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Home My WebLink About185-200Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. I .~ ~-'-- c'~0 ~ Well History File Identifier Organization RESCAN Color items: Grayscale items: Poor Quality Originals: Othe~ TOTAL PAGES: ORGANIZED DIGITAL DATA Diskettes, No. [] Other, No/-rype '~ NOTES: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) a Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) n Logs of various kinds [] Other ISl Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl Scanned ldo.e) IIIIIIIIIIIIIIIIIII PAGES: ~'"~ (at the time of scanning) SCANNED BY: BEVERLY BREN VINCE~MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: General Notes or Comments about this file: / 0/~,'~ ~ /~7,~ Isl PAGES: Quality Checked (done) ~vl~TScanned.wpcl STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ~ L~~G 1a. Well Status: Oil ^ Gas- Plugged Q Abandoned 0 Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. 1NeR Class: Development ~ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., r April 30, 2008 12. Permit to Drill Number: 185-200 / 308-147 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 pulled: October 1, 1985 13. API Number: 50-029-21426-00 ' 4a. Location of Weit (Governmental Section): Surface: 1193' FNL, 1241' FEL, Sec. 14, T12N, R9E, UM 7. Date TD Reached: October 7, 1985 14. Well Name and Number: 3C-15 • Top of Productive Horizon: 1256' FSL, 1363' FEL, Sec. 14, T12N, R9E, UM 8. KB (ft above MSL): Ground (ft MSL): 85' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 873' FSL, 1422' FEL, Sec. 14, T12N, R9E, UM 9. Plug Back Depth (MD + ND): 7091' MD / 6126' TVD Kuparuk Oil Pool ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528333 • y- 5995239' Zone- 4 10. Total Depth (MD + ND): 7840' MD / 6695' TVD 16. Property Designation: ADL 25634 TPI: x- 528224 y- 5992407 Zone- 4 Total Depth: x- 528167 - 5992024 Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 2567 18. Directional Survey: Yes ^ No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1700' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): none 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surf. 116' Surf. 116' 24" 188 sx CS II 9-5/8" 36# J-55 Surf. 3841' Surf. 3714' 12.25" 950 sx PF'E', 36o sx Class G 7" 26# J-55 Surf. 7826' Surf. 6685' 8.5" 400 sx Class G, 175 sx PF'C' 23. Open to production or injection? Yes ^ No ~ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET none n/a 7196' perfs squeezed off 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED GG ~_~-~ '-~~ ~• ~ ~. ~Q~u 7091' 61 bbls cement 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes No ~ ' If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.0~~ ~. ~¢..ll,6Q~. Ht~+t A7E NONE 3a •~ 4'fr Form 10-407 Revised 2/2007 CO N N S S E ~j`. ~J.lig" ~~ ~~ ~~~ ~I ~ 100 `~ ~ ~~ ~ L ~ ~~~ ADS 28. GEOLOGIC MARKERS (List all formations and m encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes Q No • If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1700' 1700' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7248' 6247 Base Kuparuk C 7360' 6333' Top Kuparuk A 7529' 6462' Base Kuparuk A 7680' 6575' N/A Formation at total depth: Kuparuk C 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: Guy Schwartz @ 265-6958 Printed Name Gu Schwa Title: Wells Engineer _ ~ /3 ~Q Si t gna ure Phone Date INSTRUCTIONS Sharon Allsu/rDrake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • 3C-15 Pre-Rig Events • DATE SUMMARY 4/5/08 T & IC POT/PPPOT -PASSED, LDS CONFIRMED FUNCTIONAL (PRE-RWO/ST) 4/23/08 TAGGED @ 7349' SLM. MEASURED BHP @ 7200' RKB: 3986 psi. JOB SUSPENDED. 4/24/08 PULLED GLVs AND SET DVs @ 2269, 3938, 5177' RKB. PULLED OV @ 5926' RKB. LOCKED OPEN TRDP-1A-SSA FLAPPER @ 1800' RKB. IN PROGRESS. 4/25/08 SET K-2 PLUG ASS'Y 6032' WLM. LOAD TBG / IA WITH SW & DSL FREEZE PROTECT. SET DV @ 5926' RKB. wTESTED IA 2000 PSI, GOOD. BLED TO 200 PSI. PULLED SLIP STOP AND K-2 PACKER- PLUG @ 6032' WLM. IN PROGRESS. 4/26/08 PULLED LOWER SLIP STOP @ 6026' WLM. MIT IA 2500 PSI PASSED PERFORI~AER INJECTIVITY TEST ON C SANDS 1 BPM Cad 1925 PSI TAGGED an 7315' WLM BOTTOM CSM INACCESSIBLE. PULLED DV @ 7138' RKB. READY FOR E/L. 4/27/08 SET HALLIBURTON ENERGY SERVICES (HES) 2-7/8" FASTDRILL CEMENT RETAINER WITH MID-ELEMENT AT 7155'. 4/29/08 Crew Swap, MIRU Ctu 4 4/30/08 PUMPED A TOTAL OF 61 BBLS OF CEMENT, WITH 35 BBLS BELOW CEMENT ~ RETAINER (30 BBLS INTO C SAND), UPON STINGING OUT OF RETAINER COIL BECAME DETAINED UNSURE OF HOW MUCH CEMENT WAS PUSHED INTO IA VIA GLM AT 7133' MD, FCO'D DOWN TO 6850' CTMD ALLOW CEMENT TO BALANCE OUT BETWEEN IA AND TBG. 5/2/08 MITIA FAILED. IA LEAKING VIA GLM~ MITT PASSED. TAG CEMENT @ 7091 RKB W/ 2.3" SWAGE. ATTEMPT TO PULL DV IN STA #6. JOB IN PROGRESS. 5/3/08 PULLED 1" BKDV FROM STA #6 @ 6768' RKB. STILL NEEDS COMBO MIT. JOB SUSPENDED. 5/4/08 CMIT TBG X IA TO 1500 PSI PASSED. 5/9/08 JET CUT TUBING AT 6700' WITH 2 1/8" POWERCUTTER. VAVLE CREW TO SET BPV IN AM. 6/30/08 Moved rig from well # 3C- 17 to well # 3C-15, rig up lines to displace diesel out w/ sea water. pump down IA w/tubing lined upon flow back tank. Pressure up to 1,000 psi. (1 bbl.) bleed down 1"stream, pressure dropped 200 psi. in 10 mins. Pressure upon tubing same flow, 1,000 psi. Calved town with results, Shut SCSSV, well flowing out tubing w/ IA on vacuum, pump sea water down tubing to balance, cycled SCSSV, not holding, well still out of balance. Note; Accept rig @ 18:00 hrs 6/30/08 7/1/08 Made several attempts to displace diesel from tubing and annulus. Unable to circulate. Njgple uo and test BOPE. Stopped to tighten bolts between BOP stack and riser. All componets passed test. Witness waived by AOGCC Chuck Scheve. Rigged up to pull back pressure valve /two way check. 7/1/08 JET CUT TUBING AT 5500' WITH 2.125" POWER CUTTER. THREE ELINE CREW DAYS 7/2/08 Pull back pressure valve and attempt to pull tubing. Tubing not free. Calculate freepoint and discuss with town. Decision made to cut tubing at 5500' MD. Rig up and run in hole with wireline cutter. Stacking out at 175' MD. Observed 700-1400# of overpull and found ice on tool string when pulled out of hole. Run in hole to 270' MD with 1" eipe and wash tubing. .Attempt to run in with wireline and stacked out at 800' MD. Pull wireline and run back in hole with wash pipe. Depth at midnight 820' MD. 7/3/08 Run in hole with 1" pipe to 1496' MD and wash tubing. POOH and run in with tubing cutter on wireline. Cut tubing and POOH. Pull on tubing to confirm successful cut. Circulate diesel from casing and tubing. Pull 5500' of 2-7/8" completion string. Change rams and test. 7/4/08 Finish testing BOP after changing rams. Run in hole with casing scraper and circulate hole clean. Spot 100 bbl 13 ppg pill from 5500' MD to 2887' MD. Rein 1 IT logs to locate Hof cement and casing coLars. Run bridge plug on wire line and set top at 2768' MD. Test ~asing_to 3800 osi for 30 minutes good test. Start nippling down to change tubing spool and 7" packoff. 7/4/08 RAN USIT FROM 4000' TO SURFACE. TOC FOUND AT 1803' MD. NO SIGNIFICANT CORROSION FOUND. SET BAKER 3B6 CIBP AT 2768' TOP OF PLUG. CHARGED TO RIG'S AFE. • 3C-15 Pre-Rig Events • 7/5/08 Nipple down stack to change out 7" packoff and tubing spool. Nipple back up and test BOPE. All components passed. Witness waived by AOGCC Bob Noble. Pick up and run in hole with whipstock and milling assembly. Orient and set whipstock, begin milling window. 7/6/08 Milled window and rat hole. Perform Leak Off Test (14.0 oog EMW). Trip out milling assembly and trip in with drilling BHA. Serviced rig and began drilling intermediate hole section. 7/7/08 Drilled intermediate hole to 3286' MD and could not make more hole. Troubleshoot then tripped out of hole. Mud motor failed. Picked up new motor and MWD and tripped back to bottom. Reshot surveys on the way in hole. Resumed drilling at 18:30. 7/8/08 Drilling 6-1/8" x 7" intermediate hole section. 7/9/08 Drilled 6-1/8" x 7" to 5262' MD and made a planned trip to change out motor, reamer and bit. Picked up new motor, reamer and bit. 7/10/08 Finish picking up BHA from planned trip. Trip in hole to window. Service rig and change saver sub. Trip to bottom and resume drilling intermediate hole section. Stop drilling and circulate while holding Safety Standdown. Well started breathing after resuming drilling. 7/11/08 Drilling 6-1/8" x 7" intermediate hole section. Well breathing and taking fluid. Reduce mud weight from 9.8 ppg to 9.4 ppg, make wiper trip to window. Trip back to bottom and resume drilling. Lost 378 bbls mud to formation today, cummulative losses 410 bbls. 7/12/08 Drilling 6-1/8" x 7" intermediate hole section. Pumping high viscosity sweeps and limiting ROP while rotating to keep ECDs below 11.4 ppg EMW. Dump old mud and build new mud to reduce drill solids in system. No losses to formation today. cummulative losses 410 bbls. 7/13/08 Drilling 6-1/8" x 7" intermediate hole section. Pumping high viscosity sweeps and limiting ROP while rotating to keep ECDs below 11.4 ppg EMW. No losses to formation today. cummulative losses 410 bbls. 7/14/08 Drilling 6-1/8" x 7" intermediate hole section to TD, 8748' MD, 6147.8' TVD. Backream 5 stands, trip to bottom and begin circulating hole clean. 7/15/08 Short trip and condition hole for 5 1/2, 15.5 # L-80 casing liner, POOH UD BHA #5, run liner. 7/16/08 Continue running 5 1/2 liner on DP. t/ 8,747' tag bottom ,while circulating liner became stuck and packed off. Released from liner hanger, Pumped down inside liner for an injection rate, broke @ 1450 psi. @ 1 BPM, went to the back side injection rate was 450 psi @ 1 BPM. POOH for liner contingency squeeze tool, spaced out into liner, set slips on liner hanger, pulled up 10' to expose ported sub for squeezing. 7/17/08 Service rig while waiting on cement lab results, squeeze 5 1/2 liner, set BOT packer, POOH L/D 4" DP, test BOPE. P/U BHA #6, 4 3/4" bit & scraper, 2 7/8" HWDP and 2 7/8" drill pipe. 7/18/08 Continue to RIH w/ BHA #6, 4 3/4" scraper, CBU @ landing collar, POOH, Run a USIT. and CBL. log w/ Sclumberger (logging unit down 2 hrs. with air line), USIT tool failed. 