJ'R. ET]~ FLUID, lB.2 PPG NoCI/N~ 12 5.~!~ ,~. IB.41§-lB.438' 7.2~-7,381 ' T VD LK-2; i&?SB-IB.~S' AD ?.4~-7,489' T VD 4 ~,, 0 PHASIN$ !1~.7~-!~.732' kD 7.445'7,457' F'P,,q;TLI;E STIALLATi~: 16-2B FAC ltB[~ HANZ~R V~ 3 !12' 'H' E~ PR[FILE 3 I/2' 9.2, L-BB EIJTTRESS lid: 2,9921 IRI~-IA ~a ~ I ID, 2.8t21 IB.228' BDT F~. ~ IB.242' EOT 1-13' I ID. 2.891 liB, 2,B!21 · C'~, IB.4~ ~ ,~:~:~;a,'~ & ~'~ -- ~ I~ 4~'~T '~' NI~ 12.75 IDI IB.51B' 1~1~ IAIL 1~.~6' 7' ~, L-~ B~ 16.~ ID. 6.151 7,-' 25 ...' 90 a293 SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY hi(. :3r~' ~ GA SERVATiON LOCATION · 3001 Onn?TT~T''-- DR A~ENTION ·,,~'~:~,~..~, BOYLE COMPUTING CENTER PRINT CENTER WELL NAME V/MiLNE ~n-r,x?m.,.,..,,_,,,~. UNit ~'-6,~ SERVICES · ! PL ADVISOR REPJOR? WELL NAME :~ILNE POINT UNIT C-8 SERVICES "1 PL ADVISOR REPORT NO. OF BOXES: ALL IN ONE BOX JOB NO. . .. 73975 ADD'L TAPES · -- NO. OF BOXES: ALL IN ONE BOX JOB NO. · 739'74 ADD'L TAPES · -- WELL NAME .Y'M!LNE POINT UNiT C-12 SERVICES · 1 PL ADVISOR REPORT WELL NAME t,Z' MILNE POINT UNIT C-Il SERVICES ' 1 WF/PL ADVISOR REPORT NO. OF BOXES: ALL IN ONE BOX JOB NO. · 73959 ADD'L TAPES ' -- WELL NAME ' SERVICES ·,_~ OLd_ ADVISOR REPORT NO. OF BOXES' ALL IN ONE BOX 'JOB NO. ' 73973 ADD'L TAPES · -- WELL NAME ~./ MILNE POINT UNIT C-15 SERVICES - 1 WF/PL ADVISOR REPORT SCHLUMBERGER COURIER: DATE DELIVERED: .o .. RECEIVED BY:-.. '"'-:~:" '"' CONOCO, INC. 20 Milne Point MPU C- 1 Production Logs 07-Jul-90 PL ADVISOR Production Logs Interpretation Using a Global Solver (V3) MpU C- 12 Company - CONOCO, INC. Field - MILNE POINT LOgging date - JUL 07,1990 Processing date - JUL24,1990 Reference - 73959 Schlumberger Well Services Alaska Division Computing Center 500 West International Airport Road Anchorage, Alaska 99518 907/562-2654 A~las~a Oil & Gas Oons. 'Anchorage 10350 10400 10550 10600 10650 10700 10800 I WATER V~.LO~TY -200. 40. -ao. (~) ~o7 (DE<~:) ~l-~ T~AT~ o. 10'2 (p~c~) 107 10350 10400 10800 10850 10700 10750 10800 CONOCO, INC. ~-~ Milne Point MPU C- 1~ Production Logs 07-Jul-90 COMPUTED CUMULATIVE INJECTION RATES At Down hole conditions Zone Depth Depth Total Water Oil Gas Global # DH Rate DH Rate DH Rate DH Rate Ineo- Feet Feet Bpd Bpd Bpd Bpd herence 1. 10810.0 10782.5 0. 0. 0. 0. 0.000 2. 10766.0 10522.5 663. 663. 0. 0. 0.005 3. 10490.0 10406.5 663. 663. 0. 0. 0.315 4. 10390.0 10358.5 919. 919. 0. 0. 0.009 5. 10340.0 10310.5 1217. 1217. 0. 0. 0.004 COMPUTED FLOW DESCRIPTION Assuming a I - 11/16" tool presence Zone Water Gas Mixture Friction Liq/Liq Gas/Liq Inject # Holdup Holdup Density Gradient Slip vel Slip vel Regime Gr/cc Gr/cc Ft/mn Ft/mn 1. 1.000 0.000 0.970 0.000 0.00 0.00 No Flow 2. 1.000 0.000 0.970 0.000 0.00 0.00 WATER 3. 1.000 0.000 0.970 0.006 0.00 0.00 WATER 4. 1.000 0.000 0.970 0.011 0.00 0.00 WATER 5. 1.000 0.000 0.970 0.019 0.00 0.00 WATER CONOCO, INC. Milne Point MPU C- 12 Production Logs 07-Jul-90 PRODUCTION LOG MEASUREMENTS Zone Depth Spinner Thermo # #1 #1 Feet FtYmn DegF 1. 10810.0 ---.- 104.664 10782.5 105.159 2. 10766.0 14.37 104.746 10522.5 103.152 3. 10490.0 59.66 102.550 10406.5 102.474 4. 10390.0 83.23 102.502 10358.5 102.454 5. 10340.0 109.82 102.409 10310.5 102.287 MEASUREMENT RECONSTRUCTION QUALITY Measured minus Reconstructed values Zone Spinner Thermo # #1 #1 Ft/mn DegF 1. -999.25 0.000 2. 0.01 -45.061 3. -0.63 -0.389 4. 0.02 -12.356 5. 0.01 -10.830 I I I I CONOCO, INC. Milne Point MPU C- 12 Production Logs 07-Jul-90 PL Advisor Program Parameters for Zone 1 (at downhole conditions) Zone bottom depth ............................................... 10810. Feet Zone top depth ................................................... 10783. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 60.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5279. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 150.1 DegF Minimum water rate .............................................. 0.0000 Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Geometrical factor ................................................ 0.5190 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF PL Advisor Program Parameters for Zone 2 (at downhole conditions) Zone bottom depth ............................................... 10766. Feet Zone top depth ................................................... 10523. Feet Pipe internal diameter .............................................. 6.276 Inches Pipe Deviation ..................................................... 60.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5279. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 149.8 DegF Minimum water rate ............................................... 663.0 Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter ........................... .' ........................ 1.688 Geometrical factor ................................................ 0.8380 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF CONOCO, INC. Milne Point MPU C- 12 Production Logs 07-Jul-90 PL Advisor Program Parameters for Zone 3 (at downhole conditions) Zone bottom depth ............................................... 10490. Feet Zone top depth · 10407. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 60.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5279. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 147.8 DegF Minimum water rate ............................................... 663.0 Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter .................................................... 1.688 Inches Geometrical factor ................................................ 0.8780 Resolution ........................................................ 2.000 Ft/mn Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 DegF Confidence factor ................................................. 0.0000 PL Advisor Program Parameters for Zone 4 (at downhole conditions) Zone bottom depth ............................................... 10390. Feet Zone top depth ................................................... 10359. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 60.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure .......................................... 5279. Psi Water density ..................................................... 0.9700 Gr/cc ' Wat&r ViScOSity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 147.0 DegF Minimum water rate ............................................... 919.0 Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diameter ................................................... .. 1.688 Inc-hes Geometrical factor ................................................ 0.8820 Resolution ........................................................ 2.000 FtJmn Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 DegF Confidence factor .................................................. 0.0000 CONOCO, INC. ~'~' Milne Point MPU C - 12 Production Logs 07-Jul-90 PL Advisor Program Parameters for Zone 5 (at downhole conditions) Zone bottom depth ............................................... 10340. Feet Zone top depth ................................................... 10311. Feet Pipe internal diameter .............................................. 2.992 Inches Pipe Deviation ..................................................... 60.00 Degrees Pipe absolute roughness ........................................... 0.0006 Inches Average injection pressure ........................................ ... 5279. Psi Water density ..................................................... 0.9700 Gr/cc Water viscosity .................................................... 0.7200 Cp Reservoir fluid temperature ......................................... 146.6 DegF Minimum water rate ............................................... 1217. Bpd Maximum water rate ............................................... 2000. Bpd Continuous flowmeter # 1 Blade diaeter ...................................................... 1.688 Geometrical factor ................................................ 0.8850 Resolution ........................................................ 2.000 Confidence factor .................................................. 1.000 Thermometer # 1 Resolution ....................................................... 0.0100 Confidence factor ................................................. 0.0000 Inches Ft/mn DegF /~ILNE POINT UNIT C-12 COflPLETED ON 10- 2:3- B9 F~ TL~INB ~R V/ 3 ' KOI) ' SI. · 52' KOB' GL · 35' KOP · 580' FN::: 3 I./8' APl 5EISEI CO~TiON FLUID lEI.2 PPG N~CI/N~- 687' ~ TRI]P-IA SSA SCSSV IlO · 2.812I lEI.l?3' I:XJAAY GL AAJI:)I~L 18,228' BOT PBR, SEAL ~Y ~-- IEI.242' eOT RETR [EVAELE PKR. (ID · 2.89I PE~ORAT IC]~: AK: IR 416-I8 4~ ?:~-~'.~l "l~ LK-2: I -El ' I/8 FRACTURE ST [ALLAT[~:~ AK- LK-47~'B~ Ib.. lEI 28EI' CA/I~ 'V-I ' SEleCT lYE NIPPLE liD · 2,812) lEI 345'C~ '/Y',O-2' ~ I/0 · 2.92l I El. 396' GLA 6' ~l~,l~l-~v ON EIOTTO~ OF' SEAL. 18,501' ~ 'O' NIPPLE ( 2.75 lO ) IEI,51EI' TLeING TAIL JEI,8~I ' PBTD I, 956'7' L-Be BTR~ · ,6.~; ID, 6. JSi ) GEORGE'S I cou.. , s .v.c I I 344-3323 ADDRESS CITY SHIPPER STATE ZIP ~//'.- <'-'-"~ I DATE;'~'~I.-.?/I~;,'[ TIME .... ~.; ~-./ ,:''-' . .,' - .' ,~.~-' ~,---~ ,--'ll,~ :~ i ADDRESS CITY STATE /--- ./._% ?~:.:: ~;~:;~*~:;~:::i:..:~:?~:.:`:¢~?~Y`~::~:.~{`:=~::~:!¢~!.~`...:....~:...:~.~:...:~;.~..~? :---;;?.~-:~::-':~?:~-~:!?:~:?:~-;-~:~-.:?:'.~[j_;: ~ ATTENTION ~ .-~ ,', ;, . - - PHONE . ; . - .... .: . . .-. ..-_.:f:---- -~.. . SAMEDA¥ · ..~ :.....-:..:.--:..-:::-~: -.. _. ~.: :::,-: ~.:.::;,::--...---:-.:-~ .-:,..:.... ::-:: ::.-:.-:., :: !::'·-;,:::!:;~_: .. . -. -- : : . ....... ; -;- .- , . ' . . -; :" ' :-: :; ...t :!t;.~ : : CASE NO. ONE HOUR -. : ' .--: :: - -':il;:--:'-ti::::-'::;-2~:~:..:..:;'. ~'.:.:'_ i. ~;-:':.~'!~'t:'~;:.~:-': :',"i'¢;:;':'-?~'. . COURT SAME DAY ..... - ' "' .... ' i ..... :' -': ...... '~::i ¢.:-:,_ DOCUMENTS 24 HOUR . : . . . . . . . ' : ~.::-,. :-.- . - . :: ' ': ' · . . .. ;.- -:.- ; :{~: :. ~- ' - OTHER ' . "_ ' .;~ TOTAL . .. - .. .~,~ ... .- .. . .' .- ,_ -.'?:.;...:,.:~:-~.t-~.;~..-.: t ~-. ,-:,'.. ; ' -'"; ..' ' - ~ . · . - -.. . . , .. - . . . . · . ::- [o.-.~ . . :-' . -. - _... - . ~ . ... :-~ : :. ~ ~.¢- - . . .~' ....'., ' .-..l¢. : "' I RECEIVED BY . ./ -, ~ DATE i ZIP [] ONE HOUR / '"-' TIME CONOCO, ]rnc. SCHLUMBERGER WELL SERVICES ~ RE~ TO JUL 2 1990 Pouch 340069 ~udhoe ~a7, A~ 99734-0069 Att~: ~er~e/SheZZe7 3201 "C" Street, Suite 200 Anchorage, AK 99503 ANent;on: Marc Shannon Gentlemen: Enclosed ore.2 BI. prints of the Company CONOCO, Inc. Well C-12 InjectJvJty Profile, Run 1, 7/7/90 Fie;d M~ lne Point Add[tior~o[ prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn:_ George Lamb - OF 2018 PER Counly. Nnrtb Slope State Alaska __l~rints , 1 RF Sepia CONOCO; _Tnc~ 1000 South Pine Ponca City, OK 74603 Attn: .Log L~.brary 1BL prints, 1RF Sepia OXY U.S.A.,..Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685.5600) ~rints, 1RF Sepia _Chevron U.S.A. . 6001 Bo!linger C~_nyon Road _San Ramon, CA_ 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) ~la~ka 0i~ & GasConservat.'~-q. n ~___commjs~J on ~3001Porc~pi~e Drive ' prints prints prints The film is returned to Conoco, Log Library. We appreciate the privilecje of se,wing you. Received .by; , . Date:~ Ve~ truly yours, A[ask~ 0J~ SCHLUMBERGER WELL SERW~orag° STATE OF ALASKA ~'~'"'-KA OIL AND GAS CONSERVATION COMC,-' ~-'~- .ION REPO , OF SUNDRY WELL OF,...'b ,TIONS 1. Operations performed: Operation shutdown Stimulate __ Plugging __ Perforate Pull tubing 'X'- Alter casing' __ Other 2. Name of Operator CONOCO INC. 3. Address 4. Location of w~ 496' FSL, 2027' FEL, SEC At top of productive interval NA ~ effective depth At total depth 2739' FNL, 2857' FEL, SEC. Repair well -X- L5. Type of Well: Development ~ Exploratory __ Stratigraphic ~ Service -.X- 10, T13N, RIOE, U.M. 3, T13N, RIOE U.M. 6. Datum elevation (DF or KB) KB 52 7. Unit or Property name M~_ !n~ pn')hi' 8. Well number 9. Permit number/approval number RE- 1 10. APl number' 50-- 029-2].373 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Totaldepth: measured 10956' true vertical NA Effec.tive depth: measured Z0876' true vertical NA feet Plugs (measured) NA feet feet Junk (measured) NA feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 13 3/8 108' 9 5/8 6067' 7" 10956' measured 10416'-10438'; 10750'-10796'; 10708'-10732'; 1856' for freeze protection as desribed in March 23, 1989 letter) truever~c~7289'-7301'; 7466'-7489'; 7445'-7457' True vedical depth (Last perf Tubing (size. grade, and measured depth) 3 1/2, 9.2 # L-80 BTRS, 10300' Packers and SSSV (type and measured depth): B0T "HB" Packer; 10,242' TRDp-1ASSA SSSV, 687' 13. Stimulation or cement squeeze summary NA I ntervaJstreated (measured) NA Treatment description including volumes used and final pressure NA BOT "2B" Perm. Pkr, 10,476'; RECEIVED NOV o ~ 1989 14. Representative Daily Average Production or Injection Data , . "' Oil-Bbl Gas-Md Water-Bbl Casing Pressure' ~rlC~u~a~r~ Pressure Prior to well operation Subsequent to operation 0 0 1116 Has not been put on injection 0 2606 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations -X" Oil __ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service )ed Form 10-404 06/15/88 Title Date SUBMIT IN DUPLICATE WORKOVER OF'ERATLrONS C-!2 .i... SET PLUG .,T.N W-1 NZF:'F'L.E AT .i..()324' M:[RU, ND TREE, NU BOP, TEST BOP. POOH. WITH 3; ..i./2 'T'UB:i:NG, SCSSV AND SEAl .... [.4.::.,:.