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Home My WebLink About186-091Image 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. / ~ _~- ~ q / Well History File Identifier Organization (done) ~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: Grayscale items: [] Poor Quality Originals: Other: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ~/~'~ ORGANIZED BY: ~REN -- Project Proofing NOTES: VINCENT SHERYL MARIA LOWELL [] Other By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /s/ PAGES: ~' (at the time of scanning) SCANNED BY: ~REN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: 3N-16 Run Dater 6/19/2010 July 3, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21593-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barr ab ~.com ~' .~ ~, Date: ~~ '~ ~"~ ~~~ -v~ q ~ ~v Signed: • ~~' • ELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jet Cut Record: 3N-16 Run Date: 6/18/2010 July 3, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21593-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 ~~~,o~ r 1 ~ gao Fax: 907-27 -3 5 rafael.barre ~i `^ Date: g ~" ?5 g~ q ~~~ . :=~~ Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3N-16 Run Date: 6/17/2010 July 3, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-16 Digital Data in LAS format, Digital Log Image file 50-029-21593-00 ~,~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-27 - rafael.barreto ~ lu h coin' i Date: _ , ~' : ~ ~°` =~~: '~ ~3~Q„aid ,. r a~~<;;,r,, .~ Signed: ~ ~ ~~ ! ~~~ • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned ^ Suspended a 20AAC 25.105 20AAC 25.110 ,/per GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: f~ ~" 1b. Well Class: Development Q Exploratory ^ f~~Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. D p., Susp., ~-~ j~l" j " rAband.: M 12. Permit to Drill Number. 186-091 / 310-118 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 pudded: May 12, 1986 13. API Number: 50-029-21593-00 4a. Location of Well (Governmental Section): Surface: 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM 7. Date TD Reached: May 17, 1986 14. Well Name and Number: 3N-16 Top of Productive Horizon: 1282' FNL, 823' FEL, Sec. 33, T13N, R9E, UM 8. KB (ft above MSL): 68' RKB GL (ft above MSL): ' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1417' FNL, 544' FEL, Sec. 33, T13N, R9E, UM 9. Plug Back Depth (MD + ND): 8255' MD / 6076' ND Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 518371 y- 6013799 Zone- 4 10. Total Depth (MD + ND): 9235' MD / 6851' TVD 16. Property Designation: ADL 25520 TPI: x- 522872 y- 6010969 Zone- 4 Total Depth: x- 523152 - 6010835 Zone- 4 11. SSSV Depth (MD + ND): 1772' MD / 1720' TVD 17. Land Use Permit: 2556 18. Directional Survey: Yes ^ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost MDlTVD: 1700' MD / 1700' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. Re-drill/Lateral Top Window MD/TVD not applicable 23. 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. 115' Surf. 115' 24" 24s sx CS II 9.625" 36# J-55 Surf. 4797' Surf. 3638' 12.25" 1350 sx AS III, 35o sx Class G 7" 26.0# J-55 Surf. 9189' Surf. 6815' 8.5" 300 sx Class G, 175 sx AS 1 24. Open to production or injection? Yes ^ No a If Yes, list each 25. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.875" 8255' 8636' MD / 6375' TVD 8825'MD / 6525' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement plug @ 8656' 30 bbls Class G 27. PRODUCTION TEST Date First Production not applicable Method of Operation (Flowing, gas lift, etc.) plugged 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) 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No 0 Sidewall Cores Acquired? Yes ^ No 0 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 25.071. i~~CElVED ~~~:a~: ~,; ~s'J~~ NONE ~~~,~~.~~:;.~ ~ _ .. ~ JU~~ 2 9 210 Alaska Oil Ef Gas Gees. Corrumssion Form 10-407 Revised 12/200~~UM~ SUN ~ '~ ~ CONTINUED ON REVERSE ~"~/ 4i_rl~honly~ r~ 28. GEOLOGIC MARKERS (List all formations and markers untered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ 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 8724' 6444' Base Kuparuk C g7gg' 6495' Top Kuparuk A 8884' 6571' Base Kuparuk A 9012' 6673' N/A Formation at total depth: 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 ~~ Printed Nam . Alvord Title: Alaska Drillino Manaoer TT n Signature 't ~ (n 4 i' ) Phone 265-6120 Date ~ ~a! y ~ vof INSTRUCTIONS Sharon Allsup-Drake 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 12/2009 . ~ 3N-16 Pre Rig Summary DATE SUMMARY 3/21/10 TAGGED TD @ 8953' SLM (EST. F RAT HOLE /OBTAINED SAMPLE). S~2.25 CA-2 PLUG W/ DUAL PANEX GAUGES (173.5" OAL) @ 8841' RKB. (( NOTE: NEED SHORTAXELSON FUSIBLE CAP )). 4/1/10 (PR) IC-POT -PASSED. IC-PPPOT -PASSED. FUNCTION TEST LDS's. 4/2/10 MEASURED BHP @ 8800' RKB: 2034 PSI. SET 2.29" CATCHER @ 8832' SLM. BRUSHED & FLUSHED TBG TO 8810' SLM. IN PROGRESS. 4/3/10 PULLED CVs @ 8811', 8739' RKB. REPLACED WITH DVs. IN PROGRESS. 4/4/10 PULLED CV @ 8671' RKB, REPLACED WITH DV. ATTEMPTED PULL GLV @ 7857' RKB. IN PROGRESS. 4/5/10 PULLED GLVs @ 7857', 7048', 5020', 2502' RKB. SET DVs @ 2502', 5020' RKB. IN PROGRESS. 4/6/10 SET 1" DV'S @ 7048', 7857' RKB, PULL 1.5" OV @8579' RKB, LOAD 1/A W/ 300 BBLS DIESAL, PERFORM GOOD CMIT TO 2500 PSI. JOB IN PROGRESS 4/7/10 BAIL SAND FROM 8826' SLM TO 8832' SLM TO GET TO CATCHER SUB. JOB IN PROGRESS 4/8/10 PULL CATCHER SUB @ 8832' SLM, BAIL TO 2.25" CA-2 PLUG, LATCH PRONG IN 2.25" CA-2 PLUG @ 8836' SLM, UNABLE TO PULL OR SHEAR OFF AFTER COUPLE HOURS OF JARRING, HAD TO DROP CUTTER BAR, POOH W/ALL WIRE. JOB IN PROGRESS. 4/9/10 PULL CUTTER W/ STEM @ 8800' SLM, RUN 2" LIB, GOOD IMP OF CLEAN ROPE SOCKET. JOB IN PROGRESS 4/10/10 ATTEMPT TO FISH TOOLSTRING @ 8788' SLM W/ 2" RB & RS, LATCH A 2" 52 GO W/ 2.5" G BAIT SUB TO F/N ON TOOLSTRING. JOB IN PROGRESS 4/11/10 FISH 1.5" TOOLSTRING W/ CA-2 PRONG, ATTEMPT TO PULL 2.25" CA2 PLUG. JOB IN PROGRESS 4/13/10 PULLED CA-2 w/ DUAL PANEX GAUGES @ 8841' RKB. A-ONLY BHP @ 8841' = 2049 PSI. COMPLETE. 4/25/10 PULLED C SAND DVs @ 8811', 8739', 8671' RKB. READY FOR E/L SET RETAINER. 4/29/10 SET WEATHERFORD 2 7/8" CEMENT RETAINER AT A DEPTH OF 8656'. CCL STOP DEPTH AT 8642.2'. CCL TO MID ELEMENT OFF SET AT 13.83'. 5/3/10 PERFORMED WEEKLY BOPE-TEST. PERFORMED CT CEMENT SQUEEZE PUMPING TOTAL OF 30- BBL CL'G' CEMENT: 22-BBL THROUGH CEMENT RETAINER AT 8656'; 6-BBL CEMENT INTO IA THROUGH OPEN POCKET AT 8579'; AND 2-BBL CMT IN TUBING ON TOP OF RETAINER. DURING SQUEEZE AT RETAINER, STARTED BUILDING PRESSURE AT 12-BBL AWAY AND REACHED 1500-PSI SQ.PRESS. AT 15-BBL AWAY: ESTIMATE 6-BBL OUT PERFS. ESTIMATE TOP OF CEMENT AT 8400' IN TUBING. FREEZE-PROTECTED TUBING TO 3500' MD. ***Note: AOGCC rep. Jeff Jones waived State Witness of the cement plug over the telephoone at 13:30-hrs on 30Apr10.*** 5/6/10 TAG CEMENT PLUG @ 8353' SLM. LRS TO PERFORM MITT TO 2500#. IN PROGRESS. 