7/18/08 RAN AUSIT-CBL LOG IN THE 5 1/2" LINER TO DETERMINE CONDITION OF THE CEMENT JOB. 7/19/08 Finished up w/ USIT logging, RIH w/ Fast drill retainer, set @ 8620, POH for BHA #7. 7/20/08 POH w/ retainer running tool , RIH w/ BHA # 7, stop cut drilling line and service rig, cement and retainer, cleanout to 8,725' 7/21/08 Drilled cement retainer & float equipment, change mud system f/ 9.6 PPG t/ 12 PPG, drilled 20' of new hole, preform a FIT test, drill t/ 8 795', weight up t/ 13.3 PPG, drill ahead t/ 8,964' 7/22/08 Finished weighting up to 13.7 PPG mud, drilled ahead to 9,006', lost pump pressure, tested surface equipment, OK. L/D bit, motor, stab, and Jars. Down load MWD, RIH w/ BHA # 8. 7/23/08 RIH w/ BHA # 8, watching for possible wash out, testing string on way in. condition mud @ 5 1/2" shoe, Drill f/ 9,006 t/ 9,211' MD, 6,527' TVD. • 3C-15 Pre-Rig Events • 7/24/08 Drill f/ 9,211'- t/ 9,327' MD (TD) 6,619' TVD, monitor well, static. Short trip to 5 1/2" shoe and back. CBU, 500 units gas, circulate gas cut mud out. Monitor well 15 min. (flowing) circulate light spot out, monitor well again (static), BROOH to 5 1/2" shoe to keep from swabbing the hole. 7/25/08 POOH & L/D BHA # 8, P/U & RIH w/ 3 1/2" Hydril 511, 9.2 ppf. casing liner w/ "HR" ZXP liner hanger, filling and circulating every 2,500'. 7/26/08 RIH w/ 3 1/2" liner on 2 7/8" DP staging in & circulating every 2,500', tagged bottom @ 9,327'. Pumped cement and displaced, dart failed to bump, attempt to release from liner, (would not) POOH w/ string up to 6100' CBU, dart bumped. POOH wet, broke out landing collar. Std. shoe track in DRK. 7/27/08 P/U clean out assembly, RIH staging in, circulating out cement contaminated mud. 2,500' / 5000'/ 6100'/ 8700'/ and 9,231'. Condition mud to a 28 yeild point,13.5 ppg.around. 7/28/08 Finish servicing rig, RIH to TD (9,327') conditon mud, POOH, L/D BHA # 9, P/U 3 1/2" liner w/ "HR" hanger and ZXP top packer, RIH to 1,785'. 7/29/08 Run 3-1/2 production liner on 2-7/8" drill pipe to TD. Circulate and condition mud for cement. Drop 3/4" ball to set and release hanger. Ball did not seat. Drop second ball and pump down. 7/30/08 Dropped balls to set and release hanger. Balls did not seat and could not confirm release. Cemented liner and attempted to set packer. Circulated hole clean and tested packer. Would not hold pressure. Made several attempts to set and test packer. Pulled out of hole and waited for cement to cure. Casing held 1600 psi when retested. Rigged up and began running 3-1/2" gas lift completion. 7/31/08 Run 3-1/2" gas lift completion with subsurface safety valve.. Tag up and space out. Test tubing, seals and SSSV. Install back pressure valve and begin nippling down stack. 8/1/08 Nipple down BOP stack and break down stack. Nipple up tree and test. Freeze protected well. Lay down 2-7/8" & 4"drill pipe from derrick. Cleaned pits and rockwasher. 8/2/08 Lay down 4"drill pipe, clean pits, rockwasher and cuttings bin. Rig Released at 02:00 (adjusted for 3 hours of rig maintenance completed before actual release at 05:00). ~UtlOC0~111~1~S kl,li~sia. a1,:. i.azn Comment End Data KB-Grd (k) HYS (ppm) Date Annotation Rig Release Date LOCKED OUT I ( ( ( 100 711/2008 Last WO: 37.30 ( 1019/1985 iAnnotation 'Depth (kKB) End Date Annotation End Data (Last Tag' '~ 7,315.0 4/26!2008 (Rev Reasom PREP FOR SIDETRACK I 7/13/2008 (Casing Strings Set Depth Set Depth (TVD) 1V1 I _- Casing Description (ftK8) (kKB) (Ibskt) Grade OD(in) ID (in) Top (kK6) Top Thread CONDUCTOR 16 15.062 0.0, 116.0 116.0 62.50 H-00 SURFACE li 95/8 8.765 D.O~ 3,841.0 3,713.4 36.00 J-55 PRODUCTION 7 6.151 0.0~ 7,826.0 6.684.8 26.00 J-55 ~'~ Tubing Strings Sat Depth I Tubing Description OD (in) ID (in) Top (kKB) (ftK8) Sel Depth (ND) (kKB) Wt (Ibs/fl) Gratla Top Thread TUBING 2 7/8. 2.441 6,700 0 7,465.0 6,413.7 6.50 J-56 I Other In Hole (A ll Jewelry:. Tubing Run 8 Retrievable, Fish, etc.) _- p (kK8! Descripti ~To on 'i Gommant Run Date '~ ID (in) - II 6,700.0 TUBING CUT .CUT TUBING w/2.125" JET POWER CUTTER 5/9/2008 519/2008 '~ 2440 6.768.0 GAS LIFT iCAMCO/KBMG/1/DMY/BK///Comment: STA 6 11/22/1995 1 2.347 7,133.O GAS LIF7 MMHlFMHO/t.5/OPEN/RK///Comment: STA7 5/19/1997 2-347 7,178.0 PBR Camm'OEJ' 11/1/1985 2.313 7,196.0 PKR Camm'HRP-13P' 11/1/1985 2.347 7,216.0 PackoHl - ___ - __ FF W/KOBEKNOCK OUT WlSUP STOP ABOVE AND BELOW, 7 6/7/2003 Slipstops ( set 61 2003 i 7,235.0 PRODUCTION CAMCO/KBMG/1 /DPHCVlBEK/// Comment: OPEN STA 8 6/17/2000 i 2.347 7,301.0 PRODUCTION GAMGG/KBMG/1 /DPHCV/BEKlll Comment: OPEN STA9 6/17/2000 ~ 2.347 7,397.0 Fish X23' Tool String TAGGED FISH @ 7397 (WLM) on 12/5/97; 5/21/1997 7,400.0 PRODUCTION CAMCO/KBMG/1/DMY/BK///Comment CLOSED STA 10 2/17/1997 2.347 7,439.0 PKR Otis'WD' 1111!1985 4.000 7,457.0 NIP Camco'D' Nipple NO GO 11/1/1985 12.250 7,457.0 Fish BAITSUB 8 JUNK on top of CRX PLUG 57" Bait Sub 8 CRX Plug FISH (JUNK 5/21/1997 on top of PLUG) in Hole; See WSR's from 4/5/97 to 5/21/97; Ongoing FISH 7,464.0 SOS Camto 11/1/1985 ~ 2441 7,465.0 TTL I 11/1/1985 2.441 (Perforations - - __ I snot I Top (ND) Bbn (ND) ~i Dens ~ Top (kKB) Btm (kKB) ~ (shot... Date (kKB) (kK6) Type ~ Zone Comment _ 7,346.0 7,362.0 6,322.9 6,335.2 IPERF 12.0 11/1/1985 IS" Csg Gun HJ II; 120 deg. i (phasing 7,542.0 7,547.0 6,472.0' 6,475.8 IPERF 4.0 11/1/7985 4" Csg Gun HJ II; 90 tleg. phasirg 7,S6Z0 -_ 7,582.0 6,490.5( 6,502.1 IPERF I I 4.0 11/1/1985 I4" Csg Gun HJ II; 90 deg. phasing ~~ !~? .~ % J; // /// 111.../ __... _.. _.._ ~;. s13~i~1~~11Pi~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~ JUL ~ ~ 2008 Log Description N0.4775 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE j 06/24/08 1 1 i L-20A 10215099 PRODUCTION PROFILE c~(7(J ffi 06/26/08 1 1 1 G-05 12080389 LDL Cp 06/27/08 1 1 36-10 12061714 INJECTION PROFILE 'r - t / 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 iJ-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ `fir- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY L -~ 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - ~' 06/29/08 1 1 2X-14 12080391 SBHP SURVEY 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~(- 5 06!29/08 1 1 iG-09 12080401 INJECTION PROFILE V ^' ( ~~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~"-.-e- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY b~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY / 06/30/08 1 1 iD-07 12080398 SBHP SURVEY - .l 07/02/08 1 1 2N-341 12061720 SBHP SURVEY p 06/30/08 1 1 3C-15 11982441 USIT - (](~ / 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE ~ - (p 07/08/08 1 1 i L-19 12061724 PRODUCTION PROFILE J p -b 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Page 1 of 2 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Monday, July 07, 2008 9:53 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-15 (185-200) update 7!2/08 Attachments: Greener, Mike R..vcf We cleaned out the ice plug in the tubing, got it cut at +/- 5,500' NID, pulled and our whipstock set at +l- 2,754' MD (based on USIT log information). Window cut good and we are currently in the West Sak "D" drilling ahead. ~~1~~~ .iUL ~ 3 2008 Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 07, 2008 9:16 AM To: Greener, Mike R. Subject: RE: 3C-15 (185-200) update 7/2/08 Hi Mike. Any further update on 3C-15? Note, since you have not actually milled the window in the casing by our convention the work is still taking place in 3C-15. Tom Maunder, PE AOGCC From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Thursday, July 03, 2008 8:34 AM To: Maunder, Thomas E (DOA) Subject: RE: 3C-15A update 7/2/08 Ice plugs have been cleared out. Tubing is cut at 5,500'. Will attempt to pull in a couple of hours. Mike Greener From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, July 03, 2008 7:35 AM To: Greener, Mike R. Subject: RE: 3C-15A update 7/2/08 It never ends, eh? From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com] Sent: Wednesday, July 02, 2008 3:06 PM To: Maunder, Thomas E (DOA) Subject: 3C-15A update 7/2/08 7/7/2008 Page 2 of 2 • • Attempts to pull the tubing were unsuccessful. Did stretch free point calculation which showed free point at 5,900'. Rig up wireline to run jet cutter but tubing has ice plug at +/- 200'. Currently picking up 1-1/16" tubing to wash out ice plug. Mike Greener 7/7/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com] Sent: Tuesday, July 01, 2008 8:43 AM To: Maunder, Thomas E (DOA) ~~~ _ ~Q~ Subject: Status on 3C-15A as of 711/08 Attachments: Greener, Mike R..vcf Pre-work on this well showed that the tubing (2-7/8") was cut at +/- 6,700'. Drilling has moved onto the well and attempted to circulate through the cut tubing but was only able to achieve .25 bbls/min flow rate. Currently, we are going to pick up the tubing string and attempt to circulate again. There is a possibility that there may be cement from the plugging operations to P&A the original wellbore up around our tubing string. If we can't circulate the tubing, we will free point the tubing string and make a higher cut to achieve circulation. Plan forward is to circulate 13 ppg mud as deep as possible in the well. Mike Greener ~~~i~N~~ JUL ~' ~ 2008 7/3/2008 • • 5 fjN k..q ¢ w } I ~.....,.~ .. ~. ~~ ~ ~ • . ~ ~ •-~~ ~ SARAH PALIN, GOVERNOR Oiil L11`i1 GA5 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T CO1rII~II5SIOI~T ANCHORAGE, ALASKA 99501-3539 - - " " PHONE (907) 279-1433 FAX (907) 276-7542 Guy Schwartz Wells Engineer ConocoPhillips Alaska Inc. Po sox 100360 ~~,~~~ p,pR ~ ~ 240 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3C-15 Sundry Number: 308-147 Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~' day of April, 2008 Encl. ~:. . ~~.. ~,'(~ ,~;~~~~~~ ~ RECEIVE STATE OF ALASKA •/']-T~ ALASKA OIL AND GAS CONSERVATION COMMISSION 'a"~ APR 1 ~ 2008 APPLICATION FOR SUNDRY APPROV~a oi- & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon Q Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^ Alter casing ^ Repair well ^ Plug Perforations ~ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permitto Drill Number: ConocoPhillips Alaska, InC. Development Q Exploratory ^ 185-200 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21426-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS NO Q 3C-15 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25634 - RKB 85' Kuparuk River Field /Kuparuk Oil Pool - 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7840' 6695' ' 7294' 7397', 7457' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 116' 116' SUR. CASING 3801' 9-5/8" 3841' 3714' PROD. CASING 7786' 7" 7826' 6685' Perforation Depth MD (ft): Perforation Depth ND ft Tubing Size: Tubing Grade: Tubing MD (ft): 7346'-7362', 7542'-7547', 7567'-7582' 6323'-6335', 6472'-6476', 6491'-6502' 2-7/8" J-55 7465' Packers and SSSV Type: Packers and SSSV MD (ft) pkr- CAMCO'HRP-I-SP' ; OTIS'WD' pkr- 7196' ; 7439' Camco TRDP-1A-SSA SSSV= 1800' 13. Attachments: Description Summary of Proposal Q 14. We11 Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 21, 2008 Oil J~~ t,Z•~ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ^ / GINJ ^ WINJ ^ WDSPI. ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GUV SChWattz Title: Wells Engineer Signature `-~ Phone 265-6958 Date y ~~' ~ Co sion Use Onl Sundry Number: ~ l Conditions of approval: Notify Commission so that a representative may witness ~~ g ~''7 Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~~-pp ., _ Other: ~,,~ ~~V ~ 7i t-'~~~\~.~v"`L `~ ` ~~ Subsequent Form Required: L,('~ APPROVED BY . O Approved by: O SIGNER THE COMMISSION Date: ~" Z Form 10-403 Revised 06/2006 {~~ 1 \ t t~~ ~ L Submit in licate ~ • 3C-15 P & A Outline for Sundry April 17, 2008 Summary: Producer 3C-15 was drilled in 1985, perforated in the C1/A4/A3 sands and completed as a single selective utilizing 2 7/8" tubing. A CRX plug was left in the hole (D nipple) in 1997 after fill prevented its retrieval and fishing operations resulted in a bait sub assembly and 23' of tool string being lost in the hole. As a result, the A-Sand was unintentionally isolated for the long term and the well was brought back to production as a C-Sand only well. In 2002 the well was SI after finding corrosion damage on the flowline. 3C-15 was brought back on production on 06/2006 after a flowline replacement. The well produced at high watercut levels (91 % to 99%) until 04/2007 when it was left SI after additional attempts to fish were unsuccessful. It is proposed to sidetrack well 3C-15 to the northwest corner of segment 3C02/3CD2 to provide ~ an offtake point to a segment with proved waterflood support, negligible cumulative oil .recovery, and lack of additional producers. ~ t~ ~~~ U~PEiS~Oa ~`v ~ G'D~cvi /~ ~ ~-t <as~t pit r~-~s wP~/ ~~ r~s~- ss~9' 6c° ~~Of'r,l~P~ ~ QCC2ts hy~ Pre-rig Wellwork: /~°,Pw~ /~,~ ~ Lf~ / 1) Test wellhead packoffs/ cycle LDS's. 2) Pull GLV's and replace with DVs . Leave bottom GLM at 7133'md open. Set D and D test tool at 7200' md. Fluid pack well and perform CMIT. 3) Set 2 7/8" cement retainer at 7155' md. 4) Sting into retainer and pump class G cement into C sand via retainer. (C sand volume => 8.8 bbls bbls)Continue pumping cement until squeeze pressure of 1500 psi is seen.. 5) Pull out of retainer and pull uphole laying in cement 1 - 1 to a depth of 7000' md. Open IA valve and displace another 6 bbls of cement into the IA taking returns at surface. (TOC to be 7000' in tubing and IA) 6) Tag cement. Test IA and tubing cement plugs to 1500 psi. 7) Pull GLM DV at 6768'. Cut tubing at 6700' md. (jet cut with E-line) 8) Set BPV, prep wellsite for rig. Rid Work P & A component: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MURU Doyon 15. Test BOP's. • • 2. L/D the tubing hanger and pull 2 7/8" tubing. 3. RU wireline set a CIBP inside the 7" casing at +/- 3100' MD based on casing collar depth. 4. Set Whipstock and mill out window to start Sidetrack wellbore. • ~' KRU 3C-15 ~onoCC~I'hlllips Ataska, Inc. ~~-,., API: 500292142600 Well T e: PROD An le TS: 39 de 7259 sssv SSSV Type: TRDP Orig 10/9/1985 Angle @ TD: 42 deg @ 7840 laoo 1so1 Com letlon: ( - , OD:2.875) Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference Lo Ref Lo Date: Last U date: 9/22/2006 ' Last Ta : 7294 TD: 7840 ftKB Last Tag Date: 9/8/2006 Max Hole 46 deg @ 4300 Casin SVin = ALL STRING S " Descri lion Size To Bottom ND Wt Grade Thread ', CONDUCTOR 16.000 0 116 116 62.50 H-40 SUR. CASING 9.625 0 3841 3714 36.00 J-55 PROD. CASING 7.000 0 7826 6685 26.00 J-55 L-m,.. - Tubih String -TUBING Size ~ Top Bottom TVD Wt Grade Thread 2.875 ~ 0 7465 6414 6.50 J-55 8RD EUE Perforations Summa Interval TVD Zone Status Ft SPF _ Date T Comment 7346 - 7362 6323 - 6335 C-1,UNIT B 16 12 11/1/1985 IPERF 5" Csg Gun HJ II; 120 d hasin ' 7542 - 7547 6472 -6476 A-4 5 4 11/1/1985 IPERF 4" Csg Gun HJ II; 90 deg. hasin 7567 - 7582 6491 - 6502 A-3 15 4 11/1/1985 IPERF 4" Csg Gun HJ II; 90 deg. hasin Gas Lift M - - -- andrelsNalves St MD ND ~ Man Mfr Man Type __ V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 2269 2269 Camco KBMG GLV 1.0 BK 0.156 1275 6/25/2006 2 3938 3789 Camco KBMG GLV 1.0 BK 0.188 1305 6/25/2006 3 5177 4700 Camco KBMG GLV 1.0 BK 0.188 1295 6!25/2006 ', 4 5926 5249 Camco KBMG OV 1.0 BK 0.250 0 6/25/2006 '~ 5 6335 5552 Camco KBMG DMY 1.0 BK 0.000 0 1/23/199 PBR 6 6768 5878 Camco KBMG DMY 1.0 BK 0.000 0 1/22/199 (717a-717x, 7 7133 6158 MMH FMHO Merla DMY 1.5 RK 0.000 0 5/19/1997 Prod uction MandrelsNalves PKR (71ys-71y7 St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt oD:s.151) _ 8 7235 6237 Camco KBMG MACCO DPHCV 1.0 BEK 0.000 0 6/17/2000 O en 9 7301 6288 Camco KBMG MACCO DPHCV 1.0 BEK 0.000 0 6/17/2000 O en TusiNC 10 7400 6364 Camco KBMG DMY 1.0 BK 0.000 0 2/17/1997 Closed oDaia s, ~~ Other lu s e ui .etc. -:JEWELRY iD:z.441) De th ND T e Descri lion ID ~ , 1800 1800 SSSV Camco TROP-IA-SSA' 2.312 7178 6193 PBR Camco'OEJ' 2.313 ~, - 7196 6207 PKR Camco'HRP-I-SP' 2.347 7439 6394 PKR Otis'WD' 4.000 7457 6408 NIP Camco 'D' Ni le NO GO 2.250 _ 7464 6413 SOS Camco 2.441 "- 7465 6414 TTL 2.441 Fish -F ISH Pert _ De th Descri lion Comment (734s-73x2) 7397 23' Tool Strin TAGGED FISH 7397' LM on 12/5/97• _ _ _ _ _ 7457 BARSUB 8 JUNK on top of CRX PLUG 57" Bait Sub 8 CRX Plug FISH (JUNK on top of PLUG) in Hole; See WSR's from 4/5/97 to 5/21/97. On oin FISH I i /"~ ~.' PKR (7439-744Q, OD:6.151) SOS (74647465, OD:2.875) Pert (7542-7547) Perf (7567-7582) Page 1 of 2 CJ Maunder, Thomas E (DOA) • From: Maunder, Thomas E (DOA) Sent: Tuesday, April 22, 2008 1:30 PM To: 'Nugent, David A; Schwartz, Guy L Subject: RE: 3C-15 (185-200) P&A David and Guy, Good point. There is a distinct difference in the well paths. Your original plan is appropriate. Thanks much for looking into this. Call or message with any questions. Tom Maunder, PE AOGCC From: Nugent, David A [maiito:David.A.Nugent@conocophillips.com] Sent: Tuesday, April 22, 2008 1:27 PM To: Schwartz, Guy L; Maunder, Thomas E (DOA) Subject; RE: 3C-15 (185-200) P8cA Guy/Tom I don't think we need to leave the high MW in the hole we are going to abandon. I contacted the reservoir engineer on the project and he said the fault block we are currently completed in does not have a high BHP. He is going to get me the latest BHP in the fault block and I'll let you know what it is when I receive it. The fault block we will ST to has the high BHP (I believe it is in the low to mid 13 ppg range). David From: Schwartz, Guy L Sent: Tuesday, April 22, 2008 9:39 AM To: 'Maunder, Thomas E (DOA)' Cc: Nugent, David A Subject: RE: 3C-15 (185-200) P&A Tom, I'm cc'ing Dave on this since he will be the ST drilling engineer. Anyway, we may be able to circulate the SW out and go to higher weight mud (14 ppg is KWF approx) with the rig on location before pulling the tubing and setting the CIBP. Dave what do you think??? Also, the 7 X 9 5/8 has cement where we are milling the window (3000' md) with Arctic pack above. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy, I.schwartz~conocophillips. com 4/22/2008 Page 2 of 2 • • From: Maunder, Thgmas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, Apri122, 2008 9:28 AM To: Schwartz, Guy L Subject: RE: 3C-15 (185-200) P&A Guy, Is there an option to get mud from the rig to leave between the retainer and CIBP" This well is a little differen# than most with the higher reservoir pressure. Good plan to check on the arctic pack. Could make milling messy. Look forward to your reply. Tom Maunder, PE AOGCC From: Schwartz, Guy L [maiito:Guy.L.Schwartz@conocophillips.com] Sent: Friday, April 18, 2008 2:28 PM To: Maunder, Thomas E (DOA) Subject: RE: 3C-15 (185-200) P&A 1 was thinking of just using 9.6ppg brine. We haven't been putting in KWF between the lower retainer and upper CIBP for Sidetrack P & A's that I know of ... We could but this one has high pressure at 4400psi. I will check on the arctic pack but we are not pulling the casing.... will be cutting a window out the 7" casing at 3000' which means we will be going thru the 9 5/8" also. Hope this answers your questions... Give me a call and we can go over any other questions. Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Celi: 240-5696 ATO-1512 guy. 1. schwartz@conocoph iiiips. com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 18, 2008 2:01 PM To: Schwartz, Guy L Subject: 3C-15 (185-200} P&A Guy, I am examining this sundry. What fluid will be left in the 7" casing? 6700' to 3100' is a long way. Was the OA downsqueezed with cement and arctic pack? That would prevent cutting and pulling the 9-5/8" casing. Look forward to your reply. Tom Maunder, PE AOGCC 4i22i2oag ARCO Alaska, Inc. Post Office Bo 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 15, 1988 Transmittal #: 7119 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2I~-I4 2Z-8 2H-5 2H-5 2I)-12 Kuparuk Operations Engineering Water Injection Spinner_Data, Sheet. 2-16-88 Both Sands Kuparuk Operations Engineering Water Injection Spinner Data Sheet 3-2-88 Both Sands Kuparuk Operations Engineering Buildup Analysis Kuparuk Well Pressure Report(Otis) 2-27-88 GRC Amerada Chart(2) 8-26-87 2-25-88 'C' Sand PBU 'A' Sand PBU 'A' Sand Pressure/Temperature 2-16-88/2-19-88 PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M / Cl.' L!ns!:a Oil & C~as Cons. Commission Anchorage Chevron Mobil SAPC Unocal ARCO Alaska.'lnc. is a Subsidiary of AIlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date: March 7, 1988 Transmittal # 7115 RETURN TO: ARCO Alaska, Inc, Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~-3C-12 ~ 3C-5 ----- 3C-9 Bottom-Hole Pressure Survey(Injection Profile) Bottom-Hole Pressure Survey(Injection Profile) Bottom-Hole Pressure Survey Kuparuk Well Pressure Report(Otis) 6-25-86 6-24-86 8-26-87 1-4-88 Receipt Acknowledged: DISTRIBUTION: D&M State,~of.