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Home My WebLink About182-175 Imagga"Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: -" OVERSIZED (Non-Scann able) [3 Other: ~,, NOTES: [3 Logs of various kinds [] Other BY: BEVERLY BREN VINCENT ~ MARIA LOWELL Project Proofing -. BY: ~BREN VINCENT SHERYL MARIA LOWELL Scanning Preparation (:~ x30= ~(~ + /2 -TOTALPAGES BY: ~ BREN VINCENT SHERYL MARIA LOWELL DATE: Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: BY; Stage 2 (SCANNING IS COMPLETE AT THIS POINT UNLES~ SPECIAL ATTENTION IS REQUIREC ON AN INCiVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES __ NO PAGE IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wl:~l Randilmas • Kupa Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510 -0360 ConocoP i i ps Pho ne: 907 - 265 -6830 July 15, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 G -08 (APD # 182 -175 / 304 -211) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent P &A operations of the Kuparuk well 1 G -08. If you have any questions regarding this matter, please contact me at 265 -6830 or Kelly McLure at 265 -6059. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad ORIGINAL "ATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas U Plugged ❑ Abandoned Q Suspended ❑ WAG ❑ ib. Well Class: 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WDSPL ❑ No. of Completions_ Other Service ❑ StratigraphicTest❑ 2. Operator Name: 5. Date Comp., Susp., �9 12. Permit to Drill Number: L ,111 7 Z3 ,111 182 175 / 304 211 ConocoPhillips Alaska, Inc. or Aband.: June; 2004 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 December 1, 1982 50 029 - 20849 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1323' FSL, 590' FWL, Sec. 29, T12N, R10E, UM December 18, 1982 1G - 08 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 1540' FNL, 1571' FEL, Sec. 30, T12N, R10E, UM 30' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Kuparuk Oil Pool 1091' FNL, 1944' FEL, Sec. 30, T12N, R10E, UM 4772' MD / 4539' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 540361 y 5981970 Zone 4 8715' MD / 6957' TVD ADL 25640 TPI: x - 538175 y - 5984379 Zone 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x 537800 y 5984822 Zone 4 none ALK 2571 18. Directional Survey: Yes ❑ No l= 1 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1500' MD 21. Logs Run: USIT, CCL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 30' 80' 30' 80' 24" 265 sx AS II 10.75" 45.5# K -55 30' 2232' 30' 2232' 13.5" 1300 sx AS III, 250 sx AS I 7" 26# K -55 30' 8698' 30' 6944' 8.75" 1140 sx Class G, 250 sx AS I Baker 7" K -1 cement retainer @ 6413' Baker 7" K -1 cast iron cement retainer @ 4772' 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none "): SIZE DEPTH SET (MD) PACKER SET none none perfs squeezed: 8091' -8163' MD 6495' -6547' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8187' -8192' MD 6564' -6567' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8195' -8199' MD 6570' -6572' TVD 6163' 48 sx Class G 8440' -8454' MD 6750' -6760' TVD 4772' 194 sx Class G 8470' -8493' MD 6772' -6789' TVD 6900' 40 bbls cement 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) n/a P &A Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) press. psi 24 -Hour Rate -> 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none ". ( At ii o NONE VER1 +sy fl 'tit '4 r BFI 3J . �z Form 10 -407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL • 28. • 29. • GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None ". 1G-08 not applicable N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelly McLure @ 265 -6059 Printed Na Ran Thomas Title: Kuparuk Drilling Team Leader Signature \ e • Zd S G7no Date ? Kt 5( Prepared by Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, Other (explain). Item 27: If no cores taken, indicate "none ". Item 29: List all test information. If none, state "None ". Form 10 -407 Revised 2/2003 • • ConocoPhillips Alaska Page 1 of 9 Operations Summary Report Legal Well Name: 1 G -08 Common Well Name: 1G -08 Spud Date: 11/30/1982 Event Name: ROT - SIDETRACK Start: 6/16/2004 End: 7/7/2004 Contractor Name: n1433@ppco.com Rig Release: 7/7/2004 Group: Rig Name: Nordic 3 Rig Number: Date From - To Hours Code C o d e Phase Description of Operations 6/16/2004 06:00 - 09:00 3.00 MOVE DMOB DEMOB Held PJSM on RD and moving rig, prepared rig and moved rig off 2N -311 and cleaned around well, rig off well at 08:30 09:00 - 00:00 15.00 MOVE MOVE DEMOB Began moving rig from 2N pad to 1G pad, have moved rig approx 18 of 25 miles 6/17/2004 00:00 - 05:00 5.00 MOVE MOB MOVE Fin moving rig from 2N pad to 1G pad, rig moved a total of 25 miles 05:00 - 07:30 2.50 MOVE RURD MOVE Level ground around cellar, layout herculite and berm around cellar ACCEPTED RIG @ 06:30 hrs 6/17/04 07:30 - 08:30 1.00 MOVE POSN MOVE Spotted rig over well and leveled same 08:30 - 11:30 3.00 DRILL OTHR ABANDN Loaded 8.8 ppg brine into pits and began loading pipe shed with 4" DP 11:30 - 12:30 1.00 WELCTL OTHR ABANDN RU wells group lubricator and pulled BPV, checked well presures, Tbg -0 -, IA -0 -, OA 50 psi and bled down to -0- 12:30 - 14:30 2.00 DRILL PULD ABANDN Cont to Toad pipe shed with 4" DP and flushed out surface lines with water 14:30 - 20:30 6.00 DRILL PULD ABANDN PU and stood back 40 stands of 4" DP, RU open top kill tank for well returns NOTE: While racking back DP, hydraulic fitting on spinners failed causing hyd oil to spray into floorhands eye's, flushed eye's at rig then sent to Prudhoe Bay Industrial Clinic to be checked out, was looked at and his eye checked ok and returned to work. 20:30 - 22:45 2.25 DRILL CIRC ABANDN Pressure tested lines to open top tank, checked well pressures, tbg & IA -0- psi, circ new 8.8 ppg brine around well at 4 bpm at 410 psi, blew down lines 22:45 - 00:00 1.25 WELCTL OTHR ABANDN Installed BPV and began ND Tree NOTE: Held pre - planning mtg with service company personnel followed with pre -spud mtg with rig crews 6/18/2004 00:00 - 00:30 0.50 WELCTL NUND ABANDN Fin ND 11" 3M tree 00:30 - 03:30 3.00 WELCTL EQRP ABANDN Cameron service man inspected LDS on tbg head, of the 12 LDS, 7 were in contact with pack -off, worked all LDS and found 3 that would not move, then ground down the 3 LDS, cleaned flange and hanger and installed H -P blanking plug 03:30 - 08:00 4.50 WELCTL NUND ABANDN NU 11" 3M x 11 "5M DSA, spacer spool and 11" 5M BOP stack 08:00 - 12:00 4.00 WELCTL BOPE ABANDN RU & tested BOPE, manifold, valves, rams and annular to 250 psi low and 3,000 psi high, tested to 3M due to top flange only being rated to 3M Note: Chuck Scheve W /AOGCC waived witnessing of BOP test 12:00 - 15:00 3.00 WELCTL EQRP ABANDN Backed out LDS, LDS were tight, installed blanking plug 15:00 - 18:00 3.00 CMPLTN PULL ABANDN Held PJSM, PU on hanger and 3 1/2" completion string to 100K and worked same with only 27" of movement and pipe did not come free, ordered out Schlumberger Wireline (SWS) to re -cut tbg LD 3 1/2" landing jt 18:00 - 22:00 4.00 DRILL PULD ABANDN PU and stood back an additional 23 stds of 4" DP while waiting on SWS 22:00 - 23:30 1.50 LOG RURD ABANDN Held PJSM, RU SWS scheaves and pack -off 23:30 - 00:00 0.50 LOG ELOG ABANDN RIH W /CCL and string shot to 3,000', RIH with 1 11/16" CCL and 12' single string, 80 grain string shot, max od of string shot 2 1/8" 6/19/2004 00:00 - 01:30 1.50 LOG ELOG ABANDN Cont RIH with string shot from 3,000' to 6,520', correlated to completion assembly, PU and ran string shot from 6,465' to 6,477', POOH LD fired string shot 01:30 - 05:00 3.50 LOG ELOG ABANDN MU 1 11/16" CCL and 2 5/8" chemical cutter with 4 centralizers and RIH, tool sat down at 5,130', PU on tool and began staging pump rate up to 2 bpm at 110 psi while attempting to work tool down, was able to work down to 5,279' and stopped in btm GLM, POOH 05:00 - 08:00 3.00 LOG ELOG ABANDN Changed out top centralizer from ridgid to bow spring centralizer and re- adjusted btm bow spring and ran back in hole with chemical cutter Printed: 7/13/2004 4:08:36 PM • • ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 1G -08 Common Well Name: 1G -08 Spud Date: 11/30/1982 Event Name: ROT - SIDETRACK Start: 6/16/2004 End: 7/7/2004 Contractor Name: n1433@ppco.com Rig Release: 7/7/2004 Group: Rig Name: Nordic 3 Rig Number: Sub Date From - To Hours Code Code Phase Description of Operations 6/19/2004 05:00 - 08:00 3.00 LOG ELOG ABANDN pumping at 2 bpm and 110 psi, RIH to 6,520' with no problems, PU and cut 3 1/2" tbg at 6,475' WL, POOH 08:00 - 08:45 0.75 CMPLTN PULD ABANDN PU on hanger and completion assembly, PU to 75K st wt and tbg was free, PU and LD hanger and pups, 08:45 - 09:15 0.50 CMPLTN RURD ABANDN RU to LD 3 1/2" tbg and RD SWS 09:15 - 21:00 11.75 CMPLTN PULL ABANDN POOH with 3 1/2" completion assembly. recovered 35 clamps, control line, SSSV, 4 -GLM's and 208 jts with 1 -cut piece of 3 1/2 ", 9.3 #, J -55 BTC tbg, Total recovered 6,486', Found tbg pin ends sand cut with corrosion on many of the collars, NORM tbg and checked ok. Valve pocket of # 2 GLM washed out. 21:00 - 22:00 1.00 CMPLTN RURD ABANDN RD 3 1/2" handing tools and finished wrapping conn's on tubing and unloaded pipe shed 22:00 - 22:30 0.50 CMPLTN RURD ABANDN RU rig floor to run 4" DP 22:30 - 00:00 1.50 ABANDN PULD ABANDN MU 6 1/8" bit, 7" csg scraper, bit sub, 6.16" Baker string mill and oil jars, began RIH W /BHA #1 PU singles from pipe shed, RIH at 1,300' 6/20/2004 00:00 - 02:45 2.75 ABANDN TRIP ABANDN RIH to 6,400' with BHA #1 to 6,400', Fin PU 48 jts of 4" DP from pipe shed then TIH with bit, scraper and mill from stds in derrick to 6,400', no problems 02:45 - 03:15 0.50 ABANDN CIRC ABANDN Est circ and washed down to 6,478', began seeing drag at 6,417' and set down with 30K st wt at 6,471', PU and washed down to 6,478' and set down 30K wt, appeared to be pushing fill or tagged top of stub from WL cut at 6,475', st wt up 118K, down wt 90K 03:15 - 04:45 1.50 ABANDN CIRC ABANDN PU to 6,463' and pumped 2 -20 bbls hi vis sweeps and circ hole clean, circ hole at 7.5 bpm at 1,100 psi and reciprocated pipe, had very little increase in cuttings from sweep, circ 4X btms up 04:45 - 08:15 3.50 ABANDN TRIP ABANDN POOH LD, bit, scraper and mill, found 2- 3 1/2" tbg cmt retainer slips after POOH, 1 -on mill and other from scraper 08:15 - 09:30 1.25 ABANDN TRIP ABANDN MU Baker 7" 26# model K -1 cement retainer and started RIH to 280', stopped to discuss with town about recovering slip segements 09:30 - 11:00 1.50 ABANDN TRIP ABANDN Decision was made to run gauge ring junk basket before running retainer, POOH & LD retainer 11:00 - 13:00 2.00 ABANDN PULD ABANDN Loaded pipe shed with 4" HWDP and 4 3/4" DC's and strapped while waiting on HES slickline 13:00 - 16:15 3.25 ABANDN SLIN ABANDN Held PJSM and RU HES slickline, RIH with 6.06" gauge ring /junk basket, set down at 6,372', PU and cont RIH to 6,450' with no other problems, POOH and recovered 2 additional pieces of slip segements, decision made to run retainer 16:15 - 20:45 4.50 ABANDN TRIP ABANDN MU Baker K -1 cement retainer and RIH, set same at 6,413' with no problems, st wt up 118K, down wt 90K 20:45 - 22:30 1.75 ABANDN DPST ABANDN While stung out of retainer attempted to pressure test same to 2,000 psi, after pumping 6.5 bbls of 8.8 ppg brine, only had a pressure increase of 1,300 psi, (1.5 bbls calc to press up to 2,000 psi) stung into retainer and attempted to test annulus, at 1 bpm was pumping either past retainer or had a hole in csg at 760 psi, PU out of retainer and pumped 1 bpm with same results, stung back into retainer pumping down DP and est an inj rate of 1/2 bpm at 1,710 psi below retainer with no communication into annulus, determined retainer was holding and had hole in csg 22:30 - 23:30 1.00 ABANDN OTHR ABANDN Discussed with town about hole in casing, decision was made to spot 250' /10 bbl cement plug on top of retainer to P & A lower zone, then - POOH and PU packer to isolate hole in casing. Note: Notified Chuck Scheve with AOGCC of plan forward and he approved setting of 250' plug on retainer without attempting to squeeze Printed: 7/13/2004 4:08:36 PM • ConocoPhillips Alaska Page 3 of 9 Operations Summary Report Legal Well Name: 1G-08 Common Well Name: 1G -08 Spud Date: 11/30/1982 Event Name: ROT - SIDETRACK Start: 6/16/2004 End: 7/7/2004 Contractor Name: n1433 @ppco.com Rig Release: 7/7/2004 Group: Rig Name: Nordic 3 Rig Number: Date From - To Hours Code Cade Phase Description of Operations 6/20/2004 22:30 - 23:30 1.00 ABANDN OTHR ABANDN cement below retainer due to low inj rate and pressure 23:30 - 00:00 0.50 CEMENT RURD ABANDN Held PJSM with Dowell then began batching up cement 6/21/2004 00:00 - 00:45 0.75 CEMENT PUMP ABANDN Dowell pumped 5 bbls FW and tested lines to 3,500 psi, then mixed and pumped 10 bbls (48 sxs) of class "G" cement at 15.8 ppg and 1.16 yield W/ add., ave 4 bpm at 500 psi, followed with 1 bbl FW and rig displaced cement to balance plug with 63 bbls of 8.8 ppg brine, ave displacement rate 3.5 bpm at 400 psi, CIP at 00:45 hrs, EST T.O.C. @ 6,136' 00:45 - 01:15 0.50 CEMENT TRIP ABANDN POOH slow 3 stds to 6,130' 01:15 - 01:30 0.25 CEMENT CI RC ABANDN Reversed out 1 DP cap and circ out cement contaminated brine, circ till clean 8.8 brine out, circ at 4 bpm at 400 psi 01:30 - 01:45 0.25 CEMENT TRIP ABANDN POOH 3 stds to 5,844' 01:45 - 02:45 1.00 CEMENT CIRC ABANDN Dropped DP wiper dart and circ down to wipe DP, did not see wiper plug shear, cont to circ hole at 7 3/4 bpm at 1,000 psi while reciprocating, no cement on btms up and circ a total of 4X btms up, st wt up 108K, do 85K 02:45 - 05:30 2.75 CEMENT TRIP ABANDN POOH LD Baker retainer setting tool and recovered DP wiper plug in plug catcher 05:30 - 08:00 2.50 ABANDI\ TRIP ABANDN MU Baker EA 7" retrievamatic test pkr and RIH and set same at 3,500' 08:00 - 16:00 8.00 ABANDN DPST ABANDN Pressure tested csg at 3,500' to 3,000 psi for 30 min, good test, RIH to 4,543' and tested csg for 30 min, good test, RIH to 5,490' and attempted to test csg and would not test, cont to POOH testing csg and found hole in csg at 4,845' with good csg at 4,827', tested csg at 4,827' for 30 min and had good test Good csg to 4,827' and hole in csg below 4,845' 16:00 - 19:00 3.00 ABANDI\ TRIP ABANDN POOH with Baker packer from 4,827' and LD same 19:00 - 22:00 3.00 DRILL PULD ABANDN Began loading pipe shed with 3 1/2" completion tubing and installed valve onto storm packer while waiting on Baker oil tools to return with re- dressed cement retainer and plug catcher 22:00 - 00:00 2.00 CEMENT TRIP ABANDN MU Baker 7" K -1 cast iron cement retainer, RIH at 1,900' 6/22/2004 00:00 - 01:45 1.75 CEMENT TRIP ABANDN RIH w/ Baker cement retainer to 4,772'. 