~[:.MBL. Y RIEF:'I._.ACE F:ERFORATED JOINT (:)F' TUBING ABOVE THE SSSV. AL. SO, REPLACE PERFORATED JOIN]" OF 3 ~/2" TUBING AT 997"i-'. ~ R!H. WiTH SPEAR TO RETRIEVE "HB" PACKER. REPLACED PACKER AND PBR Wi'TH 1'-"4E~4. HAD PROBLEM t/..Ji'J"H FiLL BEL. OW I:::'ACKER. Fi::i:H MULE SHOE GLJIDE ]-0 C'_EAN (r]UT 'TUB}lNG 'i"0 D-t",.Iii:PF'LE. WAS I",.I0"1" ABLE TO C':LEAN Wi]'.'Fi MULE SHOE, RIH WITH 4 3/4" MLiDD MOTOR. C:LEA. NED DOWN TO TOF' TO PERMANENT PACKER AT !0,475'. HAD PULL. "FIB" DUE TO L. EAK BELOW PACKEF;:.- R!H WITH SEAl._ ASSEMBLY AND "faB" PACKER, STING iN PERi'fiANENT F:'ACKER AT 'I. 0,475' . St:'2T HB PACKER Ai'qD SI-'IEAR OF'F F:'BR. ~ D'.[SF'LACE 1..3.2 PPG I;iL.JDD WiTH !0.2 PPG SODiLJM BROMIDE, 360 BBL 'S. STAB ]'N'TO PBR AND PRESSURE ]"ES]" TUBING "FEi 3(]:.(-)0 PSI AI",.ID ANNL.iLUS 'TO 20()0 PSI .- 8 ..... INS'T'AL.L. ED i ': G/L MANDREL AT I(")~ .......... 17."'-';' AN.r) 9_- ND BOP, NU 'TREE, RDMO. 10. COMF'L. ETE STATE MIT iNSF'EF-:TON. 11. D!SPLAC'E: ANNULUS WITH 15 BBL'S OF DIESEL, .3 1/2" X STATE O~ ALASKA ALASKA OIL AND ~ CONSERVATION COt~tI~E~IOH · IIl~ rlml ..... r~ ~_~o .,,0~L..__ _ ChokI minlfold ~ Tet~ prellVr*~.~ _~0~'_0_ ~(~ ,, ,__ . _- _~: _ _ _ Cb.ok vllv~ : __ ~/~ Nydriu110111~ o~.~ed choke _. ~/~... orlg · kOOC¢ OCT Alaska 0i1 & Gas ConS. Commlsslon j~chofa~e Inlpioto~i ME'MORANDuM State ..,f Alaska AI~AS~ OIL A~ND GAS CONSERVATION CO~ISSION ? TO: Lonnie C Smi ~(;i DATE: Commi s s ioner FILE NO: October 11, 1989 D.BDF.107 THRU: FROM: TELEPHONE NO: _zzchaez T Minde SUBJECT,' Sr. Petroleum Engineer bby Bo D Foster Petroleum insped~'r BOP Test Conoco MPU C-12 Permit No. 85-120 Kuparuk Rv Field Tuesday, October 3, 1989, The BOP test on Rig EWS #94 began at 2:15 ~-~ ~{ciude-d-~:15 pm. As the attached BOP test report shows there were no faiiunCes. The tmr~aded connections have been removed from the choke and kill lines and targeted T's have been installed in the choke manifold as previously requested by reps o~ the AOGCC. in s~zr~mary, I witnessed the BOP Test on Conoco's well C-!2 workover. Attachment 02-001A (Rev. 8~85) STATE Of ALASKA' ALASKA 01L AND CAS CONSERVAT I ON COMM ISS I ON BOPE inspection Report .U Y LOcation (general) General housekeeping Reserve Pit MuD SYSTEMS Trip. tank" pit :gaUge Flow m°ni tor Well Sign Rig Audio BOPE STACK: Annular preventer PiPe.rams Blind-rams Choke 1 i ne valves HCR valve Kill line valves check val ye Test Pressure ~O~.o ft ACCUMULATOR SYSTEM: Full charge pressure D Press after closure Pump incr clos press 200 psig ~- mia Full charge press attained ~/ mia Control s: Master U ¢ Remote~ B1 i nd Switch cover KELLY AND FLOOR 5AF~Y VALVES: / Upper Kelly Lower Kelly Ball type Test pressure Inside BOP / Test pressure Choke manifold L~_~ Test pressure / Number valves ~ psig psig _~sec sec Number flanges / ~ Adjustable chokes ~- Mydraul ical ly operated choke . Test pressure Test pressure TEST RESULTS: Repair or replacement of failed equipment to be made within __ and i nspector/Commission office notified. days Rema r ks: Distribution: - AOGCC Operator Supervisor Inspecto~ 2. STATE OF ALASKA 0 R I 5 I N A [ ALASKA OIL AND GAS CONSERVATION COMMisSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend ~ Alter casing __ Repair well x__ Change approved program __ 2. Name of Operator Conoco Tnc. Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing ~ Variance __ Pedorate __ Other __ 3. Address 3201 C Street Ste 200, Anchorage, AK 5. Type of Well: Development ~ Exploratory ~ Stratigraphic __ 9503 Service .,x_ R10E, UM R10E, UM 4. Location of well at surface 496' FSL, 2027' FEL, Section 10, T13N, At top of productive interval N/A At effective depth N/A At total depth 2739' FNL, 2857' FEL, Section 3, T13N, 6. Datum elevation (DF or KB) KB 52 7. Unit or Properly name Milne Point Unit 8. Well number C-12 9. Permitnumber 85-120 10. APInumber 50-- 029-21373 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 10,956 ' feet Plugs (measured) N/A N/A feet Effective depth: measured true vertical 10,876 ' feet Junk(measured) N/A N/A feet Casing Length Structural Conductor Sudace Intermediate Production Liner Perforation depth: measured true vertical Size Cemented 13-3/8" Measured depth 108' 6067' 10,416-10,438'; 10,750-10,796'; perf for freeze protection as described 7289-7301'; 7466-7489'; 7445-7457' True vertical depth :! ~. ~, .~'., _~ I_ 10956 /'J;~sRa 0ii & Gas Cons~ Comr~-~s~;~on~ Ar~chora~o 10,708-10,732'; 1856' (gast 1~ ~a~ch 23, 1989 lette Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 BTRS, 10300' Packers and SSSV (type and measured depth) BOT "HB" retrievable packer, 10286'; BOT "2B" permanent packer, 10476'~ Camco TRDP-1A SSA SSSV, 1873' 13. Attachments Description summary of proposal ~ Detailed operations program -- BOP sketch ~ 14. Estimated date for commencing operation September 18, 1989 16. If proposal was verbally approved Name of approver N/A Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water In~ection 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,,,~~ Title Senior Production Foreman FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent fOrm required 10- Approved by order of the Commission Original Signed By David W. Johnston Commissioner IApproval No. f_, Approved Copy Returned Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE o e 5. 6. 7. Be e WELL C-12 PROPOSED OPERATIONS Set plug in W-1 nipple at 10324'. MIRU, ND Tree, NU BOP, Test BOP. POOH with 3-1/2" tubing, SCSSV and seal assembly. Replace perforated joint of tubing. Redress seal assembly and SCSSV, RIH with 3-1/2" tubing and SCSSV. Displace hole with 10.2 ppg NaC1-NaBr brine, + 350 bbls. Spot 5 bbls. diesel on top of 3-1/2 x 7" annulus. Stab into PBR, test tubing to 4000 psi, test 3-1/2 x 7" annulus to 2000 psi. ND BOP, NU tree, RDMO. MIT (Note' Communication is thought to be the result of a leaking packer assembly. ) Anchorage i I I March 23, 1989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 Mr. C. V. Chatterton Chairman of the Commission Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Milne Point Unit, Wells C-ii (API 50-029-21321) and C-12 (aPI 50-029-21373) Dear Mr. Chatterton: With reference to your conversation with Hal Stevens on March 21, 1989 please be advised that the Milne Point Unit, Wells C-il and C-12 (injection wells) were perforated as the result of suspected communication between the tubing and annulus. Both wells were perforated using a Kinley Standard Perforator (for 3-1/2 inch tubing) with a .48 inch hole size. Well C-ll was perforated on January 2, 1987 at a depth of 1875 feet RKB. Well C-12 was perforated on January 3, 1987 at a depth of 1856 feet RKB. The communication was determined by utilizing tubing/annulus pressure readings and annular fluid samples. The fluid samples indicated the absence of a diesel pad in the wells. In order to ensure that the wells are freeze protected, the tubing in both wells was perforated one joint above the SCSSV and a mixture of 25% diesel and 75% produced oil was pumped down the backside. Injection was then resumed for several days prior to final shut- in. If you should have any questions please call Bob Soptei or Hal Stevens at (907) 659-6327. Yours very truly, D. F. Rainwater/E. L. Robinson Senior Foreman RJS RECEIVED Alaska.I)ii & Gas Cons. Commission ,-~ ~choragel Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9O7) 564-760O July 17, 1987 Ms. 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 wells No. C-12, C-16 and B-15. If you require additional information concerning these well histories, please contact Mike Zotzky at 564-7623. Yours ver~ E. D. Wilson Sr. Administrative Coordinator DRG/vv C-12, C-16, B-15 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.12- CONFIDENTIAL (7,578'-Kuparuk River) AFE 10-61-1109 API No. 50-029-21373. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 496' FSL, 2027' FEL, Sec. 10, 13N, R10E, Umiat Meridian 6-15: Skid rig. Skid pipe shed & RU. RU Tankcl starting head & 20" hydril & diverter lines, mix mud. PU BHA & service MWD. Function test hydril & diverter valve, test hydril to 100 psi +. Drlg ince in conductor f/39 to 109'. Blugged bit & POOH to unplug bit. Drlg. f/109 to 130'. 6-16: Drlg f/130 to 500'. POOH f/500' to PU Navi-drill. PU Navi-drill & orient. RIH to 500'. Orient Navi-drill & drilling 1/4 f/500'. Navi-drill & survey to 1628'. POOH f/1628' to change bits. Change bit & RIH to 1628'. Drlg f/1628' to 1907'. 6-17: Drlg f/1907' to 255'. POOH to change BHA. LD 8" Navi-drill & PU 9½" Navi-drill, orient & test MWD. RIH to 1400'. Cut drlg line. RIH to 2255' (wash & ream thru Navi-drill run to 2555'). Drlg f/2555' to 3801'. Survey & pump pill. POOH f/bit change, hole tight f/2710' to 1200'). Change bit & check out Navi-drill & Mk~. RIH. 6-18: Change bits & check out MWD. RIH to 3801'. Drlg f/3801' to 4700'. Survey & pump pill. POOH f/bit & BHA change f/4700'. LD Navi-drill 9½", PU new BHA & service MWD. RIH to 628' - bridge - PU kelly & work past bridge. RIH to 2439' - bridge - PU kelly & work past bridge. RIH & ream out of gauge hole f/4591' to 4700' (3 joints). Drlg f/4700' to 5493'. w/surveys. 6-19: Drlg f/5493' to 6090' w/survey stations. Circ & pump pill. Short trip f/6090' to 5322' (hole tight-trying to swab). Circ hole clean. Short trip f/6030' to 4106' (hole conditions good). Circ hole clean & condition MWD for csg run. POOH to run 9 5/8 strap out (no correction). LD BHA. RU csg crew. Run 9 5/8" csg. 6-20: Run 154 jts 9 5/8" 36# K-55 BTRS csg. Float shoe @ 6070', float collar @ 5987', 80 centralizers. RU cmt head & circ inside volumn & pumped 35 bbls Sepiolite @ 11 ppg. Pumped 571 bbls 12.3 ppg Permafrost E cmt w/5#/sk Gilsonite followed by 51 bbls of 15.8 ppg Class G w/3% salt & 1% CFP-2. Displaced w/rig pumps with 459 bbls 9.8 ppg drilling mud. Bumped plug w/2300 psi, floats held, cmt returns to surface 200 bbls. Lost partial returns while displacing w/rig pumps, approx 25 bbls. No top job. ~ 20" diverter & NU BOP stack. RU to test & test BOPE. Test rams, valves, choke manifold, upper & lower kelly valves, inside BOP to 500 & 5000 psi. Tested hydril to 350 and 3500 psi, test witnessed by Doug Amos AOGCC. RD test tools, set wear ring. Strap & PU BHA & orient MWD & Navi-drill. RIH to 5986'. Tag cmt top. Test csg to 1500 psi - 5 psi press drop. -1- Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.12- CONFIDENTIAL (7,578'-Kuparuk River) AFE 10-61-1109 API No. 50-029-21373. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 496' FSL, 2027' FEL, Sec. 10, 13N, R10E, Umiat Meridian 6-21: Drlg cmt & float equipment & clean out rat hole to 6090'. Drlg to 6120'. Leak off test @ 6120' 12.0 ppg EMW. Drlg f/6120' to 6479'. Pump pill & POOH for MWD failure. Service MWD & change out electronics & venting valve. Reorient & surface test MWD & fluid test MWD. RIH, fill pipe @ shoe. Survey & orient. Drlg. f/6479' to 6615' w/directional control. 6-22: Drlg f/6615' to 6669' w/surveys. POOH f/6669' (bit will not penetrate). Change bits & service MWD. RIH to 6669' (fill pipe @ shoe). Drlg f/6669' to 6917' w/surveys (bit will not penetrate). POOH f/6917' & change bits. RIH to 6917' (fill pipe @ shoe). Break in new bit. Drlg f/6917' to 7160'. 6-23: Drlg f/7160' to 9012' w/directional control. 6-24: Drlg f/9012' to 10,269' w/directional control. 6-25: Drlg f/10,269' to 10,760' T.D. 8½ hole. Circ & survey. POOH f/10,269' to 9 5/8" shoe (51 stands) tigh tin spots (no fill). Circ hole clean. POOH f/10,760' for logs (SLM no correction). LD BHA, service MWD & Navi-drill. RU Schlumberger for open hole logs. 6-26: Log run #1 w/LDT-CNL-DIL-GR (logging depth 10,644') need more depth. RD Schlumberger. RIH to 6070' and fill DP. Cut drlg line. RIH to 10,631'. Ream f/10,631' to 10,760'. Drlg f/10,760' to 10,863'. Work no rotary chain (rig is down). Drlg f/10,863' to 10,974'. Curc B.U. POOH f/10,974' for logs. 6-27: Finished POOH f/10,974'. RU Schlumberger, RIH to 10,400 w/LDT-CNL-GR-DIL, POOH installed wheels, RIH w/LDT-CNL-GR-DIL to 10,530', couldn't get any deeper. POOH, RD Schlumberger. RIH to 10,444' reamed 10 444' ' circ and ream to , , to 10,661 RIH to 10,900' 10,974' (hole packing off). Circ and condition hole, POOH f/10,974'. RU Schlumberger for surveys. 6-28: RIH w/LDT-CNL-GR-DIL to 7500', hit bridge @ 7500', POOH, RD Schlumberger. RIH w/open ended DP to 10,974'. Circ and WO Schlumberger slim hole tools, POOH w/DP to 10,557'. RU Schlumberger, POOH to 10,550', RIH w/DIL-GR-SP, to 9682'. Pumped tool down to 10,660', logged 10,660-10,557'. POOH w/wireline. RIH w/DP to 10,745', PU to 10,660'. RIH w/DIL-GR-SP to 9682', pumped to 10,865'. Logged 10,865'-10,660' Tool stuck @ 10,820' 10 810' 10 740' & 10,706' had to lower DP to get loose @ 10,706'. Logging tool not working. POOH. Found rubber stripped off part of bridle. RIH w/DP to 10,839'. Circ, repair logging tools, POOH to 10,745'. RIH w/GR, SP, IL to 9682', pumped tool to 10,745', PU DP & logging tool at the same time, logged 10,745' to 10,655'. POOH, RD Schlumberger. POOH w/DP. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. C No.12- CONFIDENTIAL (7,578'-Kuparuk River) AFE 10-61-1109 API No. 50-029-21373. Ak. Permit No. 85-120. Elevation: 59' KB. Location: 496' FSL, 2027' FEL, Sec. 10, 13N, R10E, Umiat Meridian 6-29: Finished POOH w/open ended DP, RIH w/BHA and bit to 10,851'. Reamed and washed 10,851' to 10,974'. Circ and cond mud. POOH, LD DP and BHA. Change BOP rams. RU csg crew. RIH w/278 j ts 7" 26# L-80 BTR$. 