~Alaska ~ Chevron Mobil SAPC Unocal .... : ..... ~ a ~=",fi,'Rich field C orn~any ARCO Alaska, Inc. Post Office L _, 1....360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: OctOber 28, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 J . Transmittal'# 6098 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~' 2X-16 ~3M-lO "3M-11 -- lQ-12 ~-- 3C-1 '---- 3F-5' -'-' 3F-5 ~ 3C-15 ~ 3C-16 - 3C-14 ~-3C-14 Kuparuk Well Pressure Report(Otis) 10-3-87 PBU 'A' Sand Kuparuk Well Pressure Report(Otis) 10-2-87 Static 'A' Sand Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand Kuparuk Operations Engineering Pressure Falloff Analysis3 3-15-87''A' Kuparuk Well Pressure Report(Otis) 8-15/18-87 PBU 'A' Sand Bottom-Hole Pressure Survey 'C' Dual-Zone PBU 10-13-87 50-029-21460 Bottom-Hole Pressure Survey 'A' Dual-Zone PBU 10-13-87 50-029-21460 Kuparuk Well Pressure Report(Otis) 8-28-87 Static 'C' Sand Kupaurk Well Pressure Report(Otis) 8-30-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-19-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-16/19-87 PBU 'A' Sand Alaska 0, a uss Oor, s. Commlssl01t // Anchorage Receipt Acknowledged: · DISTRIBUTION: Date: D&M BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AllanllcRichfleldCompany : ARCO Alaska, Inc Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215' Date: October 7, 1987 Transmittal #: 6078 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-I4 3C-15 Flowing Gradient Bottom-Hole Pressure Survey 50-029-21425 Flowing BHP Bottom-Hole Pressure Survey 9-27-87 9-28-87 50-029-21426 Receipt Acknowledged: DISTRIBUTION: D &H State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldComl~any' ARCO Alaska, Inc. Post Office Bo' ~360 Anchorage, Alasr, a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final --~IR- 14 ~IR- 14 2A-14 -~3A-1 ~3A-2 J-3A- 3 ~ ",,a--3A-15 ~J3A-16 ~--3C-15 '-J----3C-16 ~J3F-1 ~_3F-10 ~J --3J-4 J3J-6 ~3J-9 Prints: CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL .CET/CEL CET/CEL CET/CEL CET/CEL CET/CEL 10-12-85 Run =2 8600 10-13-85 Run #3 8550 10-02-85 Run ~1 6795 10-01-85 Run =1 7550 1G-01-85 Run #1 6680 10-01-85 Run ~1 6080 12-30-85 Run #2 6400 12-30-85 Run ~2 7300 10-!5-85 Run ~1 5887 10-15-85 Run ~1 3995 10-!7-85 Run ~1 7000 12-19-85 Run #1 5166 12-19-85 Run ~1 6950 10-05-85 Run #1 6860 10-19-85 Run ~1 7000 12-18-85 Run ~1 36 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 - 6678 Receipt Acknowledged- ~'~ Alaska Oil & Gas Co~r~. CommJs$Jorl. · o Anchorage Drilling Vault(1 film) ARCO Alaska, Inc. i.~ a Subsidiary of AllanlicRichfleidComu~ny STATE OF ALASKA \/ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG //7!, 1. Status of Well Classification of Service Well / OIL ~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-200 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21426 4. Location of well at surface 9. Unit or Lease Name 1193' FNL, 1241' FEL, Sec.14, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1256' FSL, 1363' FEL, Sec.14, T12N, R9E, UM 3C-15 At Total Depth 11. Field and Pool 873' FSL, 1422' FEL, Sec.14, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25634, ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1 0/01/85 1 0/07/85 1 0/09/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19, Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7840'MD,6695'TVD 7745'MD,G624'TVD YES [~X NO [] 1800 feet MDI 1700' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL/Cal , FDC/CNL, CET, GCT 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 116' 24" 188 sx CS II 9-5/8" 36.0# J-55 Surf 3841' 12-1/4" 950 sx PF "E" & 360 sx Class "G" 7" 26.0# J-55 Surf 7826' 8-1/2" 400 sx Class G & 175 sx PF "C" 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) 7567' - 7582' 2-7/8" 7465' 7196' & 7439' 7542' - 7547' w/4 spf, 90' phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7346' - 7362' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OFMATERIALUSED See attached Add(,ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO 3 1986 Alaska Oil & Gas Cons. Commission ~ch~rage Form 10-407 * NOTE: Tubing was run and the well perforated 11/1/85. GRU1/WC14 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7248' 6247' N/A Base Kuparuk C 7360' 6333' Top Kuparuk A 7529' 6462' Base Kuparuk A 7680' 6575' ! 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ...... (~/~n~ I ,/C~,,/,,, ~-~.,~ Associate Engineer Signed 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~ l~ojc, a~oh~O~ t~e cementing tOol. Item 27: Method. ~fc_=._0peration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, ~:-l!nject~on, Shut-in, Other-explain. Form 10-407 ADDENDUM WELL: 10/15/85 10/17/85 11/26/85 3C-15 Arctic Pak well w/175 sx PF "C". Rn CET log f/7730'-5887'. Rn GCT gyro f/7683'-52'. Frac well w/total of 428 bbls diesel, 250# 100 mesh & 5292# 20/40 sand @ avg rate of 17 BPM, 5800 psi. Lost prime @ tail end of Stage #6. Possibly pmp'd ±2 bbls extra slurry. Released to Production. RECEIVED APR 0 ~ 1985 Alaska 0il & Gas Cons. ~mmisslon Anchorage DrillingJ Superintendent · Date ARCO Alaska, Inc. Post Office Anchorage, Ala= ~9510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr Chatterton' Enclosed are the Well Completion Reports and gyroscopic surveys for the following wells' 3A-10 3A-11 3C-14 3C-15 3C-16 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L150 Enclosures ARCO Alaska, Inc. is a Subsidiary of AllanHcRichfJeldCompeny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-200 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21426 4. Location of well at surface 9. Unit or Lease Name 1193' FNL, 1241' FEL, Sec.14, T12N, RgE, UM LOCATIONS! Kuparuk River Unit At Top Producing Interval VERIFIED I 10. Well Number 1256' FSL, 1363' FEL, Sec.14, T12N, R9E, UN Surf. {..\~,,, ' 3C-15 At Total Depth B.H. t"./- i 11. Field and Pool 873' FSL, 1422' FEL, Sec.14, T12N, R9E, UM 'i Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25634, ALK 2567 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 10/01/85 10/07/85 10/09/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7840'MD,6695'TVD 7745 'MD ,6624 'TVD YES [~X NO [] 1800 feet MDI 1700' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL/Cal, FDC/CNL, CET, GCT 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 116' 24" 188 sx CS II 9-5/8" 36.0# J-55 Surf 3841' 12-1/4TM 950 sx PF "E" & 360 sx Class G 7" 26.0# J-55 Surf 7826' 8-1/2" 400 sx Class G & 175 s:~ PF "C" 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) 7567' - 7582' 2-7/8" 7465' 7196' & 7439' 7542' - 7547' w/4 spf, 90' phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7346' - 7;362' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATERiBBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co/r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ '. None . ,. ,~ Form 10-407 * NOTE: Tubing was run and the well perforated 11/1/85. DAM/WC42 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MA'RI(ERS 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 Kuparuk C 7248' 6247' N/A ~ Base Kuparuk'C 7360' 6333' Top Kuparuk A 7529' 6462' Base Kuparuk A 7680' 6575' I 31. LIST OF ATTACHMENTS Well History, Addendum (dated 12/11/85), Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associ ate Engineer Z-/~-~ 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". Form i 0-407 ARCO Oil and Gas Company "~' Well History - Initial Report - Daily Instruc[ions: Prepare and submit the "Initial Rel~ort" dh- the first Wednesday after a well is spudded or workover operations are started. Daily work prior tO spudding should bd summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 604941 County, parish or borough North Slope Borough ~Lease or Unit ADL 25634 JTitle Drill State Alaska Well no. 3C-15 Nabors 26E API 50-029-21426 Operator ARCO Alaska, Inc. Spudded or W.O. begun Ioate 1Hour Spudded 10/1/85 Complete record for each day reported 1645 hrs. Date and depth as of 8:00 a.m. lO/O2/85 10/03/85 10/04/85 10/05/85 thru 10/07/85 16" @ 116' 2106', (2000'), Drlg Wt. 9.2, PV 16, YP 25, PH 10, WL 12, Sol 6 Accept rig @ 1045 hfs, 10/1/85. NU diverter sys. 10/1/85. Drl straight surf hole to 2106'. IARCO W.I. Prior status I! a W.O. 56.24% Spud Well @ 1645 hfs, 16" @ 116' 3860', (3754'), Wiper trip Wt. 9.1, PV 19, YP 21, PH 9, WL 7.4, Sol 5 Drl & surv 12¼" hole to 3860', prep f/wiper trip. 2364', 2.40°, S59.8E, 2363.6 TVD, 26.1VS, 26.5S, 15.4E 3184', 24.0°, S2.2W, 3149.0 TVD, 234.5 VS, 235.1S, 21.1E 3657', 34.8°, S2.2W, 3562.4 TVD, 462.4 VS, 462.8S, 10.2E 9-5/8" @ 3841' 3860', (0'), Prep to tst BOPE Wt. 9.5, PV 20 Make wiper trip. RU & rn 95 jts, 9-5/8", 36# HF-ERW J-55 csg & lnd @ 3841' w/FC top @ 3757'. Cmt w/950 sx PF "E" w/10#/sx Gilsonite & 360 sx 'C1 "G" w/ 75% CFR-2 & 3% salt. CIP @ 2315 hrs, 10/2/85. RD diverter sys. NU BOPE. 3790', 37.3°, S3.2W, 3669.9 TVD, 540.6 VS, 541.0S, 6.5E 9-5/8" @ 3841' 7558', (3698'), TIH Wt. 10.1+, PV 12, YP 10, PH 9.5, WL 5.8, Sol 14 Tst BOPE. TIH to 3757', tst csg to 2000 psi, DO to 3870'. Conduct formation tst to 12.5 ppg EMW. Drl, Navi-Drl & surv 8½" hole to 7558', condition hole f/logs. RU Schl, RIH w/triple combo, hole not deep enough, POOH & RD Schl. TIH w/bit. 4207', 45.4°, S2.2E~ 3982.7 TVD, 417.0 VS, 816.2S, 4.1E 4553', 41.1°, S0.2W, 4234.7 TVD, 346.0 VS, 1053.1S, 8.2E 5197', 42.5°, S3.2W, 4715.0 TVD, 1481.3 VS, 1481.6S, 10.3W 5961', 42.5°, S1.2W, 5277.0 TVD, 1998.8 VS, 1998.8S, 29.2W 6840', 40.1°, S1.2W, 5935.3 TVD, 2581.1VS, 2580.7S, 51.5W The above is correct Signature For form p.repara, t. ion/a.nd,.dis..tribu, ti_on, Date Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official lest is nol required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ~hease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 604941 Nabors 26E Operator [ A.R.Co. W.I. I ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded lO/O8/85 Date and depth as of 8:00 a.m. 10/09/85 10/10/85 Complete record for each day reported IAccounting cost center code State Alaska IWell no. 3C-15 North Slope Borough ADL 25634 Drill API 50-029-21426 rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% Jabandonment of this well I IHour I Prior status if a W.O. 10/01/85 ! 