01:45 - 02:45 1.00 CEMENT OTHR ABANDN Rig cmt lines, Set retainer @ 4,772', Break circ, Test 7" casing to 2000 psi for 30 min. 02:45 - 05:00 2.25 CEMENT SQEZ ABANDN Held PJSM, Dowell pumped 2 bbls fresh water, Test lines to 3500 psi, Sting into retainer, Est. injection rate of 2 bpm @ 1600 psi, Pull out of retainer, Mixed and pumped 40 bbls (198 sxs) of class "G" cement at 15.8 ppg and 1.16 yield with add., ave 3 bpm at 350 psi, holding 350 psi back pressure on choke, Sting into retainer, Dowell continue to displace cmt below retainer with fresh water, ave 3 bpm displacing cmt, Max pressure 1700 psi, Shut down with cement displaced to retainer, CIP @ 04:00 hrs., Saw increase in pressure after pumping 5.9 bbls cement below retainer, while pumping 3 bpm at ave 70 psi, pressure increase to 1,100 psi, Monitored outer annulas with no change while pumping cement, Pick up out of retainer and reverse out drill pipe at 4 bpm at 630 psi, had approx 2 bbls cmt back at btm's up, circ until clean, Shut down and drop wiper dart, Wipe drill pipe and shear dart w/ 1600 psi, had no cmt at btm's up, circ total of 2X btm's up at 7.75 bpm at 1000 psi, Placed total of 38 bbls below retainer @ 4,772'. 05:00 - 06:15 1.25 CEMENT TRIP ABANDN POOH 3 -1/3 stands, Pick up Baker storm packer & set same @ 36'. 06:15 - 12:00 5.75 WELCTL EQRP ABANDN Change lower pipe rams to 4 ", Nipple down BOPE, PJSM on changing out tubing spools. 12:00 - 15:00 3.00 WELCTL NUND ABANDN Remove old 3000 psi tubing spool and Install new 5000 psi tubing spool, Test same to 3000 psi f/ 15 min. Printed: 7/13/2004 4:08:36 PM • • ConocoPhillips Alaska Page 4 of 9 Operations Summary Report Legal Well Name: 1G-08 Common Well Name: 1G -08 Spud Date: 11/30/1982 Event Name: ROT - SIDETRACK Start: 6/16/2004 End: 7/7/2004 Contractor Name: n1433@ppco.com Rig Release: 7/7/2004 Group: Rig Name: Nordic 3 Rig Number: Date From - To Hours Code Code Phase Description of Operations 6/22/2004 15:00 - 18:30 3.50 WELCTL NUND ABANDN Nipple up BOPE. 18:30 - 19:00 0.50 WELCTL BOPE ABANDN Test BOPE to 250 psi low and 5000 psi high against blinds. Witness of test waived by AOGCC inspector Chuck Scheve. 19:00 - 19:15 0.25 WELCTL EQRP ABANDN Tighten gray -loc clamps on choke line. 19:15 - 19:45 0.50 WELCTL BOPE ABANDN Test BOPE to 250 psi low and 5000 psi high against blinds. 19:45 - 20:30 0.75 WELCTL EQRP ABANDN Replace gray -loc gasket on choke line. 20:30 - 21:00 0.50 WELCTL BOPE ABANDN Test BOPE to 250 psi low and 5000 psi high against blinds. 21:00 - 21:15 0.25 WELCTL EQRP ABANDN Tighten studs on DSA (7 1/16" 5M x 11" 5m) 21:15 - 00:00 2.75 WELCTL BOPE ABANDN Test BOPE to 250 psi low and 5000 psi high. Testing blinds, choke manifold, floor safety valves, top drive. 6/23/2004 00:00 - 01:45 1.75 WELCTL BOPE ABANDN Continue testing BOPE. Test upper pipe rams, lower pipe rams to 250 psi and 5000 psi. Test annular to 250 psi low and 3000 psi high. Test accumulator. Witness of test waived by AOGCC inspector Chuck Scheve. 01:45 - 03:00 1.25 WELCTL OTHR ABANDN Pull Baker 7 ", model EA retrieveamatic storm packer @ 36', POOH, UD storm packer. 03:00 - 05:15 2.25 CEMENT TRIP ABANDN POOH LD Baker 7" retainer setting tool and recovered DP wiper plug in plug catcher 05:15 - 06:30 1.25 LOG RURD ABANDN RU SWS. PJSM, MU USIT tool string (42.5'), consisting of Q head, CAL - Y(CCL), TCC,GR, 2 knuckles, Centralizer, cartridge, SON, transducer. 06:30 - 07:45 1.25 LOG ELOG ABANDN RIH w/ USIT logging tools. Ran in hole to 4738' WLM. Correlated w/ DIUSFL log dated 12/15/1982. Casing 7 ", 26 # /ft, K -55, BTC. 07:45 - 11:15 3.50 LOG ELOG ABANDN POOH f/ 4738' w/ USIT logging tools @ 1500 ft/min. 11:15 - 12:45 1.50 LOG RURD ABANDN R/D Schlumberger WL. 12:45 - 13:00 0.25 WELCTL OTHR ABANDN Set 6 1/4" ID wear bushing. Run in two LDS's. 13:00 - 14:00 1.00 ABANDI\ PULD ABANDN PU Baker MWD f/ running whipstock, break and install cover over electrical connection on bottom. 14:00 - 15:15 1.25 WINDOWPULD ABANDN PU /MU /RIH w/ (9) 4 3/4" DC's and (21) 4" HWDP. Drift collars to 1.91 ", Drift HWDP to 2.24 ". 15:15 - 15:30 0.25 WINDOWCIRC ABANDN Circ to clean rust f/ 4 3/4" DC's. Circ @ 7.88 bpm w/ 440 psi. Circ 75 bbls. 15:30 - 16:15 0.75 WINDOWTRIP ABANDN POOH stand back4 3/4" Drill collars and 4" HWDP in derrick. 16:15 - 16:30 0.25 WINDOWSFTY ABANDN PJSM on PU /MU Whipstock assembly 16:30 - 19:00 2.50 WINDOWPULD ABANDN PU /MU Baker 7" WindowMaster Bottom Trip Whipstock System. 19:00 - 20:45 1.75 WINDOWTRIP ABANDN RIH w/ 3 stands 4 3/4" DC's, 7stands of 4" HWDP. 20:45 - 21:00 0.25 DRILL DEQT ABANDN Surface test MWD tools. 21:00 - 23:30 2.50 WINDOWTRIP ABANDN RIH w/ whipstock slow to 4,560'. 23:30 - 00:00 0.50 RIGMNT RSRV ABANDN Service top drive. 6/24/2004 00:00 - 00:15 0.25 WINDOWTRIP ABANDN RIH w/ whipstock slow from 4560' to 4,655'. 00:15 - 01:00 0.75 WINDOWSETW ABANDN Orient toolface. Set whipstock on retainer @ 4772', top of whipstock @ 4755',21 deg left of high side. 01:00 - 02:30 1.50 WINDOWCIRC ABANDN Displace 8.8 ppg brine f/ hole w/ 10.0 ppg LSND new mud to mill window. 02:30 - 03:15 0.75 CASE MIT ABANDN Test casing to 2000 psi f/ 30 min. Chart test. Good test, lost 20 psi. 03:15 - 07:30 4.25 WINDOWSTWP ABANDN Mill Window in 7" 26 # /ft, K -55 BTC. Top of window @ 4755' (4527' TVD). Bottom of window @ 4767' (4535' TVD). Drill formation to 4797' (4555' TVD). Dress window. 07:30 - 08:15 0.75 WINDOWCIRC ABANDN Pump 20 bbls super sweep pill.. Hole appears clean. Formation cuttings in returns. Blow down top drive. Stand back 1 stand 4" DP. 08:15 - 10:00 1.75 DRILL FIT ABANDN RU to perform FIT /LOT. Check 10 3/4" x 7" annulus prior to test. 130 psi on annulus. Bleed off 5 gal, pressure decreased to 85 psi. Bring bleed tank over to bleed into. Left annulus open while testing formation. Printed: 7/13/2004 4:08:36 PM • • ConocoPhilips Alaska Page 5 of 9 Operations Summary Report Legal Well Name: 1 G -08 Common Well Name: 1G -08 Spud Date: 11/30/1982 Event Name: ROT - SIDETRACK Start: 6/16/2004 End: 7/7/2004 Contractor Name: n1433@ppco.com Rig Release: 7/7/2004 Group: Rig Name: Nordic 3 Rig Number: Date From - To Hours Code Code Phase Description of Operations 6/24/2004 08:15 - 10:00 1.75 DRILL FIT ABANDN Tank level increased f/ 2" to 5" while testing. Tested formation to 1050 psi w/ 10 ppg mud. Window top @ 4755' MD (4527' TVD). EMW 14.5 ppg. Rig down test equipment. 10:00 - 10:30 0.50 WINDOWCIRC PROD Pump Dry job, Rig down circ equipment. 10:30 - 12:45 2.25 WINDOWTRIP PROD POOH w/ Baker window mill assembly. Stand back 39 stands 4" DP, stand back 7 stands HWDP, UD single HWDP, UD single 4" DP, UD (9) 4 3/4" DC's. 12:45 - 14:00 1.25 WINDOWPULD PROD UD Baker Windowmaster mills. The Full guage 6.151" is still 6.151 ". 14:00 - 15:00 1.00 RIGMNT RSRV PROD Slip and cut 1 1/8" Drilling line, cut 48.75'. Check crown -o - matic 15:00 - 19:00 4.00 DRILL PULD PROD Make up 4 -3/4" x 7" bit & BHA, Orient tools, Program MWD /LWD tools, RIH w/ DC's & HWDP. 19:00 - 19:30 0.50 DRILL DEQT PROD Surface test MWD tools, Held tripping drill. 19:30 - 21:15 1.75 DRILL TRIP PROD RIH to 4,633'. 21:15 - 22:00 0.75 DRILL REAM PROD Obtain slow pump rates, Orient tool face, Wash & ream f/ 4,781' to 4,797'. 22:00 - 00:00 2.00 DRILL DRLG PROD Drill f/ 4,797' to 4,823', AST= 0.5 hrs ART= 0.1 hrs, WOB 2/8K, RPM 40/60, 300 GPM CO 2200 psi, UP 115K, DN 85K, ROT 94K, TQ 2400 ft/lb Note; Had extreme trouble working stab thru bottom of window @ 4,767', Mild packing off and unable to work pipe up or down at times. 6/25/2004 00:00 - 02:15 2.25 DRILL DRLG PROD Drill f/ 4,823' to 4,856', AST= 0.0 hrs ART= 1.0 hrs, WOB 2/8K, RPM 40/60, 300 GPM @ 2200 psi, UP 115K, DN 85K, ROT 94K, TQ 2400 ft/Ib, Pump Hi -vis sweep, Continued to have extreme difficulty trying to slide or rotate down to 4,833' then smothed out. 02:15 - 02:45 0.50 DRILL WIPR PROD Wipe through window f/ 4,856' to 4,732' with no problems- window F/ 4,755' to 4,767' very smooth. 02:45 - 12:00 9.25 DRILL DRLG PROD Drill f/ 4,856' to 5,103', AST= 3.0 hrs ART= 4.4 hrs, WOB 5/15K, RPM 80, 300 GPM e 2450 psi, UP 96K, DN 87K, ROT 94K, TQ 3000/4000 ft/Ib, Perform clean hole base line of 10.74 ppg w/ 9.8 ppg mud. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill f/ 5,103' to 5,435', AST= 3.5 hrs ART= 5.1 hrs, WOB 4/8K, RPM 85, 300 GPM @ 2200 psi, UP 103K, DN 90K, ROT 97K, TQ 3800/4100 ft/Ib. 6/26/2004 00:00 - 09:45 9.75 DRILL DRLG PROD Drill f/ 5,435' to 5,720', AST= 0.0 hrs ART= 7.5 hrs, WOB 6 /10K, RPM 85, 300 GPM @ 2400 psi, UP 105K, DN 95K, ROT 98K, TQ 3900/4300 fUlb, Ave ECD's 10.9 ppg w/ 9.8 ppg mud. 09:45 - 10:30 0.75 DRILL CIRC PROD Circ & repair swab in pump. 10:30 - 19:15 8.75 DRILL DRLG PROD Drill f/ 5,720' to 5,887', AST= 1.0 hrs ART= 6.0 hrs, WOB 6/18K, RPM 85, 300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TQ 4100/4500 ft/lb, Ave ECD's 10.9 ppg w/ 9.8 ppg mud. 19:15 - 20:00 0.75 DRILL WIPR PROD Wipe hole 5 stands in attempt to possibly unball bit, Hole very free and in good shape. 20:00 - 20:30 0.50 DRILL CIRC PROD Circ just off btm and pump 5 ppb medium nut plug to clean bit. 20:30 - 22:15 1.75 DRILL DRLG PROD Drill f/ 5,887' to 5,912', AST= 0.0 hrs ART= 1.0 hrs, WOB 6/18K, RPM 85, 300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TO 4100/4500 ft/lb, Ave ECD's 10.9 ppg w/ 9.8 ppg mud. Note; Flow check @ 5907' due to possible gain, Lost 20 bbls mud @ 5910'. 22:15 - 22:30 0.25 DRILL OBSV PROD Observe well for losses- Well static. 22:30 - 00:00 1.50 DRILL DRLG PROD Drill f/ 5,912' to 5,937', AST= 0.0 hrs ART= 1.2 hrs, WOB 6/18K, RPM 85, 300 GPM @ 2400 psi, UP 128K, DN 90K, ROT 97K, TQ 4100/4500 ft/lb, Ave ECD's 10.9 ppg w/ 9.8 ppg mud. 6/27/2004 00:00 - 02:15 2.25 DRILL DRLG PROD Drill f/ 5,937' to 5,972', AST= 0.0 hrs ART= 1.1 hrs, WOB 6/18K, RPM Printed: 7/13/2004 4:08:36 PM 1G -O0ell Events Summary • Date Summary 06/09/04 RIH TO 7143' AND TAGGED ON COLLAPSED TUBING, CIRCULATED 190 BBLS WATER IN WELL BORE - GAS WOULD,NOT DIE. RECIPED COIL AT -7120' AND KILLED WELL WITH ADDTIONAL 150 BBLS WATER, FOLLOWED BY 40 BBLS CEMENT - SQUEEZED IN 35 BBLS WITH 500 PSI PRESSURE INCREASE. 06/11/04 CMIT -T x IA failed, LLR of 4.5 gpm @ 950 psi. Function tested all OC- LSD's.❑ [ANN COM ISSUES, WH Maintenance] 06/12/04 TAGGED CEMENT PLUG @ 7077' RKB, ESTABLISHED INJ RATE 1 BPM @ 1500 PSI.❑ [ANN COM ISSUES, Tag] 06/12/04 SET BAKER CEMENT RETAINER IN 3.5" TUBING AT 6975' (CENTER OF ELEMENT). RETAINER WAS SET IN CENTER OF THIRD FULL JOINT ABOUT CEMENT TOP (TAGGED AT 7062'). [Cement -Poly Squeeze] 06/13/04 ATTEMPTED TO SET CEMENT PLUG THROUGH A RETAINER . PUSHED RETAINER TO BOTTOM @ 7056' CTM. ESTABLISHED INJECTIVITY @ 1 BPM AND 1500 PSI. POOH AND MU CEMENTING ASSEMBLY. RIH AND KILLED WELL BY BULLHEADING 80 BBLS SLICK SEAWATER . PUMPED 14.5 BBLS CEMENT FOLLOWED BY FRESH WATER (BULLHEAD 11.5 BBLS / LAY IN 3 BBLS ABOVE RETAINER). 06/14/04 DRIFT TO 6805 SLM, TAG TOP OF CEMENT, START INJECTIVITY TEST WITH PDS SPINNER. LEAK IN TUBING BETWEEN 6500' AND 6600' [Leak Detect - Patch] 06/15/04 LEAK DETECT USING, W /PDS SPINNER @ 1 BPM (LEAK VERIFIED) @ 6518' SLM TO 6561' SLM. ❑ PUMPED 133 BBLS SEA WATER WITH A 30 BBL DIESEL FP.❑ [Leak Detect - Patch] 06/15/04 PULL DV FROM STA.# 5 @ 6604' WLM (6613'RKB) DRIFTED WELL WITH KOT WITH OD OF 2.710" WENT TO 6710' WLM. ❑ [Workover prep] 06/15/04 FIRED STRING SHOT TO CLEAN PIPE OVER CUT INTERVAL. CHEMICAL CUT TUBING AT 6665' RKB (CENTER OF FIRST FULL JOINT ABOVE GLM #6) USING 2 5/8" CHEMICAL CUTTER. WELL FLUID WAS 8.8 PPG BRINE, DEVIATION AT CUT DEPTH WAS 57 DEG. TUBING /IA EQUALIZED BY OPEN GLM #5. TAGGED TD AT 6712'. 06/15/04 PUMP KILL JOB PRE RWO WITH 400 BBLS 8.8 PPG BRINE.❑ [Workover prep] 06/20/04 DRIFTED CASING TO 6450' WLM, CEMENT & SLIP'S IN JUNK BASKET❑ [Tag, Fish] .ids CÆJ II WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL M~/ BLUE LINE REPORT WELL DATE TVPE OR S I~ PRINT[S] OR CD-ROM ILM BLUE LINE 1 -OP~1ì ). ~Ie 1 1 1 C ,'L!J , 1'-;1 )(1 c./ c::: ifj"!.._! '75 -3010 5-21-04 Res. Eva!. CH 1 1 1 1(.;. £l~ /1 ;;{ .~-l'3 (7 Mech. CH Caliper Survey 1 Rpt or 2 Color Print Name: / í. .:' I' ... 1 'I (~ . /,' ¿I', .If ',' . I .'¡ '.1,/'1 ,'.' ¡"'-. J t'tr4\ /[. {,'.{.z."/A'v"'/(/I .t~ .. . , or , I I I ., / ' >{¡~/~itl../' .J- /lJ{:-¿'~/ 7"/ ¿'L IC"" Date: '7/~-: /~ '/L ;/ j I L. ( Signed: PRoAc:riVE DiAGNOSTic SERviCES, INC, PO Box I ~b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pdsl~1'memorylog.com Website: \\"\\'\\.memorylog.com Re: 10-08 P&A Original Wellbore & CUITent Status ( Subject: Re: 1G-08 PM Original Wellbore & Current Status From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 30 Jun 2004 11:18:53 -0800 To: "McLure, Kelly" <Kelly.A.McLure@conocophillips.com> CC: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> McLure, Kelly wrote: I We have already drilled through the C sands. This was the lower reservoir pressured sand and currently in , the B sand. Below that is the A sand believed to be pressured up with max pressure of 4000 psi, but they don't expect that high. Most likely 3800 psi. \ G -0 8/ \C(; d" '- \~ 'S Either way, changing rams to run pipe would be in your future. at balance. ECD will be the telling factor. Again, good luck with the operations. Tom Maunder, PE AOGCC --_....-------- Based on the pressyj:e;your 11 ppg should We plan to change the rams for the 3-1/2" liner if we get to drill all the way to bottom and run that. -----Original Message----- From: Thomas Maunder [mailto:tom _maunder@admin.state.ak.us] Sent: Wednesday, June 30, 2004 11:08 AM To: McLure, Kelly Cc: AOGCC North Slope Office Subject: Re: 1G-08 PM Original Wellbore & Current Status Kelly, Are you already through the C sands or are they to still be drilled?? An extension of the BOP test is approved. How your work plan develops will likely be the determinant of when you next need to test. Depending on the rams in use, your next test or partial test would be to change the rams for running the liner. Good luck with the operations. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, As per our conversation we are currently at the wíndow depth of 45791 MD/4529' TVD. We have completed our open hole LOT/FIT test and found a 12.4 ppg EMW at the window depth. Our desire is to trip in the hole back to 6628'TVD/7601' MD and do 2 full circualations to increase the mud weight from the current 10.0 ppg to 11.0 ppg. We would like to do this to test the strength of the C sand interval. If it holds this mud weight we plan to drill ahead the remaining 447' to total depth of the well. We are currently at the 7 day BOP test date requirement. We have not been to surface with the bit since Sunday. I would like to ask for an extension on our BOP test to the 14 day mark from the original done on 6-22-04. Please let me know if this exception is granted. Thanks, Kelly McLure -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, June 23, 2004 4:28 PM 1 of5 7/2/2004 10:36 AM Re: 1 G-08 P&A Original Wellbore & CUITent Status ( To: McLure, Kelly Subject: Re: 1G-08 PM Original Wellbore & Current Status Kelly, Good news on the USIT log. Good luck with the remainder of the well. I will place a copy of this message in the well file. As usual, please call with any questions or information. Tom Maunder, PE AOGCC McLure, Kelly wrote: Tom, We have the USIT log for the 1G-08 wellbore. It shows no corrosion beyond a 4 pits in the casing which look to be the thickness of a couple pencil leads. Therefore, we plan to run the one trip whipstock in and place it on the top of the cement retainer that was set at 4777' MD. The window will be milled and the FIT/LOT performed to 15.0 ppg then pulled out of the hole. We will proceed with the BHA pickup and drill our sidetrack (if the LOT/FIT test is okay) . Any further questions, call me. Thanks, Kelly Kelly McLure Operations Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) -----Original Message----- From: McLure, Kelly Sent: Tuesday, June 22, 2004 8:23 AM To: Tom Maunder (E-mail) Cc: Thomas, Randy L¡ Pysz, Nick P Subject: 1G-08 P&A Original Wellbore & Current Status Tom, The top of the Our plan is to set holes at 4777' MD. below the retainer. A CCL log was already run on the original drilling of the well in 1982. It correlates with the 7" casing tally from the original well. The original rig was Parker 141 which is now Doyon 141 with an RKB of 28 feet. The current Nordic RKB is 30.3'. The data we have, plus the shallow depth makes us feel confident we will be close to the accurate depth for not placing the retainer and whipstock in a collar not having to run another CCL log. The cement retainer has been set at 4777' MD¡ 38 bbls were pumped below the retainer. The whipstock will be placed on top of the retainer and is approximately 12' long. This puts the top of the whipstock at 4765' MD. (Directional planning attached shows 4759' MD with the whipstock being placed at 4771' for planning purposes.) holes in the 7" casing were located at 4827' MD. a cement retainer +/- 50 above the top of the We will leave the 8.8 ppg Brine and cement Plan forward is to run a storm packer and set at 35'. The lower rams will be changed to 4" and then ND BOP and change out the 20f5 7/2/2004 10:36 AM Re: I G-08 P&A Original Wellbore & CUITent Status ( tubing head. Test the BOP's, 250 and 5000 psi, and pullout of the hole with the storm packer, DP, and cement retainer stinger. The window will be milled and then kick off for the sidetrack. Please contact me if you have any further questions. Kelly Kelly McLure Operations Drilling Engineer Drilling & Wells Anchorage 907-265-6059 (direct) 907-265-1535 (fax) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, June 21, 2004 9:43 AM To: McLure, Kelly Subject: Re: IG-08 P&A Original Wellbore & Current Status Kelly, I confirm receiving your message. What you propose, determining if there is a 7" casing leak is appropriate. Please keep us informed of the results and forward. Tom Maunder, PE AOGCC appropriate plans McLure, Kelly wrote: Tom, The plan as shown below for the P&A of the original wellbore as shown below. A current status is at the bottom in red. Pre-Rig Well Work: 1. Notify the AOGCC field inspector 24 hours prior to : commencing pre-rig work. , 2. Have DHD crew PT tubing and casing packoffs. Cycle lock down screws and pressure test OA. 3. Slickline: Drift and tag tubing restriction at 7127' MDRKB. 4. Rig up CTU and cement unit. RIH t07120' and squeeze away cement into to the open A and C sand intervals. Bring cement to 7050' and jet out excess. 5. Slickline: Wait 24 hours and tag TOC. Pull DV at 6681' and circulate well to seawater. Pressure (CMIT) test to 2000 psi for 30 minutes (Call AOGCC to witness tag & CMIT) BELOW SKIP TO HISTORY SEE >FROM STEP 5 ABOVE History: 5. Attempted the first CTU squeeze (without a Cement retainer) was not successful in isolating the perfs. Pumped 45 bbls cement. 6. The second CTU squeeze did not hold either as Jerry Dethlefs passed on to you yesterday. Pumped 15 bbls cement. TOC in the tubing is about 6850'. 7. Ran a memory PDS spinner which showed multiple holes in the 30f5 7/2/2004 10:36 AM Re: 10-08 P&A Original Wellbore & CUITent Status ( ~, tubing at 6500-6600 ft. above the current top of cement. We are sill able to bullhead over 1 bpm down tubing. Fluid is exiting from the tubing holes. It appears the cement in the tubing is holding OK. Plan forward as of June 15, 2004: Basically the plan is to have the rig finish the P & A. will prep the well for the rig by circulating KWF and chemical cutting the tubing. Wells Group: 1) Have SL drift tubing with 2.70" drift for the 2 5/8" chern cutter to TOC. (tagged TOC last night at 6805') 2) Pull DV in GLM @ 6681' 3) Circulate well with KWF brine (8.8 ppg brine.. assumes 150 psi overbalance with seawater below 6681' to the perfs) 4) RU e-line and chern cut tubing at approx. +/- 6640' (mid jt.) 5) Set BPV and VR, prep wellsite. Nordic 3 Rig showed up on location and accepted the rig 06:30 on 6-17-04. Plan was as follows: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. Prior to moving rig over well check handover form that BPV has been installed. 2. MI/RU Nordic 3. Check IA & OA for pressure. Record on IADC report 3. Load 4.0" DP in shed while taking Brine in pits. 4. Take on 8.8 ppg Brine in pits. Pull BPV. R/u on tree and circulate 8.8 ppg Brine. Circ through choke until clean 8.8 ppg Brine returns are observed at surface. Run and set BPV again. 5. Take KB measurement and note on morning report. 6. Bleed the lA, inner annulus and remove the tree and adapter. Check landing threads and LDS. 7 '. Install blanking plug on top of the BPV. 8. NU BOP and test. NOTE: 11" 3000 PSI BOPE to 250# I 3000# * NEED 11 3000 x 115M DSA - ANNULUS VALVES ARE 3000 PSI the Top flange of Gen 1 Spool is 9. Cameron or Valve shop to pull BPV. Engage the 3-1/2" tubing hanger with a joint and LID the tubing hanger. (If unable to use a joint to screw in we need to use a spear from Baker Fishing), notify Wells Group to have Schlumberger on notice if original tbg cut failed.) 10. LD all the tubing. Accurately record jts laid down and length 11. PU 4.0" DP and rack back. 12. PU mill and casing scraper RIH to +1- 6650' MD. C&C. POOH 13. PU 7" cmt retainer & RIH to 6600' MD (50' above tbg cut at 6650' MD). Set retainer. Pressure test the casing IA and retainer. Establish injection rate. 14. Mix 100 BBL, 15.8 ppg Class G. Pump 100 bbls of cement through the cement retainer. IF the 100 bbls gets pumped away and no pressure increase seen then plan to mix and pump another 50 BBLS. If the cement is just pumping away then we will stop there. 40f5 7/2/2004 10:36 A Re: IU-Ug P&A Original Wel1bore & Current Status f \ * We will then increase the volume from 50 FEET (2.0 bbls) to 100 FEET (3.8 BBLS) of cement on top of the retainer. This will be the P&A of the original wellbore. Current Status: When we went into pull the tubing the tubing was not cut so a second cut had to be made in the tubing. This was completed and the tubing was cut at 6475' MD. The completion was pulled and then a casing scraper and mill where picked up and ran in the hole. When we pulled out of the hole, 2- 31/2" slips were found. One found in the mill and the other in the scraper. A gauge ring and junk basket run was made and the well clear to 6450' MD. The 7" retainer was picked and ran in the hole. While stung out of the retainer attempted a pressure test to 2000 psi. Held okay. We stung into the retainer and attempted to test the annulus at 1 bpm. It was either pumping past the retainer or there was a hole in the casing. picked up out of the retainer and pumped at 1 bpm again with the same results. Stung into the retainer and established an injection rate 1/2 bpm at 1710 psi below the retainer with no communication into the annulus. Either the retainer was holdign or we had a hole in the casing. Spotted 250 feet of cement on top of the retainer and pulled out of the hole. picked up a packer and ran in hole to 3500 feet to pressure test trying to find the hole in the casing. Any questions please give me a call at 907-265-6059. Regards, Kelly McLure of5 7/2/2004 10:36 AM STATE OF ALASKA /'"'- RECEIVE~r~ ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 032004 ~ APPLICATION FOR SUNDRY APPROYIAh Oil & Gas Cons. Commission ~ 20 MC 25.280 AnchoraQe ~ 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Annular Disp. 0 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 5. Permit to Drill N)IIi11ber: ~-182-175 vi" 6. API Number: / 50-029-20849-00 V 9. Well Name and Number: 1G-08 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): ~ 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 89' 4. Current Well Class: Development - [;2] Stratigraphic 0 Exploratory 0 Service 0 8. Property Designation: ADL 25640, ALK 2571 11. Total depth MD (ft): 8715' Casing CONDUCTOR SUR. CASING Total Depth TVD (ft): Effective Depth MD (It): 6957' 8128' Length Size MD TVD 80' 80' 2143' 16" 80' 2232' 10-3/4" 2232' 6944' PROD. CASING 7" 8698' 8609' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 8091'-8163',8187'-8192',8195'-8199', 8440'-8454', 8470'-8493' 6495'-6547',6564'-6567',6570'-6572', 6750'-6760', 6771'-6789' 3-1/2" Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BOT 'HB'; BOT '2-B' pkr= 7923'; 8239' SSSV= Camco TRDP-1A SSSV SSSV= 1901' 12. Attachments: Description Summary of Proposal [;2] Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Date: 13. Well Class after proposed work: Exploratory 0 Development [;2] 15. Well Status after proposed work: Oil [;2] Gas 0 WAG 0 GINJ 0 Contact: Title: :g;;Jþ'~ /1~~Þcf Commission Use Only Phone Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test ~ Other: 3S0()\>C:;, ""~ f\\ "'""-~M.. ~'C) V ~~+ \'C>-4C)\ \~~,~~ (.c::>, ~~\ \\\"'~ \ c.:,...O~ ~ \)\ Mechanical Integrity Test 0 Location Clearance 0 Burst Collapse Tubing Grade: J-55 Tubing MD (ft): 8276' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Kelly ~~3f5~6 ~ Kuparuk OrmCn!fTeam Lea r Date biZ 0 f SUndry NUmberj 0'1. ;¿ / / V øs 9f~ JJ"o,- OR\GtNAI COMMISSIONER BY ORDER OF THE COMMISSION Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE D." ~¡ð f Submit in Duplicate r--, I"". ConocoPhillips Alaska, Inc. J .t "J," ',.,'.""""""",,: ...,. .. -- ' ... - -- . -- -- -- Well Type: PROD Orig 12/24/1982 Completion: LastW/O: 7/8/1984 Ref Log Date: TD: 8715ftKB Max Hole Angle: 57 deg @ 6900 1(;;00&' ~,:c,,;: <;'~~ API: 500292084900 SSSV Type: LOCKED OUT Annular Fluid: Reference Log: Last Tag: 8128 Last Tag Date: 11/30/1999 Casihg"String. ALL,~ SIRI NGS Description Size CONDUCTOR 16.000 SUR. CASING 10.750 PROD. CASING 7.000 Tubing)StrirîgY'FUBING,..' '.,"" Size I Top Bottom 3.500 0 7929 3.500 7929 8276 Perforati&ns"SUmmary . .., Interval TVD Zone Status 8091 - 8163 6495 - 6547 C-1 8187 - 8192 6564 - 6567 UNIT B 8195 - 8199 6570 - 6572 UNIT B 8440 - 8454 6750 - 6760 A-4 8470 - 8493 6772 - 6789 A-4,A-3 Gas Lift'MandrelsNalves ~ ".. » .. . St MD TVD Man Man Mfr Type 1 1944 1944 Cameo KBUG 2 3606 3597 Cameo KBUG 3 5212 4810 Camco KBUG 4 5279 4849 Cameo KBUG 5 6613 5601 Cameo KBUG 6 6681 5638 Cameo KBUG 7 7572 6142 Cameo KBUG 8 7640 6185 Cameo KBUG 1. Extended Pkg P roduètiol'l" MandrelsiV alves St MD TVD Man Man Mfr Type 9 7960 6403 Cameo KBUG 10 8029 6451 Cameo KBUG 11 8211 6581 Cameo KBUG Othert?lugs. ecíOip;;'etc;' ,;JEWELRY., " Depth TVD Type 1901 1901 SSSV 7127 5885 SLiPSTOP 7900 6360 SEAL 7923 6377 PKR 8239 6601 PKR 8262 6618 NIP 8275 6628 SOS 8276 6628 TTL Fish . FISH ~. Depth Description 8430 1" CV 8518 TAILPIPE w/BOT2BPKR Genèî'åI;Notu. Date Note , 3/18/1996 OV pulled grom GLM @ 7640' was flow-cut in half 9/21/1998 Leaks found at GLM @ 7640', 7690' and 8211' 9/27/1999 Tbg +/- 6570 - 7600 is tight. 12/19/199~ FCO to 8520' (fish) .. , Top 0 0 0 TVD 6381 6628 KRU 1 G-O8 Angle @ TS: 45 deg @ 7958 Angle@TO: 41 deg@8715 Rev Reason: GLV DESIGN Last Update: 5/12/2003 Bottom 80 2232 8698 TVD 80 2232 6944 Wt 62.50 45.50 26.00 Grade H-40 K-55 K-55 ,";C" Wt 9.20 9.30 I Grade I J-55 J-55 Thread BTC EUE 8RD 'N.. Ft SPF Date Type 72 12 12/23/1982 IPERF 5 12 12/23/1982 IPERF 4 12 12/23/1982 IPERF 14 12 12/23/1982 IPERF 23 12 12/23/1982 IPERF V Mfr V Type DMY DMY DMY DMY DMY DMY DMY DMY VMfr V Type DMY DMY CV Comment 5" Dresser, 120 deg DA 5" Dresser, 120 deg DA 5" Dresser, 120 deg DA 5" Dresser, 120 deg DA 5" Dr¡¡sser, 120 dell DA VOD Latch Port TRO Date Run 1.0 BK 0.000 0 5/4/2003 1.0 BK 0000 0 5/4/2003 1.0 BK 0.000 0 5/4/2003 1.0 BK 0.000 0 5/4/2003 1.0 BK 0.000 0 5/5/2003 1.0 BK 0.000 0 3/9/1990 1.0 BK 0.000 0 7/8/1984 1.0 BK 0.000 0 3/18/1996 VOD Latch Port TRO 1.0 BK 0.000 0 1.0 BK 0.000 0 1.0 BEK 0.000 0 .., Thread Vlv Cmnt (1) Date Vlv Run Cmnt 1212/1999 Closed 11/30/199S Closed 9/26/1999 Open Description Cameo TRDP-1 A - locked out 3/85 UNABLE TO PULL SLiPSTOP 5/3/2003 Bot G Seal Assy w/Otis X Profile 2.813. BOT'HB' BOT'2-B' Cameo 'D' Nipple NO GO Brown Dropped in Hole JUNK Left in Hole Comment ID 2.813 2.992 2.813 3.000 3.000 2.750 2.992 2.992 /"'""'.., r--.... We1l1G-08A Revision No.1 Saved: June 1,2004 lG-O8 Drilling Program Pre-Rig Well Work: 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. Have DHD crew PT tubing and casing packoffs. Cycle lock down screws and pressure test OA. 3. Slickline: Drift and tag tubing restriction at 7127' MDRKB. 4. Rig up CTO and cement unit. RIH t07120' and squeeze away cement into to the open A and C sand intervals. Bring cement to 7050' and jet out excess. "::::L ;) () ~ '0 \ "::. <"<C..t'V\~t'\.~ Q \ , \ 5 J;-\ 3 (S~ 5. Slickline: Wait 24 hours and tag TOe. Pull DV at 6681' and circulate well to seawater. Pressure (CMIT) test to 2000 psi for 30 minutes (Call AOGCC to witness tag & CMIT) 6. Freeze protect well with diesel. 7. Eline: Chemical cut tubing 50' above TOC (approx. 7000'). 8. Set BPV and VR plug. Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. Prior to moving rig over well check handover form that BPV has been installed. 2. MI/RO Nordic 3. Check IA & OA for pressure. Record on IADC report 3. PO 4.0" DP and rack back 4. Take on seawater in pits. Pull BPV & VR plug. RIO on tree and circulate out freeze protect fluid from tbg thru choke until clean seawater returns are observed at surface. Run and set BPV again. 5. Take KB measurement and note on morning report. Install blanking plug. 6. Bleed the IA, inner annulus and remove the tree and adapter. Check landing threads and LDS. 7. Install blanking plug on top of the BPV. 8. NO BOP and test the Top flange of Gen 1 Spool is 11" 3000 PSI BOPE to 250# / 3000# . NEED 11 3000 x 11 5M DSA - ANNULUS VALVES ARE 3000 PSI 9. Cameron or Valve shop to pull BPV. Engage the 3-112" tubing with joint and LID the tubing hanger. (If unable to use a joint to screw in we need to use a spear from Baker Fishing) 10. LD two joints tbg and run a storm packer approximately 60' from surface in the 7.0" casing. Bleed annulus pressures to Zero and leave open to tank while pulling tubing spool and changing primary seal 11. ND BOP, Pull the tubing head and packoff (btm packoff is the primary seal) 12. Remove the slip packoff (primary seal) and replace with the modified packoff. 13. Replace the spool & packoff with the McEvoy Gen 3 (11" 3000 x 7-1116" x 5M) 14. NO Bop's to the 7", 5000 psi flange & test 250 psi & 5000 psi. 1 1G-OBA DRILLING PROGRAM. doc Printed: 2-Jun-O4 1""""0.. ~ We1l1G-08A Revision No.1 Saved: June 1, 2004 15. POOH w/ storm packer. PD mill and bit scraper RIH to PBTD. C&C. POOH. RD wireline set a CIBP inside the 7" casing at +/- 5418' MD based on casing collar depth. (Note: CIBP must be:2: 2.0' above a casing collar and:2: 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. Test okay, go to next step 16. Displace the hole with new 9.8 ppg LSND mud. 17. PD and Rill with Baker's "WindowMaster" whipstock system, bottom trip anchor, MWD, and DBHO on drill pipe from the derrick. Orient and set the whipstock using the MWD with the top of the whipstock set at +/- 5400' MD. ~ End Of Decomplete Start Sidetrack ~ \ <:::'-0<6 ~ ~ 18. Shear off the whipstock. Displace the 7" casing and the pits with LSND mud. Mill the window in the 7", 26#, L-80 ~ X- casingat 5400' MD/4917' TVD, and continue milling until the upper watermelon mill is outside the casing: :2: 29'. After Ñ.