6-30: Wash down 2 jts 7" csg. PU hanger and landing jt, landed csg, 278 its 7", 26#, L-80 BTRS, shoe @ 10,956', float collar @ 10,874'. ECP #1 @ 10,750', ECP # 2 @ 10,652'. Circ csg, mix and pump 40 bbls 12 ppg Sepiolite spacer. Mixed & pumped 300 sks Class "G" w/l% CFR-2 0.3% Halad 24, displaced w/415 bbls 10.2 ppg NaC1-BrC1 brine @ 10.2 ppg. Bumped plug to 3000 psi, set pkrs and checked floats, O.K. RD Halliburton, LD landing jt & csg tools. RU Dresser, run GR-CNL-CCL-Gyro f/surface to 10,899', logged 10,899'-10,100 & 6100-4600'. RIH perforated 10,416-438' w/12 JSPF (264 shots total). Ran guage ring & junk basket from surface to 10,400'. RD Dresser. Changed rams, PU test plug. 7-1: Tested 3½" pipe rams to 5000 psi, LD test jt, RU csg crew. Ran HB-pkr and 329 jts of 3½", L-80, 9.3# tbg, dropped ball, make up hanger & landing joint, pkr @ 10,315'. Wait on ball and attempt to set pkr, dropped 2nd ball & wait on ball. Inflate pkr & shear. Shear-out sub w/3200#, shear w/45,000#. Displace tbg w/diesel, test tbg annulus w/1500#. O.K. LD test jt & tbg tools, install B.P. valve, clean pits. ND BOPs & adapter flange, clean pits & inject, PU tbg hanger, change seals, PU tree. 7-2: NU tree & test to 5000 psi, remove 2-way check & install BPV. RELEASE RIG -3- oD Tom Painter Division Manager Conoco inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and Injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Milne Point Unit. There are 19 active and 5 inactive production wells at Milne Point. ACTi%~: B-3, BZ4A, B-6, B-9, B-10, B-Il, 5-13, B-15, B-16, C-l, C-2, C-3, C-4, C-5A, C-7, C-9, C-13, C-14, C-16 STATIC: B-20, B-21, B-22 C-17, C-18 Ail active production wells will be freeze protected by displacing the top 3000' of the tubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the production casing annulus will be displaced with a diesel:oil mLxture to at least 3000'. Once the shut-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 wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells ' 'V in the Milne Point Unit '".; F ~ ~'~ ~'-' · "-~. L. [ ~L,.' ACTIVE: STATIC' B-5A, B-7, B-I9 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. Though only one well is active at any given time, all wells are capable of produc- _ ing. . A'2A; -B-t; CFP- t ' Wate~ source wells'- wilt be 'freeze protected by displacing the tubing to at lea-st 2000' with a 2:1 prOpyl.ene 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 We'll has been shut-in Since July 1986 due to a tubing leak. ~ne weI!bore is filled with natural gas so that freezing is not a concern,-.but to prevent potential corrosion an inhibitor will be displaced into the well A 50:50 methanol:water mix will be used to carry' the inhibitor. ~= you have any questions on the shutdo~m procedure pleace_ contact Don Girdler at 564-7637. Yours very truly, .. ~~v ~s ion Manage~ / STATE OF ALASKA ALASt. .OIL AND GAS CONSERVATION COMN. ~,.51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ,~ Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) Conoco Inc. 59' KB feet 3. Address 6. Unit or Property name 3201 C Street, Ste. 200, Anchorage, Alaska 99503 Milne Point Unit 4. Location of well at surface 496' FSL, 2027' FEL, Sec. At top of productive interval 3208' FNL, 2757' FEL, Sec. At effective depth N/A At total d_epth 2739' FNL, 2857' FEL, Sec. 10, T13N, R10E, U.M. 3, T13N, R10E, U.M. 3, T13N, R10E, U.M. 7. Well number 8. Permit number 85-120 9. APl number 50-- 029-21373 10. Pool Kuparuk River 11. Present well condition summary Total depth' measured true vertical 10975 feet Plugs (measured) 7578 feet Effective depth: measured :N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor 80' 16" To Surface Surface 6034' 9 5/8" 1875 Sxs Intermediate Production 10922' 7" 300 Sxs Liner Perforation depth: measured 10750'-96'; 10708'-32'; 10416'-38' true vertical 7466'-89'; 7445'-57'; 7289'-301' Tubing (size, grade and measured depth) 3~"2 , L-80, 10510' Packers and SSSV (type and measured r~e~ll'h)SCSSV @ 1873' Measured depth 115' 6070' ~ue Verticaldepth 115' 4704' 10956' 7576' ~ ~et, ?~r. @ I0286'~ ?erm. Pkr. @ i0476 12.Attachments Description summary of proposal~ 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 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~:~.~ ~.~ ~ Title Commission Use Only Date Conditions of approval Notify commission so representative may witness II Approval No./ [] Plug integrity [] BOP Test [] Location clearance Approved by Commissioner / by order of the commission Date S u b r~ it--/'/'"'in '~ri pi i c~t e Form 10-403 Rev 12-1-85 Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 12, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Freeze Protection of the Milne Point C-12 Well Conoco is planning on shutting-in injection and production within the Milne Point Unit. Consequently, we are evaluating every well within the unit to identify potential freezing problems. In the C-12 well the tubing/casing annulus has been periodically bled-off. Recent samples from the annulus indicated the presence of completion brine with diesel. We are concerned that the brine will not provide adequate freeze protection near the surface when the well is shut-in. To ensure that the annulus will not freeze, it is proposed that the C-12 annulus be protected by perforating the tubing above the SCSSV then displacing the tubing annulus with methanol and water. The C-12 well will be repaired when field injection is resumed. If you should have any questions please contact Don Girdler at 564-7637. Yours very~l~I, · R. Fainter Division Manager DRG/vv ~- C-12 Well File ......... ~'~ ~ ~'~ .....~' STATE OF ALASKA ALASK ..)IL AND GAS CONSERVATION COMM._~ION 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 L-X 2. Name of Operator 5. Datum elevation(DF or KB) CONOCO [NC. 52' KB feet 3. Address 6. Unit or Property name 3201C Street, Ste. 200, Anchorage, AK 99503 Milne Point Unit 4. Location of well at surface 496' FSL, 2027' FEL, Sec 10, T13N, R10E, Umiat Meridian At top of productive interval 3208' FNL, 2757' FEL, Sec 3, T13N, R10E, Umiat Meridian At effective depth At total depth 2739' FNL, 2857' FEL, Sec 3, T13N, R10E, Umiat Meridian 7. Wellnumber c No, 12 8. Permitnumber 85-120 9. APInumber 50--029-21373 10. Pool Kuparuk River 11. Present well condition summary Total depth: measured true vertical 10,975 ' feet Plugs (measured) 7,578 ' feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16" To Surface 120' 120' Surface 6035' 9 5/8" 1625 sxs 'E' 6070' 4702' Intermediate 250 sxs 'G' Production 10923' 7''~ 300 sxs 'G' 10956' 7568' Liner Perforation depth: measured 10,416'-10,438'; 10,750'-10,796'; 10,708'-10,732' ' - true vertical 7289'-7301'; 7466'-7489'; 7445'-7457' Tubing (size, grade and measured depth) 3~", L-80, 10,510' :.'.' I~-~-,~.,~.......~ ;-~,,, :2 ~.~'.' !_;,.'~.: , i;;.,:,;':/,~.~, Packers and SSSV (type and measured depth) Retrievable(10,286' ) ;Permanent (10,476 ' ) ;T .R. SSSV(187 12.Attachments Description summary of proposal E~i Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation January 5, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TitleSroProduction Engineer Date 12-9-86 Commission Use Only Conditions of approval Notify commission so representative may witness I ~pprovaINo. ~~~ [] Plug integrity [] BOP Test [] Location clearance ..... ~o-m~missioner Approved by by order of the commission Date /,~.,-~ ,) Form 10-403 Rev 12-1-85 Submit in triplicate ..? MILNE POINT UNIT C-12 ACTUAL COMPLETION SKETCH COMPLETED ON 7-3 1-8,5 NOTES: FMC TUBING HANGER w/ 3 I/z" 'H' BPV PROFILE 1. All mellurlmlntl ire from KDB of Ala~Q United -~-5 2. KDI - 8L = 52° 3. KDI - GL= $5' 4. lillZ, angle 60.2° ~ 10,876' MD ~ I/2"t 9.2~ L-80 Bulfress tubing (2.992" ID, 2.867" drill) G. KOP ~ 500' 8. Slant type hole 7. Min. Ingle NA YES - 1~875' CAMCO TRDP-IA SSA SSSV (2.812" ID) 8. FMC 3 1/8° APl SO00~' tree with 3 1/2" 8 rd. treetop connection. g. Min. restriction 18 CAMCO 'D' Nipple of 10,501' (2.75" ID) 10. APl No. 50-029-21373 I 1. Completion fluid 10.2 ppg NoCI-NaBr CIling end cement Information supplied on casing and cement sketch. I>ERFORATIONS BOT PBR, Seal Assembly 12 SPF, 120° r~'x)~x~, 5" guns (All depths from DIL log 4-27-85) --10,286' BOT 'HB' retrievable pecker (2.89" ID) MIDOLE KUP I0~ 416'- 10,438' MD 7,~89'--?,501 ' TVD LK-2 IO~750'-I0~796' MD 7t466'-- 7,489' TVD 10,;~'4' CAMCO 'W-I' Selective Nipple (2.812" ID) i0r~57' CAMCO 'MMG-2' Gas Lift Mondrel(GLM) LS" volvee (2.92" ID) 10,396' GLM 4 SPF, 0° pl~, 2 I/8" guns {All depths ~ I~L log 4-27-85) LK-I I0, 708'- 10,7~2' MO 7,445'-- 7,4§7~ TVD FRACTURE STIMULATION 7- 19- 85 Middle Kuporuk 75000 lb-,. 16-20 ISP 9 - 5 - 85 Lower Kuporuk 40000 lbs 16- 20 ISP (Screened-out) 404' Blast Joints (39.$4' total length, 4.~.5" OD, ~.0" ID) 1~475' BOT 'CL' Seal A~emb~y 476' BOT '2B' permanent packer (5.875" OD, 4.25" ID) with mill~uf extension (5.0" OO~ 4.4~0" ID) 10,501' CAMCO 'D' Nipple (2.75" ID) 10,510' Tubing toll O~IIIIlilAL 10,876' PBTD (Wirelins tog) 10,956' 7" 26# L-80 BTRS (6.Z78" iD, 6.1§t"dHf~) PRODUCTION LOGS I. R/A Tracer Survey ( I - 25-86) Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 August 27, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Attached are daily drilling recaps for MPU wells B-5A, B-8, B-12, B-14, B-18, B-19, B-21, C-10, C-II, C-12, C-18. Completion reports were submitted by our letter of August 18, 1986. If you should have any questions please call Charles Taylor at 564-7606. Yours very truly, E. D. Wilson Division Administrative Manager CLT/vv Well File RECEIVED ,AUG 2 8 1986 Alaska 011 & Gas Coho. Comml,c, slor~ Anchorage Kuparuk River Field - ,orth Slope Borough, Alaska ,.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 API No. 50-029-21373 Permit No. 85-120 Elevation: 52' KB Location: 496' FSL, 2027' FEL, Sec. 3, T13N, R10E, U.M. 6-15 - Skid rig f/C-16 to C-12. Skid pipe sheds & RU. NU & diverter & mix mud. PU BHA & MWD. Drlg. f/109' to 130'. RIG ACCEPTED @ 2300 hrs., 6-i4-85 Alaska United Rig #3 (0-1-0) Drlg. Foreman: R. Larkin Mud Wt. 8.7 ppg. Visc. 96 Weather: Temp.: 26° Wind: E @ 6 knots Visibility: 4 miles 6-16 - Drlg. f/130' to 500'. POOH f/500'. RIH to 500'. PU Navidrill. Drlg. f/500' to 1608'. POOH f/1628' Change bit & RIH to 1628' Drlg f/1628' to 1907'. ' ' Survey: Depth Angle Direction Depth Angle Direction 536' 1.0° N8½E 1296' 20.3° N4½W 633' 3.1° N3½W 1391' 22.8° N3½W 723' 5.4° N3½W 1485' 25.2° N5½W 813' 8.4° N ½W 1578' 27.6° N7½W 904' 10.6° N ½E 1672' 30.3° N8~W 1025' 13.6° N3½W 1116' 15.2° N ½E 1206' - 17.5° N5½W Alaska United Rig #3 (0-2-0) Drlg. Foreman: R. Larkin Mud Wt. 9.2 ppg. Visc. 77 Weather: Temp.: 39° Wind: SE @ 3 knots Visibility: 70 miles 6-17 - Drlg. f/1907' to 2555'. POOH. LD 8" Navidrill & PU 9½" Navidrill, orient & test ~fWD. RIH to 2255'. Ream thru Navidrill. Run to 2555'. Drlg. f/2555' to 3801'. POOH. Change bit. RIH. Survey: Depth Angle Direction Depth ~ngle Direction 1764' 32.2° N6.5W 2505' 46.6° N5.5W 1858' 34.8° N7.5W 2657' 47.8° N6.5W 1954' - 37.0° N8.5W 2875' 46.6° N6.5W 2041' 39.5° N8.5W 3121' 45.7° N5.5W 2134' 41.5° N5.5W 3306' 45.8° N6.5W 2227' 42.6° N10.5W 3486' 46.2° N5.5W 2319' 43.3° N5.5W 3729' 46.4° N5.5W 2380' 44.4o N5.5W Alaska United Rig #3 (0-3-0) Mud Wt. 9.3 ppg. Weather: Temp.: 31° Wind: NE @ 4 knots Drlg. Foreman: R. Larkin Visc. 70 Visibility: 1/8 mile (fog) Kuparuk River° Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AEE 10-61-1109 Change bits & check out MWD. RIH to 3801'. Drlg. f/3801' to 4700'. Survey & pump pill. POOH f/bit & BHA change f/4700'. LD Navidrill, PU new BHA & service bB~'D. RIH to 628'. PU Kelly & work past bridge. RIH & ream out of gauge hole f/4591 to 4700'. Drlg. f/4700' to 5493' w/surveys. Surveys: ~ Angle 3913' 46.6° 4094' 47.0° 4409' 48.0° 4628' 48.5° Alaska United Rig #3 (0-3-0) Mud Wt. 9.5 ppg. Weather: Temp.: 30° Direction Depth NT.5W 4836' N6.SW 5082' N6.5W 5266' N3.SW 5463' Angle Direction 48.9° N4.5W 47.4° N .5E 47.5° N2.5E 48.8° N4.5E Drlg. Foreman: R. Larkin Visc. 74 Visibility: 5 miles (fog) Wind: ENE @ 14 knots Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 Drlg. f/5493' to 6090' w/survey stations. Circ & pump pill. Short trip f/6090' to 5322'. Circ. hole clean. Short trip f/6030' to 4106'. Circ. hole clean & cond. mud for csg. run. POOH to run 9-5/8". Strap out. LD BHA. RU csg. crew. Run 9-5/8" csg. Survey: Depth Angle Direction 5638' 48.2° N5.5E 5824' 47.4° N5.5E 6050' 46.7° N4.5E Alaska United Rig #3 (0-4-0) Drlg. Foreman: R. Larkin Mud Wt. 9.8 ppg. Visc. 65 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-20 - Ran 154 jts. 9-5/8" 36# K-55 Butt. csg. Float shoe @ 6070'. Float collar @ 5987'. Circ. & pumped 35 bbls. Sepiolite @ 11 ppg. Pumped 571 bbls. 12.3 ppg. Permafrost E cmt. w/5#/sk Gilsonite followed by 51 bbls. of 15.8 ppg. Class G w/3% NaC1 & 1% CFR-2. Displaced w/459 bbls. 9.8 ppg. drilling mud. Bumped plug w/2300 psi., floats held; cmt. returns to surface. CIP @ 1715 hrs. ND 20" diverter & NU speed head & BOP stack. Test BOPE: rams, valves, choke manifold upper & lower Kelly valves, inside BOP to 500 & 5000 psi; hydril to 380 & 3500 psi. Test witnessed by Doug Amos AOGCC. PU BHA & orient M~ & Navidrill RIH to 5986' 1500 psi. · . Test csg. to Alaska United Rig #3 (0-5-0) Drlg. Foreman: R. Larkin Mud Wt. 9.8 ppg. Visc. 46 ~uparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-21 - Drlg. float equipment & clean out to 6120'. Leak off test @ 6120' 12.0 ppg. EMW. Drlg. f/6120' to 6479'. POOH for MWD failure. Service MWD & change out elec%ronics & venting valve. RIH. Drlg f/6479' to 6615'. Survey: Depth Angle Direction __ 6201~ 47-3° N3.5E 6358' 50.6° N3.5E 6517' 51.8° N1.5E Alaska United Rig #3 (0-7-0) Drlg. Foreman: R. Larkin Mud Wt. 9.9 ppg. Visc. 44 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C ~o. ~j--_ CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-22 f b~f~ f/6615'--to 6669'. POOH f/6669'. Change bits & service MWD. RIH to 6669' Drlg. f/6669' to 7160' Surveys: Depth Angle Direction 6517' 51.8° N1.5W 6640' 52.6° N5.5W 6827' 54.3° N4.5W 6985' 55.5 N5.5W 7110' 55.5° N6.5W Alaska United Rig #3 (0-8-0) Mud Wt. 10.0 ppg. Drlg. Foreman: R. Larkin Visc. 42 6-23 - Drlg. f/7160' to 9012'. Surveys: Depth Angle Direction 7297' 54.9° N9.5W 7515' 55.4° N9.5W 7703' 57.1° N8.5W 7889' 55.6° N9.5W 8046' 53.8° N10.5W 8265' 53.2° N10.5W 8545' 54.6° Nll.5W 8733' 56.2° Nll.5W 8890' 55.2° N10.5W Alaska United Rig #3 (0-9-0) Mud Wt. 10.2 ppg. Drlg. Foreman: R. Larkin Visc. 46 6-24 - Drlg. f/9012' to 10,269'. Surveys: Depth ~ngle Direction 9077' 53.3° N9.5W 9294' 53.9° N9.5W 9481' 52.2° N6.5W 9668' 52.3° N7.5W 9919' 53.3° N9.5W 10,139' 54.9° N8.5W Alaska United Rig #3 (0-10~0) Mud Wt. 10.3 ppg. Drlg. Foreman: R. Larkin Visc. 40 Survey: Depth Angle 10,389' 56.2° 10,670' 59.3° Alaska United Rig #3 (0-i1-0) Mud Wt. 10.5 ppg. Direction N9.5W N9.5W Drlg. Foreman: R. Larkin Visc. 48 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-26 - Log run -#1 w/LDT-CNL-DIL-GR @ 10,644'. RD Schlumberger. TIH to 6070' & fill D.P. Cut drlg. line & TIH to 10,631. · Ream f/10,631' to 10,760'. Work on rotary chain (rig is down). Drlg. f/10,863' to 10,974'. Circ. BU. POOH f/10,974' for logs. Alaska United Rig #3 (0-12-0) Drlg. Foreman: R. Larkin Mud Wt. 10.4 ppg. Visc. 39 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-27 - Finished POOH f/10,974'. RU Schlumberger. RIH to 10,400 w/LDT-CNL-GR-DIL. POOH. Installed wheels. RIH w/LDT-CNL-GR-DIL to 10,530', couldn't get any deeper. POOH. RD Schlumberger. RIH to 10,444'. Reamed 10,444' to 10,661'. RIH to 10,900'. Circ. & ream to 10,974. Circ. & cond. hole. POOH f/10,974'. RU Schlumberger. Now RIH w/LDT-CNL-GR-DIL. Alaska United Rig #3 (0-13-0) Drlg. Foreman: D. Mountjoy Mud Wt. 10.4 ppg. Visc. 43 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-25 - Drlg. f/10,269' to 10,760' TD 8~ hole. Circ. & survey. POOH f/I0,760' to 9-5/8" shoe. Tight in spots. Circ. hole clean. POOH for logs. LD BH_A. Service P~ & Navidrill. RU Schlumberger for open hole logs. Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIBi (10,641' - Kuparuk River) AFE 10-61-1109 6-28 - RIH w/LDT-CNL-GR-DIL. Hit bridge @ 7500'. POOH, RD Sclumberger. RIH w/open-ended DP to 10,974'. POOH w/DP to 10,550'. RU Schlumberger. POOH to 10,550'. RIH. Logged (DIL-GR-SP) 10,660'-10,557': 10,865'-10,660' logging tools sticking. Re Log 10,745' to 10,655'. POOH. RD Schlumberger. POOH w/DP. Alaska United Rig #3 (0-14-0) Drlg. Foreman: D. Mountjoy Mud Wt. 10.5 ppg. Visc. 45 Kuparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 6-29 - Finished POOH w/open-ended DP. RIH w/BHA & bit to 10,851'. Reamed & washed 10,851' to 10,974'. Circ. & cond. mud. POOH. LD DP & BHA. Change BOP rams. RIH w/278 jts. of 7", 26# L-80 Butt. csg. Alaska United Rig #3 (0-15-0) Drlg. Foreman: D. Mountjoy Mud Wt. 10.5 ppg. Visc. 45 6-30 - Shoe @ 10,956'; float collar @ 10,874'; ECP #1 @ 10,750'; ECP #2 @ 10,652'. Circ. csg., mix & pump 40 bbls. 12 ppg. Sepiolite spacer; 300 sks. Class G w/l% CFR-2 .3% Halad-24; displaced w/415 bbls. of 10.2 ppg. NaC1-BrC1 brine; bumped plUg to 3000 psi; set pkrs; floats OK. Ran GR-CNL-Gyro f/surface to 10,'899'; logged 10,899'-10,100' & 6100'-4600'. RIH perforated 10,416'-10,438' w/12 JSPF. Ran guage ring & junk basket from surface to 10,400'. Changed rams. Alaska United Rig #3 (0-16-0) Drlg. Foreman: D. Mountjoy 7-1 - Tested 3~" 2 pipe rams to 5000 psi. Ran HB-pkr. & 329 jts. of 3½", L-80 9.2# tbg.; pkr. at 10,315'; dropped ball; inflate pkr. & shear shear-out sub w/3200#, shear pbr. w/45,.000#. Displace tbg. w/diesel; test tbg. annulus w/1500#--OK. Install BP valve. ND BOPs. PU Xtree. Alaska United Rig #p (0-17-0) Drlg. Foreman: D. Mountjoy ~uparuk River Field - North Slope Borough, Alaska W.I. - 52.05955% Milne Pt. C No. 12 - CONFIDENTIAL (10,641' - Kuparuk River) AFE 10-61-1109 7-2 - NU Xtree & test to 5000 psi. Install BPV. RIG RELEASED 0800 hrs. 7-1-85. Alaska United Rig #3 (0-18-0) Drlg. Foreman: D. Mount~mv STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMI~;SION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)~( OTHER 4. Location of Well 496' 2. Name of Operator 7. Permit No. Conoco Inc. 85-120 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 50-029-21373 9. Unit or Lease Name Mili~e Poii~t Unit FSL, 2027' FEL, Sec. 3, T13N, RIOE. U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB I 6 . Lease Designation and Serial No. 47433 12. 10. Well Number C-12 I 1. Field and Pool Kuparuk' River Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other X[~] Pull Tubing [] Other [] Pulling Tubing [] (Note' Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as a water injection well on 12-4-85, and its status should be changed from suspended to service and classified as a water injection well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ .,,,////' Sig?ed~-~ four C ~_,--/~'~'-~'~_- Title The space b- ommission use · . ./ Condlt,ons~of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate N SI M PP'-'q LAGOON SCALE IN ~IL~S CONOCO MILNE P01N'T UNIT EXISTING DE.VE';.OPMENT NOTES: I. STATE PLANE CO-ORDINATES ARE ZONE ,4. Z. ALL GEODETIC POSITIONS ARE BASED ON N A.D. ICJZT. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. LOCATION IN SECTION STATE NORTHINGS FRO~ S. LINE F'~OM E. UNE 1068' 2205' 496' 2027' 4. LOCATED WITHIN SECT. 10, T 15 N, RIOT, U.M.,AK. 6, 029,351.58 6, 028, 280.21 C'13 ~ 954' 2169' 6,029,237.39 839' __l C-16 I 724' 2134' ' 2098' 610' 2063' 1287 ' 2273' 43?' 2219' C-19 I 1468 ' PLANE CO-ORDS. EASTINGS 558,255.76 558, 438.90 558 , 292.56 6 ,029 , 007.58 ___6, 028, 894.48 6, 029,569.69 __, , 028, 7i9.772 6, 029,749.88 __ CERTIFICATE OF sURvEYOR 55 8";~29 .o 6-' 558, 558, 402.27 5'58, 185.84 558, 248. 260 558, 128.09 ' ' GEODETIC LATITUDE ?0c) 29' 26. 894" N. 70 o 29' 21.260" N T0029' 25.768" N. '-'?0°29' 24.63g" N. 70° 29' 23.502" N. 70° 29'22.587"N 700 29' 29. 044" 70° 29'20. 680" 713° 29' 30.821" POSITION 149°31'25'543"W' I 6.1 ~ ~ d.B.S. 149°51'20.280"W J II -I-85 J.H. 149e~1'~4.~6"~ J 6.1, 85 J.~S. 14~3l' aZ. ~74 "W. J " 149°~1'21.557" W. J 11'1-85 J 149°~1'~550" W.J 11-9-85 L.0. 149° 51' 25. 909" W 149031'29.208" J 11-10-85 L.0. I FIELD BOOK _ 22 -85 22 - 85 22 - 85 46 - 85 46 - 85 John R. Kemp Manager of Alaskan Operations Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 September 27, 1985 Mr. Robert Burd, Director U.S.E.P.A. Water Division, Region X 1200 Sixth Avenue, M/S 409 Seattle, Washington 98101 Dear Mr. Burd: Attached please find completion report§ for Milne Point Unit injection wells B-7, B-8, B-12 and C-12. Also included are wellbore diagrams and geophysical logs for the subject wells. Ail four wells were issued emergency permits in accordance with 40 CFR 144.34 (a) (3) on December 21, 1984. Completion reports for other permitted Milne Point wells will soon be submitted. Please call Rod Schulz at (907) 564-7600 if you have any questions. ~Y°urs very tr~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RECEIVED OCT 0 1985 Alaska Oil & Gas Cons. Commissio. Anchorage ;,.~-~..D STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, 0C 20460 ~,~ ~-'-a'~ '"~ COMPL,-TION REPORT FOR BRINE DISPOSAL, '~' '--'~ "--~ HYDROCARBON STORAGE. OR ENHANCED RECOVERY WELL NAME AND ADDRESS OF EXISTING PERMITTEE NAME AND ADDRESS OF SURFACE OWNER CONOCO, INC. 3201 C Street, Suite 200 STATE OF ALASKA Anchorage, AK 99503 Form Al)l~roved OMB No. 2040-0042 Approval exo~res 9-30-R6 LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT -- 640 ACRES III Iil lt-t iiF-- --l,,ll Ii! III 111 ill _II.,l 111 Iil Iii !11 !11 III iil STATE COUNTY IPERMITNUMBER AK North Slope Borough AK-2R0081-E SURFACE LOCATION DESCRIPTION SW '~OF SW ~OF SE % SECTION 10 TOWNSHIP 13N RANGE 10E LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILUNG UNIT Surface 496ff S Location . from (N/S) Line of quarter section and202~, from(E/W) ~.. Line of quarter section WELL ACTIVITY TYPE OF PERMIT Brine Disposal [] Individual r~ Enhanced Recovery [] Area I-~ Hydrocarbon Storage Number of Wells ~ 2 2 Anticipated Daily Injection Volume (Bbls) Average I Maximum 2000 10,000 Anticioated Daily Injection Pressure (PSI~ Average I Maximum 1900 2500 Type of Injection Fluid (Check the appropriate block(si) [] Salt Water r'~ Brackish Water [] Fresh Water r-i Liquid Hydrocarbon [] Other i Date Drilling Began i Date Well Comoleted 6/15/85 I 7/2/85 Estimated Fracture Pressure of Injection Zone · 75 psi/ft Date Drilling Completed 6/26/85 Injection Interval Feet to Feet 10,416 ! 10,796 Depth to Bottom of Lowermost Freshwater Formation (Feet) 3,100' (See UIC Permit) 1 Lease Name I Well Number Milne Point Unit I C-12 Name of Iniection Zone Kupar uk River Permeability of Injection Zone 60-300 Porosity of Injection Zone 20% CASING AND TUBING CEMENT HOLE OD Size 'vYt/Ft -- Grade -- New or Used Depth Sacks Class Depth Bit Diameter 13-3/8" 48#, H40, New 108' To Surface Arctic Grad< +_128' 17-1/2" 9-5/8" 36#, K55, New 6070' 1625 Permafrost 6090' 12-1/4" 250 Class G 7" 26#, L80, New 10,956' 300 Class G 10,974' 8-1/2" 3-1/2" 9.2#, L80, New 10,338' (tubing) INJECTION ZONE STIMULATION WIRE LINE LOGS LIST EACH TYPE Interval Treated Materials and Amount Used L~ Types Logged Intervals 10750-96 1217 bbls of hydraulic frac Dual Induction - GR 10,300 - 10,788 slurry LDT-CNL 10,300 - 10,614 GR-CNL-CCL 10,151 - 10,805 and 4500' - 6025' 10416-38 75,000 lbs of sand and 966 bbls of fluid Comolete Attachments A -- E listed on the reverse. CERTIFICATION I certify under the penalty of/aw that i have personally examined and am familiar with the infor~nAti.o.n submitted in this document and all attachments and that. based on my inquiry of those ~.~U~i~, immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. ! am aware that there are sicnificant penaities, for submitting fa/se information, ~n~lud~g: the poss/h/lity of f/ne and/mpr/sonment. (Ref. 40 CFR 1 ~4.32). NAME AND OFFICIAL TITLE/Please type or print) JOHN R. KEMP Manager, Alaska , , EPA Form 7520-1 0 (2-E4) Operations Si[ n C - 12 .ATTACHMENTS A See attached diagrams. B. Pressure tested 9 5/8" casing to 1500 psi for 30 minutes with only 5 psi bleed-off (within regulatory requirements). Pressured up on tubing to 3200 psi to set packer. Pressure tested tubing- casing annulus to 1500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5000 psi for 10 minutes with no bleed-off. C. A report was submitted on May 15, 1985 which was approged on June 21, 1985. D. No defective wells. E. Included are prints of the DIL-IRT/GR and LDT/CNL/GR/CAL. RETAIN THIS SECTION FOR YOUR RECORDS RE C-12 CONOCO, INC. CN/MS 1 PRINTS 0 NEG. 1 SEPIA PRINTS NEG. SEPIA .PRINTS NEG. SEPIA PRINTS NEG. SEPIA ATT: WILLIAM VAN ALE SIG.NED Alaska ~ATE ~,,,,~ion , John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (go7) 564-7600 August 19, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No. C-7, C-9, C-ii, C-12, C-13, C-14, C-15, and C-16. If you require additional information concerning these completion forms, please contact Kent Stolz at 564-7641. Very truly yours, J R. Kemp~ ~laskan Operations KJS 5/w RECEIVED AUG 2 0 ]98§ Alaska 0il & Gas Cons. Commission Anchorage ?--'--- STATE OF ALASKA -~'"" ALASK/--. _~,-. AND GAS CONSERVATION C ..,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE~ 2. Name of Operator 7. Permit Number Conoco Inc. 85-120 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, Alaska 99503 50-029-21373 4. Location of well at surface 9. Unit or Lease Name 496' FSL, 2027' FEL, Sec. 3, T13N, R10E, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 3208' FNL, 2757' FEL, Sec. 3, T13N, R10E, U.M. C-12 At Total Depth 11. Field and Pool 2739' FNL, 2857' FEL, Sec. 3, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. muparuk River Field 52' KBI ADL 47433 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116' No' of Completions 6-14-85 6-26-85 7-1-85 N/A feet MSL 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10975' (7578') 10899' (7541'~ YES[~] NO[] 1'937 feetMDI 1800'-+ 22. Type Electric or Other Logs Run LI~T-¢.MI .-T~TT .-CR- 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9 5/8'~ q~t~ ~_~ n 6070' ~¼" 1625 °~'° Pcrmafrc~t ........... ' 250 ~ Class G 7" 269~ L-80 0 10956' 8~" 300 sks Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3~"~ ,9.2~/, L-80 10338 ' 10315 ' 10416'-10438' (M. Kup) 12 SPF, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ I OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. : Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~ 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. D~PT~I- GOR-, and timber'ach Phase. I KA 4720' 3793' MA 5146' '4080' NA 5522' 4332 ' OA 5753' 4487' M. Kuparuk 10415' 7289' Laminated Zone 10439' 7302' L. Kuparuk 10710' 7446 ' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete 'and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in-item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ALASKA. UNITED DRILLING RIG NO. 3 : LIQUID MUD SYSTEM C~'PACITIES ACTIVE SYSTEM , ~. I 5a, ou trap ..... 6bbl ' : : ~' ~": f Desilccr suBion: 55~bbl Solids removal run.ion ,:,. . , 237bb1 ' ' , . 'Mud,Tan~ ~O. I. .... e p6mp~ hP r',; , ~.s~,,o..: : , , 'MudTankNo. 4 each: 6"x 6"c ntrifugal ,75 " .-, ,..~,~,~ . ',~AC~IVE StS~EM ~O~AL ' '-' 'l~S bbl ' ~'~' ' ' ITRIP~ANK ".', ' ' I50'bbl ,';'(Ca~blated 4~elow tank.topi ' , I G e~ch: Li~htnin' mixers, 5 hp. ~ ,., ..... . .