1645 hrs. I 9-5/8" @ 3841' 7840', (282'), C&C hole Wt. 10.1, PV 10, YP 8, PH 9.0, WL 6.6, Sol 13 Drl & surv to 7840', 10 std short trip, C&C, POOH. RU Schl, rn DIL/GR/SP/SFL/CAL f/7839'-3840' WLM, rn FDC/CNL f/7839'-7100' WLM. TIH, cond hole to rn csg. 7803', 41.5°, S14.2W, 6664.3 TVD, 3205.5 VS, 3202.9S, 135.6W 7" @ 7826' 7745' PBTD, Arctic Pak 10.1 ppg NaC1/NaBr POH, LD DP. RU & rn 183 jts, 7", 26#, HF-ERW J-55 BTC csg. Cmt w/400 sx Cl "G" w/.6% FDP-C344 & .25% HR-7. Displ w/10.1 ppg NaC1/NaBr. CIP @ 2245 hrs, 10/8/85. ND BOPE, instl pack-off, NU tbg spool & lower tree, tst to 3000 psi. Arctic Pak w/175 sx PF "C", followed by 61 bbls Arctic Pak. CIP @ 0600 hfs, 10/9/85. 7" @ 7826' 7745' PBTD, RR RR @ 0700 hrs, 10/9/85. Old TD New TD Released rig Date 0700 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing J PB Depth 10/9/85 JKind of rig Type complelion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 7745' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected .. The above is correct Signature r m~r.~r t i~,.,~.~~- IDate JTitle For fo ~ epa a'~n and {~istribLtion~- see Procedures Manual, Section 10, Drillino. Paoes 86 and 87. Drilling Superintendent ADDENDUM WELL: 11/22/85 3C-15 Att to frac well w/198 bbls diesel & 1000# 100 mesh. Unable to re-establish rate after ISIP of 3240 psi w/o going over allowable press. Well trying to screen out when 100 mesh @ perfs. Drilling S%perintendent Date ~UB.$URFACE DIRECTIONAL ~URVEY [~UIDANCE F~]ONTINUOUS r-flooL Company Well Name Field/Location ARCO ALASKA INCORPORATED 3C-15 (1193' FNL, 1241' FEL, S14, T12N, R9E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71189 Loclt3ed By: PEPPEL Date 27-JAN-1986 Computed By; CUDNEY GCT OZRECT]3N,6L j, IJ S T D~qER LZSTINS 3C-15 .SJR,,/-Y 3&TE: 1S-"'CT-S:J --NGZqE:R: ~=PP=L METHODS 3: TOOL LOCATZ]N: T&NS(NTi&L- INTLRPJL4TIJN: LInEaR V:~TIC~L S ]J T -~ ARCO a,L,a, SKt~, INC. 3"-15,, KUPARJK NORTH SLOPE, ALa,,SKA CD~DJT~TIDN D~TS: =T FOR EVEN 100 F£'ET O= TRU: SdS-SEA E&SURED VERTICAL VERTICAL DEPTH DEmTq D:EPTH O.OO 0.00 -85.00 lO0.O0 100.00 15.00 ZO0.O0 200.00 115.00 300.00 300.00 215.00 ~00.00 ~00.00 315.00 500.00 ~99.99 5OO.OO 599.9'9 51~.'~9 800.00 799.99 71~.99 '~00.00 899.99 81~.99 1000.30 999.99 91~.99 llO0.OD 1099.98 101~.9~ 1200.00 1199.9~ 111~.98 1300.00 1299.~8 121$.98 1~00.00 1399.98 131~.93 1500.00 1~99.~7 141~.97 1500.00 1599.95 151~.96 1700.00 1699.93 1614.93 1800.0~ 1799.91 171~.91 1900.00 1899.28 1B14.B~ 2000.00 1999.~5 191a.~5 2100.00 2099.79 201&.79 2200.00 2199.75 211~.75 2330.00 2299.71 221a.71 2400.00 2399.54 2314.54 2500.00 Z499.~1 2414.41 2500.00 1598.55 1513.55 2700.00 2696.51 2511.51 2BOO.O0 2793.09 270~.09 31oo.oo 30 ,'~*01 ' 3Z00,00 31~"~ ?~ 30?9.7£ 3300.00 32~6o20 3171. ZO 3~00.00 33~$o16 3961.18 3500.00 3433.Z0 33a8.20 3600.00 3517.~3 3432.73 3100.00 3600.36 3515,35 3SO0.OO 36~1.10 3595,10 3900.00 3760.10 3575.10 CO'JRSE D=V!~TION aZIMUTq 353 qlN DES MIN 0 Z$ S 1,~ 51 W 0 !9 S 35 55 W 0 25 S 49 4~ W 0 13 S 5o, 5~+ W 0 19 S O 5 W 0 52 S 5 l~, E 1 10 S ~ ~! ': 1 1~ S 21 27 ~ 1 14 S 2!57 : 1 15 S 29 25 E I 1 1 1 5 13 15 22 23 23 Z~ 27 31 33 35 36 39 ~.0 57 s,.O 52 27 Z~ .57 29 lO V'RTiCAL SECTiOq ;EET 0.00 0.02 -3.04 -0.13 -0.05 0.°2= O.3Z 0.48 0.98 !. 57 2.25 Z. 96 3.57 3.91 4.24 5 .gO 7.01 9.11 11.05 14.87 !7.0-5 19.21 2!.Og 41.01 ~5 15 1~7 75 154.50 232.31 272.68 316.?1 365.4a ~13.83 475.11 SEV:RIT¥ DEG/lOO 0.00 0.35 0.27 0.15 0.21 3.11 0.27 3.99 0.!5 0 · 0.11 0. 0.17 3.50 3.51 J. Z9 0.07 9.59 3.11 3 · 05 3.7~ .!. '2 '-'- 3,72 3. '5 ! 3. '~ 4 ~ . 20 R ,=: ': T ~ ',I N37T--t/ F" F. . O. 2. O. 0 , O. 0 . !. 1. 2. 3. 3. 3. 5. 7. 11. 13. 15. 17. 21. 4i. 6 ! · !19. 15~.. 193. 2 ? .'" · Z73. 316. 355. ~. i 9. :+75 . 53 :.. 5-~a . ',JL ~ R "U "d, C 3,2!7 01 '4 a T': S :'& 5 T /~4: S l' F l-- ~5 T 2.75 ..~ 'P- · 3 4 1.75 !.~0 1.14 !.21 1.,~ ~_.75 3.5~ 21.18 13.31 9.53 3.13 1.65 7.13 14.33 := - T 0.00 0. ,.) ..~ 0 ::': -' 1 .tl 2. ,'33 3. i7 3. ~3 q.,33 '~.15 ~ · ,~2 ~.57 7. gO '). 37 1~ . 53 15'S.5! 193.51 !32. ~7 273.22 515.7~ 355.75 '41 ,~ .05 47'5..25 J ',.{ P ,5 e T d R E A Z 'r ~ i'J T H S ~+9 3:-5 " 5 37 3:3 = S ,_~5 46 ':'_: S 1'~ 1,2 -.. 55 ~.~ ~,q& ,,,'- S 17 3 S 11 Z 7 = S Z 1 57 - ... - 1 .~ 5 ~ S 15 41 - fiRCO ~LfiSKA, INC. 33-15 KUP,~RUK NDRTH SLDmE,4L~SK~ COqPUT&TI]N D~T~: iNTE:~OjL~,TE3 V~LJES FOR '"':VE",I lO0 :-i~=T J= TRU~ Sj3-S~fi E~SURE) V~RTICaL VERTI'aL 2~PTH D~OTq J~TH 4000,00 3835.88 3750,8B 4120,30 3909,27 3B29.27 4200,00 3930,5~ 3895,68 ~300,00 ~050.5~ 3995.56 4500.00 ~195.39 ~119.3~ 4500.00 4270.2~ ~155.29 4700.00 43~5.~3 4990.D~ ~420,35 %335,35 4900.00 5000.00 ~569.07 ~484.07 5100.00 5200.00 ¢716.71 4631.71 5300.00 ~790,33 ~705.33 5400.00 ~853.~8 ~773,88 5500.00 ~937.16 ~51.16 5~00.00 5010.19 ~925.19 5700.00 5800.00 5156.9~ 5071.09 5900.00 5229.32 5144.3£ C'3URS5 V=RTIC~L OOS~EG ]EVI~TI3'~ ~ZI~UTq SECTION S'~V=:RZTY 42 7 S 5 0 W 659.98 I. 21 43 26 S 3 2 W 7:17.~3 3.23 ,45 9 S 3 ~1 ~ 797. 80 1. 55 45 ~0 S 1 12 - ,~69.15 43 17 S 0 42 ~ ~3'~. 35 2, ~5 a2 4 S 0 1 E 1035.98 41 17 S 2 2 W 1073.23 41 19 S 2 15 W 113~,2i ;3,24 41 40 S g 22 W 1.105,~4 41 3[ I5 = 15 W 177/.I0 42 '27 "~ 2 25 N 1405.51 3.15 42 33 S 2 23 W i~,74.06 0.!',,'~ 42 37 $ 2 22 W 1541,72 S,lJ aZ 57 S 2 27 t.l 1677.52 4'3 lO S 2 21 ~ 17~5.8! 0.05 a3 9 S 2 1~ W 1'~1~.27 0.25 43 6 S 2 1~ ~ 13C!2.52 ~2 i2 5 2 33 W 1950.70 J. 35 ~- - ?,01=.~§ ~.73 42 lO S 3 3 ~.~ i0.35,51 0.25 ~ 2 7 IS ] I '3 '.d 22 i 3.7 '~ ]. 2 ' al ~,3 3 ~ 3~ ,q L,236.57 1.13 40 2~ S 3 ~ J ~5~,34 3. ~5 ~9 57 S S 13 W Z51~.79 0,~5 ~9 Z5 S ~ ~1 q 2577.59 1.2~ ~ ~ '9 S 5 19 J v7~O 72 O 3'9 3 S 7 ~ ~4 ;~03 51 ] 9~ 39 29 S 8 30 W !356,27 0,73 40 19 S ~ 21 W 2929,~7 3,63 40 ~g S ~. 25 ~ 2994. ~7 3.35 41 Z5 S ~ 40 W 3059.79 '3.:~ al 33 S g 31 W 519~,'2a 0,0:5 ~ 33 S ~ 31 W 3217,52 3,0.3 6000.00 5302.95 5217.95 6100.09 3377.03 529!.03 6200.03 5451. 14 536o.1~ 6300,09 5525,22 5440,22. 6430.00 5599.52 55!~.52 ,6500.00 567~.4T 5559.47 6500,09 5749,~7 566a,TT 6700.00 58Z5.32 574~.32 68DO.DP 5901.06 58i5.0b 6900.00 597,7,50 5392.5:3 7230.00 5209.50 512~,30 ~300.00 ~ZST.O0 ~00.00 636B.~0 5279.70 ~600.9~ 5515.05 543~,05 7~DO.DD 566~.73 b579.7~ 78~0.00 669a.56 6609.56 559. 727, 797. i5,E. 1005. 1372. 113:~. 1205. 127!, °317, :1 !. 221 ~. . ,_ ~ . 2 3:;I. Z&l7. 2512, 2575. Z 73'3. 2 ~01 · ~.927. 2 ~ '? 1. 3122, ~ ~7 ':7~ G !.J T "i ~:& ST/:4 :' ST ~ S A5,07 ~ 0 S 6.3.55 ~5 S 72,i5 ~ Z S 7 '9 · 79 ~': > .3:+.05 55 3 95.87 '-32 S 99,3 T 72 $ 7:3 S 109.81 30 S 117.56 32 S 126,73 2,3 S 136.1B 5~ S t. 3 S 155,35 3 1 5 155. ~ '~ ~ S 175.67 55 $ 1:i.25 13 3 ? · i 5 ! $ $ 5. 31 i ~7,~. 35 15'~1.75 1 t:,3 ). ~ .? 1577.52 17~5. "Z ! 332 · ,S 3 ! ~ ~ ''~ ,,,. 71 23~5,53 ~15~ 55 ~77, 73 27¢'). ~O 2~05.7' 2333.~4 2');3.1 ~.- 3363, ~5 3125.~7 31 ) Z. ~ D 721 3. 77 =l' ARC,] aLASqA, INC. 3C-15 NORTH SLOPE,AL&SK4 C~PUT~TiON 9~T~: 27-J~N-~5 <{LLY 5'J S'q I 'q 3 5",iDZ"4,_'{SR: P~ ~!:c ZNT:,qPSLATED VALUES FDR EVEN 1'3'33 TRUE iEASURE3 V;RTICAL V~RTZf. AL DEPTH DEPTH DEPTH 0.00 O.O0 -'g3.O0 lOOO.OO 999.9') 914.99 20DO.O0 1999.~5 191~.$5 3000.00 Z~aO.~O Z~OS.aO ~000,00 3835,$~ 3750.~8 5000,00 ~56'~,37 ~4~4.07 6000,00 5302,95 5217,95 ?000,0~ 505~.~6 5969,~5 78~0,00 5694.66 5509.66 CgJRSE V:RTICZ~L 30G: ~EG q 2'TANDiJL,AR 3EVIATI:]N AZI~iDTq SECTI'DN S'V'-. qlT¥ 3EG 'qlN DEG ~I~ :F:T D'-i'-/IOD Fi:T 0 0 N 0 9 E 0.00 3.03 O. 3 26 S 19 51 ~ 2.2,5 0.35 2. 1 ~0 S ~7 41 : 1~.$7 9.59 13. .Z2 ~I S 11 10 W 15~,50 1.~ 155. 42 ~ S 5 0 W ,559.9:~ 2. 21 ~2 12 S g 17 W 133~.15 0.28 !33:'~. 42 Z1 S 2 43 W Z018.36 0.7~ 39 25 S ~ ~1 W Z577.59 i.2~ Z'57~. 41 33 S ~ 31 ~ 3217.52 ~.00 3~13. 'DIST. -~ i I ',1 :,,J T ~ 4~C0 4LASK~, INC. -15 KJP~RSK NSRTH SLOm[,,~L~SK~ 3aT=: 27-J~N-?5 iNT'=?POL4TE3 V~LU~S ~OR EVeN TRU~ SJ~-S'='~ E~SURED VERTICAL VERTICAL 3EPTH DEPTq 9E~¥H 0.00 0.00 -85.00 85.00 BS.00 0.00 lBS.00 135.00 100.00 285.00 28~.00 200.00 385.00 3.35.00 300.00 ~85.31 4~5.00 ~00.09 555.01 555.00 500.00 5~5.01 535.00 500.00 7~5.31 755,00 335.01 ~qS.00 3OD.O0 985.01 985.00 903.00 1085.02 1085.00 1185.02 I1~5.00 llO0.O0 12~5o02 1285.00 1385.0Z 1385.00 1300.00 1585.03 1495.00 1585.0~ 1595,00 1509.00 1585.05 15~5.00 1503.00 1785.09 17~5.00 1700.00 1~85.11 18~5.00 1000.00 COJRS~ V=~TIC&L DOGLEG OEVI&TI]N aZIMUTq S=CTION SEVf~ITY 0 0 ~ 0 O '2 0.00 0 3 N 55 47 W 0.0~ O 8 N 73 21 E -0.03 0 17 N ~3 53 ~ -0.12 0 22 S 71 35 ~ -O.O~ 0 17 S 55 18 E O.1B 0 14 S :33 ~D : 0.31 0 18 S 49 37 ~ 0.43 0 20 S 1'9 3~ ~ 0.89 0 11 S 9 1~ ~ 1.48 19B5.14 1985.00 1990.OJ 2085.20 2085.00 2003.00 2185.25 2185.00 ZlO3.OO 2285.28 2285.00 2200.00 2385.35 Z385.00 230,3.00 g485.5~ 2485.00 2~,30.00 25~6.28 2585.00 250~.00 2688.15 2685.00 2603.00 2791.58 2785.00 2700.09 2996.38 2885.00 Z~O0.O0 300~.55 ZgB~5~BO 2900.0C 3113.0~ 3055~00 3000.00 3222.15 3185.00 3331.77 3Z85.00 3200.90 3~4.12 3385.00 3300.00 3561.02 34B5.00 3~00.00 30B1.21 3085.00 350J.00 3834.87 3685.00 3600.00 3~32.15 3780.00 3700.00 4056.75 3835.00 3903.00 1 35 S 45 ~2 ': 14.5) 1 57 S ~5 50 '~ 15.70 . 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H'''~''H~''+''H~'''~ ..... t'''f''f''~+''~'--'f4'''~'' 7'~'''f''~''f''~'''~'''4-'f''~'''~'''?'''H~ ~ .......... . { ,..;..-~,..;,..:-.~,.-;,..~-.;.-,; ...... ~-,.; .......... ~ ........ ;...; ,,, - ;--.;--,P-.: ...... !--:---t ,-- ~---~ -*-;-..~- ~--;---~- ~ .... ;---~--.+--~---;---~ ....... ~-,~ ...... ~-.-~---i--4-i ...... ~---t---;-- --+-~ - ~--;--i ....... ~---~---~---H--H-~---+--:--' ~ ......... 181. '-t PROJECTION ON VERT. ICAL PLANE 181. - 1. SCALEO IN VERTICAL BEPTHS HORIZ SCALE = 1/1000 IN/FT · o for timely compliance with our regulations. · · , o . Completion Report Report~ and tfateriala to be received · ,. Requ~£ed Well' Iiis tory ' / ' · Hud Log "-Core Chip~ Cbr~'Description Registered Survey Plat Inclination Survey Directional Survey Production Test Report~ Log Run ARCO Alaska, Inc. /- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-13-85 TRANSMITTAL NO: 5441 ~TUi{!~ TO: / ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINE~R/NG RECORDS CLERK ATO-1115B P.O. BOX 100360 · ANCHORAGE, AK 99510 _:QANSM.~ TTED :CnIPT mid .STURN :NAL P~IN~S/ SCHL/ OPEN HOLE/ ~F.