~ reaming through the window to eliminate burrs and other irregularities. Perform a FIT/LOT to 14.0 ppg EMW with a ,- Minimum acceptable EMW = 13.0 ppg POOH. The 13.0 ppg Minimum includes kick tolerance down to the C sand. ~ / 19. Drill the Intermediate hole section with a 6-1/8" pilot bit and a Hughes RWD (ream while drilling) Hole Opener to 7.0" to the contingency top set depth of 7622' MD/ 6628' TVD between the C sand and A sand intervals. Take an open hole FIT test to 14.0 ppg EMW. This FIT/FIT is to see if C sand will hold. When the hole takes the FIT 14.0 ppg EMW then we drill ahead. (IF NEED TO TOP SET SKIP DOWN TO CONTINGENCY SECTION) 20. Assuming the Kuparuk C sand held a 14.0 ppg FIT at approximately 7623' MD/6629' TVD, continue drilling to TD through the Miluveach Shale to give j: 200' of rat hole below the base of the Kuparuk A. The proposed TD is :t 8048' MD17006' TVD. At TD, circulate bottoms and make a wiper trip up inside the window. Rill to TD. Circulate and condition the hole to run the liner. POOH. 21. RID and run the 3-1/2" liner to TD. The required overlap is ~ 150': TOL = approximately 5250' MD. Reciprocate the 3-1/2" SLHT liner while circulating and cementing. RID Dowell and prepare to cement the liner. 22. Cement liner as per cement program bringing the cement up inside the window. Release from liner. Set the packer. 23. Displace the well above the TOL with seawater and until the returns are clean. Check for flow. POOH. LD/DP. Rill with the DP from the derrick and then LD/DP. 24. RID and RIH with the 3-1/2" tubing tag the TOL. Set packer & shear out of PBR. Space out and land. Rll.,Ds. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. 25. Install a TWC. ND BOPE. ND and test the 3-1/8" (5M) tree to 5000 psi with the IA open. Pull the TWc. Pressure up the IA to j: 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve. Install a BPV. RID and MlO Nordic 3. Post.Rig Well Work: 1. Pull the BPV. R/U SLD. Drift and tag to PBTD. 2. Dummy-off the GLM. RID SLD. 3. RID E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. RID E-Line. 5. Install new "s" riser and replace the well house(s). 2 1G-OBA DRILLING PROGRAM. doc Printed: 2-Jun-O4 ~ r'\ We1l1G-08A Revision No.1 Saved: June 1, 2004 CONTINGENCY ONLY Top Set 26. If insufficient FIT test is achieved between the C sand and A sand interval then a top set will be needed. 27. PU and run 5.5" flush joint casing to the top set depth of 7622' MD/6539' TVD. Cement as per the contingency cement program. 28. P/U a 2-7/8" DP and the 4-3/4" PDC bit, MWD, L WD, non-mag flex collars, jars, and DP as required. 29. Test casing to 3500 psi, drill cmt, float equip, drill 20' new hole and perform an FIT/LOT to 14.0 ppg EMW to ensure shoe will hold TD MW with ECD's. 30. Drill ahead, (Baker Inteq Directional Program attached). Maintain the LSND mud properties as per the MI program. The MW should be 11.4 ppg at the Top/A6: 7718' MD/6712' TVD. 31. Continue drilling into the Miluveach Shale to give .:t 200' of rat hole below the base of the Kuparuk A. The proposed TD is .:t 8048' MD, 7006' TVD. At TD, circulate bottoms and make a wiper trip. RIH to TD. Circulate and condition the hole to run the liner. POOH. 32. R/U and run the 3-1/2" liner from TD up to above the existing 5.5" flush joint liner top. The top of the 3-1/2" hydril 511 liner will be approx 5150' MD. The required overlap is;::: 150': TOL = 5150' MD. (Th second liner will be approximately 100' above the top ofthe 5.5"x 7"liner top. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 33. Cement liner as per cement program. Release from liner. Set ZXP. 34. Displace the well above the TOL with seawater and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 35. RlU and RIH with the 3-112" tubing tag the TOL. Set packer & shear out ofPBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the IA, PBR and TOL to 3500 psi. Bleed off all pressures. 36. Install a TWc. ND BOPE. NU and test the 3-1/8" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to .:t 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve. Install a BPV. RID and MlO Nordic 3. Post-Rig Well Work: 6. Pull the BPV. R/U SLU. Drift and tag to PBTD. 7. Dummy-off the GLM. RID SLU. 8. R/U E-Line. Run cement bond log inside the liner. 9. Perforate the Kuparuk as directed. RID E-Line. 10. Install new "s" riser and replace the well house(s). 3 1G-OBA DRILLING PROGRAM. doc Printed: 2-Jun-O4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 89 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Servia__ Kuparuk Unit 4. Location of well at surface 8. Well number 3955' FNL, 4689' FEL, Sec. 29, T12N, R10E, UM (asp's 540361, 5981971) 1G-08 At top of productive interval 9. Permit number / approval number 1540' FNL, 1571' FEL, Sec. 30, T12N, R10E, UM (asp's 538175, 5984379) 182-175 At effective depth 10. APl number 50-029-20849 At total depth 11. Field / Pool 1091' FNL, 1944' FEL' Sec. 30, T12N, R10E, UM (asp's 537800, 5984822) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8715 feet Plugs (measured) Fill Cleanout (12/19/99) to 8520' MD. true vertical 6957 feet Effective depth: measured 8520 feet Junk (measured) true vertical 6810 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 265 Sx AS II 80' 80' SURF CASING 2143' 10-3/4' 1300 Sx AS III, 250 AS I 2232' 2232' PROD CASING 8609' 7" 1140 Sx G, 250 Sx AS I 8698' 6944' Perforation depth: measured 8091 - 8163'; 8187 - 8192'; 8195 - 8199'; 8440 - 8454'; 8470 - 8493' true vertical 6495 - 6547'; 6564 - 6567'; 6570 - 6572'; 6750 - 6760'; 6772 - 6789' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 Tbg @ 7929' MD; 3-1/2', 9.34f, J-55 Tbg @ 8276' MD. Packers & SSSV (type&measured depth) BOT 'HB' Packer @ 7923' MD; BOT '2-B' Packer @ 8239' MD. R E C E IV E W/B-7 LOCK; SET ON 6/22/96 @ 1901' MD. 13. Stimulation or cement squeeze summaryFEB1 Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ~laska 0il & !~ Cons. C0mmissior ~1 I~1 iu! 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 99 156 3834 210 Subsequent to operation 200 112 1013 197 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ,~,. ,/~~ Title: Dat~repared~by J~ohn~ e~irc~e.~265.6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 G-08 DESCRIPTION OF WORK COMPLETED MARClT GEL SQUEEZE FOR WATER SHUTOFF 9/10/99: RIH & set a CRX Plug at 8262' MD to isolate the lower open 'A' sand perforation intervals. 9/11/99 - 9/12/99: MIRU & PT equipment. Pumped a fullbore 'C' Sand MARCIT Gel treatment for Water Shutoff, through the open perforation intervals located above the CRX plug at: 8091 - 9163' MD 8187 - 8192' MD Pumped: a) 500 bbls of Water Cool Down stage @ 3.8 bpm, followed by b) 500 bbls of 3000 ppm MARCIT Gel Polymer stage @ 3.8 bpm, followed by c) 200 bbls of 4500 ppm MARCIT Gel Polymer stage @ 4.0 bpm, followed by d) 200 bbls of 6000 ppm MARCIT Gel Polymer stage @ 4.0 bpm, followed by e) 1000 bbls of 7500 ppm MARCIT Gel Polymer stage @ 3.4 bpm, followed by f) 500 bbls of 9000 ppm MARCIT Gel Polymer stage @ 3 - 4 bpm, followed by g) 246 bbls of 12000 ppm MARCIT Gel Polymer stage @ 3 - 4 bpm, followed by h) 85 bbls Diesel Flush, followed by i) Shutdown. RD equipment & MOL. 9/19/99: RIH & bailed MARCIT Gel & fill from 8242' to top of CRX plug at 8262' MD. 9/24/99: RIH & pulled CRX plug from 8262' MD. 12/19/99: RIH w/CT & performed a fill cleanout to 8520' MD. Returned the well to production w/gas lift & obtained a valid well test. ARCO Alaska, Inc. · Post Office B~.. 400360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RI61h^ L September 17, 1990 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith: Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WELL A(~TE~ 1G-08 Stimulate If you have any questions, please call me at 263-4241. P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATO 1120 L. L. Perini ATO 1130 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments RECEIVED s E P 2 0 1990 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompany '~ '. STATE OF AI_ASKA 0 Al_A,_. ,A OIL AND GAS CONSERVATION COMMI,5omON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate _ Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3, Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1323' FSL, 590' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1487' FNL, 1624' FEL, Sec. 30, T12N, R10E, UM At effective depth 1143' FNL, 1912' FEL, Sec. 30, T12N, R10E, UM At total depth 1092' FNL, 1955' FEL, Sec. 30, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 8 71 5' feet 6957' feet Plugs (measured) 6. Datum elevation (DF or KB) 89' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1G-08 Permit 9. . ..~umber/approval number 82-~'~/ 90-383 10, APl number 50-029-20849 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 61 2' true vertical 6879' feet Junk (measured) feet Casing Length Structural Conductor 7 9' Surface 2 2 3 2' Intermediate Production 8 6 9 8' Liner Perforation depth: measured 8091'-8163', true vertical 6495'-6547', Size 16" 10.75" 7" Cemented Measured depth 265 Sx AS II 79' 1300 Sx AS III 2232' & 250 Sx AS I 1140 Sx Class G 8 6 9 8' & 250 Sx AS I 8187'-8192', 6564'-6567', 8195'-8199', 6570'-6572', 8440'-8450', 6750'-6757', True vertical depth 79' 2232' 6944' 8470'-8493' MD 6772'-6789' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 set to 8276' Packers and SSSV (type and measured depth) SSSV: Camco WRDP @ 1901', Packers: BOT HB @ 7923', BOT 2-B @ 8239' 13. Stimulation or cement squeeze summary S~'p Lo 0 7990 Intervals treated (measured) A~aSk~ Oil & Gas Cons. C0rrlrrlissJ0 A Sand' 8440'-8450' and 8470'-8493' AnChorage'' Treatment description including volumes used and final pressure Hydraulically refractured A Sd w/ 700 bbls GW and 59,700 lbs of 16/20 Carbolite. Final P=2815 psi 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 65 80 0 - 1344 176 Subsequent to operation 235 77 0 - 1277 158 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned '~~~'' ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE AlasKa, inc. · Subsidiary of Atlantic Richfield Coml~any CONTRACTO~I REMARKS WELL SERVICE REPOR' OPERATION AT REPORT TIME ARCO Alaska, In Post Office pox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 16, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 1G-08 Stimulate May, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. R. Brandstetter ATe 1120 L. Perini ATe 1130 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of Atla t cRichfieldCompaIW STATE Of ALASKA , ._ASKA OIL AND GAS CONSERVATION COIv. VlISSION i~i ~'~ APPLICATION FOR SUNDRY APPROVALS .... J 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1323' FSL, 590' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1487' FNL, 1624' FEL, Sec. 30, T12N, R10E, UM At effective depth 1143' FNL, 1912' FEL, Sec.31, T12N, R10E, UM At total depth 1092' FNL, 1955' FEL, Sec. 30, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 871 5' feet Plugs (measured) 6 9 5 7' feet 861 2' feet Junk (measured) 6 8 7 9' feet None Casing Length Size Cemented Structural Conductor 79' I 6" 265 Sx ASII Surface 2232' 1 0.75" 1300 Sx ASIII Intermediate & 250 Sx ASI Production 8 6 9 8' 7" 1140 Sx Class G Liner 250 Sx AS I Perforation depth: measured 8091 '-8163', 81 87'-81 92', 81 95'-81 99', 6. Datum elevation (DF or KB) RKB 89 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1G-08 9. Permit number 82-17~ 10. APl number so-029-20~4c,) 11. Field/Pool Kuparuk River Field Kuparuk Rive~.,O~ ol ,. ,, ...... CJi.~. Gas Cons. 6ornrr~issiu~ Measured depth ..... 79' 79' 2232' 2232' 8698' 6944' 8440'-8450', 8470'-8493' MD true vertical 6495'-6547', 6564'-6567', 6570'-6572' Tubing (size, grade, and measured depth 3.5", 9.2#, J-55 set to 8276' Packers and SSSV (type and measured depth) BOT HB @ 7923', BOT 2-B @ 8239', Camco WRDP @ 1901' , 6750'-6757', 6772'-6789' TVD 13. Attachments Description summary of proposal _ Detailed operation program X__. Hydraulically refracture A Sand w/ gelled water and 60,000 lbs of 16/20 carbolite. 14. Estimated date for commencing operation 15. Status of well classification as: June, 1990 Oil X Gas __ 16. If proposal was verbally approved Name of approver Date approved S e r vi ce 17. I here~~ th~ the foregoing is true and correct to the best of my knowledge. Signed . L~~ Title Senior Operations Engineer FOR COMMISSION USE ONLY BOP sketch Suspended _ Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integrity Test__ Approved by the order Commission Location clearance Subsequent form ORIGINAL SIGNED BY LONNiE C. SMITH require 10-/icrc Commissioner Date IApproval No.? ~...~ I Form 10-403 Rev 5/03/89 Approved Copy i~etur.ned SUBMIT IN TRIPLICATE Well 1G-08 A Sand Refrac Procedure April 20, 1990 CC: Cost tracking AFE #K80984 Property Code: 230DS10GL Refracture stimulation 1. MIRU tanks and related flowback equipment. . MIRU transports and pumps. Install 'tree saver'. PT lines. Pressure up the tbg X 7" annulus to 3000 psi. 3. Perform the standard quality control measures (On-site KOE). . Pump the fracture stimulation per the attached pump schedule. The proppant schedule should be programmed for continuous ramp. Obtain representative fluid samples of the pad, slurry, and flush stages during the stimulation. Maintain pressure on the tubing/7" casing annulus at 3000 psi during the fracture treatment. Estimated treating conditions are: WHTP(expected) = 3800 psi Fracture Gradient = 0.72 psi/ft Tubing Friction = 263 psi/1000 ft Perf friction = 100-200 psi Recommended Maximum Treating Pressure = 5500 psi Recommended absolute shut-down pressure = 6000 psi 5. Record ISIP and 5, 10, and 15 minute shut-in pressures. 6. SI well, bleed down annulus, and RDMO frac equipment. 7. Prepare well for CTU . Post-Frac CTU/SL Post-frac CTU C/O CTU clean-out procedure will be based on results from the 1Y-26A refrac and clean-out. Post-frac SL 1. MIRU SL. RIH and tag fill. RDMO. . If perforations are not covered and after the gel has fully broken, proceed with flow- back per accepted guidelines. KUPARUK WELL 1G-08 'A' SAND REFRACTURE PUMPING SCHEDULE 4/20/90 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT WT DIRTY VOLUME DESCRIPTION BBLS BPM PPG DESCRIPTION LBS STG/CUM HIT PERFS BBLS 2 3 4 5 6 7 8 9 10 GW PRE-PAD 150.0 20 0 NO PROPPANT 0 1 50 / 150 ............................................... SHUT DOWN FOR ISIP ....................................................... GW PAD 400.0 20 0 NO PROPPANT 0 400 / 550 GW w/2 PPG 18.4 20 2 16/20 M CARBO-LITE 1544 20/ 570 GW w/4 PPG 29.8 20 4 16/20 M CARBO-LITE 4999 35/ 605 GW w/6 PPG 35.6 20 6 16/20 M CARBO-LITE 8968 45/ 650 GW w/7 PPG 42.0 20 7 16/20 M CARBO-LITE 12358 55/ 705 GWw/8 PPG 40.7 20 8 16/20 M CARBO-LITE 13663 55/ 760 GW w/10 PPG 27.8 20 I 0 16/20 M CARBO-LITE 11661 40/ 800 GW w/12 PPG 13.1 20 1 2 16/20 M RESIN CARBO 6593 20/ 820 SLICK DIESEL FLUSH 76.0 +SV 20 0 NO PROPPANT 0 76 / 896 78 228 628 648 683 728 783 838 878 898 TOTAL 16/20 M CARBO-LITE= 59785 LBS TOTAL GELLED WATER = 757 BBLS DIESEL (FLUID LOSS)= 30 BBLS RESIN COATED 16/20= 6593 LBS TOTALSLICK DIESEL(FLUSH)= 76 BBLS+SV REGULAR 16/20= 53192 LBS 1. All fluids should be maintained between 90 and 100 F on the surface. 