5/7/10 PERFORMED MITT. RESULTS CHARTED. PASSED. LOCATED GLM #7 @ 8214' SLM WITH 2.5" OK-1 ZEROED @ FINGER. ATTEMPT TO CUT TBG @ 8255' RKB. SLB E-FIRE TOOL DID NOT DETONATE. TOOL APPEARED TO BE FLOODED. IN PROGRESS. 5/8/10 ATTEMPT TO CUT TBG @ 8254' RKB. DATA FROM E-FIRE TOOL INDICATES ARMING & FIRE SEQUENCE NEVER INITIATED. IN PROGRESS. 5/9/10 RAN SLB 2.125" JET CUTTER ON E-FIRE TOOL & CUT TBG @ 8255' RKB. DHD CREW TO VERIFY COMMUNICATION IN THE AM. ~rG- ri 1 /10 CMIT- T X IA POST TUBING CUT PASSED ~ 5/14/10 PJSM, ig own oor equipment, rig down compnsators, bridal up derrick, PJSM, lay down derrick w/ 340k max weight on indicator, secure derrick, raise cellar doors, PJSM, move rig 20' off well, heard loud pop, stop ~ and inspect moving system. Cover of the front axle on the off driller's side (inside tire) broken. Set rig down on ~ mats.PJSM, Remove front axle cover plate, inspect planetary gears. Plug lines, trim axle. Con't to move off of 2L-310 well and stage rig on the level pad. Pull BOP's from rig and install in traveling skid. Install rear booster wheels. Clean up equipment in cellar area and behind well 2L-310. Move rig from 2L pad to 2G pad road at midnight. Note: 12.5 miles moved today, avg 1-1/4 mile per hour. 3N-16 Pre Rig Summary 5/15/10 Move from 2G road /Spine road. to ~ok Road/ IQ pad wide spot in the road. W~n CFP3 and STP crew change out. Take on a little water f/ boilers. Continue to move Rig f/ Oiltok Road/ IQ pad wide spot in the road to 3N pad. Preparing 3N-16A well w! secondary containment and matting boards. Stage equipment behind cellar area. Prepare rig for removing rear boosters, install BOP in cellar. Install safety cables on tugger lines in crown of derrick. Preparing 3N-16A well w/ secondary containment and matting boards. Install tugger safety lines, install cellar doors. Move rig over the hole (3N-16A). Double mat, shim rig. Vlave shop pull VR plug in the IA valve. Pre job safety meeting on raising and pinning derrick. Raise and pin the derrick. Remove bridal lines. Rig up floor. Double valve the 7" x 2-7/8" annulus. Start putting. a truck load (290 bbls) of seawater in the pits. Rig up to pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. 5/16/10 Pull the FMC back pressure valve w/ lubricator. Pits, pump and 3516 engine comming from 2N pad. Note: OA has 100 psi, IA 20 psi, after pulling back pressure valve: tubing on vacuum. Note Rig floor to upper LDS= 23.23', Rig floor to lower lock down screws 25.10, Ground leve126.18'. Original tally upper LDS was noted at 35.00'. Rig accepted 0001 hrs 5/ 16/2010. RD the lubricator. RU bleed tank, choke skid, hard lines. RU circ lines & hard line to bleed tank.. Con't to take on 8.5 ppg seawater to the pits. Press test lines w/ air to 120 psi. Test lines to 2500 psi w/ mud pump- OK. PJSM on circ seawater. Pump 320 bbls sewater down tubing takin freeze protect fluid to bleed tank. Pumping 1.5 bpm, preesured to 1200 psi then broke back to 990 psi, increased rate to 3 bpm w/ 1600 psi, watching press f/ 65 bbls total, then increased to 4 bpm w/ 1800 psi to 2300 psi. Shut down after 320 bbls pumped. Strapped tank-- 320 bbls gain. Blow down lines to the tank. AES vac truck suck off the fluid from the tank. Pump down the 7" x 2-7/8" ann taking returns up the tubing. Pump 4 bpm w/ 1900 psi. Pump 40 bbls seawater 5/17/10 Finish testing BOPE. Witness of tests waived by AOGCC inspector Bob Noble. Test upper pipe rams (2-7/8" x 5" VBR) and all valves on the choke manifold, kill line, choke line and mud line to the kill line to 250 psi low and 3500 psi, hold each test f/ 5 minutes, chart all tests. Test top drive IBOP manual and automatic to 250 psi low and 3500 psi high. Tested floor safety valve and IBOP to 250 psi low and 3500 psi high. Tested the accumulator. Tested the annular to 250 psi low and 2500 psi high. RD testing equipemnt, blow down choke and kill lines. Back out FMC blanking plug. RU to pull tubing. Screw into the hanger 9 rounds and 5000 ft Ibs of torque. Back out LDS's on the tubing hanger. PU on hanger, Pull to 87k with 2' 6" of movement at the rotary table. Continue to pull with free movement at 87k to 85k. Lay down FMC (.5' length) 6.98" OD hanger w/ 3.59' pup PxP below hanger. Lay down Joint of 4" drill pipe. RU to circulate. Circulate 800 bbls while loading 4" drill pipe into the pipe shed. RU spooler for the control line. Monitor well- static. Pump a 15 bl dry job., blow down circ lines. LD a 16.45' 5/18/10 Continue to P/U 4" DP to 8227', Tag Tbg stump ~ 8227' Pump sweep around & POOH to 8227', Slip & cut drlg line 95', POOH & UD Scraper, Rig Halliburton. RIH w/ 7" CIBP, Attempt to set Cad 4940' (Firing head failed), POOH, Rig new firing head, RIH & Set CIBP @ 4940' - OK, POOH & Rig Down Halliburton, Rig & Test 7" casing to 2500 psi f/ 15 min on chart - OK, M/U mule shoe, Pick up 3 jts 4-3/4" Flex collars, 14 jts HWDP, 1 jt 4" DP, RIH w/ 4" DP to 4756', M/U 7" Storm packer & Set same @ 4839'. 5/1, 8/~1 SET BAKER CIBP WITH TOP OF PLUG AT 4940'. FIRST RUN WAS A MISRUN DUE TO POOR CONTACT BETWEEN QUICK CHANGE AND FIRING HEAD. PLUG SET SUCCESSFULLY ON SECOND RUN. 5/19/10 Release from storm pkr @ 63' & POOH, Pull wear bushing, N/D BOP & tbg spool, Change out pack offs and test to 3000 psi, N/U BOP, Install test plug & Test break between BOP &Tbg spool to 250/3500 psi, Pull test plug & Install wear bush, Run over shot & Retrieve storm pkr, UD same, POOH, Make up whipstock BHA & Orient to MWD, RIH to 4815, Orient whipstock to 28 deg to highside, Tag CIBP @ 4950' & Set anchor & shear off whipstock, C/O to 8.9 Flo-Pro mud, Cut window f/ 4932' to 4945', Cut guaged hole to 4965', Rig & preform FIT to 11.1 ppg EMW, Rig do & blow dn. '~~~,'~ KUP ~ 3N-16 •- _ Cd~COP#1~~~ip~ + 'I ~ Well Attributes _ Max Angle S MD TD F>. I,, I rl' Wellbore APIIU WI (Field Name (Well Status Inc! (°) IMD (ftK8) Ac[Btm (RKB) 500292159300 KUPARUK RIVER UNIT PROD 56 10 4 700.00 9,244.0 ( Comment H2S (ppm) Rig Release Date KB-Grd (ft) Data Annotat on End Date __ ( SSSV: LOCKED OUT ~ 740 ( ( I 12/15/2008 Last WO: 39.49 5/20/1986 _ _WeIIC fig 3N:16, 5/ S Jhematc 15I201~ IG'.:~ AMUaI ' ~:~n - Depth (ftK8) '(End Date ( A Cation -._- _-_ - Annotation Last Mod By End Date _ . ( Last Tag: SLM 8.953.0 ; 3/21/2010 Rev Reasom Set CMT Plug, TBG Cut I Imoshor 1 5/14/2010 - - F Casin Strin s CONDUCTOR, ~ ~ ~ St ing OD String ID Set Depth Set Depth (ND) I String Wt String 115 - ~ Casing Description (in) (in) Top (ftK8) (ftK8) (RKB) ~. (Ibs/fl) Grade I Str ng T_ op Thrd ' - - _ CONDUCTOR 16 15.062 00 115.0 - 115.0 62.50 H-40 $AFEN vLV, 1,n2 -- - - SURFACE 9 5/8 8.765 0.0 4,797.0 3,6382 36.00 J-55 -' PRODUCTION 7 ' 6.157 0.0 9,189.0 6,815.4 26.00 J-65 GnsuFT, _ _ _ _ Tubing Stnngs ---- ---- zso2 String OD ' String ID Se[ Depth Set Depth (ND) Sbing Wt String Tubing Desci ption (i^) ~ (i^) Top (fiK6) (ftK8) (RKB) (Ibsfft) Grade Str ng Top Thrd SURFACE, x,797 TUBING 2 ll8 2.441 0.0 8,255.0 6,075 f 6.SOIJ-56 EUESrdABMOD TUBING Original I 27'8 2441 8 2550 8540 8 s.solJ-ss Q548.41 EuESrdABMOD GAS LIFT, _--_- __ 5,020 , bin Run 8 R Oth I H l All J l T , , ) Fish etc etrievab I e __ J - __ _-_ --- er n o e ew e : u . _ _ , , Top Depth (TVD) Top Inc! GAS LIFT,__ __-__-_ -- Top (ftK8) (ftK8) (°) Description Comment RunDt (D(in) s,as7 79 8 1 9~ SAFETY VLV Baker'FVL' (Liked Out 12/8/89) 7!13/1986 i 2.310 ' 2 602 22 . 