-4 ,' 5" '° DIL/SFL \2"~ DIL/SFL ~ ~YBE~OOK ~F-3 %5"3 DZL/S~-G~ ~2" DIL/SFL-GR ~5:{ DEN/NEU PORO ~:/ DEN/NEU PORO DEN/NEU ~W ~YBE ~ OOK ~-15 ~5 "5% DIL/SFL-GR ~ . ~2~~ DIL/S~-GR ' 5"~ DEN/NEU. GR ' ~W ~YBE~OOK ~ :-14 ~ DIL/SFL-GR DIL/SFL-GR " ~ DEN/NEU PORO "~ DEN/NEU PORO ~ "~ DEN/NEU ~W - ~~ DEN/NEU ~W HERA~qITH APE THE FOLLOWING ITF/,iS. PLEASE ACKNO%~LEDGE SIGNED COPY OF THIS TRANSMITTAL. ONE * OF EACH 10-13-85 RUN' 91 3031-6888 10-13-85 RUN %1 3031-6888 10-13-85 RUN 91 6050-6860 10-13-85 RUN ~1 6050-6860 10-13-85 RUN- ~1 6050-6860 10-13-85 RUN ~1 6050-6860 10-13-85 RUN %1 6200-6700 10-08-85 RUN %1 3446-7926 10-08-85 RUN %1 3446-7926 10-08-85 RUN #1 7100-7900 10-08-85 RUN %1 7100-7900 10-08-85 RUN ~! 7100-7900 10-08-85 RUN %1 7100-7900 · 10-08-85 RUN #1 7100-7877 10-08-85 RUN 91 3842-783! 10-08-85 RUN %1 3842-7831 10-08-85 RUN ~1 7060-7806 10-08-85 RUN #1 7060-7806 10-08-85 RUN ~,1 7060-7806 10-0 ~-85 RUN #1 7060-7806 10-08-85 RUN 91 7060-7831 10-15-85 RUN 10-15-85 RUN 10-15-85 RUN 10-15-85 RUN 10-15-85 RUN 10-15-85 RUN 10-15-85 RUN CEIPT ~CKNO%~LEDGED: AE CURRiER EVRON M* BL DIS T.RIBUT ION: Dt{ILLING* BL ~. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OiL · NSK CLERK*BL J. RATHMELL*BL %1 4062-8383 4062-8383 7650-8357 %1 7650-8357 %1 7650-8357 #1 7650-8357 7650-8~/~ DATE: ~ ..... ~ u,~ STATE OF ALASKA~,B~ SOHIO UNION VAULT/ANO* FI LMS Alaska. Inc ARCO Alaska, Inc. Post Office , .,~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE:ll-07-~5 TKANSMITTAL NO:5431 ~TURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECOi<DS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~J~N SMI TTED ]CEIPT AND ~EN H~QLE LIS TAPES 3J--8" 10-16-85 $]--7~/' 10-09-85 3F-5~ 10-20-85 3~4 / ~C-16~ 3~6~ ;~-5~ HERE~WITH ARt] THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE KETURAI ONE SIGNED COPY OF THIS TRANSMITTAL. 10-13-85 09-29-85 10-08-85 10-15-85 10-24-85 10-18-85 10-11-85 PLUS LISTING/ RUN %1 2188 RUN %1 1748.0- RUN %1 1994' 0- RUN ~1 3030.0- I{UN ~1 3692.5- RUN ~1 3816.0- RUN %1 4050.0- RUN ~1 1948.0- RUN %1 3410.0- RUN %1 3952 5- SCHL/ ONE COPY OF EACH .5-7344.0~6;~74~-S-0/~e0 7585 O~d ~ 7 ~-%~ 5-~_e~- / ? ~- g.5-Flf 8647 ~ 0~ 7z/~-J-~/'e/4- 69 00. 6851. 8425. 7269. 7617. CEIPT ACKNO%4LEDGED: DISTP, iBUTiON: AE DRILLING W. PASHER CURRIER' L. JOHNSTON EXXON EVRON ~OBIL PHILLI PS M NSK CL E t<K J..1%ATHMELL · :C * STAT_~.:z O.F. ,ALAS SOHIO ~" ~ C~z C~ OIL 'UNION '-.. :c.-~.-.~.~' VAULT/m~O ARCO Alaska, Inc. is a Subsio~ary ol AllanllcRichiieldCompany ARCO Alaska, Inc. ~ "-~' Post Office / . ,,~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 11-07-~5 TF, ANSMITTAL NO: 5431 UTURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEKING RECORDS CLEI{K ATO-illSB P.O. BOX 100360 ANCHORAGE, AK 99510 ~SMITTED HEREWITH Alee THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE ~CEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. ?EN H~QLE LIS TAPES ~S-8" 10-16-85 3J=7~ 10-09-85 3F-5~ 10-20-85 3F-4 -"" 10-13-85 16w~'~ 09-29-85 15""10-08-85 14'--'"10-15-85 !0-24-55 6 ,~"' 10-18-85 5~''' 10-11-85 PLUS RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN LISTING/ SCHL/ ONE COPY OF EACH ~1 2188.5- 7344.0~6~7~$-S -~/~e~ ' ~/~- 736~9~ 1994 O-8647.~~~'J-~e~-/~-~7 i 3030.0-6900 3692 5- 685'1~ 4050 CEIPT ACKNO%~LEDGED: AE CURRIER- EVRON M DISTKIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL PHILLIPS OIL NSK CLERK J. i%ATH}.".ELL soa:fO"- t .... C ..... ".££.'£.7 UNION .... :...:...~:.~ VAULT/Ai~O ARCO AlasKa. Inc. is a Subsi01ary o! AllanlicRichheldCo"~..:~any ARCO Alaska, Inc. ' Post Office B', ~0360 Anchorage, Alas'ka 99510-0360 Telephone 907 276 1215 November 15, 1955 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 the October monthly reportS for the following wells L2-3 lB I (workover) 3A-7 3C-15 3J-6 9-24 L2-13 - 3A-8 3F-3 3J-7 9-36 L3-5 2A-B 3F 4 3J-$ 16-17 L3-11 2D-12 (workover) 3C-6 - 16-15 3C-13 3F-5 4-21 3A-5 3C-14 3F-6 4-22 18-6 (workover) 3A-6 If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tW GRU12/LSO Enclosures RECEIVED NOV 15 1,985 Alaska Oil & Gas Corls. Gr.,mm!ss on Anchora09 ARCO Alaska, InC. is a Subsidiary o! AtlanticRichlieldc°mpany ,--,. STATE OF ALASKA ALASKA C.._'AND GAS CONSERVATION COI,..41SSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-200 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21426 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 1193' FNL, 1241' FEL, Sec.14, T12N, R9E, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 85' RKB ADL 25634 ALK 2567 10. Well No. 3C-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. October , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1645 hfs, 10/1/85. Drilled 12-1/4" hole to 3860'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7840'TD (10/7/85). Ran logs. Ran, cmtd, & tstd 7" csg. Arctic packed well. PBTD = 7745'. Secured well & RR @ 0700 hfs, 10/9/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set ~ 116'. Cmtd w/188 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3841'. Cmtd w/950 sx PF "E" & 360 sx Class "G". 7", 26.0#/ft, J-55, BTC csg f/7826'. Cmtd w/400 sx Class G & 175 sx PF "C". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL/Cal f/7839' - 3840' FDC/CNL f/7839' - 7100' CET f/7730' - 5887' GCT f/7683' - 52' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. & ~ ,~.~4~L/ Associate Engineer //./4o~' SIGNED _ TITLE DATE NOTE--Report ~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· DRH/MR46 Fnrm 1 n-4.FI4 Submit in duplicate MEMORANOUM TO: THRU: State of Alaska October 11, 1985 C -~/')-"~-_~'~Y'~'. FILE NO: D H~[ 80 Lonnle C. Smith Co~i~ S io~r TELEPHONE NO: FROM: Harold R. Hawkins ,,.~ ..... .j" SUBJECT: Petroleum Inspector ~'/~/( BOPE Test ARCO, KRU, DS 3C-15 Pemit No. 50-200 Kuparuk River Field Thursday, October 3, 1985: While I was on the slope, subject of other ~pOrtS~;~- I wen~° ARCO's KRU, DS 3C-15 to witness a BOPE test. I witnessed the BOPE test and there were no failures. in summar~%: I witnessed the BOPE test that Nabors Drilling Crew 26E performed for ARCO on Well No. 3C-!5. The tests were satisfac- toffy. Attachment ' 02-O01A(Rev. 10/~9) - O&G #4 5/$4 · I_nspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Well Well "' Location: Sec Drilling Contractor~M~~ Ri Wen Representative Permit ~! ~-D-- Representative ACCUMULATOR SYSTEM Trip Tank Pit.Gauge Flow Monitor Gag Detectors General Housekeeping ~/~ Rig Reserve Pit MUd Systems Of[ Visual· · Audio BOPE Stack Annular Preventer ~' Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures Full Charge Pressure ~ 0 psig Pressure After Closure · Pump incr. clos. pres. 200 psig . Full Charge Pressure Attained: Controls: Master ~./~ -- min2D see. A min ~'~ sec. Remote 0/[ Blinds switch cover~,6~/~ Kelly and Floor Safety Valves Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold No. Valves_/~~ No. flanges %~" Adjustable Chokes. ~~ ,drauicall, :ed choke ~,'~ Test Time / hrs. /.9-- Z,w~'~ Test Pressure Test Pressure Test Pressure Test Pressure Repair or Replacement of failed equipment to be made within:,~ days and Inspector/ Commission office notified. / ~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector~ August 28, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3C- 15 ARCO Alaska, Inc. Permit No. 85-200 Sur. Loc. l193'FNL, 1241'FEL, Sec. 14, T12N, R9E, UM. Btmhole Loc. 1029'FSL, 1328'FEL, Sec. 14, T12N, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is Conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their .drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Ke~zn Kuparuk River Unit 3C-15 -2- August 28, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. ~atte~ton Chai~n of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO~-!ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery %e%ephOn ~uDuSt 9, 19B5 C ~' chattertOn . '_. ioner · -~ stat.e u~l & G~s ~" ~up~rUk ~C-t~ SUBj5C%o[ed ~ . . erm~t to Dr~ll ~uP~rUk 3C-15, along Dear Mr. ChiliertOn: ~ith o ~ro~ect~On~ diwerter Diagr~m ~nd desCr~ptS°n o{ the sur~ce hole o em . the BOP equipment5 I{ you h~ve syst 5nd descript~°n of on octO~ Z, 19 · ~ questionS' 9 Sincerely ' OBi/j~B/t~ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage £ncl osureS .... STATE OF ALASKA ~' ALASKA ~J~L AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work. DRILL [2~X REDRILL [] DEEPEN [] lb. Type of well 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGFJ4~H lC SINGLE ZOIXI~ [] ~. Unit or lease name '~ Unit' Kuparuk River 10. ~ell number 4. Location of well at surface 1193' FNL, 1241' FEL, Sec.14, T12N, RgE, UM At top of proposed producing interval 1416' FSL, 1317' FEE, Sec.14, T12N, R9E, UM At total depth 1029' FSL, 1328' FEL, Sec.14, T12N, R9E, UM / 5. Elevation in feet (indicate KB, DF etc.) 6. Lease~signation and serial no. RKB 85', PAD 48' ADL 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number Federal Insurance Company #8088-26-27 3C-15 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi, NW of Deadhorse 16. Proposed depth(MD & TVD) 7637' MD, 6523' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2414 feet. 21 14. Distance to nearest property or lease line miles 1029' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 42 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 3C-16well 60' ~ surface feet 18. Approximate spud date 10/02185 2735 3160 psig@ 80°F Surface psig@ 6202 ft. TD (TVD) Hole 8-1/2" SIZE Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 I~eld J-55 I BTC HF-ERW J-55 [ BTC HF-ERW SETTING DEPTH Length MD 80' 37' I 37' 3784' 37' I 37' I TOP TVD 7601' I 36' I 36' MD BOTTOM TVD 117~ 117' 3821'1 3697' I 7637'1 6523' QUANTITY OF CEMENT (includestagedata) ± 200 cf 880 sx CS Ill & 360 sx CS II 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7637' MD (6523' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2735 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects'. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3C-15 will be 60' away from 3C-16 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer~y'~t hat//the fo/ ~--?.. _~,,,4 ~,,/regOi ngis tr ueand correct to the best of my knowl edge ~,::~__~),__.~,//~~. The so f ssion use ,] /' / Samples required []YES ~NO Permit number zoc)_ APPROVED BY Form 10-401 (JFB) PD/PD14~ CONDITIONS OF APPROVAL Mud log required Directional Survey required I APl number Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE AU~U.