~' .... ~g~I[Oka' Work~n~ Pressure 10,: O0 ps~ ~/'~{2)~ CR : :.j ; ~ ..,.. ,. Choke (1) Type -' (2) Manual::-~ ~ "." · ~ :~ ~..~ ~ , -_, ~,,. Choke (2) Type (1)~ g'fltoma"Z~c ~'? ."~ ~ ".-' JOB NUMBER A0685G0317 SURVEY BY B JAHN Eastman/ Whipstock A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TiONA i. SURVEY CONOCO, I~.~C. COMPANY Pad C, Well Number: 12 WELL NAME Milne Point, North Slope, Alaska LOCATION TYPE OF SURVEY Gyro Multi-Shot RECEIVED Alaska Oit & Gas Co,s. Cornmissior~ Anchor.3..,?e OFFICE Anchorage, DATE 2 8-JUN-8 5 Alaska Eastman (907) 563-3650 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 Date: August 7, 1985 Conoco, Inc. 3201 C Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad C, Well No: 12 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 28-JUN-85 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: A0685G0317 Atten: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the orginal and one copy of the Gyro Multishot survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 Copy delivered to drilling for 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 future. rely, Technical Coordinator cc/file cc: Phil Salvador - Conoco West Coast & Alaska Division O.G. Kiel - P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco %- William Van Alen- Alaska Oil & Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. Concord Office Dale Bossert - Champlin Petroleum Co. C.E. Seery, Jr. - Reading & Bates Petroleum Co. Neil Buttram - Cities Service Oil & Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide CONOCO~ INC:. PAD C:, WELL NO: 12 GMS JOB NO: AO685G0317 MII..NE PT. , NORTH SLOPE, ALASKA GMS, 0-108£)0 MD, SI. IRVEYOR: B' JAHN, DATE RI..IN: 28-JI..IN-85 CAMERA NO: 7':-/, $/O DEG A/LI NO: 144:3, GYRO NO: FORESIGHT: N53 30E VERTICAL SEC:TI ON C:ALC:UI_.ATED IN F'LANE OF F'RCIF'OSAI_ DIRECTION: N 5 DEG. 31 M'[N. W REC:ORD OF SL~RVEY RADIUS OF CURVATLIRE METHOD Eastman Whipstock A PETROI. ANE COMPANY '_:ONID CO ~ I NF_:. ='AD C, WELL NO: 12 GMS "III_NE PT. , NORTH 81...OPE~ AI..ASKA JOB NO: AO/:,85GO:B1.7 COMF'UTAT ! ON T I ME DATE :10: 42: 22. 3 .1 d LI L.- ,: ..... PAGE NC!. ~ i TRUE ~IEASURED DRIFT DRIFT COURSE VERTICAl_ VERTICAL SI..IBSEA R E C: T A N G LI i_ A R C L 0 S U R E DOGLEI DEPTH ANGLE DIRECTION I,.ENGTH DEPTH SECTICIN TVD C 0 0 R D I N A T E S DISTANCE DIRECTION '.--;EVERI' FEET D M D FEET FEET FEET FEET FEET FEET D M DG / 1001 0. 0 0 0 0. 0.00 0.00 -52.00 0.00 0.00 0. 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'-'1 '--' ._, .... -- . .=...IB.:,EA R E C T A N O U L A R C L 0 o U R E r'~OGL.E( DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION TVO C 0 0 R D I N A T E S DISTANCE DIRECTIF~N¢'F.=.._VERI] FEET D M D FEET FEET FEET FFE'F FEET FEET F.~ M [:11'_.; / 100F 3000. 45 15 N 6 W 3100. 45 0 N 5, W 3200. 45 15 N 5 W · :,..,00,. 45 1 ...,"-' N 5 W 3400. 45 15 N 6 W 100. 2603.49 1185,. 51 '2551.49 1180. 19 N 100. 25,74.04 1257.37 2622.04 1250.66 N 1 O0. 2744.60 13;7:9.2:2: 2692.60 1321.20 N 100. 2815.00 1399.25 2763.00 1391.95 N 100. 2885.40 t470.26 2833.40 1462.64 N 122.59 W 11:-36.54 N 5 56 W 130.00 W 1257.4('.) 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'?1 57474.60 N 100. :3913.82 256 .1.. 8:..: 3:5:61.82. 2548./:.9 N 100. 3980.7:_'4 26:36. 15 :3'P:.--..:8.7:3 2622. :>.,6 N 100. 404-8.29 2709.72: 3995,. 29 2695,. 54 N 100. 41 tG. 49 27:32.5:3 4064.49 2769.67 N lC)C) 4184. :2:7 285~ .~4 4.132 37 --,,c: . ....... ~._43 09 N 1 O0. 4251.2:3 29:29.2 l 4199.2:3 2917. :35_-, N 23'-?'.84 W 2:2&,4.83 N 5 54, W 2:'~'-"7 95 W 2:2::'::'.~ c)¢) 1'4 5 .... . . ,m _ . · . . ._1.'% . 247.07 W 241:2:.:3.1 N 5 tS:E: W 254 1 ...... '~ W 24.:5:'7 /" '-" N = .=i'.:'W . .. ,.., ~2_ .. ~... 2'.60.02 W '---.'5A~.91 N 5 50 W 264. = .... _ _ ..:,5, W 26:5:6 ~7 N .=, 4A W 267, 1`5: W 2709.74 N 5 .'2:9 W 2/.:,7.77 W 27:=.:2.5:2: N 5 31 Icj 25,./-., 49 W '-"-'='=' · - -"': .............. N 5 21 W 263.89 W 2929.27 N 5 1. 0 W 0.25 0.7L:: 0.74 0.74 0.74 1.78 0.7:2: 1·55 1.00 5500. 48 15 N 2 E 5600. 4:3 0 N 4 E 5700. 48 0 N 4 E 5800. 47 30 N 4 E 5900. 47 0 N :3 E 100. 43 .1.7.71 300:7:, .5::7: 4265.71 2992.06 N t 00. 4384.46 :5:076.96 43:32.46 3066.42 N 100. 4451.37 315o.25 4399.37 3.1.40.55 N .1. 00. 45 ! :3./:.0 322:3.25 4466.60 32 l 4.39 N 100. 45:36.49 :::'..--'.95.78 45:2:4.49 .'2::287.69 N 261.29 W :300:3.45 N 4 59 W 257.39 W :3¢')77.2c) N 4 4:3 W 252.20 W 3150.66 N 4 35 W 247.04 W 2:223. :E:7 N 4 24 W 24:2.56 W :5::.796. 62 N 4 13 W 0.25 1·51 0.00 0.50 0. :2:.p Eastman A F~.'FRO~ANE COMPANY _-:ONOCO, INC:. PAD C:~ WELL ]' NL. 12 GMS 9ILNE PT. NORTH SL'OPE ALA.:,K.A ,_lOB NO: -'".=, ~ - '" A06,:,.. (] (J._', 17 C:C~MPUTATION TIME DATE l~'' ":":' 31-,IlJL-:R5 J.42:.~.~ .... PAGE NO.. 3 TRUE MEASURED DRIFT DRIFT COURSE VERTICAl.. VFRTICAL SUBSEA R E C T A N G LI L A R C: L 0 S; U R E DOGLE~ DEPTH ANG~..E DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE .DIRECTION SEVERI' FEET B M D FEET FEET FEET FEET FEET FEET D M DG/1001 6000. 46 30 N 4 E 6100. 46 30 N 4 E 6200. 46 45 N 4 E 63£)£). 48 30 N 2 E 6400. 49 45 N 0 E 6500. 51 30 N 3 W 6600. 52 0 N 5 W 6700. 52 30 bl 6 W 6800. 53 45 N 8 W 6900. 54 15 N 7 W 100. 4655.00 3367.71 46,03.0£) 3360.39 N 100. 4723.84 3:439.25 46,71.84 3432.75 N 100. 4792.52 35!0.94 4740.52 3505.26 N 1£)0. 4859.91 3583.?~ 4807.91 3579.03 N 100. 4?25.35 3659.11 4873.:~5 3654.62 N 100. 4988.79 3736.21 4936.79 373]. 89 N 100. 5050.7£) 3814.71 4998.70 3810.22 N 100. 5111.92 :3893.78 505'2.92 3888.92 N 100. 5171.92 :9973.74 5119.92 :~968.32 N ] 00. 52.]:0.70 4()54.59 5; 78.70 4048.52 N 238.11W 3368.81 N 4 3 W 233.05 W 3440.65 N 3 53 W 227.98 W 3512.67 N 3 43 W 224.11W 3586.04 N 3 35 W 222.7~ W 3661.41 N 3 2~ W 224.82 W 3:738.65 N 3 27 W 230.:90 W 3817. 17 N :B 28 W 237.87 W 3:F:96.19 N :3 3(])W 247.62 W :3976.03 N :3 34 W '~'~'=' 1 E: W 4~'~5/-, 75 N :3 c:o W ..,... ~.l. .... . ,_ .. 0.88 0.00 0.25 1.96 ~0 1.6._, 0.94 2. £):3 0.95 7000. 55 0 N 8 W 7100. 55 15 N '? W 7200. 54 15 Iq 9 W 7300. 54- 15 N 11 W 7400. 54 30 Nll W 100. 5288.59 41:36.08 5236.59 4129.36 N 100. 5345.77 4218.01 5293.77 4210.51 N 100. 540S:. 49 4299.53 5351.49 4291.16 N ; 00. 546!. 91 4F:80.43 54£)9.91 4371.08 N l () 0. ~ ~'-., r~ ...... · . ..... 1 A_ -44.4, 1 . .'-'=:,._, .~ 46:'--:. ..... 1A 44.~0.88 N · -:,/. c. 8'.-~ W 4.1:38 10 hi :3 4:3 W 280.95 W 4219.87 Ix! :3 4? W 29:3.7:3 W 43£).l. :,-::1 N :3 55 W :307.82 W 4:38.1.. 9 ! hi 4 2 W 3;--.':3, :33 W 4-4/::,2.61 N 4 9 W 1.11 0.86 1.0C) 1.6,2 0.25 7500. 54 45 N 10 W 7600. 55 0 N !1 W 7700. 56 45 N 10 W 7800. 57 15 N 10 W 7900. 55:30 N 10 W 8000. 54 45 N 11W 8100. 53 30 N 11W 8200. 52 45 N 11W 8300. 53 0 N 1] W 8400. 52 45 N 12 W · 5 '-'. _ 5526 .... 100 5... 7,.-, 05 4542.57 ¢)~ 4531.04 N 100. 5 6. :--: 5..~,':~ 4/-, 'F: 4. (') ~q ~' =- "-' '-, ~ 9 4611 46 N ._ .. ...... , ..I ..') ,'~ ~, . - . ~ 00. ~ 69 ~ . 68 4706,. 51 5639. E, 8 4692.86, N 1 ('x')_.. 5746 . l ..~ 47'9c). _, 12 5694.. . 1 ...., '= 477S._. 4.5 N 100. 5:::('); .... , :'-'._, ~ 487:3 , 1':'.., ~1749. .52 ~,._~°S~, .45 N 100. 5858.70 4954.86 5806.70 -4938. 11 N 100· 5917.30 5035.52 5865.30 5017.6,5 N 1 (') ..... ('). ?, 977 . :31 5115. 15 .=, .... '~,. '.-75 · :_E: 1 ?,_ ~-),p/-,_. .1. ,_-, ~', N 100. 60:37.66 5!94.52. 5985.66 5174.45 N 100. 6078.02 5273.82 6046.02 5252· 58 N 338. 19 W 4.543.6,5 N 4 16, W :--:53.0'2 W 4624.96 N 4 '2:3 W :'-:68. 17 W 4707.28 N 4 29 W 382.74 W 47'P0.7/_-, N 4 3:5 W 397.20 W 487:--:. 66 hi 4 40 W 412. 15 W 4'255.2:=: Iq 4 46, W 427.61 W 50:35.84 N 4 52 W 442.87 W 5115.38 N 4 58 W 45:E:.09 W 51'74.69 N 5 4 W 47.:q. 'P 8 W 527:3. 'P'2 N 5 9 W . r i"t. I 0.86 ~ . 94 0.50 1.25 0.75 0.25 0.84 8500. 54 0 N 1'-' W~ 8600. 54 45 N 11 W 8700. 55 15 N 12 W 8800. 56, 0 N 12 W 8?00. 54 45 N 11 W 100. 6157.68 5353.56 6105.68 533~.08 N 100. 6215.92 5434.40 6163.92 5410.73 N . . ~- - .:i,: 87 622 .._. 100 6.27 :F.: ~ ~.-: ....,15. !. c, 8 , 5491.0(') N 100. 6:329.74 5597. E:8 6277.74 .=.,571.73 N 100. /_-,386,. 56, 567:9.7; 6:334.56, 5/_-,52. :'::7 N 490.67 W 5353.62 hi 5 16 W 506.87 W 54:34.42 N 5 21W 523.21W 5515.87 N 5 27 W 540.37 W 55~7.88 N 5 32 W 556,.77 W 5679.73 N 5 38 W 1.25 1.11 0.96 0.75 1.50 Eastman ]:ONOCO, INC. "-'AD C~ WELL NO: 12 GMS 4ILNE PT. , NORTH :~[.OPE, ALASKA dOB NO: AO685G0317 COMPUTAT I ON T I ME DATE I c).: 42: ~'"" 31 -,JUL-85 PAGE N;]~ 4 TRUE ,-1 ,-' _ DOGL.E( ~IEASURED DRIFT nRIFT COURSE VFRTICAL VERTICAl. .=,_IB.=,EA R E C T A N G U L A R C L 0 S II R E DEPTH ANGL.E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E :S DISTANCE DIRECTION SEVERI] FEET D M D FEET FEET FEET FEET FEET FEET D M DG/100F 9000. 54 15 N 9 W '~100. 53 0 N 9 W ?200. 53 15 N 8 W ~300. 53 30 N 8 W 9400. 53 0 N 8 W '~500. 51 30 N 7 W 9600. 51 45 N 7 W ~700. 52 0 N 7 W 9800. 52 30 N 7 W 'F.~900. 52 45 N 8 W 100. 6444.6:3 5760.87 6392.63 5732.54 N ~ 00. 6503. ?3 5:E:4 I. 24 /:,451. 93 5812.06 N 100. 656:3.94 5921.12 6511.94 5891.17 N 100. 662:3.60 6001.3(:) 6571.60 5970.65 N ..... '~ 66:31.4:3 6047.99 N 100 AGR3 43 6081 .... , 1 O0. 6744.65 616£). 37 /:,z..-,92./:,5 6128.38 N 100 6806.73 6238 74 .:,7... 4 73 620~-, 19 N 100. 686:::. 47 6317.38 /",816.47 6284.27 N 100. 6929.69 6396.42 6877.6':.--~ 6362.75 N 100. 6990.40 6475.84 6938.40 6441.54 N 570.91W 5760.~0 N 5 41W 583.50 W 5841.28 N 5 44 W 5~5.33 W 5721.18 N 5 46 W 606~4~ W 6001.37 N 5 48 W 617.65 W 6081.44 N 5 50 W 62.7.S.~7 W 6160.47 N 5 51 W 637.52 W 62:38.85 N 5 52 W 647.11 W 6:3:/7..50 N ~; 5:=: W 656.74 W 63'?.~6.56 N 5 54 W /-,67. 12 W 6475.S.~9 N 5 55 W 1.70 1.25 0.84 0.25 0.50 0.25 0.25 O. 50 0.83 10000 .~'-' = .... .~ 1 N '-} W 10100. 54 4.5 N 7 W 10200. 55 0 N 9 W 10300~ 55 15 N .9 W 10400. 56 0 N 10 W 100. 7050.5:3 6555.59 /:,'?~:3.58 65'7.0.5:3 lq 100. 7.1C)'.:.~. :2:5 6/=,:2:6.4.1 7057. :2;5 /:,/.-,00,/:,3 N 100. 71/76,8S' 6718. 12 711.4.89 6681.6:3 N · . . /:,7 :,.-. 66 N 100 7224 07 6800. (') :,'? 7172 0'7 /. '" 1 A 0 7 2 P, 0 ='- /_ o,:,.: ..... ' ~ 6:3 4 4 0 6 N ..... ,.j ........ ~..: .... 7 2 2 8 .~':' 678.92 W 6555.78 N 5 57 W 6'.~70.1.:.:.: W 6,~-,:36.6:.--.".N 5 58 W 701.56 W 6718.:36 N 6 0 W 714.40 W 6:'=:00.27 N 6 2 W 728.02 W 6:.--;8'.2.67 N 6 4 W 0.94 '::.'. 21 0.25 1. _1.'2 10500. 57 0 N 1! W 10600. 58 0 N !.2 W 10700. 59:30 N 12 W 10800. 60 !5 N 13 W :'RO,JECTEI-~ TO F'BTD 100 "' '-' .~ .... . 7.:,.:,._ 72'. 6965 42 728:.:.: 72 6926 05 N 100. 73:=.:?. 45 704'?. :30 73:37.4:5 700:=:. 69 N 100. 7441. :--:3 7; :--:4.24 738'F.~. 3:3 7092.3:?. N -'-' 7176 7A N 10 o 74'? 1 .5 ~ 7220 ('~ '-.? 74:3'.-.? .~':' · 9 743 21 W /:,:./: ..... 1 N 6 7 W 760.03 W 704':.?.78 N 6 11 W 777.8Q W 7134.84 N 6 16 W 796.52 W 7220.82 N 6 20 W 1. :=:0 1.31 :1,50 1.14 10876. 60 15 N 1:2: W 76. 752?. 2:7: 72:E:5. 51 7477. '2:F,: 724.~. 05 N 8.! 1. :36 W 7286.3(-, N 6 24 W 0.00 :'RO._IECTED TO TD 10775. 60 15 N 1:3 W · . · -' .=i '-' ::: N'] . . 99 7578 35 7:370 7:2: /...'6. __ 73:24 80 N 8:.--:0.70 W 7:37~. 7.5 N 6 28 W 0.00 FINAL CLOSURE - DIRECTION: ;T.I I STANCE: N 6 DEGS 28 M INS 13 .SECS W 7371.75 FEET Eastman/ Whipstock A PETROLANE CONOCO, INC. PAD C, WELl_ NO: 12 GMS dOB NO: AO685G0317 MIl. NE PT., NORTH SLOPE, AI..ASKA GMS, 0-10800 MD, SURVEYOR: B dAHN, f'~ATE RUN: 28-dUN-85 CAMERA NO: 79, 90 DEG' A/U NO: 1448, GYRO NO: 399 FORESIGHT: N53 30E RECORD OF I NTERF'OLATEIT~ SURVEY Eastman; Whipstock ~_~ A t':'ETI~O~.ANE CONOCO, INC. PAD C, WELL NO: 12 GMS MILNE PT. , NORTH SLOPE MEASURED DEPTH FEET 100. O0 200.01. 300.02 400.04 500.05 600. 13 700.43 801. 11 902.47 1004.80 ! 108.00 1212.33 1:318. 18 142/_-,. 10 t 536.50 1649.9./:, 1766. :38 1887.62 '2013.32 2144.72 2279.85 2417.74 2561.58 2707.79 2852.26 2995.04 3136.79 3278.70 3420.8:3 3563.50 AI..AoKA TRUE VERTICAl._ DEPTH FEET 100. O0 200. O0 300.00 400. O0 500. O0 600. O0 700.00 800. O0 900. O0 1, 000. O0 100.00 200.00 :300. O0 400. O0 500. O0 1600.00 170c). O0 1800.00 1900.00 2000.00 21 O0.00 2200. O0 2300. O0 2400.00 2500. O0 2600. O0 2700. 2800.00 2?00.00 3000.00 ,_lOB NJ]: SLIBSEA VFRTICAI.. DEPTH FEET 48.00 148.00 248. O0 348.00 448.00 548.00 64.8. O0 748.00 848. O0 948.00 t 048.00 1148. O0 124:3. O0 1348.00 t 448.00 1548.00 1. 64 :E:. C) 0 ~ 74:3.00 1. 848.00 1 '.'? 48.00 2048. O0 ~-' .148 (]0 · ..: .:-. 4._ 0(-) ,'._ 4.:. · "mi ~. .,'.44._ 0(] 2548.00 :2648.00 2748.00 2848.(}0 2948.00 A068500317 R E C T A N G U L. A R C 0 0 R D I N A T E S FEET 0.00 0.00 O. 20 N 0.85 E 0.54 N 2.56 E 0,.82 N 4.28 E 1.69 N 6.c)0 E 4.9'7 N 7.63 E '12.60 N 7.56 E 24.17 N 6.04 E 40.53 N 4.76 E 62.11. N 3.04 E :37.46 N 0.56 E ~16.95 N 2.77 W 151.40 N 6.27 W 191.72 N 9.89 W 23:3.16 hi 14.80' W :291.19 N 2~..75 W :'"':51.11 N :30.17 W 4.~8.01 N 40.01 W 4-93.1.'~ N 51.70 W 577.6:3 N 63.05 W 667.89 N 73.65 W 762.36 N 82.88 W 865.28 N 92.28 W 971.46 N 102.45 W 1075.29 N 111.86 W 1176.68 N 122.22 W 1276.62 N 132.49 W 1376.88 N 141.66 W 1477.42 N 151.34 W 1._7c,,62 N 161 -9'7 W COMPUTAT I ON TIME DATE 10,' 43 .' 34 . ...,":'1 -JUL - ,,':'.~,., ._ PAGE Nq. C L 0 S U R E D I STANCE D 1RECT I ON FEET O M 0.00 0 0 0.87 N 77 0 E 2.62 N 78 0 E 4.36 N 79 12 E 6.24 N 74 14 E 9. 11 N 56 56 E !4.69 N 30 57 E 24.91 N 14 3 E 40. ::.:0 N 6 4.2 E 62. 1 ':? N 2 4:.-7,: E 87.46 N 0 22 E 116.99 N 1 21W 151.5:3 N 2 22 W 1~!.97 N 2 57 W 2:38.62 N 3 ::::3 W 292.00 N 4 16 W 352.41 N 4-55 W 4.19.':72 N 5 28 W 495. '.,70 N 5 5':? W 581.06 N 6 14 W 671.74 N 6 18 W 766.85 N 6 12 W 870. !9 N 6 5 W 776.85 N 6 1 W 1081.10 N 5 56 W 1.1,83.01 N 5 5.6 W 128:::. 47 N .J= 56 W !:::84.15 N 5 52 W 14:R..~ !~ N = ~1 W 158.A.9; N 5 52 W Eastman ":ONOCO, INC. PAD C:, WE..I..L. NC'i: 12 GMS i'"II'LNE PT. , NORTH SI.OPE, ALASKA ,JOB NO: AO685G0317 TRUE '..:.;I. IBSE A MEASI. IRED VERT I CAI.. VF..RT I CAI. DEPTH DEPTH DEPTH FEET FEET FEET 3705.98 3100, O0 222048. O0 3849,51 3200. O0 3 .1. 