48 --4 ( GAS LIFT MERLA/TMPD/1/DMY/BW!/ Comment: STA 1 4/5/2010 2 375 GAS LIFT.- _- _ _ ].oae `' 5,020 3,764.0 55.01 GAS LIFT _ !MERLA/TMPD/1/DMY/BK//f Comment: STA 2 4!5/2070 _- 2.375 r 6,467 _. 4,716.0 44.33 GAS LIFT __- 'MERLA/TMPDl1/DMY/BKl/f Comment: STA 3 - 4/28/2003 __ 2.375 GASUFT. 'Y -7,048 5,140.8 42.43 GAS LIFT MERLA/TMPD/1/DMY/BK//1 Comment: STA4 __- 416/2010 _ __ 2.375 7.666 '~ 7,486 - - 5,474.2 - - _- 38.96 GAS LIF7 - - __ - MERLA/TMPD/1/DMY/6WU Comment: STA 5 - _ 4/6/2010 - 2.375 7,85J 5,764.1 38.43 GASLIFT MERLA/TMPDl1lDMY/BK///Comment STAG 4/27/2003 2.375 GAS LIFT, _ 7.s5] r _ 8,236 6,060.7 38.27 GAS LIFT - ___ _-_ MERLA/TMPDI7lDMY/BK///Comment: STA7 - 10/12/1990 - __ 2.375 8,255 6,075 6 38.27 TBG CUT 5/9/2010 2.441 GAS LIFT, 8,353 6,152.6 38.38 CMT PLUG CEMENT RETAINER SET PRE-SIDETRACK 4/29/2010 0.000 6,236 8,579 6,330.4 37.82 GAS LIFT MMH/2.875x1.5/1.5/OPEN/RKl/l Comment: STA8 4!6/2010 2.347 iaGCUr.___. i 1 8,618 6,361.2 37.54 PBR 'Brown PBR - 7/13!1986 2.500 s,255 ~.~ 8,636 6,375.4 37.54 PACKER Brown'HB-1' PACKER 7/13/1986 3.000 !' 8,671 6,403.2 37.53 PRODUCTION MERLA/TMPDIt/OPEN/BK!!/Comment: STA9 4/25/2010 2.375 cMi PLUG, 8.353 . 8,739 8,457.1 37.53 PRODUCTION MERLA/TMPD/1lOPEN/BK!// Comment: STA 10 -. - __ 4/25/2010 _. ___.- 2.375 --- GAS LIFT. -- _ , 811 8 6 574 3 37 50 PRODUCTION MERLAlTMPDl1/OPEN/BK///Comment: STA 11 4/25/2010 2.375 as]9 , , . . -._ - _- 8,825 6,5254 37.47 1PACKER Brown'18'PACKER 7/13/1986 3.250 ~ ~, 8,841 6,538.1 37.43 1 NIPPLE Camco'D'Nipple NO GO 7/13/1986 2.250 PeR.esle-- . ' 8,853 G,547.6 ~~ 37.40 SOS - (Brown - 7!13/1986 2.441 8.854 GS484 37.40 ~TTL ----- 7/13/1986 2.441 PACKER, 8.636- - - ' Perfora tions & Slots --_. _..--_ _. -_- --_.-___. n r - -._ Shot ToP (TVD) Btm (ND) Dens S Top (fl K8 Btrn ftK8 (RKB ( ~ ) RKB) ~ ( Z e - Date - (h.., Type Comment -__ - 8,778 8.799 6,488.1 6 504.7!C -1, UNIT 8, 7/11/1986 12.0 IPERF 120 tleg ph 5' HJ II Csg Gun PROOUCnoN,_ 13 N-16 8,6]1 8,896 8 914 6,581.8 6,596 0 A -3, 3N-16 5/1/7990 6.0 RPERF 2 1/8" Dyna Strip; 0 deg. ph PROOUCnoN,_ _ __ _ ]39 8 ~ 8,896 ' 8,914 6,587.8 6,596.0 A -3, 3N-16 9/2311993 80 I RPERF 21/8" EnerJet; 180 deg ph _ _ - __ , 8,904 8,904 6,588.0 6,588.0 A -3, 3N-16 7/11/1986 1.OI IPERF 4" HJ II Csg Gun; 90 deg p r - 8,906 8,906 6,589 6 6 589.6 A -3, 3N 16 7!11/1986 1.0' IPERF 4" HJ II Csg Gun; 90 deg ph IPERF, 8,778-8,799 ~~~ =- ~ -~. 8,908 - 8,908 - 1 6,591.2 6$91.2 A -3, 3N-16 7111!1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 8,920 8 940 11 6,600.8 6,616.71A -2, 3N-16 ! 5/1/1990 6.0 RPERF 2 1/8" Dyna Strip: 0 tleg. ph PRODUCTION, -~ 8 924 8 944 6 604 0 6 619 91 A 3N-16 ~~ -2 9/23/1993 8 0 RPERF 2 1/8" EnerJet; 180 deg ph 8,811 , , . , . , . I ~ _ _ ___ ~ 8,929 8,929 6,607.9 6607 9 A -2, 3N-16 9/23!1993 1.0 IPERF '4" HJ II Csg Gun; 90 deg ph PACKER, eszs-- - ---` ~ `~ -' 5,931 8,931 6,609.5 6,609.5 A -2, 3N-16 7!11/1986 7.0 IPERF 4" HJ II Csg Gun; 90 deg ph - -- -` -` 8,933 8,933 6,671.1 6,611.1 A -2, 3N-16 7/17/1986 1 0 IPERF 4" HJ II Csg Gun; 90 deg ph ~ 8,935 8,935 6,612.7 6,672.7 A -2, 3N-16 7/11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph NIPPLE, a,ed1 - - ---- 8,941 8,957 6,617.5 6,630.3 A-2, 3N-16 7111/1986 1.0 IPERF 90 deg ph; 4" HJ II Csg Gun SOS, 8,853-- - - -- - TiL, 6,856- - IPERF, 8,906- - RPERF, ~ . ~ .-__-:'_ M 6,896-8.514 RPERF, ~ -~ 8,896-8,914 ' IPERF, 8,906- -- IPERF, 8,908--- - - -- IPERF, 8,929 ~_ -_ _ RPERF, _- - ~-: 8.920-8.560 ..- IPERF, 8.531 IPERF, 8,933 `- -=_ RPERF, =_ _ _ 8,926-8,964 ----- - IPERF,8,935- - ' IPERF, 8,561-8.55] PRODUCTION. ' 9.189 TD (3N-16). 9,244 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3N-16 Run Date: 5/18/2010 May 20, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Haliiburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21593-00 s4 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto ab 4 co Yr ,, ~, ~ , .i .. c Date: ;~1~''i ~ -- ~ ~~~~ ~~ ~;~ ~ Signed: ~j` ~/ ~ i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Cement Retainer Setting Record: 3N-16 Run Date: 4/29/2010 May 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N-16 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21593-00 < <~ , ~. ~~, .~ ~~ ~ ~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 I ~~ -09 I Office: 907-273-3527 ~ ~ ~~~ ~1 Fax: 907-273-3535 rafael.barreto ~, Date: SAY .~ t 2010 Signed: ~® ®-.- . corr.: E :lt~~ ~~ C~ John Peirce Wells Engineer ConocoPhillips Alaska, Inc. / Q P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-16 Sundry Number: 310-118 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of April, 2010. Sincerely, Daniel T. Seamount, Jr. Chair Encl. STATE OF ALASKA ~,(~. ~~ ALAS~IL AND GAS CONSERVATION COMMISS~ ~C APPLICATION FOR SUNDRY APPROVALS ;fib ,~~,q'~~ ?,~AAC 25.280 RECENE~ APR092010 1. Type of Request: Abandon h an~ Rug for Redrill i7 Perforate New Pool "` Repair well ~ C ~ Sus end p ~` ~ c ~ Plug Perforations j' ~ ` Perforate ~""° PUII Tubing ~"", '~ tension Operational Shutdow n ~ Re-enter Susp. Well ~ Stimulate '"` Alter casing Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory 186-091 ° 3. Address: Stratigraphic ~ Service ~°' 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21593-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? Yes No 3N-16 9. Property Designation: 10. Field/Pool(s): ADL 25520. Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9235 ' 6851 9102' 6745' Casing Length Size MD ND Burst Collapse CONDUCTOR 115 16 115' 115' SURFACE 4797 9.625 4797' 3638' PRODUCTION 9189 7 9189' 6815' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8778'-8799', 8896'-8914', 8920'-8956' 6488'-6505', 6582'-6596', 6601'-6617' 2.875 J-55 8854 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -BROWN 'HB-1' PACKER MD= 8636 ND= 6375 PACKER -BROWN '1 B' PACKER MD= 8825 ND= 6525 BAKER 'FVL' MD= 1772 ND= 1720 12. Attachments: Description Surrmary of Roposal ~', 13. Well Class after proposed work: Detailed Operations Program ~"' BOP Sketch J~'" E~loratory ~"'" Development ~' Service J'°•" 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/15/2010 Oil r ~u Gas WDSPL ~ Suspended ~" ~ 16. Verbal Approval: Date: GINJ (° WAG ~~~ Abandoned "; WINJ '~ Commission Representative: GSTOR SPLUG ~` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John P21fCe Title: Wells Engineer ,~ Signature •.-~'" ~ e Phone: 265-6471 Date g C Sundry Number: ~ ~ ~~'~ Conditions of approval: Notify Commission 1 so that a representative may witness J Plug Integrity ~ BOP Test Mechanical Integrity Test Location Clearance ~ 3Sov pS~ ~d IP s f- Other: Subsequent Form Required: ! v . / () APPROVED BY D t ~ /~ Approved by' a e: [ COMMISSIONER THE COMMISSION L ~l, ( Form 10-403 Revised 1/2010 c~~ Submit in Duplicate f ~ iv ~ ~~ a ~~ . Sundry Request ~° 4-8-10 ~ ,~K~'° PTD # 186-091 ~~` ~ The purpose of the planned May 2010 sidetrack of 3N-16 is to move bottom hole location away ., ~~. Nc'~ from a fault zone responsible for the wells underperformance. 