2. Proppant schedule should be programmed for continuous ramp. 3. Pre-pad and Pad should contain 40#/1000 gal silica flour 4. Stages 1 through 4 are: 40#/1000 gal gelled water, surface crosslinked(nondelayed), with 2% KCL by weight and 5% diesel by volume 5. Stages 5 through 9 are the same as the above but without diesel. 6. Stage 9 is all resin coated 16/20 carbolite. 7. Stage 10 (FLUSH) should include a volume adjustment (if needed) for surface equipment between the wellhead and densimeter. 8. This job is intentionally underflushed by 2 bbls. Bypass the blender tub at flush. ARCO Alaska, Inc. Date: July 15, 1988 RETURN TO: Transmittal #: 7225 ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following i{ems. one signed copy of this transmittal. t30-15 Kuparuk Fluid Level Report 30-10 Kuparuk Fluid Level Report 2 D-15 Kuparuk Fluid Level Report 2A-06 Kuparuk Fluid Level Report 1 G-07 Kuparuk Fluid Level Report 1 G- 08 Kuparuk Fluid Level ,Report 1 G-15 Kuparuk Fluid Level Report 31-01 Kuparuk Fluid Level Report 31-1 2 Kuparuk Fluid Level Report · 2A-03 Kuparuk Fluid Level Report 3 H- 14 Post Frac Job Report 2 B- 16 Bollom Hole Pressure' Survey 3J-1 0 Kuparuk Well Pressure Report Please acknowledge receipt and return Receipt Acknowledged' 7-11-88 7-11-88 7-12-88 7-12-88 7-08-88 7-08-88 7-08-88 7-08-88 7-08-88 7-O6088 7-O9-88 7-03-88 3-08-88 Tubing Tubing Casing Tubing Casing Casing Casing Tubing Tubing Casing AIIo Frac A-10 PBU Amerad ............. ~ ..... ' Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Mobil Unocal Chevron ATTACHMENT I I Drill Site lA Wel 1 No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 lA- 16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9 Date Drill Site Well No. Log Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 1B-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Well No. 1C-1 1C-2 lC-3 1C-4 lC-5 1C-6 1C-7 1C-8 ' . Lo9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 10 Well No. Log Date 1D-1 · 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 10-8 (WS-8) 5/i0/78 Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ ~lQ~~1Z/1]/85' Drill Site Well No. Log Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 16 Well No. Lo9 Date 16-1 16-2 16'3 16-4 16-5 16-7 16-1) Drill Site Well No. Log Date 9/7/82 1F 1F-1 9/25/82 1F-2 9/28/82 1F-3 12/8/84 1F-4 10/13/82 1F-5 11/12/82 1F-6 3/!2/83 1F-7 Al~ Oil & Gas Pons. 6ommi:::: ~.morage 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment Page 3' Drill Site 1Y Wel 1 No. .Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 JZ_ ~_3~ 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1.Y-9 6/20/83 tI~+'%11i 5/10/83 ~-~. 11/21/83 ~7/28/8~ 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 ]0/15/84 12C~. Drill Site 2Z' Well No. Lo9 Date 12Z~'~.,_ 7/10/83 ~/22185 2Z-2 "6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg:O052 R ED Alar, Aa Oil & Gas Cons. Comm..!::'-' Anchorag~ '=- .... Drill Site _ 1H Wel 1 No. ~H-~ ~1H-4 ~1H-7 ~1H-8 Lo9 Date 8/16/82 8/13/82 6/21/82 7/2O/82 7/22/82 Drill Site 1E Well No. 1E-lA 1E-2 1E-5 1E-6 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 · 1E-25 1E-26 1E-27 1E-28 1E-29 Loci Da te %8/19/81 '8/17/81"-) '""1/17/84/ 1E-3 '"'10/18/81'~.. "-11/7/81/ 1E-4~\,[ '-'8/4/80'x. '~10/27/81 "10/21/81"~> '~11/12/82// '~)/28/81~, ? %10/28/81/Y ~ . "~11/1/81/ '~11/28/84 "-8/26/82 '"8/29/82 ~9/1/82 '"~5/7/83 "-2./17/83 '~1/17/83 ~1/13/83 ~0/31/82 ~10/27/82 ]} "~6/13/83 '"i0/18/82~/ '"7/18/83 '"-~. O/16/82 Drill Site 1G Well No. "~1G-1 ~x,~l G_2 ~ ~"1G-3 "JlG-4 '~4G-5 % 1G-8 Lo9 Date 9/7/82 '9/25/82'~, 9/28/82 12/8/84/ I0/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Loo Date 1F '~1F-1 2/19/83 '~1F-2 2/3/83 "~1F-3 1/31/83 ~F-4 5/29/83 '~1F-5 10/25/82 '~1F-6 10/28/82 ~ 1F-7 11/19/82x,, ~ 517183./ RECEiV "/,L F E B 2 1 1986 Alaska Oil & Gas Cons. Commission Anchorage , .. ;-':c-:,'£77 5E~? : Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~BL?) ' 5/28/84 2c-1 11109183 · ' 2C-2 11/09/83 2C-6 11/08/83 2~-_J 11108183 C2C-27- 4/18/83 ~2-CT~' > 4 / 24 / 83 f2~--~-4":;4122183 2~3. 4/28/84 "~y~> 4/29/~ · ' ~-5 8/12/~ -' C~87 5/08-/~ .... . 3C-6 5719184 3C-6 5/17/84 -Otis Lynes -Lynes Lynes Lynes Camco Camco Camco Otis Camco Dresser PBU Flow Survey (Gradient) Otis Static Gradient Otis DrhSser Dresser Mini Drawdown & BUildup Survey / cat Receipt Acknowledged: Date: DISTRIBUTION B. Adams D&M W.V. Pasher F.G. Baker Drilling G. Phillips Phillips Oil P. Baxter Geology BPJ~E Mobil C. R. Smith Chevron NSK Operations Sohio J.J. Ra thmell Union R&D Well Files ARCO Alaska, inc. . ".'-"-E~ - ) 3~" '; ', ~:a'~ ~.:: .. ~ , -..;-',c-r.~ 9;~7 £77 5C37 Return To: . . . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: 4759 PAGE 1 of 2 ransmitted herewith are the following items. Please acknowledge receipt ' and return one 'signed copy of this transmittal. ' ~.u '~ORVE~S/PRESSOXE ~ANALYSTS <lA-2' 5/11,12/84 Torque Turn (Pressure & Temp Surveys) lB 11 ........ >iA-10 jlC-1 /1C-6 /!G-10-' ~ 1G~ ~¢,6:' /~-4 ~Y-5 7/00/84 7/10,12/84 5/10/84 i2/i7/83 8/04/84 12/2%/83 12/23/83 8/ii/84 5/21/84 5/13,14/84 6/26/84 6/30/-84 5/26/83 8/11/84 6/28/84 5/i8/83 7/07/84 12/27/83--. 12/14/83 12/15/83 7/03/84 4/10/84 C~mlco Otis Otis Static Otis Cam~o Cam~o Otis Camco Torque Turn (Pressure & T_m~p Surveys) Camco Static C~]~co Camco Camco C~CO Camco' Otis Otis Otis Otis Otis Canno HP Static Re ce ip F ~actnowl edg e d: B. Adams F.G. Baker P. B~x t er BPAE Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W,V. Pasher G, Phillips Phillips Oil J,J, Rathmell R g D C. R. Smith Sohio Union Well Files ~ARCO Alaska, In?''''- Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1G-8 Dear Mr. Chatterton: Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/LI05 Enclosure If t' CEIVED AUG 2 2 ~ .-.~ ~,~ ~, ,~s Cons. Commlssl~n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , ?--- STATE OF ALASKA ..... · ' ALASK.- .)IL AND GAS CONSERVATION ~ 'MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-175 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20849 4. Location of well at surface ~). Unit or Lease Name 1323' FSL, 590' FWL, 5ec.'29, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1487' FNL, 1624' FEL, Sec.30,'TllN, R10E, UM 1G-8 -- At Total Depth 11. Field and Pool 1092' FNL, 1955' FEL, $ec,30, T11N, R10E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 89' RKBI ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 12/01/82 12/18/82 1 2/24/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8715'MD, 6957'TVD ;1612'MD, 6879'TVD YES [] NO [] 1901 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run FDC/DIL/CNL/GR, BHCS/GR, Gyro/CCL, CBL/VDL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' PL 24" 265 sx AS II 10-3/4" 45.5# K-55 Surf 2232' 13-1/2" 1300 sx AS Ill & 250 sx AS I 7" 26.0# K-55 Surf 8698' 8-3/4" 1140 sx Class G & 250 s; AS I 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) 8470' - 8493' 3-1/2" 8276' 7923' & 8239' 8440' - 8454' 8195' - 8199' w/12 sPf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8187' - 8192' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8091' - 8163' 7892' - 7894' 250 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATi© TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA R j~ ~' ~ I ~/ ~' I~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. L. ~., L ! V ~ L~ NONE AUG 2 2 I,~ A~aska Oil & Gas Cons. Commission Anchorage Form 10407 GRUS/WC07 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . 30. . . ' :. · · GEoEoG¢cMARKERs.. : 'i' - ": "" : ' FoRMATiON TESTS . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7956' 6400' N/A Base Upper Sand 8163' 6547' Top Lower Sand 8418' 6733' Base Lower Sand 8548' 6831' 31. LIST OF ATTACHMENTS Workover Wel 1 Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /~/,,,,~_~ ~/'~~~ Area Drilling Engr. Signed Title Date , , , 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". Au~. or W.O. n~ ~ Ai~:-:, F~i':1204633 -- Cap 103993 -"SlOpe' BorOush :ADL ~25640 Ist~o Alaska ]Well no. 1G-8 W/O Recompletion Operator ARCO Alaska, Inc. .. Spudded or W.O, begun _ Workover? Date and deptfl aa of 8:00 a.m. 6/29/84 ]Hour Complete rocord for eech dey ro~)rtod IA.co w.,. 56.24% Prior statul if a W.O. 2000 Hrs. 7/02/84 7/03/84 7/04/84 thru 7/05/84 7/06/84 7" @ 8612' 8612' PBTD, POOH 8.8 NaC1 AcqepC ri~ @ 2000 hfs, 6/29/84. Pull BPV. Att to kill well, hole taking fluid, pmp total of 90 bbls BridseSal pill & 9.8/8.8 ppg NaC1. (Accum fluid loss - 512). RIH, pull dummy vlv. ND tree, NU & tst BOPE. RU Schl, RIH w/Jet tbg cutter on WL, cut tbg @ 7798', spot 25 bbls BridgeSal pill, POOH w/3½" tbg, std back 93 atds. TIH w/BRA, tag fsh @ 7801' DPM, wrk over fsh, POOH. 7" @ 8612' 8612' PBTD, Cln out to PBTD 8.8 NaC1 POOH, no fsh. TIH w/BHAw/4¼" grapple, chase fsh to 8148', POOH, rec'd complete fab (pkr, "D" nipple, shear out assy, 3½" pups). RIH w/bit & scrpr, tag up @ 8358', wsh to 8395'. 7" @ 8612' 8612' PBTD, Prep:~o-rn CA 8.8 NaC1 :- :_ :. -' Wsh 8345'-8607-~i~BU,' circ, SI, POOR 125', rev circ, spot 45 bbls Brid~on b~m, POOH, LD csg scrprs. RIH w/Bkr R-3 pk~~Pmp. 50 bbls fluid. (Total fluid loss 681 b~~~--~L.'B pkr, set @ 8249'. RU to rn CA. ,, 8612~ P~TD', ~ZR w/sage flag/CC-'% 8.8 RaC1 ~ w/CA, stta$ taro ~ra. 2-~ pkr @ 82~9' WLM, pushed top of da hole to 8527' BP~, vould acc go further. POOH w/CA. ~H ~/gage ~t~g/CC~. RECEIVED AUG 2 219 4 Alaska OJJ & Gas Cons. Commission Anchorage IDate I Title Oil and Gas Company -. Daily Well History-Final Report I=lb~a: Prepare and submit the "Final R~porr' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. ? "FI~ Re,orr' should be submitted also when operatione ere suspended for an indefinite or appreciable length of time. On workovers when an official test is not req,,Ired upon completion, report completion and representative test data in blocks provided. The "Final Repert" form may be used for reporting the entire _ol~eration If space is available. North Slope Borough ADL #25640 District ~ County or Parish I Alaska Field Lease or Unit Kuparuk River Auth. or W.O. no. T~'tle AFE: Exp 204633 - Cap 101993 rAccounting State cost center code Alaska Well no. [G-8 w/O Recompletion Operator AR.Co W I. ARCO Alaska, Inc. 56.24% Spudded or W_O. begun Date Workover Complete record for each day reported Date and depth as of 8:00 a_m. 7/07/84 6/29/84 otal number of wells (aclive or inactive) on this DSt center prior to plugging and bandonment of this well 1 our I Prior status if a W.O. 2000 Hrs. I 7" @ 8612' 8612' PBTD, RR 7.0 Diesel & crude RIH w/gage ring & CCL, tag TOF @ 8518' CBL meas, POOH. RIH w/BOT 2-B pkr, set @ 8239' CBL. Rn 206 its, 3½", 9.2#, J-55 BTC tbg & ind. Set BPV, ND BOPE, NU &tst tree to 250/3000 psi. Displ well w/30 bbls diesel, followed by crude. Set BPV, secure well. RR @ 1930 hrs, 7/7/84. Tbg tail @ 8276', "D" Nipple @ 8262', BDT 2-B Pkr @ 8239' HB Retrv Pkr @ 7923' Old TD Released r,g 1930 Hrs. Classifications (oil. gas. etc.) Oil New TD Date Producing method Flowing Potential test data 8715' 7/07/84 PB Depth 8612' Kind of rig Rotary Type completion (single. dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Dale Reservoir Producing Interval Oil or gas [Test time Production I Oil on test Gas per day Pump size, SPM X length Choke size ' T.P. C.P. Water % GOR Gcavity Allowable Etfective date corrected __ The above is Correct Date ]Title 7/23/84 Drilling Superintendent ARCO Alaska, Ir~ Post Office i~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1G-8 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L97 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED AUG 1 6 1~ AlaskB Oil & GBs Cons. Commission Anchorage STATE OF ALASKA ----, ALAS~ . OIL AND GAS CONSERVATION ,MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-175 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20849 4. Location of Well Surface: 1323' FSL, 590' FWL, Sec.29, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 89' 12. 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number lC-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ' [] Pulling Tubing ~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig @ 2000 hfs, 06/29/84. Pulled BPV. Pumped 25 bbls Bridgesal pill followed by 9.8 ppg NaC1. Dis pill w/70 bbls H_O. No visible fluid level. Pumped an additional 25 bbls pill followed by 51 bbls 8.8 ppg NaC1. Pulled duZmmy f/side Pocket ~ 7781'. Mixed & circ. 8.8 ppg NaCl - lost 216 bbls in 6 hrs. Set BPV. N tree. NU BOPE & tstd to 3000 psi - ok. Pulled BPV. Unable to shear SBR. RU &circ Bridgesal pill. RIH w/tbg cutter, on W/L, & cut tbg ~ 7798'. Spotted 25 bbl Bridgesal pill. POH w/3-1/2" tubing. RIH & tagged fish @ 7801'DPM. Worked over fish - unable to hold it. Circ& spotted 30 bbls 10.0 ppg NaCl, 40 bbls 10.8 ppg Bridgesal & chased w/lO bbls 10.0 ppg NaC1 & 30 bbls 8.8 ppg NaC1. POH & LD cut jt of 3-1/2" tbg & SBR barrel. TIH w/4-1/4" grapple & chased fish to 8148'. Recovered fish (seal bore assy, pkr, 3-1/2" pup, "D" nipple, 3-1/2" pup, shear-out assy), POH & LD. Washed f/8345' - 8607'. Spotted 45 bbls Bridgesal pill. RIH & set R-3 pkr @ 8450' RIH w/2-B pkr assy & set ~ 8249' POH. RIH w/compl assy. Sting into pkr ~ 8249' Pkr started downhole. Push.ed top of pkr to 8527'DM (34' below btm perf ~ 8493'). POH w/compl, assy. LD 64 jts tubing & jewelry. RIH w/gauge ring & CCL. Tagged top of fish ~ 8518'. RIH w/2-B pkr & jewelry & set ~ 8239'. RIH w/completion assy (SSSV @ 1901' & HB retrievable pkr @ 7923'). Stabbed into pkr ~8239'. Pressured up on tbg to check stab-in. Spotted 10 bbls fresh water across perfs. Landed hgr & tstd packoff t~ 5000 psi. Dropped ball & pressured tbg to. 2000 psi - ok. Bled pressures. Set BPV. ND BOPE. NU tree & tst~ to 3000 psi - ok. Pulled BPV. Disp well w/30 bbls diesel followed by crude oil. Opened SSSV. Set BPV. / Secured we1,& released rig @ 1930 hfs. 07,07,84. R E C E IV E D AUG 1 6 1984 14. I hereby c.e,r~ify that the fore.o~ing is true and correct to the best of my knowledge. AlaSKa 0ii & Gas Cons. O0mmissiu. {,~///~ ~~~. Anchorage , / . Area Drilling Engineer Signed Title Date ~//~/~ The sp mission ~se ~ ~ '(~. ,~ ,.~ . ,..'~' ~ ConditiOns of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10~,03 GRU8/SN36 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaskz Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 10, 1984 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached following in duplicate are subsequent notices on the wells at the Kuparuk River Field: Well Action Date Performed 1F-11 Fracture 6/25/84 1F-12 Perforate 6/29/84 1F-12 Fracture 7/08/84 1G-6 Re-perforate 8/01/84 1G-7 Fracture 7/29/84 1G-8 Fracture 7/23/84 2B-7 Perforate 7/24/84 2B-8 Perforate 7/25/84 2B-9 Perforate 7/27/84 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED AtJG ! 1984 Oil & Gas Cons. Commission Anchoraga ARCO Alaska, Inc. is a Subsidiary ol AllanlicRichlieldCompany STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 1323' FSL, 590' FWL, Sec. 29 T12N, R109E, UM OTHER [] 5. Elevation in feet (indicate KB, DF, etc.) (RKB) 89 ' 12. 7. Permit No. 82-175 8. APl Number 50- 029-20849 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-8 1 1. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RI VER O I L ADL25640 ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] 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.) (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). On July 23, 1984, the "A" sands of Kuparuk well hydraulically fractured and propped to improve treatment consisted of 158 BBLS of gelled water fluid and 5,544 LBS of 12/20 sand as proppant. 1G-8 were production. The as pad and carrying Prior to pumping, equipment and sand was tagged with R.A. tracer performance. lines were tested to 5000 psi. The to aid determination of job P, ECEIVED AUG 1 3 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATI ONS COORDI NATOR The space below for Commission use 8110184 Date Conditions of Approval, if any: Approved by COMM ISS ION ER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' -_ Attached are notices-of intention to 1G-1, -2, -3, -4, -5,--6, -7 and -8. fracture If you have any questions, please call Kuparuk we l Is me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JUL 1 2 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichlieldCompany "~-" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY .NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 9951 0 4. Location of Well SURFACE LOCATION' 1:323' FSL, 590' FWL, T12N, R109E, UM Sec. 29 7. Permit No. 82-175 8. APl Number 50- 029-20849 9. Unit or Lease Name KUPARUK RIVER UNIT 5. Elevation in feet (indicate KB, DF, etc.) (RKB) 89' 12. 10. Well Number 1(3-8 11. Field and Pool KUPARUK RIVER FI ELD I 6. Lease Designation and Serial No. KUPARUK RIVER O I L ADL25640 ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ 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.) (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). It is proposed that the "A" sand in Kuparuk well 1G-8 be hydraulically fractured and propped to improve production. treatment uses gelled water as the pad and carrying fluid sand as the proppant. The and 12/20 Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant and pre-post frac logs are included in the treatment program. Fluid' Gelled Water Proppant' 12/20 sand ANTICIPATED START DATE' BBLS 167 LBS 7,500 July 30, 1984 Subsequent Work Reported on Form RECEIVED JUL 1 21984 Alaska 0il & Gas 00ns. C0mmissi01 Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. //~/~__~~~ KUPARUK Signed --_ _ ~, -ride OPERAT IONS COORD i NATOR The space below for Commission use Date 7/10/84 Conditions of Approval, if any: Approved by Approved Copy By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 25, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 1G-8 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose to convert 1G-8 to a selective single completion. Since we expect to start this work on June 2b, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area ~illing Enginelr JBK/JG'tw GRU8/LIO Enclosures RECEIVED JUN 2 5 1984. ~'r,:~';,a Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~ .,_ AND GAS CONSERVATION CC ..,,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL []X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-175 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20849 4. Location of Well Surface: 1324' FSL, 589' FWL, Sec.29, TllN, RIOE, UM TD: 1092' FNL, 1955' FEL, Sec. 30, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 89' 6. Lease Designation and Serial No. ADL 25640 ALK 2571 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 16-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 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 [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Tubing t[~) Other [] Pulling Tubing Pull v (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). ARCO Alaska, Inc., proposes to convert well 1(:;-8 to a selective single completion. The procedure will be as fol 1 ows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. A retrievable packer will be run to verify zone isolation between A and C sand. Well will be cement squeezed if communication exists between "A" and "C". 4. The well will then be completed as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: June 25, 1984 RECEIVED Subsequent Work JUN 2 Alaska Oil ~'A~'~ c'ons. Cornrnissl~ 14. I hereby c~that the foregoing is true and correct to the best of my knowledge. //~~ ~, Signed ~/~~~,/~'"~'~ Title Area Drilling Engineer The spac~low/~o~sion use Conditions of Appro~//if any: / Approved by. BY LO,q,qlE 5. SllilT! COMMISSIONER Approved Copy .Returned By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU8/SN04 TO: William VanAlen Transmitted her~Pith are the following: D~ W. Bose~~~4~W PLEASE ~,F- FILM, T- TAPE, PC - PHOTCCOPY PLEASE ~ R~CE~ TO: ANCHORAGE, AK, 9951~ / ~../<.'/2~ R£CE I VjED FEB ~-~ I.~ -g 3'---- DATE: Alask~ Oil & Gas Anchorage /~Rco Alaska, Pos! Offic )x 360 Anchorage, Alaska 99510 ,Telephone 907 277 5637 February 10, 1983 · Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas ~Conservation Commission 3001 Porcupine Drive Anchorage,'AK 99501 SUBJECT'' State Reports Dear Mr. Chatterton- Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 Also enclosed are well completion reports for' 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska, Inc. is a subsidiary of AllanticRichlJeldConlpany Oil 8: Gas i]~]ris Uoln[iilS.'-::irjs, ~" ~"- STATE OF ALASKA ALASK,.L, :.LAND GAS CONSERVATION ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL []~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-175 3. Address 8. APl Number P.0. Box 360 Anchorage, AK 99510 5o-029-20849 4. Location of well at surface i~O~, 9. Unit or Lease Name ----- Kuparuk River Unit 1323' FSL, 590' FWL, Sec. 29, , R10E, UM I LOCATION,S At Top Producing Interval!? I VERIFIED 10. Well Number 1487' FNL, 1624' FEL, Sec. 30, ~,~-IN, R10E, UM i.urrc 1G-8 At Total Depth !~ I~, H ~-- 11. Field and Pool 1092' FNL, 1955' FEL, Sec 30, Tj-$N, R10E, UM z.~'.~ . Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 89' RKB I ADL 25640 ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., SuMp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 12/01/82 12/18/82 12/24/82I N/A feet MSL[ 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD} 19. Directional Survey I 20. Depth whereSSSV set ~21. Thickness of Permafrost 8715'MD, 6957'TVD 8612'MD, 6879'TVD YES~] NO[][ 1996 feetMD 1500' (aDDrOX.1 · , , 22, Type Electric Or Other Logs Run FDC/DIL/CNL/GR, BHCS/GR, GYR0/CCL, CBL/VDL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' PL 24" 265 sx AS II 10-3/4" 45.5# K-55 Surf 2232' 13-1/2" 1300 sx AS III & 251) sx AS I 7" 26.0# K-55 Surf 8698' 8-3/4" 1140 sx Class C, & 2 i0 sx AS I 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) 8470' - 8493' 3-1/2" 7880' 7841' 8440' - 8454' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8195' - 8199' W/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8187' - 8192' 7z~)2_]' '7~o~' 250 sx Clas_~ G 8091' - 8163' ' - i 27. N/A PRODUCTION TEST . Date First ProductiOn I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST pER,OD ~ " Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None i~ ~i!' i~' £;:i V E ~ Ar:oh0rag0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. "'w'" .... 30. '~ ' GEOLOGIC MARKERS ' ' ' FORMA'TIONTESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7956' 6400' N/A Base Upper Sand 8163' 6547' Top Lower Sand 8418' 6733' Base Lower Sand 8548' 6831' I 31. LIST OF ATTACHMENTS Drillin.q History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed, ~,~~4,~..~ Title Area Drillinq EDgED. ate 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". 1G-8 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 0130 hrs, 12/01/82. Drld 13-1/2" hole to 2250'. Ran 54 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2232'. Cmtd 10-3/4" csg w/1300 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. ,~to 373 ps~- ok. Drld 8-3/4I' hole to 3785' (Locked-up BHA apparently sidetracked hole @ KOP of 2499' and drld straight ahead to 3166'). Picked up DD & kicked off @ 3166' to original target. Cont. drlg 8-3/4" hole to 8625'.. Ran FDC/DIL/CNL/GR & BHCS/GR. Cont drlg 8-3/4" hole to 8715'TD (12/18/82). Ran 7", 26#/ft, K-55 BTC csg w/shoe @ 8698'. Cmtd 7" csg w/750 sx Class G & 390 sx Columbia G. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 8612'PBTD. Ran Gyro/CCL. Ran CBL/VDL/CCL. Arctic packed 7" x 10-3/4" ann. Disp well to NaC1. Ran CBL. Perf'd 7892' - 7894'. Set retainer @ 7842'. Squeezed 250 sx Class G cmt. Drld retainer. Tstd csg to 1500 psi, Perf'd the following interval s: 8470' - 8493' 8440' - 8454' 8195' - 8199' 8187' - 8192' 8091' - 8163' w/12 spf Ran 3-1/2" compl, assy. w/tail @ 78'80' & pkr @ 7841'. SSSV @ 1996'. Tstd tbg hanger to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball. Closed SSSV. Secured well & released rig @ 0930 hrs, 12/24/82. JG'ltc FO7 COMPLETION REPORT ARCO ALASKA, INC. GYROSCOPIC SURVEY RADIUS OF CURVATURE HETHOD OF COHPUTATION COMPUTED FOR SDI BY I~EAHTECH(FH LIHDSEY & ASSOC.) RECORD OF SURVEY TRUE ~ ~. DRIFT VERTICfl~ SU~:~' DRIFT DEPTH ANGLE DEPT~: SEA DIREC D M ~s' PEG 0 0 :0 1 O0 2.0O 0 17 .~,'.3:00.. 0 25 400 0 I? 500 600 e'oo 900 lO00 1400 .:! soo 1700 1800 .19'0O 2000 21 ~ 2300 0 4 .0 16 0 10 0 14 '0 · 5 ,0 11 0 17 0 17 021 0 2O :0 1S 0 16 0 22 0 3 '0 45 '1 .33 I 23 1 33 . 100, 200, 300, 400. 500. 599 699 799 899 999 1099 1199 1299 1399 1499 1599 1699 ~799 1899 1999 2099 2199 2299 O0 -8 O0 O0 11 O0 21 O0 31 O0 41 99 99 61 99 ' 71 99 81 99 91 99 1 01 99 111 99 12.1 99 131 99 141 99 151 98 161 98 171 98 181 98 191 96 201 92 211 89 221 9,00 1 ,O0 1,00 1,00 1,00 1,00 0,99 0,99 0,99 0,99 0,99 0,99 0,99 0,99 0,99 O ,99 0,99 0,98 0 98 0 98 0 98 0 96 0 92 0 89 N , N 8, H 4. 1,138, N62, H , N 1, H52. 854, 859 N87, $70. $71 N79 . 839 $~9 $58 H7 l $81 OOE 62E SSE 58E 47E 43E 575 82E 65E 0SE 27E 42E 97E 671..I 9 ~ I.,.I 4E:LJ I~E 0SE KUPARUK ~ELL I-G-8 KB ELEV.. 89 FT, SURVEY DATE 18 DEC. JOB HO 1367' TOTAL COORDINATES 82 CL'OSURES DISTANCE ANGLE D H 1,97 H 1,67 E 2,58 ,N 40 24 9 E 1,93 H 1,90 E *-;,,71N 44 33 4'0 E 1,80 t4 2,29 E 2,91 N 51 49 29 E 1,76 N 2,77 E 3.29 H 57 34 0 E 1.66 N .3,30 E 3,69 H 63 22 4 E 1,20 N 3.67 E 3,86 H 71 55 2 E ,66 N 3.75 E 3,80 H 80 4 32 E ,21 N 3,56 E 3,57 N 86 42 7 E .27 ~ 3,29 E 3.30 S 85 16 13 E ,59 S 3,40 E 3.45 8 80 9 54 E ,84 $ 4,05 E 4.13 S 78 13 15 E .?'2 S 6,06 E 6,10 8 83 13 10 E .26 $ 8.60 E 8.60 $ 88 15 I E .41 S 11 ,,18 E 11.19 S 87 52 57 E DOG LEG SEYER]TY DEG,,/100FT .,000 , '050 .233 .133 , 133 ,217 .200 o100 , , 150 . 047 ,100 .100 ,145 ,067 .017 , 033 .033 .lO0 .317 ,700 .834 .200 ,200 Oo SECTION DISTANCE. .00 ,04 ,26 .53 ,51 ,59 ,81 .96 ,74 .48 ,36 .18 -,17 - - -1.54 -2, O0 -2.21 -2.39 .-2,?0 -3,32 -4,56 -5.91 -7,73 ARCO KUPARUK '1-G-8 GYROSCOPIC SURVEY JOB 140 1367 SURVEYED 18 DEC, 82 TRUE HERS, DRIFT VERTICAL DEPTH ANGLE DEPTH 2400 216.0'0 ;:27.0'0 28:00 2980 30:0,0 31,~0'0 32:00 3300 349.0 35~00 3600 37~) 38,00 4100 4200 43.0.0 44'00 4500 46,00 47'0'0 4800 4900 5000 5!.00 ,., D H I 46 2399,85 I 23 2499,81 · I 11 2599,78 I 5 2699,76 'l 2 2799,75 I 17 2899,73 I I1 2999.70 I lO 3099.68 2 19 3199.64 6 15 3299,34 10 40 3398,22 14 34 3495.79 19 19 3591.42 22 19 3684.88 26 23 3775.97 30 9 3864.03 32 53 3949,2? 35 22 4032.05 36 35 4112.97 38 20 4192,35 40 5 4269,83 41 58 4345.27 44 11 4418,31 45 53 4488,98 4? 42 4557.44 50 15 4623,07 52 2 4685,81 54 16 4745,78 SUB SER 231 0,85 241 O, 81 251 O, 78 261 O. 76 271 O, 75 · 281 O, 73 2910. 70 301 O. 68 3110.64 321 O, 34 3309.22 3406.79 3502.42 3595.88 3686,97 3775.03 3860,27 3'343.05 4 023,9 ? 4103,3,5 4180,83 4256,27 4329,3 I 4399,98 4468,44 4534, O? 4596 4656.78 RECOkD OF SURVEY DRIFT DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D H DOG LEG SEVERITY DEG/IOOFT S82 N89 N21 N 7 t,I12 N17 N29 N46 N35 N35 1,137 N38 t437 N3.9 H44 N44 N44 N44 H44 H44 N44 H44 H44 H43 N43 ,80E .83E ,32E .02E ,52E .03E ,45E .42E . ,42id .60W .83W .57W .30W .13W ,23W .23W .35W ,25W 97W 68bJ 83W 03W .82 S 14,07 E 14,'I0 tS 86 38 57 E .9'-3 $ 16,81 E 16,84 S 86 37 20 E ,20 H le,55 E ~e.ss a e~ ~2 5~ E 2,1~ N 19..03 E lC,IS H 63 40 I E 3.93 N 19.35 E 19.,74 N Ze 30 44 E' 5.~ N 19,86 E 2'0,72 H 73 29 37 E. -7,~4 H . 20.52 E 22..00 U 68 51 le E 18, ' '" ~"" ''~':' ~''' ''`'~'' '~' ~ ' 70,84 N .... /~:2'3, ~'~ ~[~i<.)~'~ e7 N ' .62 N 18 19 15 W 98.79 H 43,39 ~ 108,72 N 24 40 32 ,12W 745,35 N E56,97' bi 131,29 H 7.0,76 W 149 168.48 N 100,05 Id 208,42 N 133,77 bi 24? ............ .~...4_..9.__,.~ I N l 71 , O 4' W 3 0 3 291,66 N 212,86 W 361 335.19 N 255.33 W 421 3S0.19 H 299,72 Id 484 42.6,?4 N 345,99 W 475,22 N 394,09 W 61 525.38 FI 443,99 Id 68? 577..0'3 N 4cj5,35 W ?60 630,98 t4 548,14 W 035 913 993 ,14 N 28 19 24 bi ,95 N 30 42 9 la .65 N 32 41 4t, W 004 N 34 32 37 la ,O?N 36 7 19 W .36 N 3? 17 54 Id .12 N 38 15 ! la .38 N 39 2 3 W .37 N 39 40 5 la ,86 H 40 12 I W ,53 N 40 38 29 W ,81 N 40 58 52 U .59 N 41 13 19 W ,86 N 41 23 36 W . '183 .383 .,202 ,1.00 , 050 .250 ,100 ,017 1, I~f3 3,938 4.432 3.900 4,754 3,004 4. 076 3, ?95 2 ,'8'03 2., 6;'9 1. 750 1 , 775 i. 888 2,218 I, ?00 1,817 2.588 I .805 2. 254 SECTION DISTANCE -9,96 -Il .91 -12. l? -11 -9.91 -8~79 -7.70 -6.69 -4,32 3.11 17.79 39,51 60 1 04, .00 145,14 192 40 244.66 300.73 420.16 483;29 548,82 ,617,01 687.64 76 O, 42 835.76 9.13.57 993.55. '' C-.~ ARCO KUPflRUK 1-G-8 GYROSCOPIC SURVEY JOB HO 1367 SURVEYED 18 DEC. 82 RECORD OF SURVEY TRUE HERS, DRIFT VERTICAL SUB DRIFT DEPTH AHGLE IDEPTH SEA DIREC D H DEG. i' ~15~0:0 55 8 4803,56 4714,56 H43,'42M ~,:~3~ 55 15 4860,65 4771,65 H43.43U 5409 55 26 4917,52 4828.52 H43,?2W .5599 55 47 4974,0'0 4885.00 N43,32W TOTRL COORD[NRTES 8~4.78 N 864,41H 924.9t,H 983.60 N C L 0 tt U R E a" D X STANCE ' AHGLE D H S .: 712.9.6 1~ , 1~)75,'t3 H 41 32 8 '~ 769,34 ~ 'I'IS?,2O H 41 40 1'0 ~ 826,:04 W 1239,41 H 41 47' 45 ~ 383,12 ~ 1321,88 H 41 55 ' 8 ~ 5608 56 I 503.0,06 4941,06 H43,52~ 1043,5.0 H '940,30 57~ 55 22 5086,43 4997.43 H43,'02~ t103,~ ~30~ 55.28 5143,19 5054,19 N42,,85~ 1163.~- .:1,052,99 se~ ~5 31 5199.e4 5110,84 N42,4e~ 1~4,~~1.!0e 61.09 55 32 '5312,70 5223,70 N42..08~__~~~~ 6299 55 38 5369,22 5280,22 H42..07~ 1408,'0: .6390 55 44 5425.60 5336.60 H42,3?U 1469,2; ~64.0.0.55 55 5481.7.7 5392,77 H42,42~ '1530,31 ii~i.~5~:0,56 6 5537,68 544~,68 H42,35M .:t59J,55"N ~442,'~3 6690 56 9 5593,42 5504,42 N42,52M 1652,83 N '149~,25 '~0 56 2'0 5648,99 5559,99 H42,30W 1714,21N 1554,32 ,~ 56 I 5704.65 5615,65 N42,07~ 1775,.7.7 N 1610,10 69~ 56 53 5759,92 56?0,92 N4"I,?3U 1837.80 ?~00 56 44 5814,66 5725,66 H4t,45~ ........ 1.90.0.~39..;.H 71~ 56 14 5869,88 5780.38 N41,SeU 1962,81H 72~0 55 50 5925,75 5836.75 H41;',?SU 2024,77 H''I331,?l'U 273,a,36 N 42 3 2 ?390 55 31 5982,14 5893.14 f142.',O3U 2086.25 N 1386,85 7400 55 l:O 6,039.01 5980.01 H42.I3Y 2147.29 H tg4t,98 75~9 53 6 6'097.59 6003.59 H4'O.43U 22'08.13 H 1995.48 ?6:00 5'0 37' 6'I 59,35 6070.35 N39.20~ 2268.59 N 2'045,8:0 ;~7700 48 47 6224,03 6135,03 H39,65~ 2327.59 N, 2;094.23 ,7800 46 53 6291,15 6202,15 H40.10~ 2384.38-H 7g09 45 34 6360,33 627t,33 H39,78~ 2439,74 · .DOG LEG SEVERITY .DEG/IOOFT SECTION DISTANCE .890 ,117 ,266' .357 .311 .733 .151 ,254 ,338 .238 ,tOl ,22~ ,189 .125 ,355 .898 1075,13 ~ 1157,20 1239.40 1321,87 1404.62 1487.19 1569,49 1651.88 1734',43 1816;99 1899.48 I ee . 07 · 2064.. 79 2147.70 =":~ 2230,72 . 