48.00 3'7'73.68 3300.00 3248.00 4138.82 3400.00 3348.00 4284.15 3500' 00 23448.00 4431,74 3600.00 222548.00 4580.50 2370c). 00 23648.00 472?;, 90 3800,00 3748. 4:37'7.35 3900.0c) 3848.00 5028.52 4000. O0 3948. CDC) · _, 17 5.8 2 410 CD. 0,0 4,L) 4,=.. 0 0 F.._ .:, ~' ='-, ,,'-~, 3 6 4 2 0 0 .0 0 414 8 . O. 0 547 :'::. :34 4:300.00 4.,::. 4,=,. 00 5623.23 4400.00 4:..-.:4:3.00 5772. :3 :R .4500.00 444:3.0 cz) 5919.72 4/:,00.00 4548.00 6065.37 4700. O0 4648.00 621..1. 11 4800.00 4748.00 6361.26 4900.00 4848.00 6518. 11 5000, O0 4'748. cDC) 6680.53 5100. O0 5048.00 6847.77 5200.00 5.1 48.00 701 ?. '95 5300. O0 524:3. O0 7193.96 5400.00 5348.00 7365.39 5500.00 5448.00 7538. 15 5600.00 5548.00 7715.27 5700. O0 5648.00 7897.25 5800.00 5748. (1)0 8070.48 5900. O0 523423.00 :3237.60 6000.00 5948.0¢) R E C T A N G U L A R C 0 0 R D I N A T E S FEET 1679.56 N 172.58 W 1781.95 N 183,35 W .1'-".-~ ~ '-*" · ,=,,. .... , ...... 3 N 1. '74. '20 W 1989,85 N 205.20 W '7094.72 N 216.'22 W '-' "q'-' 68 227, ~_z,. ,.. N 57 14 222312,26 N 2:3:3, 56 W 2422.75 N 249.20 W 2533.3'~ N 258,82 W 2643.87 N 265,2'7 W 2751.99 N 267·61 W 22F260.44 N 265.82.--: W · -,,~ --., .-,[. .-...7-. J.~ N 1 98 W . --- "' -! m :2:08.3.64 N 256, 18 W 231923.96 N 248,47 W 22222202. 03 N 241.68 14 :3407.6? N 2:34. :30 W 222513.45 N 227.55 W :3625, :34 N 22:3. :31 ~ · 3746.07 N 225.8.1. W 23873,60 N 236.40 W 4006.63 N 252~67 W 4145.55 N 271.24 W 4286.29 N 292..95 W 4423.26 N 317.96 W 4561.72 N 34.22.87 W 4705.47 N 370.40 W 4855~19 N 396.80 W 4994. 17 N 47'.23.04 W 5125.60 N 448,59 W COMF'UTAT I ON 'T I ME DATE 10: 43: :34 31 -JLIL-85 PAGE NO. C: L. 0 S U R E D I STANCE D I RECT I ON FEET D M 16238.40 N 5 52 W 1791.36 N 5 52 W 18'75.21 N 5 53 W 2000.40 N 5 53 W 2105.85 N 5 54 W 2214.41 N 5 54 W 2:3724,54 N 5 5:3 W 2435.53 N 5 52 W 2546.57 N 5 50 W 2657. 15 N 5 44 W 2764.97 N 5:3:3 W 2872.77 N 5 19 W 298:3.67 N 5 '2 W 3094.26 N 4 4.5 W :320:2:./:, 1 N 4, 27 W :32310.86 N 4 11 W 23415.77 N :3 57 W 22252(]), :--: .1 N :3 42 W 2362':22. 21 N :2: 22.1 W 2227522.87 N :A 27 W 2388c'). 81 N :3 :.'.-i', 0 W 4014.59 N 3 37 W 4154.41 N :2:45 W 4296.2'.9 N 3 55 W 4434.68 N 4 7 W 4574.67 N 4 17 W 4720.02 N 4 30 W 487!.38 N 4 40 W 5012.c)5 N 4 51 W 5.1.45.20 N 5 0 W Eastman .';ONOCO, I NC. PAD C, WELL NO: .1.2 GMS ~I!LNE PT. , NORTH SLOPE, AL. ASKA MEASURED DEPTH FEET TRUE VERTICAL. DEPTH FEET 8403.32 8572.66 8747.33 8923.15 9093.37 6100.00 6200.00 6300.00 6400.00 6500.00 9260.44 9427.06 9589.15 9751.50 6600.00 6700. O0 6800.00 6900. O0 7000, 00 10084.08 10257..91 10435.28 10620.33 10817.10 7100. O0 7200.00 7:300. O0 7400.00 750,0,. O0 dOB NO: A0685G0317 SUBSEA VERTICAL DEPTH FEET 6048. O0 6148.00 6248. O0 6348, 00 6448.00 6548.00 6648.00 6748.00 6848. O0 6.948.00 7048.00 7 .1. 48.0 (1~ 7248.00 734 :.--.:. 00 7448.00 R E C T A N G U L A R COORDINATES FEET 5255.19 N 474,54 W 5388.76 N 502.44 W 5527.21N 531.33 W 5670.93 N 560.04 W 5806.78 N 582.67 W 5~3~.21N 602.08 W 6071.21N 620.44 W 61~7.76 N 636.48 W 6324.~.'~ N 652.07 W 6454.14 N 669.00 W 6587,89 N 688.37 W 6728, 55 N 708.?~2 W 6872.'.-.?'~ N 733.38 W 7025.70 N 7/_-.3.64 W 71 '.'.--¢ 1. '.22 N 7.9.9.86 W COMPUTATION TIME DATE 10:43:34 31-dilL-85 CLOSURE D I STANCE D I RECT I ON FEET D M 5276.57 N 5 10 W 5412.33 N 5 20 W 5554.68 N 5 29 W 5698.51 N 5 38 W 5835.?4 N 5 44 W 5.96?.65 N 5 47 W 6102.83 Iq 5 50 W 6230.:--:5 N 5 52 W 6:-::58.21 N 5 5:3 W 6488.72 N 5 55 W 6623.75 N 5 58 W 6765.80 N 6 1 W 6.912. O0 N 6 5 W 7067.08 N 6 12 W 72:--:5.57 N 6 21 W PAGE NO. 3 Eastman/ Whipstock A ~r'rRO~ AN~' ¢';f~tF)ANY CONOCO, INC. PAD C, WEL.L NO: 12 GMS dOB NO: A0685G0317 MILNE 'PT., NORTH SLOPE, A[.ASKA GMS, 0-;0800 MB, SURVEYOR: B dAHN, BATE RUN: 28-dUN-85 CAMERA NO: 79, .90 PEG A/U NO: 144:.].', GYRO NO: FORESIGHT: N53 30E REC:ORD OF INTERPOLATED SURVEY Eastman Whipstock A PETROtANE COMf¥CCY ONOCO, INC. 'AD C:, WEL.L NO: 12 GMS I ILNE PT.. NORTH '..--.:LOPE, ALASKA MARKER-- CODE NAME dOB NO: AO685GO:317 dA KA KB I<C f:.'.D TRUE SUBSEA MEASIJRED VERTICAL VERTICAL DEPTH DEPTH DEPTH FEET FEET FEET LA LB MA MB MC 4622.00 3727.80 :3675.80 4720.00 :3793.38 3741.3:3 4773.00 3828.84 3776.84 4873.00 :3895.75 3843.75 4956.00 3951.29 3899.29 NA NB NC ND NE 5006.00 3984.79 3932.79 5062.00 4022.62 3970./:,2 5146.00 4079.66 4027.66 5246.00 4147.72 4095.72 5312.00 4192.40 4140.40 NF OA OB ':','.. 5/'='''_ ,_, F:SG T/MK- 1 5522.00 4332.39 4:,').80 ,. 39 554:9. O0 4349.75 4297.75 5580.00 437!.1! 4319.11 5612.00 4392.48 4340.48 5642.00 44] 2,, 56 4360.56 B/MK-.! L L-9 T/LK-1 B/LK- 1 569'.-7~. 00 4450.70 439 :::. 70 5753.00 4487. O0 4435.00 5875.00 456S~. 52 45 'L 7.52 6069.00 4702.50 4/:,50.50 10415.00 7288.81 7236.81 T/LK-2 F'BTD TO 104 :B'.--.~. 00 7302.05 7250.05 10524.00 7348./:,2 7296.62 1056:,--_-'. 00 7369.03 73: ], 7.03 10710.00 7446.35 7:394. :2:5 10734.00 7458.39 74£)6.3:9 10752. O0 7467.4:_7 74 t 5.4.3 :t 087A. 00 ~.~ '2 .....- _ /....... ~ 3 7477. c":: 10975.00 7578.35 75:..-..'.6.35 COMPUTATION TIME DATE " : , I '~ 10.48 02 31-dl_L-o._ PAGE NO. . 1 R E C T A N G U L A R C 0 0 R D I N A T E S FEET C L 0 S U R E D I STANCE D I RECT I tIN FEET D M 2342.93 N 241.5~ W :2415.42 N 248.49 W 2454.63 N 252.27 W 2528.68 N 258.45 W 2590.22 N 262.56 W 2627.28 N 264.71 W 2668.54 N 266.15 W 2730.!8 N 267.42 W ~.~,..;,.44 N 267.18 W 2852.00 N 266.18 W 2oM~ c,R N M 53 W ..i,_ .... ~1._ 2428.17 N 5 52 W 2467.56 N 5 52 W 2541.86 N 5 50 W 2603.50 N 5 47 W 2640.58 N 5 268~.78 N 5 42 W 2743.:~5 N 5 36 W 2816.15 N 5 27 W 2864.40 N 5 20 W 3008.42 N 260.4:3 W 3027.75 N 257.41W 3051.55 N 258.17 W :9075.31N 256.77 W 3097.55 N 255.21W 3019,67 hi 4 57 W 30:.?,8.85 N 4 54 W :B062.45 N 4 50 W :E-,'086.01 N 4 46 W "-"1OR 05 N 4 43 W 3139.f::1 N 252.26 W 3.179.69 hi 249.47 W :32/:,9.36 N 24:3./.:,8 W 34.1 (')... ..,'~'""'..- N 23:4. .62 W /:,856.36 N 730.30 W 6876.04 N 733.94 W 6945.89 N 747.25 W 6977.29 N 753.64 W 7100.76 N 77?.67 W 7121.03 N 784.17 W :3149.9:3 N 4:36 W .318.c.~.4/:, N 4 '.-2~~ W 3278.43 N 4 16 W 3418~ ._-, ~',=,'-' N :]-: 56 W '-"--'/~".. ~ '~1 6o; ..... 1.4 N 6 ! ,. 69.15.10 hi 6 6 W 67~85.97 N 6 8 W 7017.87 N 6 10 W 714:2:. 44 N 6 16 W 7:!64.07 N /:, 17 W 7136.2:3 N 787.54 W 7241.05 N 811..36 W 7324.80 N 830.70 W 7179.55 N 6 18 W 7286.36 N 6 24 W 7371 75 N 6 '~ Eastman/ m Whipstock l 4 ~:¥:'TRtTM AN,¢ CONOGO, INC. PAD' C. WELL NO, 12 HILNE'PT.~ NORTH SLOPE, ALASKA EASTHAN WH[PSTOCK~ [NC. ....... ~-'~!'-'~" -~ .......... l ~--~ ...................................... ~ .......... ~ ..... HOR I ZO'NT:AI_'-' P,~RO'~JE*CT-I'ON SCALE 1 IN. - 2000 FEET DEPTH INDICATOR' TVD 336: 4655 t3646 0 FINAL STATION~ DEPTH 10975 MD. 7~78.~$ TVD NORTH 7~24.80 WEST 8~0.?0 CLOSURE 737,1.75 N 6 28 13 W CONOCO, i' ! '' PAD O; WELL . , .... · EASTMAN WHIPSTOCK. [NO. VERT!CAL PROJECTION SCALE 1 IN. - 12.000 FEET --2000. II'1 · - 4000 rtl ....... 6000 8000 200O 3000 4000 5000 600O 7000 SO00 9000 0 2000 4000 6000 VERTICALiSECTIOH CLOSURE .7371.75 iN.6 _28 li:3 W 10000 10975 . ! Booo Suggested form to----~e inserted.~ each "Active" well folder to check for timely compliance with our regulations. _ Reports and Materials to be received by: Date Required Date Received Remarks Completion RepOrt Core Chips Core Description ~~' ~ _~. ~~ . Registered Survey plat Inclination Survey Dr~ll Stem ~est Reports Digitized Data STATE OF ALASKA' ._.. ~" ALASKA :-'.AND GAS CONSERVATION C( VIISSION //,,.. 'MONTHLY REPORT DRILLING AND WORI OVER OPERATION 1. Drilling well [] Workover operation [~ 2. Name of operator 7. Permit No. Conoco Inc. 85-120 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50_029-21373 4. Location of Well at surface 496' FSL, 2027' FEL, Sec. 3, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 4 7434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 12 11. Field and Pool Kuparuk River Field Kuparuk River · For the Month of July ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month: 10,974' MD Footage drilled: 0' 13. Casing or liner run and quantities of cement, results of pressur~ tests Ran 329 its of 3~" · 2 , 9.2#, L-80 tubing, packer at 10,315' MD. MI and RU Roll'n #4. Pull tbg. out of PBR. POOH w/PBR. RIH w/3½" Butt. workstring. Wash from 10,555' 'to 10,882' (recovering frac sand & 10.2 brine) Circ. well clean.' 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE RECEIVED 6. DST data, perforating data, shows of H2S, miscellaneous data AUG 1 '9 198§ Perfed f/10,750' to 10,796' w/12 spf. Set top of packer @10,47~S.ka 0il & Gas Cons. Commission · Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev. 7-1-80 Eastma[ Whipstock A PETROLANE OOMR~NY (907) 349-4617~'~' P. O. Box 4-1970/Anchorage, Alaska 99509-1970 August, 1985 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two copies of the Gyro Multi-Shot survey run for Conoco Inc. on Pad C, Well No: 12. This is to be considered a formal letter of transmittal. The data herein, is to considered strictly confidential. A copy of thiS letter is being sent to Conoco's represen- tatives, Mr M. Bradshaw and Mr S. Davies. Should you have any questions regarding this survey data, please refer all questions to CONOCO INC. ctfu , D ist~~echnical Coordinator cc: -M.' BRADSHAW S. DAVIES .lUaska Oi'l & Gas Cons. Cor~mJssJor~ Anchorage Directional Drillers/Sub-Surface Surveyors/instrument & Tool Rentals/Sales/Worldwide STATE OF ALASKA --'- ',..~ '-' ALASKA C,...AND GAS CONSERVATION CO,, ,IISSION MO ITHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well 1~] Workover operation [] 2. Name of operator 7. Permit No. CONOCO INC. 85-120 3, Address 8. APl Number 3201 "C" Street, Ste. 200 50- 029-21373 4. Location of Well at surface 496' FSL, 2027' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB I6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well No. CNo. 12 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of .Tune ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date: 6-14-85 Depth at end of month (TD): 10,974' 13. Casing or liner run and quantities of cement, results of pressure tests Ran 154 jts. 9 5/8" 36# K-55 BUtt. csg. Pumped 571 bbls. 12.3 ppg Class G w/3% NaC1 1% CFR-2 Cmt returns to surface. Ran 278 jts. of 7" 26# L-80 Butt csg. 300 sks. Class G cmt. w/l% CFR-2 .3% Halad-24 14. Coring resume and brief description None 15. Logs run and depth where run LDT=CNL-DIL-GR @ 10644' DIL-GR-SP 10,660'-10,557' and 10,865' -10,660' Relog 10,745'-10,655' GR-CNL-Gyro from 10,899'-10,100' & 6100'-4600' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed 10,416'-10,438' w/12 JSPF jUL 1 g i!],?,5 h~aska Oil & Gas Cons. Oornmission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. F~rm 10-404 Submit in duplicate CONOCO, INC. 3201 "C" STREET SCRLUNIBERGER OFFSHORE SERVICES ANCHORAGE, ALASKA 99503 Attention: MIKE BRADSHAW A Division of Schlumberger Limited HOUSTON. TEXAS 77001 PAGE 2 OF 2 JULY 10th, 1985 [~LEASE REPLY TO SCHLUNIBERGER OFFSHORE SP2RVtCE~ POUCH 340069 PRUDHOE BAY, AK 99734 ATTN: HOLLY BURGAN Gentlemen: Enclosed are__.prints of the 2" & 5" DIL/IRT, LDT/CNL Company CONOCO,. INC. , Well MILNE POINT UNIT _C-12 Field MILNE POINT , County NORTH SLOPE State. ALASKA AddiHonal prints are being sent to: 1 BL prints & 1RF prints CITIES SERVICE OIL & GAS CORP. P.O. BOX 939 BAKERSFIELD, CA 93302 ATTN~ NEIL BUTTRAM c/o JIM QUINN on: prints prints prints __prints prints prints SOS--1565 -A The film is RETURNED TO coNoco We appreciate the privilege of serving you. ,. a jUL 1 6 1995 lmohorago DATE: Very truly yours, SCHLUMBERGER OFFSHORE SERVICES CATHERINE GADOMSKI DISTRICT MANAG£R MEMORA OUM State of Alaska July 16, 1985 D.ADA. 27 ALASKA OIL Al'ID GAS CONSERVATION COMMISSION // *~ DATE: TO: C.y. terton Chal~.~~ FiLE NO: THRU: Lonnie C. Smith ~f'~' TELEPHONE NO: Co~issioner / FROM: Doug ~os ~- SUS0ECT: Petrole~ Inspector BOPE Test Conoco' s ~U C-12 Well, Permit No. 85-120, Kuparuk River Field. Tuesday, June 18, 1~85: I traveled this date from Anchorage to P?udhO~ Bay to"~i~heS~ the BOPE test at Conoco's C-12 well. Wednesday, June 19 1985: The testing commenced at 11:45 pm and ~'-ConCludedrat' 1~:45~m. There were no failures and I filled out was an AOGcC BOPE inspection report which is attached. In summary, I witnessed the BOPE test at Conoco's Milne Pt. C-12 well. Attachment 02-00IA(Rev. 10179) o&G #4 4/80 ' .i STATE OF ALASKA OIL & GAS CONSERVATION COMMISSION . - B.O.P.E. Inspection Report Inspector Ope rator 5~ / O Wel-1 ~/- ~ Location Sec ~ T/!;4 R/J~ M Drilling COn'tractor ~L(~ Rig # Date Well /~/-- Representative /~ ~ ~asing Set Representativ~ Location-/ General. . Well Sign., .General Housekeeping Reserve pit Rig ' BO-~Ei;:~-.~.'ack ' Annu-~.~_/:.~pr eve nt er ' Pipe R~s ~. h~ ~_ . Blind R~s - . Choke Line V~ves _ .- <':-"-.. '-- 'H. C.R. valve ~ ~ "" Kill Line Valves ~'~ Check Valve / Test Pressure ACCUMULATOR SYSTEM .. FulI Charge Pressure ~) ~9~70 psig PreSsure After Closure /~7~ psig 200 ps'ig Above Precharge Attained: Full: charge Pressure Attained: · Z~o ' - Controls: Master Remote ~ Blinds switch cover~ Kelly and Floor Safety Valves Kelly. · I ~est Pressure Lower Kelly ~/ Test Pressure Ball Type ~] Test Pressure Inside BOP -~/ /' Test Pressure Choke Manifold. / ~Test Pressure No. Valves _ _// No. flanges adj usta~le Chokes Hydrauically' operated choke. Test Results: Failures Test Time -: , ~:Repair or :Replacement of failed equipment to .be made within. , . :.InspectOr/CommisSion office notified. Remarks: min ~ se min ~ se i/ /~/(~ ~'~ ~-- ~> hrs .. ~ days and · _. ///// Distribution orig..