3N-16 has been shut-in since ~" /,~ yc^''~ March 2009 due to low production volumes (<100 BLPD) causing frequent hydrate formation SJ~° ~ ,~t ,~~ and freeze off. 3N-16 currently gets limited waterflood support from water injectors 3K-02 and ~ ha~~1 ,.~`. ,~ 3K-04 through a system of baffling faults. l~"'~`"a r ~~~f o/ ~ ~ _on The objective of drilling 3N-16A is to provide waterflood support to two dead segments with l~ti ~e~~,~, current offtake and no injection support. This will be accomplished by setting up the well with a _ ~"1 ~~ ~~,eR rotary sidetrack from 3N-16 followed by CTD quad-lateral drilling. 3N-16A will be placed on PWI service after CTD drilling is completed. Facility construction is expected to occur before and after rotary operations to allow for reduced `put on injection' (POI) time. c~-o -tom '~`Q~l !'~ Procedure Outline: 1,~,~-~r Slickline Pre-Cement Squeeze Prep work: a) Tagged PBTD at 8953' SLM; 1' RH. (done 3/21/10) b) Set CA-2 Plug & gauges in D Nipple at 8841' RKB for A Sand SBHP. (done 3/21) c) Perform IC-POT and IC-PPPOT. Function test LDS. (done 4/1; passed) d) Set Catcher on CA-2; get C Sd SBHP dunk at 8800' RKB. (done 4/2; 2034 psi) e) Pull CV's at St#11 at 8811', St#10 at 8739', and St#9 at 8671' RKB. Set DV's in all 3 of these stations for CMIT. MIT tubing to 2500 psi. (done 4/6) f) Pull OV from St# 8 at 8579' RKB. Leave pocket open for CMIT. (done 4/6) g) Perform CMIT to 2500 psi. (done 4/6) h) Pull Catcher Sub from top of CA-2 Plug at 8841' RKB. (done 4/8) i) Pull CA-2 Plug 8~ gauges from D Nipple at 8841' RKB. Download data. (done 4/13) k) Pull DV's from St#11 at 8811', St#10 at 8739', and St#9 at 8671' RKB. Leave all 3 pockets open for cement squeeze of the selective. St # 8 at 8579' RKB should remain open pocket (see step `f' above) to enable cement circulation to the IA for spotting cement on the packer inside the IA (per step 3 below). 2. E-line Set Cement Retainer (for depth control) a) RIH with a millable Cement Retainer for 2-7/8" tubing (2.187" run OD). Set the cement retainer at +/- 8656' RKB at the middle of a full joint just below the upper Packer of the C sand selective at 8636' RKB. Note, the PBR is immediately above the Packer and a GLM is made up just below the full joint. • 3. CTU Cement Squeeze a) RU CTU & PT equipment. Notify AOGCC Inspector (659-2714; pager 659-3607) of date and time of operation. b) RIH with cement retainer stinger assembly with centralizers to ensure coil has a straight shot at the retainer. Stab onto retainer at +/- 8656' RKB, and shift slide valve open. Pump slick seawater at 1 - 2 bpm to establish injection rate and pressure. c) Mix 30 bbls (150 Sxs) of CI `G' cement with additives. Pump 22 bbls (110 Sxs) of the cement through the cement retainer until a target squeeze pressure of 1500 psi is reached. Target squeezing at least 6 bbls of cement into the formation, if possible. Cement volume calculation: (7" casing vol from bottom perfs to upper packer of the selective = 12 bbls to cement fill) + (4 bbls cement to fill another 100' of 7" casing) + (target of 6 bbls cement behind pipe) = 22 bbls total minimum required cement to pump through the retainer. Since we also want 200' of cement plug on top of the retainer and packer in the IA, we add ~8 bbls to arrive at grand total = 30 bbls mixed cement.. d) Pull out of retainer, open CT x tubing annulus and pump 7.2 bbls of cement into the tubing while taking 1:1 returns. Park the coil at 8400' RKB and assist cement U-tube by pumping cement from the tubing to the IA through the St #8 GLM open pocket at 8579' RKB. Take 5.8 bbls of returns from the IA then shut-in the IA. The maximum estimated TOC in the 2-7/8" tubing should no cement enter the IA is 7412' RKB. A 7.2 bbl cement volume is sufficient to leave 220' of cement plug on top of the cement retainer in the tubing and 200' of cement on top of the packer inside the IA. Estimated TOC in the IA and the tubing after U-tube of cement will be 8436' RKB. After 5.8 bbls of returns have been taken from the IA and IA has been shut-in with the CT at 8400' RKB, swap to pumping Biozan and POOH with CT circulating out contaminated cement. FP the upper 2500' of the tubing with 15 bbls Diesel. RD CTU. 4. Slickline Post-Cement Squeeze a) Wait 24 hours for cement to set. RU slickline to drift for tubing cut. Drift tubing to PBTD (TOC) with 2.28" gauge. PT cement plug to 2500 psi on tubing and IA, and hold for 30 minutes. Record test results. Notify AOGCC Inspector (659-2714; or 659-3607 pager) of the timing of the post cement plug tag and PT. "~ b) Perform drawdown test by bleeding any tubing, IA, and OA pressure to open-top tank. Tubing, IA, and OA should all bleed to 0 psi. 5. E-line Tubing Cut `,,~{~" -~-''~ P` RIH with cutter with anchor arms for 2-7/8" tubin arld cut the tubing at +/- 8252' RKB. is puts the cut at the middle of the first full joint below GLM #7. This cut location is well below the planned sidetrack KOP of +/- 4920' RKB. POOH with E-line. Pump diesel down the tubing while noting rates and pressures to verify likelihood of a successful cut. RD. 6) Set BPV & VR plug. Pull the well house and prep site for rig. Notify the Wells group of well status. • 7) Rig Operations MIRU Doyon 16 on 3N-16. Notify AOGCC before working on well. Check tubing and IA pressure. Ensure well is dead. RU circulating lines and test. Place Gauge on OA to monitor and report daily. Pull BPV. Circulate well with seawater through tubing cut displacing diesel to open top grounded tank. Set BPV. ND tubing head adaptor & tree. Install BOP blanking plug in lift threads. NU BOP on 7-1/16" 5K flange. 3 Sao Test BOPE to 250 psi low and •5686°~psi high per State Permit. Pull blanking plug and BPV. Pull 2-7/8" tubing and hanger. Lay down hanger & 2-7/8" tubing. Tubing should be cut at +/- 8252'. If tubing is not free: ^ Establish free point in tubing by stretch. ^ Rig up to cut tubing. ^ Lay down tubing and hanger PU 7" casing scraper and 6-1/8" pilot bit and 4" DP. RIH to top of tubing stub. Circulate until clean returns. POOH. RU wireline and set a CIBP in 7" casing at t 4930' RKB. POOH. RD wireline. Test 7" casing &CIBP to 2500 psi and hold for 15 min (chart test). . ND BOP. Break tubing head from casing head. Remove tubing head. Remove and replace 7" casing packoff. . Install new tubing spool - 11" 3K flange bottom x 7-1/16" 5K flange top. • Test new ports to 3000 psi or 75% collapse of the casing NU BOP on 7-1/16" 5K flange. Test BOPE at pressures according to State Permit. RIH with whipstock /milling assembly to just above the CIBP. At just above CIBP, displace well to drilling mud. Orient whipstock 45 degrees left of low side above CIBP. ~~~ Set Bottom Trip Anchor. Work pipe to shear whipstock bolt. Mill window in 7" casing until watermelon mill is outside casing > 20' MD. Ream window to eliminate burrs and irregularities. Pump sweep pill and CBU. I Perform LOT per AOGCC requirements. POOH with milling BHA. ~r,.