~¢_ 28~ !985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3C-15 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. . ....... ........ ....... .... ............................................................. ............ _ . . .............................. - · BASE PERH^FROST - TVD=17'12 .... - . .... __ ...... 2.000 _ .. . ........................ ........ KOP--- 1¥D---241 4 IHD=241 4 DEP=O ............ - 3 .... ~OP'UONU SND$ IYD=25357TI~lD'2535'DEP=.4'L~. ~ '~' EOc (cSO PT) TvD=3697 T"D=382' DEP=495 ' ~ ":- X AVERAGE'-' ANGLE . ...... ................... VERTIO^L .SECT-ION ....... _ ...... ._ - ............... .............. ~ ...... ARCO ALASKA,-INC. ---~ ............. :- ~ .... '-:L-~"://~ PAD 3C,~ ~ELL NOt 15 .-~ PROPOSED L- '- ;-::.'/II ';::'--:'--~:':'. : ::'::;:-:' - ................... KUPARUK-FIELD,--NORTH SLOPE':ALASKA .... / ..................................... ~EST-EAST ..................... ...... 3000 . 2000;~;.'_;T_ 3000' __- ..... 0 _. 3000 . ' '" .-.. ................... ]'__ _.' .... -. ' ' _ .]]_SURFA~ LOCAT[DN~ '~ - ' . ' :' '~'.'. .._ :-_-:_TZ':-..;~':-:~::-: ............ 1193' FNL, 1241' FEE . .. .................................. SEC, i~, T I2N, R~ ........... :-- ~7~. ................................................................................................. -2 ~ ............... : ......................... ...... ...................... TAR~T ~NT~ TAROT L~ATION~ TVD-6202 - 1320' F~L, 1320' FEL ........... T~7203 ..... '-- SEC. 14, Ti2N R~ ~000 .... -- - DEP=27~ ..... . ............................ : ................................ ............. ......... SOUTH 2Z67: --~:- '--" - - - ..... ~ST Z9 .......... TD LOCAT[OH~ ......... 1029' FSL, 1328' FEL ................... ..... ~C. 14, TI2N, RgE ...... . ..... ~ -: .............. 4000 ...... -:": ...... :'- ' : ..... :' ' . ....................... ........... ~ ....... : ........... : ...... : ........ . ........ . - ; !00 _ ;00 _ ~00 _ ;00 _ ·; ....... ~'""t""~ ....... P.i-,-.,' ),,..-! ............. J,.--~ .... 5 il ,, 40 ' 11:300 1200 1100 i! '": m , i I , m ARCOi ~LASKA,' J INC. ~! PAD':'3¢',,-i'"'WELL N'O~,' 13-14-15"-16 PROPOSED KUPARUK FIELD, NORTH" SLOPE' ALASKA .: ....... ;....:.-!EASTt~AN-WHIPS~OCK ...... INC ......... ' .... ..[..;..~..,..,, .;. i. . 5;327 191 NORTH 1000. I NOTE' 5455 1 277 2855 1455 2940 3023 900 800 700 6.00 I I i I 5 WELL.PATHS EXTEND BEYOND THIS VIEWING WINDOW ' · ) . . 625? 1540 02 1623 I TO2 I T?B ' 185O 1919 KUPARUK R~VER UNIT 20" .DI VF__J:~TER SCHEMAT I C DESCRIPTION 7 6 7 I. t6' C~CTOR. 2. TAM,(O STARTER HEAD. ; 3. TAI'*(O SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/I0' OUTLETS. '7. !0' HCR BALL VALVES W/lO' '.-// D:[VERTER LINES.. VALVES OPEN AUT~TICALLY UPON CLOSURE OF' At'C,,I.)L AR PREVENTER. 8. 20" 2CX:X3 PSI Aht,AJLAR PREVENTER. MAINTENANCE & OPERATION 2 I. UP-ON INITIAL INSTALLATIOf~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY, 2. CLOSE Ah~NULAR PREVENTER AhD BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5. CLOSE Aht~LAR PREVENTER IN THE EVENT'THAT AN Ih, FLUX OF WELLBORE · " FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANtJALLY OVERRIDE Aha) CLOSE APPROPRIATE VALVE TO ACHIEVE DO~i, iNWII~:) DIVERSION. DO NOT SHUT IN ~LL Uh, E)ER ANY CIRCUMSTANCES. 7 6 DIAGRAM #1 13-5/8" 5~. PSI RSRRA BOP STACK I. 16' - 2000 PSI TAh, KCO STARTING HEAD 2. I1' - 30CE) PSI CASING 3. I1' - 3000 PSI X 13,-5,/8' - 5000 PSI SPAC~ SP(~ 4. 13-5,/8' - 5000 PSI PIPE RA~ 5. 15-5,/8' - 50:30 PSI CRILLING SPCCL W/Q-O<:E A/~ Kill 6. 13-5,/8' - 5000 PSI ~ RAM W/PIPE ~ CN TCF'. 7. 13---5/8' - 5000 PSI ~ · ACOJVLJL, ATC~ CAPACITY Tg.ST i. C]-EC]< AhD FILL ACCL~TOR RESERVOIR TO PRC~ LEVEL WITH HYDRAL~IC FLUID. 2. A~ THAT AC~TOR PRESSI.12E IS 5009 PSI WITH 3. ~ TINE.. TI-F_.N CLOSE ALL UNITS SI~,~U,_TAh~(:I~Y ALL UNITS ARE CLOSE~ WITH Q.iARGING Pl~ (:FF. 4. RECC~ ON NADC REPCRT, T]~ ACCE~'rABLE LOA~ LIMIT IS 45 SECCI~ CLOSING TINtE AI~ I P_O0 PSI REMAINING L 5 ,]' 13-5/8" BOP STACK TEST Z~ 1. FILL BCP STA(:X AhD C~ MANIFCl. D WI~ ~IC 2. ~ ~T ~ L~ ~ ~ IN ~Y ~RA~. ~T ~T WI~ ~I~ ~ ~ ~ IN L~ LI~ V~VES ~~ TO B~ STA~ _ 4, ~~ ~ TO ~~ F$ ~0 M~N, ~ ~~ TO~~ ~ F~ I0 MIN. B~ ~~ TO 0 ~I. . 5. ~ ~ P~ ~ ~AL KI~ LI~ VALVES. ~ T~ PIPE ~ ~ ~ VALVES ~ KI~ ~ ~E LI~ -~. TEST TO 2~ PS~ ~~ PS~ ?. ~I~ TESTI~ AL~~S, ~ ~ES W~TH A ~ PSI L~ ~ ~ PSI HI~. TEST AS IN 2 ~T A ~L ~I~ P~IT~ ~ ~. ~Y ~. ~ T~ PI~ R~ ~ ~ BO~ PI~ TEST B~ PIPE R~ TO ~ ~I ~ ~ ~I. 9. ~ ~~ PIPE ~, BA~ .[ . I0, ~ ~I~ ~ ~ TEST TO ' '- PSI. Ii. ~ ~I~ R~ A~ ~I~E TEST ~. TEST ST~~ VALVES, ~Y, ~Y PI~ S~Y VALVE, ~ ~ 3~ 13. ~~ TEST ~~T~ ~ ~Y T~~~ ~~LY ~~ ~ ~ILY. A~ask'a Oil & G~s-Cons. Commission ~hurd!je ARCO Alaska. Inc. Post Office r.,,.,.,. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 20, 1985 Mrs. Elaine Johnson State of A1 aska Alaska Oil & Gas Conservation Commi ssi on 300! Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3C Pad Wel 1 s 1-16 Dear Elaine: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate En§ineer JG/tw GRU6/L113 Enclosure If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany N o R T H SEC. II SEC. 14 DRILL SITE 3'0 ,~,,~:,.:,oo. · AS- BUILT CONDUCTOR LOCATIONS WITHIN SECTION 14, TI2N, 'RgE, U.M., ALASKA NOTE: COORDINATES ARE ALASKA STATE PLANE ZONE 4.' SECTION LINE DISTANCES ARE TRUE. HORIZONTAL POSITION PER LHD E ASSOC. MONUMENTS 19-1 B 19-2_. VERTICAL POSITION PER LHD 6 ASSOC. TBM OP16, 8 DOC. 125. 'WELL NO. 6 ii{FORMATION PER DWG. NO. NSK 9.05.$03dl. ¥: 5,995,835. 15 WELL I x: 528,205.68 596"FNL, 1366'FEL Lot. = 70°23'58.955'' Long.= 149°46' 13.622" Y -' 5,995,893.75 WELL 2 x-- 528,195.14 537' FNL, 1378'FEL Lot. : 70°23'59.532" L~ng.: 149046. 15.983' Y = 5,995,952.4;5 WELL :5 x-- 528,,80.60 478'FNL, 1390'FEL Lot. = 70°24'00. I10" Long.= 149°46' 14.343' Y = 5,996,011.07 WELL 4 x= 528,~68.~2 420' FNL, 1402'FEL Lot. = 70°24'00.687' Long.= 149°46' 14.703" Y = 5,996,086.$5 WELL 5 x-- 528,57-o.~6 346'FNL, 1050'FEL Lot. = 70°24'01.414" Long.= 149°46'04.$80 ' Y: 5,996,027.76 WELL 6' x= 57-8,537-.83 404' FNL, 1038'FEL Lot. = 70°24'00.837' Long.= 149°46'04.015 ' ¥: 5,995,969.11 Lot. = WELL 7 x,528,545.24 Long.= 463'FNL, 1025' EEL 70°24'00.260" 149°46'03. 658" T = 5,995,910.44 Lot. : WELL 8 ×= 57-8,557.7~ Long.: 5?_2'FNL , 1013' FEL 70023' 59.683" 149°46' 03. Y= 5,995,372.49 Lot. = WELL 9 ×, 528,672.61 Long.= 1060'FNL , 901'FEL 70o23,54.387, 149°45' 59.993" ¥'- 5,995,314.06 Lot. WELL I0 x=528,685.04 Long.= lllg'FNL , 889'FEL 70° 23' 55.812" 149o45'59.636 · Y = 5,995,255.22 Lat. WELL '11 x= 57-8,6,7.6~ Lang.= 1177'FNL, 876'FEL 70°23'53.233" 149°45'59.274' Y = 5,995, 196.51 Lot. = WELL 12 x= 57-8mo.~9 Lo.g.= 1236'FNL, 864'FEL 70023'52.655" 149°45'58.912" ¥= 5,995,121.33 Lot. = WELL 13 x=5?.8,358. I0 Long.; 1310'FNL, 1217'FEL 70°23'51.929" 149°46'09.235' Y= 5,995,180.01 WELL 14 x: 57-8,3~5.63 IZSI'FNL, 127-9' FEL Lot = 70°23'52.506" Long.= 149°46'09.594" ¥ = 5~995,238.66 WELL 15 ×= 5?-8,333.07 1193'FNL, 1241'FEL Lat. : 70°23'53.084'' Long. = 149°46'09.956' Y: 5,995,297.32 Lot. : 70°23'53.661" WELL 16 x= 5?.8,3?-0.55 Long.:149°46'lO.316" ii34' FNL, 1253'FEL C ERTl F'IC ATE lass§§, _ .............. llcHECKE~ J. HERMAN 3340 Arctic Boulevard. Suite 201, Anchorage, Alaska 99503- IIJ°B . ~. 85029 OF S U R VE'"i"OR -' I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVE¥,NG ,N THE STA'r~-- OF ALAS,<A THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS A~= OTHER SURVEYE9 FOR: ARCO Alcskc, Inc. ~ .... - - ~ .,~d~b CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (8) (3) Zdmin ~/< f-~J-~/ 9. 12> 1o. (10 and 12) 12. (4) Ca sg z~.~.~, (13 thru 21) (22 thru 26) (6) Ad d: ~/,, .~,,.~, F.-/~'-f?O''' Company Lease& Well No. YES NO REMARKS 1. Is the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. Does operator have a bond in force .................................. ,~K Is a conservation order needed ...................................... ~0~ Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... __ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface'. .. Will cement tie in surface and intermediate or production st Will cement cover all known productive horizons ........... ' .......'' . . Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 .......... Is adequate wellbore separation proposed .......................... Is a diverter system required ................ ~ Are necessary diagrams of diverter an~'~P";q~i;~;~; ;tta~;d iii.iii Does BOPE have sufficient pressure rating- Test to ,~C)C~z9 psig'. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. 27. Additional requirements ............................................. Additional Remarks: o ~z H o Geology: JAL ---- Engineerin~ :' LCS ............ MTM ~- HJH ~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE .. , ,. , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS T VERIFICATION LISTING SERVICE NAME :EDIT DATE :$5/10/10 ~RiG!N : REEL NAME :142628 CONTINUATION ~ :OI PREVIOUS REEL : COMMENTS :LIBR,~RY TAPE g~:: TAPE HEADER ~g SERVICE NAME :EDIT DATE :85/10/10 DRIGZN :0000 TAPE NAME :0864 CONTINUATION ~ :01 9REVIOUS TAPE : COMMENTS :LIBRARY 'TAPE -,--,- FILE H=AOER~ ~,:' '~,- FILE NAME :EDIT .001 SERVICE NAME : VERSION ~ : OATE : MAXIMUM LENGTH : 1024 FILE TYPE : PREVIOUS FILE : ....-,--,-" TN:ORMATION_ , RECORDS ~¢ MNEM CONTENTS CN : AR WN : 3C FN : KU RANG: 9E TOWN: 12 SECT: 14 COUN: N. STAT: AL CTRY: US MNEM CO CO ALASKA INC -13 PARUK N SLOPE ASKA NTENTS ~RES: E -,--,- COMM:NTS UNIT UNIT TYPE 000 000 000 000 000 000 000 000 000 TYPE 000 CA'T E 000 000 000 000 000 000 000 000 000 CA TE O00 SIZE Ilim 018 006 014 O02 004 002 012 006 0O3 SIZE 001 CODE 065 065 065 065 0,55 065 065 065 055 CODE 065 [ vD r~l. 0oH02 VER'~'FICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING 'CENTER COMPANY : ARCO ALASKA INC WELL = 3C-15 F'iELD = KU~ARUK COUNTY, = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 7086~ RUN ~1, DATE 'LOGGED: B-DC'T-85 LOP: M. OGDEN CASING TYPE FLUID DENSITY VISCOSITY DH FLUID LOSS MATRIX SANOSTONE : 9.625" @ 3840.0' - BIT SIZE '= 8.5" 'TO 7840.0' = L.SND : 10.0 LB/G RM = 3.180 @ 72,0 DF = 38.0 S RMF : 3.120 @ 72.0 DF : 9.5 RMC : 2.360 @ 72.0, DF : 5.5 C3 RM AT BHT : 1.664 2 144. OF THIS DATA HAS NgT BEEN DEPTH SHIFTED- OVERLAYS FIELD PRINTS $$~*:~ , ,,~ n,n ~a~ v~oi~ICATION LISTIN& PAGE 3 SCHLUMBERGER LOGS IN:CLUOED WITH THIS M4GN=TIC. TAPE: '4"' ~',= DUAL INDUCTION SPHERICALLY FO:CUSED LOG (DiL) -,.