- AO&GCC' cc - Operator cc - Supervisor Inspector '~~ SCHLU~.1BERGER OFFSHORE SERVIC'-'S A Division of Schlumberger Limitecl HOUSTON. TEXAS 77/001 PAGE 1 OF 2 JULY 10th, 1985- CONOCO, INC. 3201 "C" STREET, SUITE-200 ANCHORAGE, ALASKA 99503 Attention: MIKE BRADSHAW - - PLEASE REPLY TO SCHLUMBERGER OFFSHOR-~ POUCH 3,10069 PRUDHOE BAY, AK 9973~-' ....'...: ATTN: HOLLY BURGAN '".:.'j-'" -. . · . · . _. ; Gentlemen: ..- . -- ' . _.- Enclosed are 2 BLprints of the 2" &' 5';i_:~;:..D.I.L/~I:R__~:/.:.~DT/.CNL . Company. - CONOCO INC. . .; wei.l~ ~O_'~N~}UNtT C'i2 ' ......:~.!''Field MILNE POINT ........... ; County. NORTH SLOPE .State -ALASKA ~ - . '..L .- . '. " " i .. ' ;, .-' ,':.:. --'. .--. ....... . . - -- .... ' .' . "' ..... Additiono! .... "" being sent to: '- :. - prints are ' "- -.. ..... :.,~.'.' :1 BL.prints'& 1RF .... - ..... :.. 1 BL .prints & 2RF ' ':i~-.:': WEST COAST & ALASKA'DIvISION, :--. CHEVRON U.S.A., I_N_C_. . ........ '-- 290 MAPLE COURT, SUITE 284 .- P~_O_.__B__~. 1_0_7_8_39 . -._-._= - VENTURA, CA 93003 .~-':;,:'. ATTN: PHIL SALVADOR - ' . '"--=:.__ '- 1 BL.prints & 1RF - ' '' .... ' CONOCO, INC. . - P.E.S. RESE yOIR S CTION OFFSHORE BU! !~DING . P.O. BOX 2197 · HOUSTON, TX 77252 ATTN: GERALD KIEL c/o. GEORGE LhMB: 1 BL.prints CONOCO, INC. P.O. BOX 1267 . PONCA CITY, OK 74603 ATTN: H.E. GILLILAND/_6356RW .. -.. ANCHORAGE, AK 99510 ' -- : ATTN: J~_T~~R ] i- "' "'- . . "TM ..... '3 - .. . ;:. ..'~':'.--- .- . . . - . - . .. 1 B~L '-'nrints & 1 RF CHEVRON U.S.A., INC. P.O. BOX 8200 . . . - 1 BLprints & 1RF .... · ALASKA OIL & GAS CONSERVATION CO~MISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: WILLIAM VAN ALEN CONCORD, CA 94524 ATTN: DAVE ENGSTROM c/o LOUIS KLD~N_SK__Y 1 BL ·prints & 1 RF CHAMPLIN PETROLEUM COMPANY P.O. BOX 1257 ENGLEWOOD, CO 80150 ATTN: JAMES T. LAWS .. . . .... '--:7;-:;. 1 BL' prints & 1RF' READING & BATES PETROLEUM CO. 3200 MID CONTINENT TOWER TULSA, OK 74103 ATTN: C.E. S~_~..R__y~. JR. The film is. RETURNED TO CONOCO We appreciate the privilege of serving you. DATE: Alaska OH ~ ucs u0ns. Commission Anchorage Very truly yours, SCHLUMBERGER, OFFSHORE SERVICES CATHERINE GADOMSKI D I &;l'l~ I C'I' M,A N AG :'P. SO$--1565-A John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 July 1~, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99601 Dear Mr. Chatterton: Attached are the Sundry Notices for Milne Point Unit Wells C-12 and B-6. These Notices are applications to fracture stimulate the C-12 well and pull tubing on the B-6 well. If you have any questions, please call Dan Robertson at 564-7635. Very truly yours, /Manager of Alaskan Operations DIR/vv Sundry Letter cc: MP C-12/B/6 Correspondence Files STATE OF ALASKA -- ALASK/-, ~,~L AND GAS CONSERVATION C,..,,vlMISSION S NDRY NOTIC S AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED ~E LL~I-I OTHER [] 2. ~Jame of OpP.,.rator 7_ Permit No. uonoco ~nc. 85-120 Addr~_c 8. APl Number 3"32~IS"c" Street, Suite 200, Anchorage, Alaska 99503 $~29-21373 9. Unit or Lease Name Milne Point Unit 4. ~.~TcC~ Well 496' FSL, 2027' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 · 10. Well Number C No.12 11. Field and Pool Kuparuk Field 12. {Submit in Triplicate) Perforate [] Alter Casing [] - Perforations Stimulate J~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To in~licate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-12 well was originally completed as a single producer in the Middle Kuparuk Formation (10,416' - 10,438') on June 30, 1985. We now propose to test the Middle Kuparuk and fracture stimulate (if pressure build-up indicates a permeability less than 150 MD). After completing a post fracture flow test, the tubing and production packer would be pulled in order to perforate the Lower Kuparuk (2) from 10,750' - 10,796' (46')._ The well will then be completed as a single selective with the Lower Kuparuk (2) being the primary formation. The Sundry Notice approved 6-21-85 was filed in anticipation of a single selective completion. The intentions are still applicable as the work will be done after the well is recompleted. R£C£1V£D JUL 1 6 ]985 Alaska Oil &.Gas Cons. Commission ~nChorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. · . Sr. Production Engineer Signed The space below for Commission use Date 7-16-85 Conditions of Approval, if any: ORIGINAL SIGNED Approved by. COMMISSIONER APProved Cop'./ Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev: 7-1 ~0 __ John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 June 25, 1985 Mr. C.V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Chatterton: Attached is a Sundry Notice for Milne Point Unit Well C-12. The Notice is an application to increase measured depth from the permitted 10,941' to 11,000'. The increase in measured depth is a result of deeper than anticipated zones. Verbal approval to exceed the permitted depth was given on. June 25, 1985. If you have any questions, please call Kent Stolz at 564-7641. Yours very truly, YJohn R. Kemp Manager of Alaskan Operations KJS/vv Chatterton cc: MP C-12 Correspondence File RECEIVED JUN2 6 ~i~ Alaska Oil & Gas Cons, Anchorage ~---- STATE OF ALASKA ~-'-. ALASKA _ AND GAS CONSERVATION Cf,,..,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELLZEI COMPLETED WELL [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-120 3. Address 8. APl Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21373 4. Location of Well 9. Unit or Lease Name SURFACE: Milne Point Unit OTHER [] 496' FSL, 2027' FEL, Sec. 10, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 52' KB Pad 17' 6. Lease Designation and Serial No. ADL 47434 12. 10. Well Number C-12 11. Field and Pool Kuparuk Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all Pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The subject well was originally permitted for a total depth (TD) of 10,941' M.D. (7610' TVD). Due to actual formation tops being slightly deeper than anticipated, Conoco estimates that the measured depth of the well will exceed the permitted depth, and now requests approval to drill to a new final TD of 11,000' M.D. The well is expected to reach T.D. on June 25, 1985. Verbal approval to drill to 11,000' M.D. was given to Kent Stolz on 6-25-85 by C. V. Chatterton. RECEIVED J U N 2 6 1985 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si§ned Title The space below for C ission use Date 6-25-85 Conditions of Approval, if any: ., Approved by ~' ~'~'~,Y ~' ;''~ b~ COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA "-'-' ALASKA ~ .- AND GAS CONSERVATION CO,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL iX1 OTHER [] 2. Name of Operator 7. Permit No. Conoco Inc. 85-120 3. Address 8. AP~ Number 3201 "C" Street, Suite 200, Anchorage, Alaska 99503 50029-21373 4. Location of Well SURFACE: 496' FSL, 2027' FEL, Sec. 10, T13N, R10E, U.M. _ 5. Elevation in feet (indicate KB, DF, etc.) 52' KB 6. Lease Designation and Serial No. ADL 47434 9. Unit or Lease Name Milne Point Unit 10. Well Number C-12 11. Field and Pool Kuparuk Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate} Perforate [] Alter Casing [] Perforations Stimulate [[ii Abandon [] Stimulation Repair Well [] Change Plans ' [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The C-12 well was originally completed as a single selective with the Lower Kuparuk (2) (the bottom lobe of the Lower Kuparuk Formation) as the primary sand and the Middle Kuparuk as the selective. We now propose to finalize our completion program by fracture stimulating the Lower Kuparuk (2) then wireline perforate the Lower Kuparuk (1) through tubing. Our objective is to improve the productivity of the Lower Kuparuk (2) so that it will deplete consistently with the L.K. (1) (on the average the permeability of L.K. (1) is approximately twice that seen in L.K. (2)). On a number of the "C" pad wells the post completiOn flow test left significant fill in the casing~ Prior to the fracture treatment each well is to be checked for fill. If the C-12 well has insufficient rat hole remaining (minimum of 35') a coiled tubing unit will be used to clean-out to PBTD. RECEIVED J U N 2 0 1985 Alaska Oil & Gas Cons. Cornmissior~ ~1,. ti'.:, c:t ,~ - 14. I herq~/ce--Pt, ify that the foregoing is true_and correct to the best of my knowledge. '" Si§ned ~-Jtq,4~ ~ . The space below for Commission use Conditions of Approval, if any: ~,pproYed Copy R~turn~d BT LONNI[ c. suit, By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate June 12, 1985 Mr. Kent J. Stolz Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. C-12 Conoco Inc. Permit No. 85-120 Sur. Loc. 496'FSL, 2027'FEL, Sec. 10, T13N, R10E, UM. Btmhole Loc. 2960'FNL, 2720'FErn, Sec. 3, T13N, R10E, IIM. Dear Mr. Stolz: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys.. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you .may be contacted by the. Habitat Coordinator's Office, Department of Fish and Game, Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted bY a representative of the Department of Environmental Conservation. Kent J. Stolz Milne Point Unit C-12 -2- June 1° 1985 To aid us in scheduling field work, please notify this office 24 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. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C' V. Chatterto~ i Chai_wman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMJMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowell John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 June 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point C-12. A $100 check is being submitted with the permit application to fulfil], the permitting fee requirement. If you have any questions, please call Kent Stolz at 564-7641. Very truly yours, John R. Kemp Manager of Alaskan Operations KJS/vv cc: MP C-12 Correpondence File RECEIVED JUN 0 7 Alaska Oil & Gas Coos, Commission Anc,horage ,-'-" STATE OF ALASKA ~-' ALASKA ~..,L AND GAS CONSERVATION CC,.,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] I b. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICEA[] STRATIGRAPHIC [] SINGLE ZONE I-] MULTIPLE ZONE [] 2. Name of operator Conoco Inc. 3. Address 3201 "C" Street~ Suite 200~ Anchorage, AK. 99503 RECEIVE 4. Location of well at surface 496' FSL, 2027' FEL, Sec 10, T13N, R10E, g.M. At top of proposed producing interval 3100' FNL, 2700'FEL, Sec 3, T13N,RlOE, U.M. At total depth 2960' FNL, 2720' FEL, Sec 3, T13N, RiOE, U.M. 5. Elevation in feet (indicate KB, DF etc.) KB 52' Pad 17' I 6. Lease designation and serial no. ADT. 47434 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 ) 9. Unit or lease name Milne Point Unit 10. Well number rlr-nJssi0r~ C No. 12 11. Field and pool Kuparuk River Amount $200~000.00 13. Distanceand directionfrom nearesttown 33 mi NW of Deadhorse miles 16. Proposed depth (MD & TVD) *10641' MD 7419'TVD feet 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. MAXIMUM 21 SIZE Hole 8~" 14. Distance to nearest property or lease line 3100' FNL, Sec. 3 at top of prod. f~t. 17. Number of acres in lease 2,560 20. Anticipated pressures HOLE ANGLE 50.6°0 (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed well C-16 9 feet 18. Approximate spud date 6110185 2230 psig@ 80OF Surface 3800 psig@-74A-9~ft' TD (TVD) Proposed Casing, Liner and Cementing Program CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Casing Weight Grade 13 3/8 48 H-40 9 5/8' 36 K-55 7" 26 L-80 22. Describe proposed program: Coupl lng Length I PELP 80 ' I BTRS I 6163 ' I BTRSt10609' MD TOP TVD 35' I 35' i 33' I 33' 32' I 32' MD BOTTOM TVD I i 6196' ! 4600' I I 7419' 10641' I (include stage data) +250 sk.~ Clm.m~ G m250 sks Clas$ G ±180 sks Perm "C" Conoco Inc. proposes drilling the subject well as an injection well in the Kuparuk River field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13 3/8" conductor for drilling surface hole. A 13 3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is C No. 16 which is 9' from C-12 at 1035' TVD. Arctic pack will be placed in the 7" X 9 5/8" annulus after disposing~test oil and excess drilling fluids. The well will be perforated and completed before releasing the drilling rig. It will be flow tested after the rig is released. *This depth may be exceeded if formation is deeper or wellbore does not follow proposed path. A Sundry Notice will be submitted if total depth exceeds permitted depth by more than 300'. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space below for Commiss~/on us CONDITIONS OF APPROVAL Samples required []YES ~XlO Permit number Directional Survey required ~J.y ES []NO APl number 50- o z-~ -?-I 37 ~ Mud log required []YES ~10 Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE June 12, 1985 by order of the Commission Form 10401 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL Conoco et al - Milne Point No. C-12 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 ±1515 sacks of Permafrost "E" cement followed by ±250 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ci The 7" production casing will be cemented in two stages. The first stage will consist of ±250 sacks of Class "G" cement pumped around the casing shoe (estimated ±1400' 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 down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY (Depths are TVD) 0' - 4500' Surface conglomerates, clay, silt and sand sequences. Estimated base of permafrost at ±1700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±7000' subsea TVD. III. FORmaTION EVALUATION A~ Wireline logs for the 8%" hole (from T.D. to ±lO00'above the Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho Density 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 6196'-T.D. V. DIRECTIONAL PROGRAM The C-12 well will be drilled to a proposed KOP of 500', then build angle in a north 5.5° west direction. The closest that the C-12 will come to another wellbore is during buildup, where the proposed C-12 will be approximately 9' from the existing C-16 we].].. Extreme caution will be taken and an M~ tool will be run while drilling for surveying purposes. Other wellbore paths which are crossed during buildup are C-Il, C-13, C-14, and C-15. Closest distances on these four wellbores are as follows: C-il (38' at 2080' TVD), C-13 (95' at 1888' TVD), C-14 (63' at 1707' TVD), and C-15 (55' at 1510' TYD). Final hole angle will be 50.6°. The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300', a Sundry Notice will be submitted. i~"~''W~E~_'NO, 12 PROPOSED MIL.NE PT,, NORTH SLO.