~ I PU hole drilling BHA &RIH. • 3N-16A SIDETRACK 3-'h" TRMAXX-CMT SSSV w/2.812" "X" profile (5.176" O.D.) @ +/_ 2,106' MD 3-'h" x 1" KBMG, (5.39"O.D) EUE 8RD Mod,CamcoGLM inside 7" 9-SB" 36# J-55 casing 4,797' MD ! 3,638' TV D TOL @ +/_ 4,700' MD Sidetrack KOP w! window in 7" @ +!- 4,920' MD Baker "K-1" CIBP below setpointfar wYapstock ~ 4,920' 7" x 9-SB" annulus Arctic packed in 1986 w1 29 bbls cmt+60 bbls diesel Est. TOC @ 3,820' MD GLM Phcement 3,036' 3-'h" x 1" KBIuIG GLM (inside 7" csg) 5,078' 3-'h" x 1" KBG2-9 GLIvI (inside 5-112" csg) 6,281' 3-'h" x 1" KBG2-9 GLM (inside S-II2" csg) 7,114' 3-'h" x I" KBG2-9 GLIuI (inside 5-1(2" csg.) 7,640' 3-'h" x t" KBG2-9 GLIvI (inside S-1 /2" csg) (7Fais mwtdre! will have The anrseIus to Tubing shew~) 3-'h" 9.3#, L-80, IBTM wl Est. TOC on 3.865" O.D. Special Clearance 7" csg. ~ Tubing chemical cut couplings to top of liner with 3,818' MD +/ @ 8,252, 3.5", 9.3# L-80 EUE above liner top Brown `HB-I' Packers 8,636' Tubing cmt retainer TOC @ +/- 6,625' MD ~ 8,656' MD Perfs~ 8,778' -8,799' Brown `1B' Packer ~ 8,825' 2.75" "X" Nipple In tubing tail 3-112" x 5-112" Btim oftubing@ Retainer Production Packer 8,854' MD ~ 7,975' MD Perfs~ 8,896' -8,957' Estimated BHP 4 PPG 5-112" ST-L 15.5# C asing set ~ 8,12 S' MD @ 9,189' MD 6,815' TVD • 3N-16 Pre-Sidetrack Plug & Abandonment 2.875" J-55 Tubing 9.625" Casing i 8 GLM's Brown PBR Brown 'HB-1' Packer 8636' RKB C Sand Perfs Brown '1 B' Packer 2.25" Camco D-Nipple A Sand Perfs 7" Prod Csg =st. ST KOP +/- 4920' RKB Tbg Cut at 8252' RKB TOC at 8436' RKB Cmt Retainer at 8656' RKB C Sand Cmt Sqzd A Sand Cmt Sqzd Current Completion Proposed Pre-ST P&A - ~~ - KUP ~ 3N-16 ~CJI'1(3C(}~'11I~1~'35 '• Well Attributes I gle & MD_ _ ;Max ° TD " "~ Wellbo•e APINWI _ jl SU0292159300 - Field Name Well Status Intl ( ) MD (ftKB) KUPARUK I:I 'ER. LINIT (PROD '. 56.10 4,700.00 i Act Btrn (ftKB/ 9,2440 Comment ",H2S {ppmf - End Date KB-Grd (ft) Date Annotation Rig Release Date wen coney 3N~1s, t /sno UT 140 i ~:; ' oc s~ -- - SSSV_ LOCKED / 12/15/2008 Last WO~ 39.49 ~ I 5/20/1986 _-_ Schema/ A ~ -Annotation i Depth (ftKB) End Daie I Last Mod By Annotation IEntl Date Last Tag~RK6 8 ,958.0 4~,1,'?UC8 Rev Reason: TAG Imosbor 11/6/2009 . , , .. -.~ ,.: Casl S 9 tr n s 9 -_ , ~ .. CONDUCTOR 9 _ OD i g ID St g str string - Set Depth Set Depth (TV D) Str g Wt . 5 ~ o nn n ( 1 . nl ~ Top (ftKB) (ftKB( (ttK8) (Ib/ftl Grade Siring TopThN CONDUCTOR . lsa62 16 0o ttso naa G2so H 0 sAFETV VLV. ~ 'SURFACE ~ 95/8 F 105 0.0 47920 - :36382 3G.OO~J-55 I 1,772 PRODUCTION 7 fi151 00 9,1890 6,5154 2600 J-55 Tubing S I trings ~ -- cnsuFr. 2.502 , String OD ' SFring ID _ .. Set Deplh Sot Depth (TVD) 1 String Wt ~ String Tubing Description lin( (ini lop (ftKB) (flK8) (ftK6) '. (Ibs/ft) Grade String Top Thrd suRFACE- :, '.TUBING 2 718 ~~ 2.941 00 8,8540 6,5484 6.50 J 55 EUESrtlABMOD a75] Other In Hole ( AIl Jewelry: Tubin g Run & Retrievable, Fish, etc.) _ __ GAS LIFT - Top Depth . 5,826 (TVDI ', Top Intl Top (ftKB) (kKel (°) Des nptien I _ Comment __ Run Date ID (inl 1,772 1.720.1 29.92 SAFETY VL:~ 'Baker'FVL' (Locked Out l2/8/89) 7/13/1986 2.310 GAS Ufr, ~ 2,502 2,279.8 49.48 GAS LIFT MERLA/TMPD/1/GLVIBK/.125/1375/Comment: STA1 4/28/2003 ,I 2.375, 6.467 , 5020 3,764.0 55.01 GAS LIF~I MERLA/TMPD/1/GLV/BK/.156/1390/Comment: STA2 4/28/2003 2.375 - 6467 4,716.0 44.33 GAS LIFT MERLA/TMPD/1lDMY/BKI//Comment STA3 4/28/2003 2.37511 GAS LIfT. 7,648 7048 5,140.8 4243 GAS LIFT MERLA/TMPD/1/GLV/BK/.188/14061 Comment STA4 4127/2003 2.375, - 7,486 5,474.2 38.96 GAS LIFT MERLA/TMPD/1/DMYlBK/// Comment: STA S 4/27/2003 2.375'. GAS'I66 - 7,857 5,764.1 38431GAS LIFT MERLA/TMPD/llGLV/BK/.1 8 811 3 8 81 Comment: STA6 4/27/2003 2.375 I 8,236 6,060.7 38.27GAS LIIe ~I MERLA/TMPD/1/DMYlBK///Comment: STA7 10112/1990 2.375 li $579 6,330.4 37.82~GAS LIFT MMH/2.875x1.5/t5/OV1RK/.156//Comment: S7A8 4/27/2003 2.347 Gns uFT, 7,857 8 818 6,361.2 37.54~PBR Brown PBR 7/13/1986 2.500 8,636 6,3754 37.54 PACKER Brown'FIB-1'PACKER 7/13/1986 3.000 8,671 6,403.2 37.53 PRODUCTION MERLA/TMPD/1/CV/BEK///Comment: OPEN STA9 4/5/2005 2.375 GAS LIFT, e,23s I 8,739 6,457.1 37.53 PRODUCE tON MERLA/TMPD/1/CV/BEK/// Comment OPEN STA 10 4/s/2005 2.375 66 1 8 811 6,514.31 37.50 PRODUCTION ~MERLA/TMPD/1/CV/BEK/// Comment OPEN STA 11 4/4/2005 2.375 GAS LIFT 6575 8825 6,525.4 1 3747 PACKER Brown'18'PACKER 7/13/1986 3.250 8.841 6.538.1 37.431 NIPF`L.h ~.Camco'D NiooleNOGO 7/13/1986 2.250 PACKER, 6,636- RODUCTION. 6,611 - - - Top (ftKB) 8,778 ~ Btm (ftK8)'i 8,79911 TOp (TVD) (ftKB( 6,488.1 Btm {fVDI (ft1(6j Zone 13.504.7 C-1, UNIT B, 3N-16 Dale 7111/1986 SI De (s. 1 8,896 8 914 6,581.8 IS.S9G0 A-3, 3N-i6 5/1/1990 PRODUCTION 8,896 8,914 6,581.8 15,59 G.v' A-3, 3N-16 9/23/1993 , __. 8,739 - 1 8,904 8,964 6,588 0 ti.588.0 A-3, 3N-16 1 7!11!1986 8,906 8,906 6,589.6 6,5.59 ~~ A-3, 3N-i6 1 7/11/1986 IpERf, 8,908 ' 8,908 6,591.2 ei,591.2 A-3, 3N-16 7111/1986 B,]IB-8,]99 -- ~, 8,920 1 8,940 6,600.8 6.616.: A-2, 3N-i6 5/1/1990 8.924 ~~ 8 944 6,604.0 6,619.9 A-2, 3N-16 9/23/1993 PROOUCr1oN' B.Bt 1 ';;. ,, 8.929 1 8,929 6,607.9 5.607.9 A-2, 3N-16 9/23/1993 8,931 8,931 6,609.5 6,fi09S A-2, 3N-16 7/11/1986 PncK=R. e,e2s - Y 8,933 8,933 6,611.1 G,f,11-1 A-2, 3N-16 7/17/1986 ~" ~r 8,935 8,935 6812 7 r.f1 ;% A-2, 3N-16 711111986 ~ 8,941 8,9571 6,617 5 i.C30.3 A-2, 3N-16 7111/1986 NIPPLE. 8.841 SOS.6.853- TTL, 8.854 -_ IPERF. 8.900 RPERF, 8,896-8,914 RPERF _ 8.896-8.514 IPERF, 8.906- IPERF, 8,908 IPERF, 8.525 RPERF.-_ 6.9208.540 IPERF, 8.931 - - IPERF. 8,933--~-_ RPERF. __ 8.926-8,944 -- IPERF.8.935 -- 2.O~IPERF 1120 deg ph; 5" HJ II Csg Gun 6.0 RPERF 2 i!8" Dyna Strip; 0 deg. ph 8.0 RPERF 2 1/8" EnerJet; 180 deg ph 1.0 IPERF 4" HJ II Csg Gun; 90 deg p 1.0 IPERF 4" HJ II Csg Gun; 90 tleg ph 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 6.0 RPERF 2 178" Dyna Strip: 0 tleg. ph 8.0 RPERF ~2 1/8" EnerJet; 180 deg ph 1.0 IPERF ~~4" HJ II Csg Gun; 90 deg ph 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 1 0 IPERF 4" HJ II Csg Gun; 90 deg ph 1 0 IPERF 4" HJ II Csg Gun; 90 deg ph 1.0! IPERF 90 deg ph; 4" HJ I I Csg Gun IPERF, 8.941-8,957 PRODUCTION. 9,189 TD. 9,244 Well History 3N-16 500292159300 Page 1 of 7 ~~~~1 Well History 3N-16:500292159300:4/8/2010 Date Event 04/07/2010 BAIL SAND FROM 8826' SLM TO 8832' SLM TO GET TO CATCHER SUB. JOB IN PROGRESS 04/06/2010 SET 1" DV'S @ 7048', 7857 RKB, PULL 1.5" OV @8579' RKB, LOAD I/A W/ 300 BBLS DIESAL, PERFORM GOOD CMIT TO 2500 PSI. JOB IN PROGRESS 04/05/2010 PULLED GLVs @ 7857', 7048', 5020', 2502' RKB. SET DVs @ 2502', 5020' RKB. IN PROGRESS. 04/04/2010 PULLED CV @ 8671' RKB, REPLACED WITH DV. ATTEMPTED PULL GLV @ 7857 RKB. IN PROGRESS. 04/03/2010 PULLED CVs @ 8811', 8739' RKB. REPLACED WITH DVs. IN PROGRESS. 