2313.85 2396.92 2480,26 ,248 , 2563,94 .508 2647.31 .416 2?'30.25 ,371 2812,83 ,, 356 2895.08 2..335 2976,1 I 2. 590 '3054. ?2 I .35! 31 30,92 ' 1.915 3205,00' I .326 3277,18 GYROSCOPIC: SURVEY 0 JOB. HO '136:7 SURYEYED 18 DEC, 82 RECORD OF. 8URV, E¥': TRUE ' * . HEllS DRIFT VERTICRL SUB , DRIFT TOTR[:'COGRDI:HI~TES ~EPTH RHGLE. 'DEPTH SER DIREC ,..,,. , ..,. · 800~ 44,49 6430.81 6341,8l N39~8,?~_~3 H ... 2233;54 81'~Q 44 44. 6501 .80 6412,'80 'H40,18U 2540,16 H 2278,84 U 3418,51 H 41 40 ~3 U 82~0 44 19 6573,.09 6484,09 ~H4'O,67U 26:01.,54 H :"23~4,3l U 3488,6t H 4~ 46. 43 U 83~.0 42 28 6645,75 6556,75 H4.0.62~ 2653,67 H 236~,.'05 U ~557,30 H 41 45 .24 U 840'0 41 49 6719,90 6630,90 X39.,?SU 27~4'91 H 2412'36 U 3624,37 H 41 43 40 Y 85~ 41 28 6794,63 6705.63 ,H4.O,~O~ 2755.,~ H ~454,98 g .3690,,,78.H' 41 41 41' U .~TTOH HOLE CLOSURE 3832.!9 FEET'.'RT" 4", 37, ~/~~?Orillin, g..~ . ... International , '". ' DOG 1LEG · 'C L'O 8' U' R E S '~EVER]TY OISTAHCE ~INGLE ' ' DEG/IO'OFT '::'," , D H.'8 ,., 701 '178 ,479 ,850 ,748 ,363 ,768 ,000 .SECT]OH D]$TRNCE 3348.,09 3419,50 3498.60 3557,29 3624.36 3690,79 3723,76.. 3632.19 t IRCO KUP~R~K I-G-S GYROSCOPIC SURVEY' dOB HO '1367 · IE~SURED DEPTH gHD.OTHER D~Tg FOR EVERY EVEH '1~ FEET OF SUB SE;I DEPTH. HE~SURED DEPTH TRUE VERTZC:RL SUB HD-TYD DEPTH SE~ DZFFEREHCE 0 lS9 189, 289 289, 389 389, 489 489, 589 '589.~ 689 689. 789 789. 889' 889. 989 98.9, 1489 1089. 1189 1.189. 1289 .1289, 1389 .1.389'; '1489 1489~ 1689 1689. 1789 1789, 1889 .1889. 1989 1989. 2.089 2089, 2189 2189. 2289 2289° 2389 2389, 2489 2489, 2589 2589° 2689 2689, 2789 2789, 2889 2S89. 2989 2989, 3089 3089, 3189 3189, 3290 3289° 3391 3389° 3493 3489, -89 100 200 300 400 500 600 700 800 900 1ooo 1100 1200 130Q 1400 1500 '16 O0 1700 1800 19.0'0 2000 2'100 2'200 2300 2400 2500 2600 2700 2800 2900 3.000 3100 3200 3300 3400 '0 :0 '0 0 0 0 0 '0 '0 '0 0 0 .0 '0 · 0 .0 :0 0 0 0 0 0 0 0 0 0 ,0 YERTZCRL :. CORRECTION"'.~ .... ;~ .~ ' ~ ' 'i~ "~ · . . i"q':4 , : , ~ '" ~ ,,,~' . :...~" . ~ ~ . . . O '~ ..... . t.97 : :'=':""¢.. ' ." 1,8~ Scientifi : IntornatiOO [ ,. ~ ',0' ~0 ~0 :O iQ ~O ~0 0 TOT;IL COORDZH~TES .21 , ,59 .,27 o el 1.91 3 ..74 ?,.73 9,67 11 ' eo '1 ?. 88 28 ~4~0 N N N N N H N' N S $ $ N N fl N N fl N HN ,, ·. 00' 'g .02 I~ ,16 E ;62 'E ,83 E .., 83 E .95 E 1;26 E I ,66.E I ;eT.:E 2,24 E 2,72 .E 3.'. 25 E 3,065 E 3;?'5 E 3,60 ,E 3~32' E 3',38 E 3~92 E 5,'77 E 8,33"E 1'0.88 E 13.74 E 16,55 E 18.46 E 19,01 E 19,31 E 19,80 E 20,45 E 21~11 E 22.87E 17,08, E 7.73'E 5;03 ~ SURVEYED '18 DEC. RRCC) KUPRRUK 1-G-8 GYRO$coPzc SURYEY JOB NO 1367 HE~ISURED DEPTH RHD OTHER D~TR FOR 'EVERY 'EVEH 1~0'~ FEET OF SUB SEA DEP~'H. '" HEt~SURED DEPTH 3~597 3704 3015 3929 4.048, 4170 4296 4425 4559 4700 535'0 55,27 5705 5881 6058 6235 6413 6772 6'953 7134 7486 7646 7797 7941 8082 8222 8492 8625 8715 TRUE VERTICRL SUB HD-TVD DEPTH :SER DZFFEREHCE 3589. 3500' 3689, 36 O0 3789. 3700 3889. 38'00 3989. ~ 3900 4089. 4000 4'189, 4'1 00 4289, 420.0 4389, 4300 4499, 4400 4589, 4500 4699, 4600 4789 ,. 4700 4889. 4800 4989. 4900 5089. 5.000 5189. 51'00 5299, , 5200 5389. 5300 5489. S400 5589. 5500 5689. 5600 5?89, 5700 5889, 5800 5989, 5900 6089, 6000 6189. 61 O0 6289, 6200 6389. 6300 6489. 6400 6589, 6500 6689. 6600 6789. 6700 6809, 6800 6957. 6868 15 39 58 '106 '136 170 211 258 316 385 460 537 691 769 846 923 1903 '1 082 1164 t245 1323 1396 1507 1592 t633 1669 ! 70.3 1736 YERTICflL.. CORRECTZOH',":" -' T. OT~iL~ .COORD'ZHRTE8 .'. '78 .7.? 7.7 80 79 82 78 73 61 50 44 4'1 .4t 36' 3~ 33 1321 . :09 '1429; 52 1538,21 .1647,97 "1758,46 1871 ,,03 '1,984,14 2 093., 63 2199,44 2296,12 2382,59 2462,';08 2538.46 26'13,24 2683° 62 2752,0? 2819,42 2864° 80 22; 95 46 ,' 45 74,74. '109p41 151..'34 200,5! 253 ~ 51 311,2l 374,32 444,00 .5~o.23 604.86 698.,61! 797.56 998,44 999.46 1 098. I 8 t t96,55 1294;49 1393.., 56 1493,80 1594~46 1695.32 1.795.52 1893.51 1987°97 2068.34 2140,24 2206.72 2270,66 2334,36 2394,52 2451,77 2507° 73 ,, 2545 'o 3.2 SURVEYED 18 OEC. 82 u Y Y Y # # U Y Y u Y Y Y Y W ,y Y Y Y Y Y Y W ,a~co kuPnRUr, ! -G-8 GYROSCOPIC SURVEY JOB NO 1367 0 SURVEYED 18 DEC. 82 INTERPOLATED YRLUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 0 O. 100'0 1000, 2'00'0 2000, 3000 3000.. 4000 3949, 5000 4686, 6000 5256, 7000 5015. 8'000 6431, 8715 ~957. 1000 FEET OF MEASURED DEPTH, SUB SER TOTAL COORDINRTES -89. ,'00 $ , 911, 1,97 N '1, 191 I. ,84 8 4, 2911. 7,94 H 2:0. . ' 4597. 687.17 H 602. 6342. 2494,23 H 2233, ~ ~:~ ,. , ;~, '.,, ~,, ,~;~ , ~)~, .,. ,., ,.1019 NO 0 SURVEYED t8 DEC. 82 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES RND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES CLOSURE DI STANCE ANGLE D H SUB TOP U SAND ?'956 6399.68 BSE U SAHD 8163 .6546,65 '1~ L SnND 8418 6733.32 . L SAND 8548 6830.69 PBTO 8~12 687~,91 TO e7,5 695~.51 2470 35 N 2581 88 N 2714 13 N 2780 23 N 2812 64 N 2864 80 N 2~13.61 W 2307.47 W 2420.04 W 2475,26 W 2502.11W 2545.32 W. 3317.03 N 41 51 4~ W 6310.68 3462.74 H 41 47 15 W 6457.6~ 3636,36 N 41 43 17 W 6644.32 3722.44 N 41 40 44 W 6741,69 3764,50 N 41 39 22 W 6789.91 3832.19 N 41 37 t3 W 6867.5t 'I ...... - ......... ' ~ .......... .?-t-t--~.-' .: .-'~-~--'~. ,T' '=- ..... ' · ' i ; · : : : I ~ · ' I ' t- ........ T..- ....... --~--,-.4---: ...... -t-T------~- =?- .- ~ :-; · · -..-'.,.-i-i- '..'~, t , :- ~ * f: ~ : -: * , I * : * ' I : ~ * · [ ; * ' : ' ~ . .?~. 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' -Ope_rato~r, ~ei-i Nan~ ahd~Number Reports and Materials to be received by: /_ ~ Date Required Date Received R.emarks Completion Report Yes Well History Yes _Samples . -. _--- , -- ._ . Core Chips .... Core Description Registered Survey Plat ~ ~j f t \.. Inclination Survey ...... '. · , ' ,4/~' '::'~ ~''-., ,, Drill Stem Test Reports //.'/J/~--- / _ , -f/-'6~ L/',, TO: William VanAlen D. W. Bose/Lorie L. Johnson DATE: WELL NAME: Transmitted herewith are the following: PI.FASE NOTE: F - FIfbI, T- TAPE, PC - PHOTOCOPY ARCO ALASKA, INC. Alaska 0il & Gas Cons. Commission Anchorage A'I'Z~: LOR.IE L, JOHNSON - AFA/311 P, O, BOX 360 ANCHO~, AK. 99510 TO: William VanAlen FROM: DATE: / // ¢/~ WEI.L NAME: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.FASE NOTE: BL- BLUELINE, S- SEPIA, F- FIIbI, T- TAPE, //z~I~ ACKNC~'~SED: JAN i~ ? i98:~ ~~ D~TD: Alaska 0il & Gas Cons. Cornmissior~ ARC-'O AZASKA, :l:lX]C. Anchorage ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 A/gCHORAGE, AK. 99510 ARCO A~laska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi ssi crier State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2~11 13,98 1G-8 7-16- 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well 13-11 1F-4 #1 Also enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/JGL28'llm Attachments RECEIVED JAN i 4 Alaska 0il & Gas Cons. C0mrnissi0rl Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA G.~ AND GAS CONSERVATION CO '--'ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well at surface 1324'FSL, 589'FWL, Sec. 29, T1 IN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 89' RKB 6. Lease Designation and Serial No. ADL 25640 ALK 2571 For the Month of December ,19 7. Permit No. 82-175 8. APl Number 50- 029-20849 9. Unit or Lease Name KuDaruk River Unit 10. Well No. 1~-8 11. Field and Pool Kuparuk River Field Kuparuk RiYer Oil Pool 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ; Spudded we1] @ 0130 hrs, 12/01/82. Drld 13-1/2" hole to 2250'; ran, cmtd & tstd 10-3 4" csg. Drld 8-3/4" hole to 8625'; ran logs. Cont. drlg to 8715'TD, ran, cmtd & tstd 7" csg. Ran logs. Squeezed cmt. Perf'd well. Ran 3-1/2" completion assembl.v. Secured well & released rig @ 0930 hrs, 12/24/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2232'. Cmtd w/1300 sx AS III & 250 sx AS I' 7", 26.0#/ft, K-55, BTC csg w/shoe @ 8698'. Cmtd w/750 sx Class G & 390 sx Columbia G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run FDC/DIL/CNL/GR f/TD to 10-3/4" shoe BHCS/GR f/TD to 10-3/4" shoe Gyro/CCL f/PBTD to surface CBL/VDL/CCL f/PBTD to 2000' CBL f/PBTD to 2000' 6. DST data, perforating data, shows of I-]2S, miscellaneous data RE£E!VED 8470' - 8493' 8440' - 8454' 8195' - 8199' 8187' - 8192' 8091' - 8163' w/12 spf Alaska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-- t orm is required for each calendar month, regardless of the status of operations, and must be Oil and C4~s Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 f~le~ '~/duplicate with the Alaska Submit in duplicate 1G-8 DRILLING HISTORY NU Hydril & Diverter. Spudded well @ 0130 hrs, 12/01/82. Drld 13-1/2" hole to 2250'. Ran 54 jts. 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2232'. Cmtd 10-3/4" csg w/1300 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 373 psi - ok. Drld 8-3/4" hole to 3785' (Locked-up BHA apparently sidetracked hole @ KOP of 2499' and drld straight ahead to 3166'). Picked up DD & kicked off @ 3166' to original target. Cont. drlg 8-3/4" hole to 8625'. Ran FDC/DIL/CNL/GR & BHCS/GR. Cont drlg 8-3/4" hole to 8715'TD (12/18/82). Ran 7", 26#/ft, K-55 BTC csg w/shoe @ 8698'. Cmtd 7" csg w/750 sx Class G & 390 sx Columbia G. Instld 7" packoff & tstd to 3000 psi - ok. Drld cmt to 8612'PBTD. Ran Gyro/CCL. Ran CBL/VDL/CCL. Arctic packed 7" x 10-3/4" ann. Disp well to NaC1. Ran CBL. Perf'd 7892' - 7894'. Set retainer @ 7842'. Squeezed 250 sx Class G cmt. Drld retainer. Tstd csg to 1500 psi, Perf'd the following intervals: 8470' - 8493' 8440' - 8454' 8195' - 8199' 8187' - 8192' 8091' - 8163' w/12 spf Ran 3-1/2" compl, assy. w/tail @ 7880' & pkr @ 7841'. SSSV @ 1996'. Tstd tbg hanger to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well to diesel. Dropped ball. Closed SSSV. Secured well & released rig @ 0930 hrs, 12/24/82. JG:ltc FO7 AlasKa Oil & Gas Oons, Anchorage TRANS~n~AL # .Z/~ 7 TO: William VanAlen Transmitted herewith are the following: PT.WASE NOTE: BL - BI/3ELINE, S - SEPIA, F - FTT~4, ~ D. W. Bose/Lorie L. Johnson PC - PHOICCOPY RECEIPT ACKNfTWT AT~KED: Pr,VASE REITS~ Rt~CE~ TO: ARCO A/ASK,A, ZNC. Alaska Oil L~ Gas C::uu;. ATIN: LORIE L. JOHNSON - AFA/311 A~cI~o~ag,,; '., P. O. BOX 360 ANCHORAGE, AK. 99510 - -MEMORANDUM State of Alaska ~.~ A!.,~.SKFiOI~ Ar~.D GAS CONSERVATION COMMISSIO~ T.~: C. V ton ' DATE: ~cem~r Z0, ~82 Chai~~ ~ FILE NO: 108A/E THRU: Lon~e C. Smith Co~i ~sion~r TELEPHONE NO: FROM' ~dgar ~{. Sip~!e~ Jr~¢- ~trole~ Ins~ctor SUBJECT: Witness DOP~; Test on ARCO's Kuparuk 18-$ Parker Drilling Ri9 141 Sec. 20, T12I'._", R10~;, U[q, Permit No. 82-175 Saturday,_D,e,c,ember 4, 1982 - I arrived at ARCO's ~.uparuk 1G-8 ~Rrker Rig 141 to witness a DOPE test. Parker L;rillin9 Company was in the process of running casing. The DOPE test commenced at 11:30 a.m. and %-fas concluded at 3:30 p.m. There were three failures, the lower kelly valve failed and. t~e outside valve on the kill line leaked. A unibolt leaked on the choke m~.nifold, tightened the unibolt up and it tested to 3000 psi. The lo~-~r kelly valve and the outside valve on the kill line will be replaced befoze drilling operations resu~. The A.O.G.C.C. BOPE test report is attached with this report. In summary, I witnessed the DOPE test on ARCO's Kuparuk 1C-8 Parker Drilling Rig 141. Attachment: Mr. L~rry McDowell called the A.O.C.C.C. office December 7, 1982 and said the lo%~mr kelly valve and the outside kill line valve was installed and tested to 3000 psi. 02-001 ~ Rev.10/79~ ~LASKA Oi. & CAS (/)[!SERVAT.[~ 'i~ :.:(~q~-~SSION B .O.P.E. Inspeebion l-k'_'bX~Y~ Well I C- Y Location: Sec ~ Q Fril linq Contractor Location, -General__ Wel 1 Sign Ceneral Housekeeping__ ~eserve pit Rig BOPE Stack ,_~%nn~ar Preventer -- 0~{ Pipe }~ams ~& g/< B 1 ind ~Pams_ ____Dj[ Choke ~ine Valves.__ 0'4r.3'I _2< ~ IH'C .R. ~al~ ."- ' Kill ~e Wl~s. Che~ Val~~ Test Pressure ~00 ~ ~00o Test Results:. Failures. Representative Permit ~ ~ Z -- /o~ Casing Set --Ri~_. ~7 ~/ Repre~ntat ive ~ ~ii ~:arge ~es~re ~( Ressure After Closure ~ ~p incr. clos. pres. ........................ ~ ........ ~est .Tim ~ ~s psig psig. / rain / l sec. ~ rain S~ sec. Repair or Replacement of failed cquipmpnt to be made within oq- days .; · Inspecto~/Cc~migSion office notified. -__ Distribut ion 'orig. - BO&CCC cc - Ofxerator cc - Supervisor Full Cha~e pressure Attained: N2 Jt/~O. .z-~oo ~'~. ,.~/~,., R~g.__~ ...... Blinds. ~it~L.~oygr Kelly and Flor Safe~, Valves ~r Kelly.. "'' I -- O ~ Test Pressure ~11 ~pe?o P~, Test Pressure Test ~esmre Choke ~nifold Test ~essure October 26, 1982 ~k. Jeffrev B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 1G-8 ARCO Alaska, inc. Permit No. 82-175 Sur. Loc. 1324'FSL, 589'~",q~, Sec. 29, T12N, R10E, Bt~hole Loc. 866'FNL, 1574'FEL, Sec. 30, T12N, R10E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. Well s~ples and a ~d 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 informs, at!on shall be submitted on all logs for copying except experimental logs, velocity surveys and dtpmeter surveys. bfany rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. ~erations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, AlasP~a Administrative Code). Prior to conm~encing operations you may be~ contacted by the Habitat Coordinator's Office, Depart~mnt 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 Adm~inistrative ~ -~ ~o~e, Chapter 70) and by the Federal Water Pollution Control 'Act, as amended. Prior to commencing operatiorm yo,u may be contacted by a representative of the Department of Envzron~ental Conservation. ' To aid us in scheduling field work, please notify this office 24 hours prior to co~encing installation of the. blowout prevention equipment so that a representative of the may be present to .witness testing of the equipment before the Mr. Jeffrey B. Ke~in Kuapruk River Unit 1G-8 -2- Ocotber 26, 1982 surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Con, mission 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. C~a~tertofi BY ORn~ OF T~ CO~r~I$$ION Chairman of~ Alaska Oil and Gas Conservation Commission Eric 1 o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC:be ARCO Alaska, Ir,~''' Post Offic Jox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 October 15, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1G-8 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1G-8, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map. o A discussion of wellbore crossings. o A diagram and description of the-sur'faCe hole diverter system. o A diagram and description of the BOP equipment. If you have any questions, please call me at 263-4970. Sincerely, ~ Kewi n Senior Drilling Engineer JBK/JG:sm Enclosures GRU2/L17 ?ECEIVED OCT 2 1 1982 Alaska Oil & Gas Cons. Comr~ission Anchorage ARCO Alaska. Inc. is a subsidiary o! AtlanticRichfieldCompany · '>-~', STATE OF ALASKA '~ ~ ALASKA-G,- AND GAS CONSERVATION CO-,.,~vIISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL J~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 360, Anchorage, Alaska 99510 R E £ E IV E D 4. Location of well at surface 1324' FSL, 589' FWL, Sec. 29, T12N, R10E, UM OCT 2 1 1982 At top of proposed producing interval @ Target: 1320' FNL, 1228' FEL, Sec. 30, T12N, A~i~,~I~! & Gas Cons. Ocmmissi0f At total depth Anchorage 866' FNL, 1574' FEL, Sec. 30, T12N, R10E, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 16-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 6,L. 60' RKB 89' ADL 25640 ALK 2571 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 32 Miles NW Deadhorse miles BH @ 866'FNL Sec 30 feet IG-4 we11194' ~ 3286' TVD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8566' MD, 7095' TVD feet ±2459 11/10/82 19. If deviated (see 20 AAC 25.050) I2o. Anticipated pressures 2725 psig@~0°F Surface KICK OFF POINT2500 feet. MAXIMUM HOLE ANGLE 45° oI (see 20 AAC 25.035 (c) (2) .3220 psig@ 6298 ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight 4" 16" 65# 3-1/2" 10-3/4" 45.5# 8-3/4" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 PEB K-55 I BTC K-55 I BTC Length SETTING DEPTH 2171 ' MD TOP TVD 80' 30' I 30' I 29' 29' I I I 28' I 28' 8538' MD BOTTOM TVD 110' 110' 2200' 12200' I 8566' 17095' I I QUANTITY OF CEMENT (include stage data) 200 cf 1200Sx AS III & 250sx AS II 1000sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 8566' MD, (7095'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2725 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected'intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. See attached discussion of wellbore crossing. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge The space be/(~'o~ission Samples required []YES [~NO Permit number APPROVED BY TITLE Senior Drilling Engineer DATE CONDITIONS OF APPROVAL Mud Iogrequired I DirectionaI Survey required I APl number []YES {~NO J ~YES []NO J 50- ~3'L~-'L o ~-~ ,z~,~ r o.~i~l date ,COMMiSSiONER DATE Oo~gbe~ ~ ~g8~ by order of the Commission Form 10-401 GRU2/PD8 Submit in triplicate ii!i :::~ i !!! i! iii! i! ! '~I~'~ ~ ~ .~:i '.ii .... ii, ,,: i ~ ; ! ~ i ; i , ', ; i i ~ i i i i i I i i i i !iii i,ii iiii iii' i I i i i ', ' i i , ! , i i I i ,' , ,, ~ ,! !i~i ~x~ ,~ ~i, i~ I Ii~ ~l i i' ~ii ~i~ ~i~ ' . , ' i ,11~ ~i iili ilil fill i~II ii!~UUi~ ~itilii~ ~.i ~ii i! . . II~ ! . , , , , , i ~ ' ' I i~il iN!! Iii !~ I I '1 I iill , !~ fill il , . ~ ~ , ~ · i ii ' i iill ill~ yili Rlil I il I 1~ !!,, I ~ !1~i ti ,, ,,- . , . : " , ,i, . !i ' ' !~, iii, iili iiil /iil! Nlil I i ~! ' i111 ' ~ iii: It '"' '" "' 'i '"' ! ! 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Ii1~ i~ii ~li llii ilil Iiil iiii iiii I i~ ~ I! ~i~ 'Iii . ~ ~i i~ , ifil !iil iiii iiii iiii ~Iii ill iiil iill Ii~i ili i, li'i i~li ii'i iiI~ i il i~ ~ : ~ ' il ~111 il~l I I ~!i li~ ~ ~ ~' . ,_ , . . , i i I ! i ~ ! i, i ~ I i. , i i t I i~, i i I I. ~ , I~, i i i ~. i I ~. il ~i ~il! iiii iiii iii! iiii i 11 l!li llli !~i~ iii~ ~ii ~iI~ .. ~ ~ '. iii ilii il!i !iii ili! !1!~ ii!i i i! iiil Ii!i !Ill l!ii ',11i iili iii! ~t!i iiii ilii i i~i I ii i i!i i i! !ii~ l i,~ !i~i i~l! ~ pl.'Ir ~,i~-t.-~ !iii i ijl i ill ~,'j ~il! i,, J~i l ill i ljl l i! i i il i li~ i(r:ii,i' ~'I~. ,,i, ,~- ~, i~l !i~j i'll ~' iiil !!II .J!il i',ii illl illd~lF'i'~ i'.ii iii ~ ~, ii ~, i~l i~ll Ii1! ;i, ~iiii , iii iili il il ~ii,, ~-i~j .... ,i.:...]~,h~ ~i!i ~ ~ ~ ~ i iiii i ili i iiil~ll~ I1' ! iili i lll i~ ~.!~.~ ~. i.! ILI~Z , ~I! iii! ~iii ill~ iiil !liill,iI !ill iill iii~ ,, ,, illl '~iI1 ~i!i ~ i J ~UU ' i: ~ ~ ! ii'~ , . ;l~!. ,~J''. , . Jit~ i ! ! ! i ! i i i. ii'!., illi ~ll~ ~Ji!. i'll, !,,,,, ii~ ~,', , i! i iii i! i i iii ~ ii ~ i ill iii! :j i ! ii I~ii i, ~ ~li~~ lil~ L~iris · ! I I i . i , i , i i ~ ! I ~ I ~ ,i l.i liilLJi~ iili J 11 iit~ ~llL iil iili i!ii I t !!!! !! ANALYSIS OF 1G-4/1G-8 WELLBORE CROSSING NOTE' Please refer to the attached proximity map 1G-4/1G-8 The proposed well 1G-8 will cross well 1G-4 by a distance of 194' at a measured depth of 3310'. This distance was calculated using proposed well path data for 1G-8 and single shot survey data for 1G-4. Well 1G-4 has an ellipse of uncertainty of 84' across its major axis at its crossing depth of 3329'. Well 1G-8 will have an ellipse of uncertainty of 68' across its major axis at its crossing depth of 3310'. The areas of uncertainty for the two wells will therefore not intersect. ARCO proposes the following procedures be used to drill 1G-8 safely past the aforementioned well crossing' 1. The 13-1/2" surface hole will be surveyed to its total depth (+_2200'). The 8-3/4" hole will be surveyed to its kickoff depth of 2500'. 2. If calculations show that an intersection 76' or less will occur between the two wellbores, a jetting assembly will be run approximately 300' above the crossing depth to impart a small angle (3°+_) in the appropriate direction. (The distance corresponds to an intersection of the area of uncertainty.) In addition to the above precautions, the on-site personnel and supervisor will continuously monitor all parameters as the intervals of interest are dri 11 ed. GLA: 1 lm 10/19/82 ALV/A ~1.3-5/8" 5000 PSt °RSRRA BOP ST2~CY.... I. 16" Bradenhead r ! ~] 2. 16" 2000 PSI × 102 ~3 ?SI c~sing head · . 43,] lO" 3000 PSI tubing b, ead 10" 3000 PSI x 13-5/8" 5000 ?SI .. L// ~NNUL_.qR - adapter spool .-:' . 13-5/8" 5000 PSI pipe ra:s . ." PREVENTOR '1 . 13-5/8" 5000 PSi drilling spo;1 w/choke . , - 9 -' J and kill lines . ..- ' - . . --' '-_ -' 7.13-5/8" 5000 PSI pi~a'ra~s-':'-._'" .-" ~.-' .". "---: -- ' -'i ;---:~-- -- ~.~-~/~" ~ooo ~_ ~..,~ ,--..--~ :- -". --'-_-:-'....- - ,"-~ii: !~ ~:.- ~-s/a" sooo Ps~ ~.,,=~,,- -- -'- .- .'--~..-:-'.::'i,-:--- -- , PIPE RR~S _ ' z. -7 ( - SPOOL ' -. . ". 6 I. -) · . l__ 3. _ P i pi:' R,qMs I : '.. r-.I- '-'.5 o -' -' - - ' :i;--;:- . - 7. -4 TBG :'-'-' ':- ' - ---F';CT 2-i ::i-SSz -- - - O--IEL-~ ~D FILL ACO~,.rL~"fOR -~-.~_S£R'¢OID ~ P~P~ ~'~ WIT~ HYDP~ULIC ~ID~ ~S~ ~T A~-~T~ PP~S~E ~I~ TS00 PSI ~S~YE TINE T~ C~E ~ L~ITS S~T~- ~L~ ~D RECOP~ ~ T~ ~ ~~ ~I~ ' I~ ~ A~ ~tlTS ~ ~ ~ ~!~G ~ OFF. . ~ ON [~C R~P,T. ~ A~~ t~.~ L~IT IS 45 SE~';~ ~I~ T~E ~ 1~ PSI ~NI~ P~SU~. - 13-5/8' BOP, ST~=( TEST FILL BOP STACK ARD I'~.~'([FOLD l~lTl-I ~'J~C DIESEL. ~E~ ~PAT ~ HO~ ~.A~D. P~D~E~-:II~ DEPT~ T~T ~'I~ S~T AI~ S~T I~; ~~D. ~ I~ L~ ~N SC~S IN H~. ~E ~C'tU~2. PR~R ~D C~-~ ~ ~P~S Y~Y~ 0~( l.~q I FOLD. ~jT ALL C~q~IDITS TO ~ ~Z ~'~ ~D F~2 lO MII~S. I~;C~E PRESS~ TO l~ ~I ~qD e~ ~P. lO MINUTES. B~ED TO ~0 ~I. PIPE ~. V~VE ~D Z~D PSI ~~~. TO ZLRO PSI. - _ ' ~gl TOP S~ OF PiP~ S~ ~ PIPE ~. ' I~E PP. ESSU?~ TO 3~ ~ mJ;D .~ ~ lO ~!I~JT~. B~ED TO Z~ PSI. ~ ~IIFOLD ~D ~)~ ~ ~u~ ~ ~C · DI~ ~;D ~L YALY~ ~ S~ ~]( ~I~I~ ~I~I. - _ T~T ~IDPIPE Y~Y~ TO ~ ~I. ' P~ TEST YI~R. - . . - - -® Surface D+'-Lrter Ssstem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 720" bell ~nipple. Maintenance & Operation ~- 1. Upon initial installation close annular ! preventer and verify that ball valves I - have opened properly. - I 2. Close annular preventer and blow air ~_ . through diverter lines every 12 hours. 3; Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manual ly over- ride and close ball valve to upwind diverter line. Do not. shut in well ,, , under an), circumstances. 16" Conductor Z~ Sz /-~T. ?o ° Z,, 'go. ~ ?,'~ /_z~/x~. /~'e° ~o'/Z~. ~Zo ' 4~d/ '/~. ~V: ~ . ARCO Alaska. Inc. drawn by '~I~ ldwg no · '¢' CHECK LIST FOR NEW WELL PERMITS Company Lease &' Well No. /<. ~. ~ ITEM APPROVE DATE (1) Fee (2) Loc /(2 thru 8) 3. 4. 5. 6. 7. 8. (3) Admin: ./!?~_,,~. /o-t~-~'~-- (9/ thru 11) . 10. 11. Is the permit fee attached ..... ............. I .... ' .... 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 P°'°~ Is well to be deviated and is well bore plat included Is operator the only affected party ... ........ ' .......... Can permit be approved before ten-day wait .............. Does ~operator have a bond in force ................................ Is a conservation order needed .................................... Is administrative approval needed ................................. YES NO ~ , R~ARKS (4) Casg ~. ~.~, /D -~/- ~ (12 thru 20) (5) 'BOPE (21 thru 24) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................ ................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production Strings ... Will cement cover all known productive horizons ...................... Wil 1 surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. n Is old wellbore abando ment procedure included on 10'403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ................................ ....... <~' Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to .~OOQ psig .. ~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. / I / ~Z Geology: Engineering: ncs- ~A ~_..~ JK~ RAD IAL MTMV~ HJH -ev: 08/19/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. i,, : 1 G - a 0 () 0 00 (.) 004 065 i',~ : K [.1 p A R t~ t( 00 O 000 0 (; 8 065 i l,~ (;: 1. (2 i~; 00 O O 0 0 004 065 E;CT: 29 r) O0 0()0 O 02 005 q~P O:IO.F!O,I Vi'[~R.tF ]'Ch']:.[(:i~l L]S'i":IiH(~; IPAGF: 2 l.~ t.~" C 8;.>. B H T 980 ~'a '15. 2'70 f, '75,0 (-')'70ra 75. 607 (a, 14,5 ATR I,X S Ar",l i)ST'fl~,,~ l< ;,~Et,~ SE[~VlCE 5E~VI. Ck; C;~,IT APZ apl aPI !kPI FILE S:IZ[}': PROCESS E P T ~' "F [.) 0 0 0 0 4 0 F h t..t I) I h t'J ,H i'v, ~ '7 0 0 0 0 4 0 ~ H I ~ 140 :~!I, 2t~. L ~ AT ~RA 4 O 4 ~ 0 4 0 4 0 4 0 4 0 4 0 4 I 0 DATA -999. 2500 Z999.25GU 999. 2500 -999. 250() C .,.~ L 1 400,00 () U -17.2813 28. 466h 943,00(~0 -21,515~ 842,b0~0 3.1~b5 -5U.'I~13 26,220'1 2 , 9375 1 l..," 0,250 (.) 1:.> T 5,5,430 ¢;~'~ 81,31.25 0,04:74 8.0875 /. 5,1328 I !.., ~".: 94..., .1. 250 !)T 93.5000 9,4 009 1 (.), h u 47 i. i, ,4 80,7 bOG l?'l :), 0161 ~,,,iub -999.2500 IbD 106,3'750 GR -999.250o ~Cr,,~h -999.2500 NRAT 2.556~ l.bu 104,7500 Gt~ 100,2500 NR.AT 10,0~59 I£,D 89,3750 GR 2,3770 NCNb 81.31,25 NRAT 4,41.02 87,5625 2,4141 94.1250 N~AT 90.7500 2.3 ~ 26 93.5 () O 0 8. 2656 89.1~_'15 2.3789 0, 7 ~ O I,) 250 o 625( -99~.25('10 -999.~500 2.51,1,7 I 10,93'75 3.3056 9,9766 84,0000 2790,0000 2,7095 4.2500 103 3750 2812:0(,00 2,'71b8 7,50t)0 92,250() 2684.000() 2,7188 8.5625 85.3750 2812,0000 2.0387 ? 900,00()0 -9,5078 GR 734 5000 Cai 1 ' 5 -a Ul, b6 GR -999 2500 -999 2500 C ~ 1., I -999.2~00 {;PT '7 ?00, OuuO S ::' ' 14,265~ GR ,,.w H I - q 99.25 U u l.) 2 ~'~ I.., -999 2500 x~ A -999 ~ 25U 0 !:PT l 6()9. f) O00 SVLu p ~. 4~44. GR PHI -999. 2500 ~. L 999 2500 CALl ~,~ ~ ~ -999,2500 EFT 7 5()0,00o 0 P -11.015~ PHI -999.2b09 Crib -999,~50o CAI.,, ! NRA -999.25U0 EPT 7400. 0000 P -b0,5~13 GP Phi -999.2500 C~L -999.25u0 Cabt a~A -g99. 2500 I .7a32 11.8,9375 999,250 o lO.0000 2. 1406 130,6250 999.250 () 10.9453 4.12l 1 213.7500 999,2500 10,8672 237. 5000 -999.25U0 10,4297 3.49 B (:i } I., 21 I. 8750 L'T 12.04-69 (7:~' 22.1"719 ll~D F~ 6,75 O 0 G R 2 · 5 I, 5 {5 :',~C N L 67 · 3750 NRAT 2.01, 56 IL.O 111.7500 {JR -999. 2509 NCb)L 118.9375 NRAT 2.01.76 ILD 114,0000 -999.25()0 130,6250 3.7q49 1(.)6,1~75 GR -999.~500 r.~CNL 213,7500 2.1719 9~,187b -999. 250(> 237 ,SUOu 3.5742 IL, I) 11,2.1~75 - 999.25 00 N C N i,.., 211,~'150 v~RAT 6 b, 000 () ,240B. OuO0 3,293O .. 3359 7 7500 317 0000 2.4590 3.0645 111,B125 0000 2574,, ( , 7402 5000 -999.2500 1.9697 131,000U -999.25U0 -999,2500 1.9355 129,00Q0 -999.~500 -999,2500 3,6719 252.7500 -999.2500 -999.2500 1.99bl 26~,7500 -999.2500 '999,~500 3,6~1.6 208.7590 -999.2500 -999.2500 -64,8125 GR ~I 999,250,J CALl '~RA -999. 2500 ~..; i,;) 'T' 67L)0. {}{)()u L.:, 1-' l.,),t P -89,3'i25 CHI, -999.2500 ,~! 1~ A -999.25U0 EPT 660 O, 00 O0 $1:' L.o P -04. 5000 (;i, PHi -999.2..500 I,~ }, ~,i [.;'., CNL -999.2500 C t~.t.., l ~R~ - 999,25t JO 999. ~"":' " .,:, t.,' ( ~ t.,! !4 t, F, 2,007 t.; 102,9375 lOT -999,2500 1 .,I,, 1562 }., 9 <,:i 22. 1 [., 120,5(.)00 OT -999,256u !. I , 4'~09 1 . 9707 !. (..~ ~', a7.31.25 b']7 11,2813 C;R 3 . 8 I 6 ,% I ,t~ I,;' 103,1875 G R 132. 2500 al'RAT 2.125() ILl) 99,56~ GR 9 9,2 5 1~ C N [., 06. 502.,, NRA ~.216B 93,~(;)00 -999 86 2,9 ~') ~ )~ 89,750() -999.250{) 92. 2500 2.2 4 8 (} ,L [., D 10.4,5625 (JR -999.2 5(;0 r~C Nb 127,0000 NR.AT 2,1660 ]. '[.., D 9'1, ? 5t)g GR -999,2500 NCbb i02,9375 t~RAT 2 . 5506 i bi3 96,5625 GR -999.2500 'hCNI., 120.5o00 NRAT 2.2363 .iL, b 98. 0000 GP -999.2500 ~'/.3125 ~H A'I' 2. I 695 i b D 99. '1500 - 999.250 ("' 93.937b r.~k'AT 3,82~I 122,5625 -999.2500 -999.2500 2,0840 1.20, ,12250 -999. 500 -999.2500 2,1.445 80,6875 '999.2500 -999,2500 2. 8047 109~ 25O0 -99 ' 2500 2,1.953 141,5000 -999.25O0 -999.2500 2. l.l 91 104,0625 2999,2500 999.2500 2,5664 11~.87b0 -999,2500 -999,2500 2.20'10 99.3750 -999'2500 -999.25U0 2,1680 9~,8750 -999.2500 -999,2500 i~,? ~ l I 11 il JI:-I ~[t [:--1 ~ :) ri .'! - 9 9 9.25 {) () I:~ R H 1~ :t 2mL -999,2500 CAE I ~3 P T 6 ].. 0 0,00 O {) S F 1., ~] P ~ 4 ,0313 G k P H ~ 999.25 U 0 L.~ k ~,~l ~ 2NI., -999,2 5 u ('~ CAI.., I, NRA '999. 2500 [SPT % 5L, O. <,~(} 0 () SFI,U P -3'i.7813 GR P r~ .! - 999.2500 L; ~'~ r, i} C[~I .... 99g.2500 CALl r'~k~ -999. 2500 2.3 0 b h 1.1'_, a 9 ~, ~ o 0 o D'I' - 999.250 (') 5' ,~.i ['.i [~ 11.4219 GR 2,8477 1' L a 1.05,3125 UT - 999 ' 25 O 0 fl. ~.! 0 tfl 1.0, i~047 GR 2.6 '73 ~{ i t., ,1. 21. 5000 D -999.2500 11.0313 GR 2. '1 '7 ? 3 I L, 122.0025 12. '; () 31. (; ~{ 2.1738 - 999.25 O 0 12.62.59 2.2324 100. Ot)Oo Gl:( -999.2',:)00 92.4.375 NRAT 2,3789 I I.,D 97,7500 Ga - 999,2500 89. 0625 .maAT 2. 3262 I,L,D 100,0000 G R -999. 2500 88.4375 3. 1562 I[.,D g 3,3 750 G R -999,2500 i",; C i~{ L, 100,0625 h~RAT 3,0i:~98 I[,D 93' 5O25 (,iR -999.2500 1.(.~5,3125 N R A',r. 2. 953 t It,,!) 96,0000 GR -999.2500 121,5000 3.1230 '[ L D 101.7500 (JR -999,2500 NCNb 122.0625 2.4 ~. 24 I b D -99q.2500 2,2051, 99,43'75 -9q9. 2500 -9%~9,2500 2,3652 i'j 7,1250 -999.25(')0 -999 . 2500 2,~,Ib4 92, li7S -999. 2500 -999,2500 2.5918 1o4,25~25 ..999, ~00 -999,2500 3.1250 -999.250() -999,2500 3,1445 -999,2500 -999,2500 3.0o00 1.1~,3750 -999,250O -999,2500 3.130'1 135,8750 -999.2500 -999.2500 2.5684 12~.187b -999.2500 -99W.2500 ~, . ,,~ I:;', A - 999.2 b C,, 0 5-43,5313 -999. 2500 -999,2500 -50.0313 -999. 2500 Cab:I 500t.:. Ou O0 - 59.2,813 G -999.2500 '999,2500 4900.0 O 00 S -64'81.25 -999.2500 C ~,I., :I: -999.25(,)0 -999.2500 Cnl,I -999. 250(.1 2.2031 -999.25(i0 1. ~, ? u 31 2.5527 95.3125 -gqq.25fiO 12.9297 3.117'2 'I LD 99.3750 G R - 9 9 9.250 u ~'~ C r,,.~ b 100. 1250 NRAT 3,406 3 [ b D 99,0000 G R 109,9375 2.7285 I. b D 104.0000 GR -999,2500 ~C~L 11,4.2500 ~RAT 2.525.4 I b D 106,7500 - 999.2500 ~,i C ~ I,~ 113,3125 NRAT 2,8965 111,0000 -999,2500 NCNL 1.16,1950 NRaT 2.4629 ILl) 109.7500 GR 106,1~75 h, RAT 2.9062 I[,[> 10e.7500 GE -999.2500 95,3125 i~RAq' ~2,7 07 0 - 99 ? 0 0 -999. 2500 3.2148 1:16,4375 -999, ~5(.)0 3.4551 115 5000 999 ' ' .2500 -999,2..500 3,0 020 106,7500 -999 ,2500 -999.2500 2,7773 117,7500 -99g,2500 -999,2500 2,5625 1.12,3125 -999.2500 -999,2500 2,9687 127,1,250 -999.2500 '999,2500 2.49~0 122,0~25 -999,2500 -999,2500 2.9922 11V.1875 -999.2500 -999,2500 "(' zl 5 ,: 0, :al', -999. 2500 ~R a -999,2bO · :' - 25, ~ N b g 69.00 ~7, PT 4 300. OOU(} ::~ -3 ~, 5000 :.~ N l,., 524,0000 ,,[i~ e.2 3""5 {iPT 4,200 "' N I .... 556, ?.1P T q ]. 0 t~. 0000 :' -38.0313 TN[., 449. 5000 E P T 4000 P -31 .2500 PHI ~0,5'702 Chi., 439. 7500 EPT 3900.0000 P -32,2813 P H 1 46.337 9 C N l... 4 t) a. b 00 0 P -35,5313 P H I 3 '7, Cab 536.50UO Ni{~ 3.4922 E P q' 37 (; 0 P - 33 P H I 42.52 Chi., ,13.~. 0000 92.4375 L f O. 015 ! k t..i O 12 . ii 0 '12 (; 86.4375 D T 11,8125 GR 2,1523 g5,5000 13.5~b9 4,7422 80.1250 DT 0.0 l 4 t:.., R h 0 13. 4063 GR 2.9 '/65 75.5025 13.1'71,9 108 5625 - 9 9 9 2, 5 o 0 95. 2. 927'7 30, ,00 00 2,3'730 7 4 · l ~ 75 3.2383 I 0 il. 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