~~', ALASKA EASTHAN WHIPSTOCK. INC. : . . .... 1000 SURFACE ......... KOP TVD=500 TMD=500 DEP=O _ Il) 20 BUILD 2 1/2 DEG 25 i ...... PER 100 FT : 8000 - 0 . . 1 000 2000 ~000 4000 5000 6000 ?000 VERTICAL SECTION ......... 2000 4o ' ' .- · 45 : ~ . ~ P=838 _, 3000 4000 g . : ...... ; ........... .,,,,,.. 9 5/8' CSG PT :. ~ _._ .~4,~?~.~ _ ~ "~" ~ Oii& Gas Cons. Gomm~ssio~ ' ' ,ooo "TENTATIVE" TD TVD=~419 TMD=10641 DEP=T112 ~A~-~;-WELL NO, 12 PROPOSED MILNE PT>~... NORTH SLOPE. ALASKA EASTMAN W,~IPSTOCK, INO. - WEST-EAST ~000 2000 1 000 0 1 000 8000 ~ ~ ~ ~ ........................................... N 5 DEG 31 MIN 6996' (TO TARGET) .. 7000 ' . ~. ..... ............. _ . .. ..: ..... ~ ..... . . 49~' FSL, 2027' FEL -- SEC. I0, TI3N, RIOE 2400 1600 1500 · . · 2300 2200 . . . I NORTH 2100 2000 I 1900 1800 1700 I I CONOCO, INC. PAD C, WELL NO, 12 PROPOSEB FIILNE PT,, NORTH SLOPE, AK EASTHAN WHIPSTOCK, INC. 1400 1 300 . . 2256' . . 4527 : NOTE, WELL PATHS EXTEND BEYOND THIS VIEWING WINDOW 2831 · , 2751 29l I 2672 1693 2593 2512 ! 768 44 1920 1997 20/'3 2149 1600 I 1200 ':':: - ............ ' .... ii GO ; . 1000 900 800 ._ 70O 60O 500 400 2257 2077 2048 . '1973 6693 ' 1895 · 81 . '- : .... ~ ....... :- - · 1731 - .......... : -:! ..... ~:- - ~ .... ; _ . _ _ :-: .~.. i ' r4138 - . ! . . . : . 4225 ~4310 · · JUNo :? 1g'?,5 .... ........2293: ..... · 2462 ;)~623 4238 - - 4373 4591 CONOCO INC. MILNE POINT UNIT 20" DIVERTER STACK ~ ~ Flow Line Fill-up Line ~ . _ - . (0L 0 0ar0 Preventer i -_ HCR [ i 1 HCR - · ValveL' . I Valve - , Drilling Rel±ef Line ~' - S ' 6 Rel±ef Valve '~ '~'-~20"x 20" 2000 p~ ! ; Connec¢ Assembly :.,~ ~~' Assembly '~'-~ I>:!' ' ~ ~ Saver Sub ..~.~ ~ .~ I-:. . Startmng '~-J ~ Head ~ J ~'-'~ , I k- _J .,-'. ~(~:. 1. Relief lines.from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with API specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes, then either one may be closed. Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. CONOCO INC. MILNE POINT UNIT BOP STACK · Line~Fl°w -! Annular [ Preventer Line (1) B.O.P. stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. (2)' BOPE to be operated on each trip & pressure tested weekly. (3) 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. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet API RP 53 class 5M requirements. RAM 13 5/8" - 5000 --RAM 13 5/8" - 5000 2" - 5000 Side Outletsi 3" - 5000 Side Outlets' I RAM 13 5/8" - 5000 3" - 5000 Side Outlets 11" - 5000 ALASKA UNITED DRILLING;', RIG NO. 3 .OUTTErIFLY.. VALVE CLOSF, D i SUCTION CLOSED Flow path ~- . . ~ Solids removal ~" · DEGASSING FLOW PATH 1 FIowline linl & pass:shaker., screens 2 Shaker discharge into sar:id trap {ditch to pit room. closed) 3 Sand trap overflow into degasser suction (des er ,S,uction 4 Degasser discharge into ditch S Overflow returns to clegasser suction lunderf,o~ bu,",~terfly 6 Switch desander suction out of degasser t~nk ~,? .. , . cti (NOr i) "' ' 7 Desiltersu on ma · ,~ · 8 Cleaned mud to treatment pit 9 Underflow from treatment to suction pit 10 Gravity-flooded suction ,,~: · ,, i .'N .. PT. UNIT o_= SCAkg. IN ~IL. ES. C,O N 0 GO~ · MILN[ POINT UNIT EXISTING DEVELOPMENT NOTES: !. STATE PLANE CO-ORDINATES ARE Z~NE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927o OFFSETS TO SECTION LIb;ES ARE COMPUTED BASED Or~ PROTRACTED VALUES OF THE SECTION CORNER I LOCATION IN SECTION W-eLL ! FROM <j. LI~J F~O'M E. UNE c-,41 S39' I z154' t t ' I STATE PLANE C0-O RDS. GEODETIC POSI¥10N I LATITUDE 7o~- z9'- Z&:$93 7o'-z9' ZE. 7G7'~ 7o'- z9t z~. ~13v LONGITUDE I DATE 14qt]l' Z3..4.4ouJ II-I-/:,4 14-~'- ~f- Z7, 3&-q,.t II - ! - Sa Il - t II t- 54 CHECKED IFIELD ~OOK j.~. j 'I 3. w z~- S4 d. ~.. 2/-+- ~& j, H. J Zz - ~.... J 24-$d BUILT - . ~ x-..- Fa - 7 ' ~ , ~_4 ,'~ - ~,~,~r" ' ~ '~ I" a 400' J 2 0F 2 ~ %~,' ""e$ o~"~c5' ~ AND COMM E N TS : ............ -,.~ c~ . ~ ~ ~' ~.-~_~ .... CHECK LIST FOR NEW WELL P~iRMITS Company Lease & Well No. ~, ITEM AppRovE DATE (2) thru (3) Admin (_7~../ ~ thrh i2) 1.3, ~e 5. 6. 7. 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 '''''''i''''''' Is operator~.the.only~affected.party·. ...................... Can permit be. approved before'ten-day wait ' ..... ~ . Does operator have a. bond in force '' ...®e®eeeleelee~l'eeeeeeeeellelel. · . . Is a conservation..order needed ...... -.. ;.... ....................... Is administrative'ApproVal:needed .................................. Is the lease number appropriate ::" ' ' ~:e~eelee. eeelelleeell®eee..eeeeeeee. YES NO · · ~'~ .... : (4) Casg ~ (13 thru 21)' (22 thru' 26) 13. 14. 1..5. 16. 1'7. I,~3. t9. 23. £.~. ::?5. 2'6. 'I conductor ing provided ' 'S': 'str ....................................... Is ,enough:".cement used~to circulate on conductor and surface ......... Will.,:cement:"tie:in:.-surface ~nd intermediate or production strings .. Wilt':.'nement.:cover all known':productive horizons ..................... Will surface casing protect fresh water zones ....................... Will ~ll. Casing'-give'adequate safety in collapse, tension and burst.. Is this'.Well',to b~:kicked'Off from an existing wellbore ............. %s Old:wetlbore abandonment procedure included on. 10-403 ............ {s,.: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 to ~ psig Does, the choke'manifold comply w]API'RP-53 (Feb.78) .................. 'Is the presence of H2S gas probable ................................. .. · Additional reqUirements· -, ..e®eeeeele'e'ee.eell.eleeeeeee..eeeeee.eeeeeee. · , "..'' . .. , . · . , ~ ~ ~ A d~-t~onal ,-Rema~~q~~~~_~_/~ ~_~_~__~-- . .--- · R~RKS Geology: Engineering: HWK~ LCS Y~' BEW.~/.~.~ WVA~ MTM .~-'--HJH ~ rev: 03/13/85 6. 011 ~" ',...,,..:'i '. .I'~ITIAL 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. ~m~m~mmm~mmm~m~m~mmm~m~ RECEIVED ********************** JUL 1 6 1985 v~r~c~'~o~, 6VP 010,~0~ VE IFICA?ION LISTING PAGE ! I~* F,,TL~ ~EADER ~'ILE NAMK : ~DI'I' ,001 ~E~VIC~ ~AM'E : )ATE ~ ~AXi~ ~ LENGTH : 1024 ~ILE TYP~ >REV!OUS FILE t~, INFnR~ATIC]N R~cnR?)$ ** ~N~N CONTEN,T$ ~N : CONOCO A~,AAKA ~ANG: TOWN: 1 SECT~ 10 CTRY: USA ~N~N ~ONT~NTS UNIT TYPE CA?g SIZE CODE 000 000 013 065 000 000 008 065 000 000 007 065 000 000 00{ 065 0o0 000 00~ 065 000 000 002 065 000 000 007 065 000 000 00~ 065 000 000 00~ 065 TYPE CATE SIZE CODE 000 000 001 O65 ]'VP 010,~0~ VE~IFICATIfiN LISTING PAGE 2 ~OB ~{U~BF,,R AT ACC: 70599 9.6~5"~ 6070' - BTT SIZE = B,5" STAFLO/SY',~E~-X 10,4 LB/G R~ 30,0 S R~F 4,0 c~ ~ ~ a.~ THIS DATA HA~ NOT BE~N DEPTH SHIFTED -' OVERLAYS FIELD PRINTS LVP OIO,H0~ VERIFICATION blSTING PAGE , , , , , , , , , · , , · , , , , , , , , , ,, , , * , , ,, , · 8CNbl)~E~GER hOGS INCbUDED , , · DUAb INDUCTION LATER[,O(; · DATA AVAILARhMI 1078~ · ~ITHO DENSITY COmPeNSAble [,O~ :(LOT) * · CO~PMN,~ATEB NEUTRON !,,D~ (bDT) * · DAT~ AV~ILABbM~ 10614' TO I0300' * * , , , , , , , , , , , ** DAT~ ~ORMAT RECORB ** 2 1 66 0 4 1 66 I 8 4 73 60 9 4 65 ,lin ~,6 I 66 0 I 66 0 DATUM SPMCIFIC~TION BbOCKS ~NEM $~RVICE SERVICE UNIT API AP1 APl AP? ~iSE SIZE SPb REPR PRO:CE~S IP OPDER # bOG TYPE CLISS MOD NO, CODE (OCT'5] DEPT FT O0 000 O0 0 0 4 ! 68 00000000000000 i.. iCATION [.,]$TIlU(, PAGE ~FLU r, II., OHMM O0 I[LD DIL OHv~5~ O0 lb,~ OIL OHUM O0 ~P ~IL ~V O0 ~R ~ i/.., ~API O0 ~FLU ~I~,~ OH~M O0 b ~ D I L 0 H ~ ~ 00 ,;R ~IL OAPI O0 ~R LDT ~API O0 A t, I L D T 'I N O0 ~RMO LDT ~/~ O0 VaST t,Dm O0 A LD~ O0 PHI [~DT PU O0 ~EF LD:T O0 VCNL bDT CPS O0 ~CN~ LDT CP~ O0 ~ i., D T ~ A P I 00 ~HOB {,DT ~/C3 00 PRHO LDT ~/C~ 00 %~RAT LDT 00 RN~A !,,Dm O0 NPHI LD~ PU no PEF LDT O0 WCNL [,O~ CPS 00 ~CNb LDT CPS 00 SN IR~ OH~M O0 tbD TR~ OHUM O0 SP iRT MV O0 ~R IRT ~API O0 SN IRT OHv~ O0 IhD YRT OH~M O0 SP IRT ~V O0 ~R %R~ ~API O0 ~R TR~ CAPI O0 220 120 0.! 0 220 1.2o O! 0 50 420 000 890 ~0 10 280 350 000 ~0 3~0 1 ~ 0 OiO {.20 010 310 040 120 ol 46 44 nl O1 O1 46 44 o! O1 o! Ol. 02 ol O1 oo oo o ~o O1 Ol 02 ol ol oo OO o1 ~0 4~ o oi 4~ O! O! O1 sP CALl RNr~A ORMC) 1!903 5000 SFLU 090:2500 09o,~500 -999 2500 -999 ~SnO -099 ~500 NR~T -999,~500 ~CHL -999,2500 -999,2500 -990,2500 -999,~500 ..99,2500 990,~500 8FLU P£~ CAbI ~NRA ~CNb 0 o 0 o 0 o 0 o 0 o o o o o 0 o o o o 0 0 o 0 0 o 0 0 0 o o o o 0 0 0 o 0 o o 0 0 o 68 68 68 68 68 68 68 68 68 68 6:8 68 6.8 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 -999.2500 '999,2500 lbo '999,2500 GR -999 2500 NRtl -999~500 ~CFG -999,~500 "999,2500 NPHI '99~,7500 00000000000000 000000000~0,000 000000000 0000 000000000000:00 00000000000000 000000000000'00 00000000000000 0000000000:0000 000000.00000000 0000:0000000000 00000000~000000 000000000000:00 00000000000000 00000000000000 00000000000000 0000:0000000000 ooooooo'ooooooo §§ooooooo,.ooooo oooooooooooo §ooooooooooooo 0000000000000 000000.0,00000,0,0 00000000000000 00000000000000 00000000000000 O000OOOg:§O0000 0000000 00000 00000000000000 00000000000000 0000000000 oooooooooo~°o~6° ooooooooooooo ooooooooooooo 000ooo0000 0 o00o000000~ ° O0 00000000000000 00000000000000 00000000000000 00000000090000 00000000000000 00000000000000 00000000000000 -999 2500 -999 2500 -999 2500 -99 O0 -999 -~99 )~0000 -999 ~500 bT, STING PA~E 5 '999,~500 SP 4,7578 SP -999'2500 SP 10900 0000 SF"LU 3bUT SP ~N~A DRHO TLD DEPT SP CAhZ TbD Tb~ ', r '999 -999 '999 -999 '999: -999 -099 -999 4 -999 2500 2500 2500 ?500 ~]PHI 2500 2500 ~R~T 2500 ~CNL 2500 SP 7578 2500 10~00 0000 SFt, U "999 "999 '999 "999 "999 "999 5 4 500 500 ~500 2500 2500 ~945 8~2 -999 -999 -099 -999 0 ].0700 0000 SFt. U 500 gR ~305 SP 2500 RHOB 2500 ~PHi 2500 ~R 0864 NRAT 2285 ~C~5 4.77]4 SP 4.~492 ~P {0600 0000 ..35 2 1(173 0 72~7 ~P 1016 RHOB 7363 ~P~I 00o0 gR 0908 NR6T 2676 ~CNh ~.992 SP -. 2500 SP 999. 141.~750 ~p ~0~00 0000 ~F;.U -~9u.2500 UR -9~,6875 GR -990,7500 ~R -999 2500 '~99 250~ SFLU -~99 ~50 ~R -99~ 2500 DRHO -999 ~500 PEW '090 2500 CALl -99g 2500 ~NRA -999,2500 FCNL -999,2500 '98,6250 GR -999,~500 -999, 2500 · .999 ~00 -999 O0 -999 -999 -999 -999 -999 -999 -80 -099,2500 SN -319'5000 SN -999,2500 -999,2500 ib~ -999,~500 IbP '999,2500 GR '999,~500 NRAT '999,~500 NCNb -999,:~50~ PHOB -999,~500 NPHI -999,~500 SN 319,5000 ~N -999,2500 -999.2500 Ib~ -999,~500 Xb~ -999,~500 GR 2500 DR~O -999,2500 NRAT ~500 PEW -999,~500 NCNb {500 CAbI -999 ~500 RHOB 2500 ~NRA -9991500 NPHI .~500 FCNL -999 500 ~N ~500 ~R -999 500 SN 4375 GR 61 00,0 SN 4375 ~R 211,7i9 '999,.2500 IbD '999,2500 8FLU '8~.,6250 OR .99 25oo V HO -q9 1 50o 101,0000 CALl 0000 FCNb 50,6563 GR -71,7500 GR -59.5313 ~R 5 8320 TbD 55 0938 SFLU -55 7188 gR 2 4141 DRHO 27 4414 PEr 103 3750 CALl 2 6797 RN~A 2R3~ no00 WCNb -55i5313 GR -999 ~500 ~R -184.1250 ~R 6.6602 TbD -g99,2500 5'2305 101,0000 -999,~500 NRRT soo 1,0898 ,P~I 916,0000 57,9687 80,t750 26,7011 6.1133 5.7891 XbD I03,3750 ~R 0,I284 NRAT 2,4746 NCNb 8,8125 ~,9160 071.0000 8N 76,0000 SN -999,2500 SN 20.9375 6,5547 TbM 6,7031 5,6211 -999,2500 '999, i°° -999, ~'00 '0:'991'::'00"99:'~"999~50:0621,1~00 -999250:0 -999,2500 :-999,2500 -999,2500 -999,2500 -999,2500 -.999,2500 '999,2500 7;~273 12,3672 .999 2500 5 '1719 -999 2500 '99~ 2500 2500 '992 4258 346191 36660 5 8633 5 8633 6 1953 15 3 6 09~8 55 2 5352 293~ 0000 4492 28 7109 6 402'3 -999 2500 -0 0495 6,6953 6,5820 '-,VP 010.H02 VEPIFICATION LISTING PAGE DEPT 5P -990 IbM C. AI,I -999 RN~A -999 WCNb -999 PEP -999 ~bm TbD IbD -999 48 ~P ~14e4 D, HOB ~402 NPHI NRIT ,;840 NCNb ,5O0 SP ~500 ~P 06~5 SP 0400 0000 SFt, U 06~5 ~R ~500 SP 4844 RHOB 49~2 NPHi 0000 fir ~500 NRAT 2500 NCNb 0000 SP ~500 SP ~750 SP 10300 0000 SF!.,U 9500 gR ..50o 9687 RHOB 48~4 ~{PHI 0000 ~R ~500 ~500 NCNb 6250 SP 2500 SP ~500 SP 10~65 5000 SFLU ~500 2500 25OO 2500 NPHI 2500 2500 2500 ~CNb 2500 SP 2500 SP 2500 -57 6875 (;R ? 4375 DRHO 33 0078 Pg~ 84 7'500 CAb! ~ 7578 ~N~A ~0 4 ,0000 rCNb ~]O ~7~0 ~R -999 ~500 GR -746 1250 GR ~559 2 ~922 DRHO 3~ 207 PEW "99q 2500 GR -~27 5000 2 t152 124 9375 SFbU -999 2500 2 48~3 DRHD .03'4 91~1 PEF .,.99 2500 CA[,I "999 2500 rN~A -999 ,2500 -~36 6250 ~R 999 2500 250o -ggO 2500 -999 2500 SFLU -~99 2500 -999 ~500 DRHU -999 2500 CALI 'q9q ~500 '999 ~500 FCNb -~48 6250 ~R -999 ~500 -99~ ?5O0 ** FTLE TRAILED SER¥IC~ NAME VEDSTON ~ ~ATE ; MAXIMIJ. LENGTH : lO24 wILE TYP~ : 84,7500 GR n,066.4 NRAT 2.67'58 NCNb e RHOB 586 NPHI "999 -999 0 2 -999 -999 -999 42 -999 47 ~500 0 0854 NRA~ 6504 NCNL 2500 RHOB 2500 NPHI 2500 5313 2500 SN 031~3 2,7441 '999,2500 -999,~500 GE 0'06:64 NR~T ],02?3 NCNb ,2500 NPHI -999,2500 41,5000 -999,2500 SN -999 2500 ibp -999 -~99 '099 -999 -999 -999 -999 -999,2500 -999,~500 00 I[,D O0 GR ~00 NRAT O0 NCNb ~'500 RHOB 2500 NPHI 25'00 SN 7500 SN SN 83,8125 2,9512 3078,0000 2,4043 29;9805 0,00:00 -999',2500 -0'0493 2 4941 117;7'50:0 2302,00'00 -999,2500 0,:t:.953 -999,2500 -:0,2446 . 2, ,43 12~ O0 ~410 000 00 -999 ~00 O' 953 -999 500 ~99'9 ~500 -999 2500 -999 ~500 -999 2500 -~99 250'0 -999 2500 -999 2500 -999 2500 0 1953 -999 2500 '999 2500 3RTGIN : ~EXT R~EL ~A~E