04/02/2010 MEASURED BHP @ 8800' RKB: 2034 PSI. SET 2.29" CATCHER @ 8832' SLM. BRUSHED & FLUSHED TBG TO 8810' SLM. IN PROGRESS. 04/01/2010 (PR) IC-POT -PASSED. IC-PPPOT -PASSED. FUNCTION TEST LDS's. 03/21/2010 TAGGED TD @ 8953' SLM (EST. 1' OF RAT HOLE /OBTAINED SAMPLE). SET 2.25 CA-2 PLUG W/ DUAL PANEX GAUGES (173.5" OAL) @ 8841' RKB. ((NOTE: NEED SHORT AXELSON FUSIBLE CAP )). 12/15/2009 BRUSH & FLUSH SSSV @ 1763' SLM. JOB COMPLETE 06/17/2008 MEASURED C SAND SBHP @ 8778' RKB.(1576 psi). PULL 2.75" C-A2 PLUG W/ GAUGES FROM 8841' RKB (A SAND PBU 1281 psi) JOB COMPLETE. 06/13/2008 GAUGE TBG TO 2.34" TO 1772' RKB. GAUGE TBG TO 2.27" TO 8841' RKB. SET 2.25" CA- 2 PLUG W/ DUAL PANEX GAUGES (OAL= 179") @ 8841' RKB. JOB COMPLETE. 04/04/2008 DRIFTED TBG WITH 10' x 1.875" STEM, TEL, SAMPLE BAILER. LOCATED TTL @ 8839' SLM, 8854' RKB. TAGGED @ 8958' RKB, EST. 1' RATHOLE. READY FOR E/L. 12/29/2006 PULLED CATCHER & CA-2 PLUG @ 8841' RKB, TAG TD @ 8957 RKB (EST.PERFS ARE OPEN) JOB COMPLETE. 12/28/2006 C SAND ONLY SBHP TAKEN AT 8788' = 2007 PSI @ 156 DEG F. ATTEMPT TO PULL CATCHER SUB. JOB IN PROGRESS. 12/27/2006 ATTEMPT TO PULL CATCHER SUB @ 8833' RKB JOB IN PROGRESS. 12/15/2006 BRUSHED/FLUSHED TBG. SET 2.25" CA-2 PLUG @ 8841' RKB. SET CATCHER ON PLUG @ 8833' RKB. 10/18/2006 A sand Scale Squeeze. Pumped 10 bbls of Seawater pre-flush containing 30 gallons of WAW- 5206. Pumped 20 bbls of Seawater containing 110 gallons of SCW-4004. 08/05/2006 A STATIC BOTTOM HOLE PRESSURE SURVEY WAS OBTAINED. PRESSURE @ 8926' WAS 1681PSI, 160 DEG F. PRESSURE @ 8800 WAS1644 PSI, 159 DEG F. TAGGED TD @ 8959'. WELL LEFT SHUT IN. 08/26/2005 PROD PROFILE W/ DEFT -LOG FROM 100 - 8962 (HUD). GLS PERFORM (8579 LIFT GLM). CROSSFLOW OBSERVED DURING FLOWING PASS AND SHUTIN (A TO C). FLUID EXITING PROD MANDREL @ 8810 FT. SPLITS: 0% A SAND, 100% CSAND - DOWNFLOW OBSERVED IN 7" (A SAND). [PROD 06/27/2005 POTENTIAL A SAND INTERACTION WITH 3N-18L1P LAG MONTHS =PEAK GOR = COMMENT =LOOKS LIKE THE DECLINE RATE IN 3N-16 INCREASES AFTER 18L1 IS BOL. 04/05/2005 SET CV'S @ 8671' & 8739' RKB. CONFIRMED CV @ 8811' IN POCKET. [GLV] http://akapps. conocophillips.net/webbert/Well/Report/rptWellTable.aspx?REPORT=..%2f..%2fUse... 4/8/2010 Page 1 of 1. { Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Form 10-403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D, will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or Cade, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will alsa review the list of suspended wells for accuracy. Thanks, Steve D. file://F:\Daily_Document Record\Procedures\FW INTENT PLUG for RE-DRILL WELLS ... 4/9/2010 • • Mr. Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 \~~ 09~ Re: Kuparuk River Field, Kuparuk Oil Pool, 3N-16 Sundry Number: 309-414 ~'~~~ JINN `~ 201 Dear Mr. Christensen: 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 19 day of January, 2010 Encl. Daniel T. Seamount, Jr. Chair • ConocoPhillips • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 ~~~~ Y G® December 8, 2009 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`" Ave. Ste. 100 Anchorage, AK 99501 DEC ~ 209 :Alaska Oil ~ Gas Cans. Cammissi~n An~harag Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3N-16 Oil . Production service to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3N-16 (PTD 186-091). If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659-7535. Sincerely, Robert D. Christensen Attachments ~Br~MS .f~N -7 ~~I', D o ~ ~ o~c ~ o ?o~~ S ~ ~ STATE OF ALASKA l'~ ~~ ALASKA OIL A D GAS CONSERVATION COMMISSION ~~BSka ~I~ ~ ~~ G08S, GOtYlIIIISIa~01t APPLICATION FOR SUNDRY APPROVAL ~~ Anc!~~r~ae 20 AAC 25.280 ~~-t ~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ pil to WIND Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPh'tllips Alaska, Inc. Development 0 Exploratory ^ 186-091 • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21593-00 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 Required? YeS ^ NO ^~ 3N-16 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25520, ALK 2556 RKB 68' Kuparuk Rivern Fie ld /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft)a, otal Depth TVD (ft): , Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4' ~~ $869' fvGS`l 9102' - 6745' .- Casing o`I Length ~~~ Size MD TVD Burst Collapse CONDUCTCS~2 115' /Z 16" 115' 115' SURFACE 4729' 9-5/8" 4797' 3638' PRODUCTION 8121' 7" g1 gg' 6815' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: ,~ $ Tubing Grade: Tubing MD (ft): 8778-8799'; 8896-8957' 6488-6505`; 6582-6630' J-55 8854' Packers and SSSV Type: Packers and SSSV MD (ft) ~G.- 7t •!7 o q Brown'HB-1', Brown'1B' 8636, 8825 Baker'FVL' (Locked out) 1772 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ • 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Jan 7, 2010 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name obe .Chris ensen Title: Production Engineering Specialist Signature Phone: 659-7535 Date/ ®g' Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~l"~ "~ tlert t lSe ~~~ Oh a. ~~tr STc.d~ ~iLe~ ih~Cvi~i011. /. Subsequent Form Required: ! ~ . L/a ~/ F,_ Approved by: OMMISSIONER APPROVED BY THE COMMISSION / Date: ~ b Form 10-4b3 Revised 06/2 '"` r ~ t ~'' t t v i ~ t. J.G- /. 5/. /o ~',~. /2f/sT~ Submit in Duplicate~~~~ /~.. <:=~ • 3N-16 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3N-16 from Oil Production service to A sand Water Injection service. Well 3N-16 was completed as a Kuparuk Oil Pool A/C sand, single selctive, producer on May 20, 1986. Well 3N-16 has been SI since March 25, 2009 due to low productivity. Conversion of the well 3N-16 to injection service will provide pressure support to offset producer 3N-18. Future plans include sidetracking well 3N-16 when injection water breakthrough occurs at well 3N-18. The 16" Conductor was cemented with 249 sx CS II. The 9-5/8" Surface casing (4797' and / 3638' tvd) was cemented with 1350 sx AS III & 350 sx Class "G". The 7" Production casing (9189' and / 6815' tvd) was cemented with 300 sx Class "G" & 175 sx AS I. The 7" Production casing also had 2 cement squeeze jobs performed with 150 sx Class "G" each (8880' - 8882' md/ 6569' - 6571' tvd) on July 7 - 10, 1986. A CET was not run after these squeeze jobs. An MIT-OA was last performed on 10/18/08; MITOA 1800 psi, 30 minutes, Passed The injection tubing/casing annulus is isolated via Brown 2-718" x 7"'HB-1' Packer located @ 8636' and / 6375' tvd. The Top of the Kuparuk C sand was found at 8724' and / 6445' tvd. The Top of the Kuparuk B sand was found at 8784' and / 6492' tvd. The Top of the Kuparuk A sand was found at 8883' and / 6571' tvd. The CET Cement Evaluation log performed on June 7, 1986 indicates fair to good A sand isolation 8854' - 8883' and (6548' - 6571' tvd) with poor C sand isolation above 8854' md. Our current plan is to mechanically isolate the C-sand and inject only into the A sand. We will run apxefirl~ LC ~~ ~ l survey to verify the C-sand is isolated after the well is injecting. This plan will be followed until the well is sidetracked to a new bottom hole location, at which the existing C and A sand locations will be plugged and abandoned. ~Z.tT .