-" DATA AVAILABLE: 7831.0" TO 3842.0' ~ FORM.~TION DENSITY COMPENSATED LOG (PON) .~,; COMPENSAT~:D NEUTRON LOG (FDN) ~:~ O4TA 4V~ILAB'LE: 7806'0' TO T060.O' :',~"'-,- D,~TA FORMAT R:CDRO,. .... -,--,- ENTRY BLOCKS TYPE SiZE REPR CODE ENTRY 2 1 65 0 4 1 66 ! $ 4 73 60 '~ ,~ 6 5 . 1 1 N 16 1 66 1 0 i 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API API API API FILE SIZE SPL REPR PROCESS iD ORDER ~ LOG TYPE CLASS MOD NO. CODE (OCTAL) DEPT FT O0 000 O0 0 0 4 1 68 O0000000OO0000 q~:l II RTl Tin DZL ILM SP 'GR CALi FDN RH08 FDN DRHO FON NR .41' FON RNRA ,=DN NPHI FON NCNL FON FCNL FrjN DEPT SP NPHI DEPT RHOB NPHI SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP NPHI O6PT S~ ~HOB NPHI O~OT ~ , ~HO~ NPHI OHMM O0 220 O1 0 OHMM O0 120 46 0 OHMM O0 120 44 0 MV O0 010 O1 0 GAPI O0 310 O1 0 GAPi O0 310 O1 0 IN O0 280 O1 0 G/C3 O0 350 02 0 G/C3 O0 356 Oi 0 O0 ~20 Ol 0 O0 000 O0 0 PU O0 890 O0 0 CPS O0 330 31 O CPS O0 330 30 0 7864.0000 -24.1514 2.4436 34.6191 7800,0000 -28,995.1 2,5051 35.5957 7700.0000 -38,2070 2,3909 45.4590 7600.0000 -37.2383 2.4104 33,2520 7500.00O0 -37.6133 2.4749 32.1777 7400.0000 -37.i758 2.422i 30,9082 7300,0000 -44.8633 2.4631 23,7793 7200,0000 SFLU GR DRHO N.CNL SFLU DRHO NCNL SFLU GR ORHO NCNL SFLU GR DRHO NCNL SFLU GR DRHO NCNL SFLU GR DRHO NCNL SFLU ~RH~ NCNL SFL~J 3.7834 103.1523 0.1875 2197.5000 3.2776 104..4648 0.1015 2231.5000 2.7014 103.9023 0,0928 2057,5000 5.2468 109.3398 0.0317 2423.5000 4,2820 36.6523 0.0574 2589.5000 8.9785 79.0273 0.0166 2683.5000 6.6414 74.0898 0.0127 3213,5000 4.0554 ILD GR NRAT FCNL ILD GR NRAT FCNL ILD GR NRAT FCNL iLD GR NR~T FCNL ILD GR NR4T FCNL ILO GR NRAT FCNL ILO GR NR~T ~CNL ILD . 103. 3. 664. . 104, 3, 550. . 103. 3. 538. 4. 109. 3. 748. 4. ~6. 2. 858. 7. 79. 2. 878, 4, 74, 2, 1242, 3, 762.5 1523 0334 8125 7776 4648 1077 3125 3594 9023 6858 8125 2273 3398 0120 3125 4512 6523 9768 8125 22'73 0273 8928 3125 8445 0898 4827 6875 5526 1 68 00000000000000 I 68 00000000000000 1 68 00000000000000 1 68 00000000000000 i 68 00000000000000 1 68 00000000000000 I 68 00000000000000 1 68 O00000OO000000 I 68 00000000000000 1 68 00000000000000 ! 68 00000000000000 i 68 00000000000000 I 68 00000000000000 1 58 00000000000000 ILM 3.6448 CALI 8.5020 RNRA 3.2073 ILM 2,8381 CALi 8.7676 RNR4 3.3772 ILM 2.4573 CALI 9.2598 RNR4 3,~352 ILM 4.3601 CALl 9,1582 RNR4 3,2366 ILM 4.3953 CALi 9.6113 RNR~ 3.1311 ILM 7.6609 C&LI 9.611~ RNR~ 3.0530 ILM 5,2351 C~LZ 10.4316 RNR4 2.5962 iLM 3,8049 I V~ OlO.'H02 VERIFICATION LISTING PAGE 5 NP~! OEPT SP RHOB NPHi DEPT SP RHOB NPHI DEPT SP RHO6 NPHI OEPT RHOB NPHI RHO'B NPHI OEPT SP RHO5 NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHi OEOT SP RHOB NPHI DEOT SP RHO5 NPHI -50,9258 GR 2,5413 ORHO 28,027.3 NCNL 7100,0000 SFLU -45,,~255 GR 2,3010 DRHO 50'3415 NCNL, 7000.0000 SFLU -44.80,08 GR -999,2500 ORHO -999.2500 NCNL 6900,0000 SFLU -46,93'70 GR -999,2500 DRHO -999,2500 NCNL 6800,0000 SFLU -~6,,4883 GR -999,2500 DRHO -999,2500 NCNL 6700,0000 SFLU · -57,6445 GR -'999,2500 ORHO -999,2500 NCNL 6600,0000 SFLU -59,1758 GR -999,2500 DRHO -999,2300 NCNL 6500,0000 SFLU -51,64.45 GR -999,2500 DRHO -999,2500 NCNL 6400,0000 SFLU -59,7383 GR -999,2500 DRHO -999,2500 NCNL 6300.0000 SFLU -34,9853 GR -999.2500 DRHO -999,2500 NCNL 6200.0000 SFLU -49.2070 GR -999.2300 DRHO -999.2500 NCNL 128,3125 GR 0,0400 NRAT 2641,5000 FCNL 1,6885 ILD 121,7773 GR 0,0107 NRAT 1845,6875 FCNL 2,3655 ILD 125,9023 GR -999,2500 NRAT -999.2500 FCNL .2,5979 ILD 147,5625 GR -999,2500 NRAT -999,2500 FCNL 2,3987 ILD 249,6875 GR -999,2500 NRAT -999,2500 FCNL 2.9280 ILD 126,4023 GR -999,2500 NR4T -999,2500 FCNL 3.4612 ILO 113.5273 GR -999.2500 NRAT --999.2500 FCNL 3.9373 !LD 128.7148 GR -999.2500 NRAT -999.2300 FCNL 5,1726 ILO 121,4023 GR -999,2500 NR&T -999,2500 FCNL 2,3831 ILD 113,5273 GR -999,2500 NRAT -999,2500 FCNL 1,3672 ILO 96,0898 GR -999,2500 NRAT -999,2500 PCNL 128,3125 2,8069 911,8125 1,6241 1,21,7773 4., 04'76 450,3906 2.14,28 125.9023 -999.2500 -999.2500 2,5178 147,5525 -999,25,00 -999,2500 2.1252 249.6875 -999.2500 -999.2500 2.8713 126.4023 -999.2500 -999.2500 3.3792 113.5273 -999.2300 -999.2500 3,5315 126,7145 -999,2500 -999,2300 4.3445 121.4023 -999.2500 -999.2500 2,4612 113,5273 -999,2500 -999,2500 2,1174 96,0898 -999,2500 -999,2500 CALI RNRA ILM CALI RNRA iLM C~LI RNR& ILM CALI RNRA ILM CALl RNR4 ILM CALl RNR~ ILM CALI RNRA ILM CALl RNRA ILM CALI RNRA ILM CALi RNR& CALl RNRA !1.3223 2.8948 1.6915 10.4004 4.0164 2,2053 10.5410 -999.2500 2.4749 10.8066 -999.2500 2.1565 10.0410 -999.2500 2.9104 11.9629 -999.2500 3.4514 11,6738 -'999.2300 3.8780 10.6504 -999.2500 4.0671 10.6113 -999.2500 2.5081 10.3145 -999,2300 2.0862 '9.9238 -999.2500 ,~v= n~,.~n~ V~R'iFICATI~N LISTING PAG~ 6 n~PT NPHI OEPT SP RHO6 NPHI OEPT SP RHOB NPHI 9EPT SP RHOB NPHI · DE PT SP RHOB NPHI DEPT SP RHO8 NPHI OEPT SP ~HOB NPHI C'EPT SP RHOB NPHI DEPT SP RHOB NPHI DEmT SP RHOB NPHi SP NPHI 5100.0000 SFLU -49.1758 GR -999.2300 DRHO -999..2500 NCNL 6000..0000 SFLU -52.9570 GR -999.2500 DRHO -999.2500 NCNL 5900.0000 SFLU -52.8945 GR -999.2500 DRHG -999.2500 NCNL 5800.0000 SFLU -60.1445 GR -999.2500 DRHO ,-999.2500 NCNL 5700.0000 SFLU -60.,4258 GR -999.2500 DRHO -999.2500 NCNL 5600.0000 SFLU -59.9883 GR -999.2500 DRHO -999.2500 NCNL 5500.0000 SFLU -17.2451 GR -999.2500 DRHO -999.2500 NCNL 5400.0000 SFLU -16.9951 GR -999.2500 ORHO -999.2500 NCNL 5300.0000 SFLU -22.2139 GR -999.2500 DRHO -999.2500 NCNL 5200.0000 SFLU -21.2295 GR -999.2500 DRWO -999.2500 NCNL 5100.0000 SFLU -25.401~ GR -999.2500 ORHO -999.2500 NCNL 3.2190 ILO 95.2773 GR .-999.2500 NRAT -999.2500 FCNL 2.2620 ILO 88.2773 GR .-999.2500 NR,AT -999,.2500 FCNL 2.4065 ILD 94.7148 GR -999.2500 NRAT -999.2500 F,CNL 2.0491 ILO .123.7148 GR -999.2500 NRAT -999.2500 FCNL 2.5178 ILO 115.2773 GR -999.2500 NRAT -999.2500 FCNL 2.6077 ILD 116.7148 GR -999.2500 NR.~T -9'99.2500 FCNL 3.2952 ILD 108.7773 GR -999.2500 NRAT -999.2500 FCNL 2.7776 ILO 115.8398 GR -999.2500 NR~T -999.2500 FCNL 2.5725 ILO 125.0273 GR -999.2500 NRAT -999.2500 FCNL 2.3850 ILO 91.5898 GR -999.2500 NRAT -999.2500 FCNL 2.4905 ILO 102.4648 GR -999.2500 NRAT -999.2500 FCNL 2.6350 95..2773 -999.2500 -999.2500 2.2170 88.2773 -999.2500 ,-999.2500 2.4124 94.'7148 -999.2500 -999.2500 2.0042 123.7148 -999.2500 -999.2500 2.8772 115.2773 -999. 2500 -999.2.500 3.2502 116.7148 -999.2500 -999.2500 3.5061 108.7773 -999.2500 -999.2500 4.5242 115.8398 -999.2500 -999.2500 4.4500 125.0273 -999.2500 -999.2500 3.5803 91.5898 -9'99.2500 -999.2500 3.7971 102.4648 -999.2500 -9'99.2500 ILM CALI RNRA IL'M CALi RNRA ILM CALl ,RNRA ILM CALI RNRA ILM CALI RNRA ILM CALI RNRA ILM CALl R NRA ILM CALl RNRA ILM CALI RNR~ ILM CALl RNR4 ILM CALi RNRA 2.7,581 9. '7' 285 -999.2500 2.2620 9,.6.113 -999.2500 2.4749 '9.54 88 -999.2500 2.0413 9.80,66 -999.2500 2.937'7 10.1426 -999.2500 3.2151 9.5332 -999.2500 3.4924 9.6348 -999.2500 3.2542 9.6113 -99'9.2500 3.2366 10.2520 -999.2500 2.7424 !0.3223 -999.2500 2.8595 9.8379 -9'99.2500 I VP 010.H02 VERI~iCATION LISTING PAGE 7 S~ RHOB NPHI OEPT SP OEPT SP RHOB NPHI DEPT SP RHOB NPHI OEPT SP RHOB NPHI ucPT SP RHOB NPHI DEPT SP RHO~ NPHi DEPT SP RH05 NPHI OEPT SP RHO8 NPHI SP RHO8 NPHI ~ , SP RHOB 5000.0000 -2'7.2139 -999.2500 -999.2500 49OO.0OO0 -30.4951 -999,2500 -'99'9,2500 4800.0000 -27.1514 -999.2500 -999.,2500 ,4'700.0000 -24.7139 -999.2500 -999.2500 4800.0000 -25.7451 -999.2500 -999.2500 ~500.0000 -28.995.1 -999.2500 -999.2500 4400.0000 -33.4570 -999.2500 -999.2500 4300.0000 -32.0820 -999.2500 -999.2500 4200.0000 -36.1445 -999.2500 -9'99.2500 4100.0000 -34.4883 -999.2500 -999.2500 4000.0000 -35.4258 -999.2500 SFLU GR DRHg NCNL SFLU GR DRHO NCNL SFLU GR NCNL SFLU GR DRHO NCNL SFLU G~ DRHO NCN~ SFLU GR DRHO NCNL SFLU DRHO NCNL SFLU GR DRHO NCNL SFLU DRHO NCN~ SFLU GR DRHg NCNL SFLU GR 2,2092 ILD 105.2148 GR -999.25'00 NRAT -999.2500 FCNL 2..4905 ILO Ii1.4023 GR -999.2500 NRA'T -999.2500 FCNL 2.6311 ILD 107.2773 GR -999.2500 NRA'T -999.21500 FCNL 2.8401 ILO 95.5895 GR .-999.2500 NRAT -999.2500 FCNL .Z,5042 ILD 103.4023 GR -999.2500 NRAT -9'99.2500 FCNL 3.5471 ILO 97.5273 GR -999.2500 NRAT -999.2500 FCNL 2.$206 ILO 98.7148 GR -999.2500 NRAT -999.2500 FCNL 2.5022 ILD 108.0898 GR -999.2500 NRAT -999.2500 FCNL 3.2932 ILD 106.0898 GR -999.2500 NRAT -999,2500 FCNL 2.6936 ILD 99.0898 GR -999.2500 NRAT -999.2500 FCNL 2.8733 ILg 97.9648 gR -999.2500 NRAT 4.0867 105.2148 -999.2500 -999.2500 3.7053 111.4023 -999.2500 ,-9~9.2500 4.2117 107.2773 -999.2500 -999.2500 4.7000 95.5898 -999.2500 -999.2500 4.9578 I03.4023 -999..2500 -999.2500 5.8679 97.5273 -999.2500 -999.2500 4.676,5 98.7148 -999.2500 -99'9.2500 3.6897 108.0898 -999.2500 -999.2500 3.6760 106.0898 -999.25Q0 -999.2500 4.3054 99.0898 -999.2500 -999.2500 4.7273 97.9648 -999.2500 ILM CALl RNR4 ILM CALl RNRA ILM CALl RNRA ILM CALl RNR4 ILM CALl RNRA ILM CALI RNRA ILM CALZ RNRA ILM CALl RNRA CALI RNRA ZLM CALI RNRA ILM CALl RNRA 3.0159 10.1504 -999.2500 2.834,2 9.9160 -999.2500 2.9690 9.8770 -999.2500 3.3440 9.9707 -999.2500 3.4807 9.9004 -999.2500 3.9221 10.470'7 -999.2500 3.2737 10.1348 -999.2500 2.7542 10.5645 -999.2500 2.5784 10.4082 -9'99.2500 3.0999 8.38a8 -999.25oo 3.3420 9.4755 -999.2500 ,vm nln,,Mn2 VFRZFZC. ATiDN LISTING PAGE 8 NPHi -999.2500 NCNL DEPT 3900.0000 S~LU SP -39.7383 GR RHDB -999.2500 DRHO NPHI -999.2500 NCNL DEmT 3818.0000 SFLU SP -0.7344 GR RHO8 -'999.2500 ORHO NPHI -999.2500 NCNL -999.2'500 FCNL 3.2698 ILO 86.1523 GR -999.2500 NR4T -999.2500 FCNL 2000.687:5 ILD 58.6055 GR -999.2500 NR~T -9'99.2500 FCNL -,..- FILE TRAILER .......,--,. FiLE NAME :EDIT .001 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FILE NAME : .... ,- TAPE TRAILER :k::: SERVICE NAME :EDIT DATE :85/10/10 OR'IGIN :0000 TAPE NAME :0864 CONTINUATION ~ :O1 NEXT TAPE NAME : COMMENTS :LIBRARY 'TAPE ~:~:: REEL TRAILER ~'~ SERVICE NAME :EDIT ~ATE :85/t0/10 ORIGIN : REEL N,6ME :142628 CONTINUATION # :01 NEXT REEL N.~ME : CgMMENTS :LIBRARY TAPE -999.2500 6..3757 86.1523 -999.2500 -999.2:500 10.6582 58.6055 ,-999.2500 -9'99.2500 ILM C,ALI RNRA iLM CALI RNRA 4. 1335 11..330! -999.2500 2000.6875 8.7520 .-999.2500