~ ~ u., C J!. W ~.~1(j~l.~T`.'~I.7 r lG'~v~s`Si~Gr:j %(J ~a~ Via( /'r ©~°~ ~i; / ~~+ S~IV:~/c~ /~~~/f /~~ ~~ 1 (/1 :'~ l' %P Cy f fit ~P C ~ ~+,C~ Cv '7~' ~.~¢.~ ~/` W e ~~~ KUP ~ 3N-16 COI'lOCO~'11~~I P5 Well Attributes Max An le & MD TD Ai;{tiK.1 ~rl, Wellbore A Pl/UWI Fieltl Name Well Slatua Inc! (°) MD I(tKe) Act atm ((t K8) 500292159300 KUPARUK RIVER UNIT PROD 56.10 4,700.00 9,244.0 Comment H25 Ippm) Date Annotation Entl Date KBlirtl (R) Rig Release Date ••• - -- SSSV: LOCKED OUT 140 12/15/2008 Last WO: 49 5/20/1 39 986 Wall Confl -3N-16 1 1 Td1 0091:06.56 PM . Schematic -Ac Nel Annotation Depth (ftNB) End Date Annotation Last Motl By Entl Date Last Tag:RKB 8,958.0 4/4/2008 Rev Reason: TAG Imosbor 11/6/2009 Casin Strin s CONDUCTOR String OD String ID Set Depth Set DepN (TVD) String Wt String 715 Casing Descrip[lon (in) (in) Top IRKB) (RKB) (RKB) (Iba/fl) Dratla String TOp Thrtl CONDUCTOR i 6 15.062 0.0 115.0 115.0 62.50 H-00 sAFErv vl.v. 1,1R SURFACE 95/ 8 8.765 0.0 4,797.0 3,638.2 36.00 J-55 PRODUCTION 7 6.151 0.0 9,189.0 6,815.4 26.00 J-55 cnsuFr Tubin SUin s , 2,502 String OD String ID Set Depth Sel DepN (TVD) String Wt String Tubing Deacriptlon (in) Iin) Top ((tKB) (RKB) (RKB) (IDs/ft) Gratle String Top Thrtl suRFACE, 4 191 TUBING 27/ 8 2.441 0.0 8,854,0 6,548.4 6.50 J-55 EUE8rdAB MOD , Other In Hole A ll Jewel : Tubin Run & Retrievable, Fish, etc. GAS LIFT, Top Deplh 5,020 (TVD) Top Inc! Top (fR(8) (RKB) (°) Descriptlon Comment Run Date ID (in) 1,772 1,720.1 29.92 S AFETY VLV Baker'FVL' (Locked Out 12/8/89) 7/13/1986 2.310 Gns uFT, s 461 2,502 2,279.8 49.48 G AS LIFT MERLA/TMPD/1/GLV/BK/.125/1375/ Comment: STA 1 4/28/2003 2.375 . 5,020 3,764.0 55.01 G AS LIFT MERLA/TMPD/1/GLV/BK/.156/1390/ Comment: STA 2 4128/2003 2.375 GAS LIFT 6,467 4,716.0 44.33 G AS LIFT MERLA/TMPD/1/DMY/BK/// Comment: STA 3 4/2&2003 2.375 , 1.D49 7,048 5,140.8 42.43 G AS LIFT MERLA/TMPD/1/GLV/BK/.188/1406l Comment: STA4 4/27/2003 2.375 7,486 5,474.2 38.96 G AS LIFT MERLA/TMPD/1lDMY/BK/// Comment: STA 5 4/27/2003 2.375 GAS uFT 7,857 5,764.1 38.43 G AS LIFT MERLA/TMPD/1/GLV/BK/.188/13881 Comment: STA 6 4/27Y2003 2.375 ~ °~ 8,236 6,060.7 38.27 G AS LIFT MERLA/TMPD/1/DMY/BW// Comment STA 7 10/12/1990 2.375 8,579 6,330.4 37.82 G AS LIFT MMH/2.875x1.5/1.5/OV/RK/.156UComment: STAB 4/27/2003 2.347 Gns uFr, ~ esT 8,618 6,361.2 37.54 P BR Brown PBR 7!13/1986 2.500 8,636 6,375.4 37.54 P ACKER Brown'HB-1' PACKER 7/13/1986 3.000 GAS LIFT, 8,671 6,403.2 37.53 P RODUCTION MERLA/TMPDl1/CV/BEK//l Comment: OPENSTA9 4/5/2005 2.375 e.z3s 8,739 6,457.1 37.53 P RODUCTION MERLA/TMPD/1/CV/BEK!/I Comment: OPEN STA 10 4/5/2005 2.375 8,811 6,514.3 37.50 P RODUCTION MERLA/TMPDl1/CV/BEKI/I Comment: OPEN STA 11 4/4/2005 2.375 GAS uFr, 6,519 8,825 6,525.4 37.47 P ACKER Brown'1 B' PACKER 7/13/1986 3.250 8,841 6,538.1 37.43 N IPPLE Camco'D' Nipple NO GO 7/13/1986 2.250 PBR 8 610 8,853 6,547.6 37.40 S OS Brown 7/13/1986 2.441 , , 8,854 6,548.4 37.40 T TL 7/13/1986 2.441 _ Perfora tions & Slots PACKER, 8,636 Shot Top (TVD) Btm (TVD) Dena Top (ftKB) Btm (FtK6) (RKB) (RNB) Zone Data Ian... Type Comment 8,778 8,799 6,488.1 6,504.7 C -1, UNIT 8, 7/11/1986 12.0 IPERF 120 deg ph; 5" HJ II Csg Gun PROOUCrION, esn 3 N-16 8,896 8,914 6,581.8 6,596.0 A -3, 3N-16 5/1/1990 6.0 RPERF 2 1/8" Dyna Stdp; 0 deg. ph PRDDUCnoN, 8,896 8,914 6,581.8 6,596.0 A -3, 3N-16 9/23/1993 8.0 RPERF 21/8" EnerJet; 180 deg ph 9,139 8,904 8,904 6,588.0 6,588.0 A -3, 3N-16 7111/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg p 8,906 8,906 6,589.6 6,589.6 A -3, 3N-16 7/11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph IPERF, e naa 199-~ 8,908 8,908 6,591.2 6,591.2 A -3, 3N-16 7/11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph . , 8,920 8,940 6,600.8 6,616.7 A -2, 3N-16 5/1/1990 6.0 RPERF 2 1/8" Dyna Strip; 0 deg. ph R 8,924 8,944 6,604.0 6,619.9 A -2, 3N-16 9/23/1993 8.0 RPERF 2 1/8" EnerJef 180 deg ph P ODUCTION, 9,en 8,929 8,929 6,607.9 6,607.9 A -2, 3N-16 9123/1993 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 8,931 8,931 6,609.5 6,609.5 A -2, 3N-16 7!11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph PACKER, 8,825 8,933 8,933 6,611.1 6,611.1 A -2, 3N-16 7/11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 8,935 8,935 6,612.7 6,612.7 A -2, 3N-16 7!11/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg ph 8,941 8,957 6,617.5 6,630.3 A -2, 3N-16 7/11/1986 1.0 IPERF 90 deg ph; 4" HJ II Csg Gun NIPPLE, 6,641 $DS, 6,653 TTL, 8,&54 ~ IPERF, 8,904 RPERF, 9.896-8,914 RPERF, 8,896-8,914 IPERF, 8,91% IPERF, 9,906 IPERF, 8,929 RPERF, 9,920.8,940 IPERF, 6,931 IPERF. 8,933 RPERF. 8,924-8,944 IPERF, 8,935 IPERF, 9,9419,951 PRODUCTION, 9,189 T0, 9,244 ,I t ,I i ,~ I I i i ~~ I I ~j j .. i i ~~ I ~ i I i i i i i i i I i I 1; I I ~I i 1; I R j I j i I T--~.- . i ._ ~ _ ___. l _.__~_-~~-~ .. j j M i i I I I I I w I I I -t--~ I I ' I I I I M I I I I I I I I ~ I i i i i i I I I I I I I I I I i I I I ~I I ,=/ I I I I I ~`l ~~ I I I I I I I ,~yd V n ~ $64Q Q \, "' -__'.._T-_ -_.. ~ I I Y I - *~-__y_ _. ..-. _~ I - -- - -- -- -- -- - -- -- - - - - - -- -- - - --- - - - - t -~ , -- -- - --- - - -- - -- - - -- --- -- - --- -- -- - - - -- -- -- - -- -- - --- -- - -- - - - -- - -- -- -- --- - -- --- -- -- 1. ~~ ~ ~ ~ d~zM ,~ 0 0 -~ ~ N~ 4 r. .: 4, _ ~ d/ 2~'C:~ANICAL INTEGRITY RL'PORT ~ I~ =IIUD it~_: : OPER fi FIELD ~ono~o / ~~1~'~~l~~vl =,G n~?.~rS~: SZo ~` i.~.,L NiJMHER 3~'~~0 ~.LL DAT ~: TD : .2~.. ______._ 3'v'D. ; : BTD : ?SD T_'VD Casing : ~ S~ ~~ ~ Shoe : _~, . Shoe : `~' 1 Z f . MD '-` . ~ ~ l ~~ 7VG ; .' C P . _ ____- ~ '"''D _ ___---- g : vZ~P2cker~ aci ^ 7S TVD; 3 ~r Set at . . _, r, :ale Size and 8 5 " Perfs 8"77g r to ~ Z~~ - ~ G . . ~ ~~G y~ f~~ S'7 ~ ~~ '~: ~.t~.N i C~.L iNTEGR?TY -PART # ? " Annulus Press Test: _.~',,,,, ~: 15 mi n a r~ ~ `_____• comments : N~ ~r ,~.~ Nt ~ I ~r"i ~. . , . , ' r~w~Y ~rwrrr~iA~ ^~ .- " '~ECIiANIC?~ INTEGRI'T`Y -PART ~ 2 ~ ,~ ~S~ 3aolx ~ / 3 ~' s,,~ v ; ~V C emenc Volumes : Amt . i~:.~r / ? Ss~ S1 Gs g 35r sK . ~ ._..r.:.:...._._. s~, . Cast Jol to cove= per.:s r . 'w~a+~.~r.. - - -- The+~recical Y0C 7'' mss . k~.L -~w-6 s9•~~ ~-a~Css ~ ~Q ~e.~-e_- l~ e--~'+~.... ~~~ _,s ,tom as - e. F_ 7-' Cement Sand Lc g ~ No) _~ -----~ In AOGCC F it e______,_ C9L :.v,eluatioa, zone Goove perfs -~'~ ~o~.'P -~ !^e_co t'-'~-e~ ~ ~~L Production I.og: J Grp ~ ~ nJ~ _i ~ n ~ .~-t--~ C ~~~. S ~~ . '_rppe ~ JU a Evaluation ~ v Qto,K. C~ s~NDs ' ~CONCLUSiONS: .w.... r ?art" #2 :: FL ~ y.cri ~~ ~sd ~~~ .~ o u-~ e s¢~v~. _ ~ ~~~ _ 3N-16 Area of Review ~~ ~ g~ - o~ ~ Figure 1: Areal View of the current location of 3N-16 in relation to surrounding wells. The red circle indicates a 1/4 mile radius centered on 3N-16. 3N-16 is ready to be setup to inject into the perforated A2 and A3 sands. The C1 sand is perforated in this well but mechanically isolated from the A-sands. Quarter Mile Infection Review 3N-18 was originally drilled in May 1986. It produced from the AZ and A3 sands. In March of 2003 3N-18 was abandoned and sidetracked. 3N-18L1 PB1 is within a quarter mile (1,320') of 3N-16. 3N-18L1 PB1 was drilled on 3/26/2003 into the A3 sand. This lateral's hole deteriorated and had to be plug backed. An open hole whipstock was set in the 3N-18L1 PB1 to kick off and drill 3N-18L1 3N-18L1 is within a quarter mile (1,320') of 3N-16. 3N-18L1 was drilled on 4/1/2003. This producer penetrates the A3 sand and is currently on production. 3K-04 is beyond the quarter mile (1,320') of 3N-16. This injector penetrates the A2 and A3 sands and is currently on sea water injection. • ~~ ConocoPh s I I i ps Alaska F.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~g~,- o~ ~ ~~ Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRi1). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 19, 2008 and the corrosion inhibitor/sealantwas pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 90'7-659-7043, if you have any questions. Sincerely, ,~~ ~~ MJ La eland /~~~~ ~ ~ ~1 ~. ~ 2 Q~~ ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field note 10/22/2008 .-.. Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19!2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 08/09/06 Schlumberger RECEIVED NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Þ.lJG 1 0 2006 S(;l\tVNED JlUG 1 4 2nnfL -. ~U''\,;ompany: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .\.~~ OH & Gas Cons. Commission Anchorage 1'?5'~' -- O~ { Field: Kuparuk Well Log Description Date BL Color CD Job # 1 J-127 11216302 USIT 06/05/06 1 1 D-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1 Q-13 11249936 INJECTION PROFILE 08/02/06 1 1 Q-26 11249937 PROD PROFILE WIDEFT 08/03/06 1 1R-14 11235386 PROD PROFILE W/DEFT 08/03/06 1 1 G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 SBHP SURVEY 08/05/06 1 1 E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ,? A~RCO Alaska, Inc. ( Post Office B, 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION o gS-:zz~, 3F-02 Stimulate '~?.--2.-~ ~3M-09 Stimulate '"3M-09 Perforate ,E,~- 72-, 3N-10 Stimulate ~,~,--~1 t 3N-16 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AL~,SKA OIL AND GAS CONSERVATION COMMI',.._ . )N REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Operation Shutdown ~ Stimulate X Plugging ~ Perforate X Pull tubing ~ Alter casing Repair well Other 2. Name of Operator ARCO Al~sk¢. Inc. 3. Address P. 4. 12. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 561' FSL, 30' FEL, SEC.29, T13N, R9E, UM At top of productive interval 1282' FNL, 823' FEL, SEC.33, T13N, R9E, UM 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit feet number 8. Well number 3N-16 9. Permit number/approv~ 7</ % At effective depth 1382' FNL, 616' FEL, SEC.33, T13N, R9E, UM At total depth 1417' FNL, 544' FEL, SEC.33, T13N, R9E, UM Present well condition summary Total Depth: measured 9 2 3 5' true vertical 6 85 1 ' feet Plugs (measured) feet 10. APl number 50-029-2159300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 9 1 02' feet Junk (measured) 6745' feet Casing Length Structural Conductor 80' Surface 4 76 0' Intermediate Production 91 8 9' Liner Perforation depth: measured 8778'-8799' true vertical 6488'-6505' Size Cemented Measured depth True vertical depth 1 6" 249 SX CS II 115' 113' 9-5/8" 1350 SX AS III & 4797' 3637' 350 SX CLASS G 7" 300 SX CLASS G & 91 8 9' 6 81 4' 175 SX AS I 8896'-8914', 8920'-8940', 6582'-6596', 6601'-6617', 8941 '-8957' 6618'-6630' 13. Tubing (size, grade, and measured depth) 2-7/8" J-55 ABM@ 8854' Packers and SSSV (type and measured depth) PKRS: BROWN HB1 ~ 8636', BROWN 1-B ~ 8825' SSSV: BAKER FVL ~ 1773' R E C E IV [ b Stimulation or cement squeeze summary A SAND FRACTURE TREATMENT NOV Intervals treated (measured) 8896'-8914', 8920'-8940', 8941 '-8957' A!~ska 0il & Gas C0ns. C0mmission Treatment description including volumes used and final pressure Anchorage SEE A-I-FACHED WELL SERVICE REPORT SUMMARY 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 165 79 0 11 O5 479 320 0 1257 Tubing Pressure 130 125 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended ~ hereb rtify that e foregoing is true and correct to the best of my knowledge. Signed ' Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 Service SUBMIT IN DUPLICATE MORNING REPORT SUMMARY 10/01/93 TO 10/03/93 CPF-3 DS-3N 3N-16 10/02/93 GSW DATAFRAC W/DOWELL. PUMP BD, PI's and DF's @ 15 BPM. DATA AS FOLLOWS: STAGE VOLUME FWHTP ISIP CLOS P FG BD @24BPM 150 7150 2930 4900 .89 PI gl 25 5012 2806 4950 .87 PI ~2 25 5012 2769 -- .86 PI ~3 25 4999 2724 -- .86 FLUSH 50 5030 2843 5020 .88 DF gl 200 5012 2989 5560 .90 DF ~2 120 5484 2984 5650 .90 PERF/XS FRIC FE 50 - - 23% 10 16% DS COMPUTER LOCKED UP ON 2ND & 3RD PI. NO SMART COMPUTER (UTILIZING REAL TIME TRANSMISSION TO ANCHORAGE). INCREASED PAD TO 125 BBL BASED UPON FLUID EFFICIENCY. ABORTED JoB WHEN TREATING PRESSURES INCREASED TO 6150 PSI DURING PAD (MAX 12 PPA STAGE WAS 6000 PSI). PUMPED 60 BBL DIESEL FLUSH. ESTIMATED TOT FLUIDS: WATER=720 BBL, DSL(FLA + FLUSH)=93 BBL, ADD'S=50 BBL. ALL FLUIDS LOOKED GOOD. (GOLDEN/BOTELLO/HARVEY) Gas Cons. Comlnis~ion Anchorage ARCO Alaska, Inrr Post Offic; ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 8, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska. 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ¢5- z.~_z. 3A-06 Stimulate ~57--?& 3H-04 Stimulate ~=c,,-q ~ 3N- 16 Perforate If you have any questions, .please call me at 263-4241. Sincerely, P. S. White Senior..Engineer Kuparuk Petroleum Engineering RECEIVED OCT 1 1995 Nas~ 0il .& 6as Cons. Comm'~ssiO~ Rncfi0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-C STATE OF ALASKA AI_~._. ,A OIL AND GAS CONSERVATION COMMIS~._ N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing ~ Alter casing Stimulate ~ Plugging ~ Perforate X Repair well Other i2. Name of Operator ARCO Alaska. In6. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1561' FSL, 30' FEL, SEC.29, T13N, R9E, UM At top of productive interval 1282' FNL, 823' FEL, SEC.33, T13N, R9E, UM At effective depth 1382' FNL, 616' FEL, SEC.33, T13N, R9E, UM At total depth 1417' 544' FEL, SEC.33, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9235' feet Plugs (measured) 6 8 51 ' feet 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3N-16 9. Permit number/approval/.m31'ffS~--~ 90-747 //~'~..-,,,-,;~,~'-~'--?i /) / 10. APl number 50-029-2159300 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth' measured true vertical 9 1 02' feet Junk (measured) 6745' feet Casing Length Structural Conductor 80' Surface 4 7 6 0' Intermediate Production 91 8 9' Liner Perforation depth: measured 8778'-8799', true vertical 6488'-6505', Size Cemented Measured depth True vertical depth 1 6" 249 SX CS II 115' 113' 9-5/8" 1350SXAS III& 4797' 3637' 350 SX CLASS G 7" 300 SX CLASS G & 91 8 9' 6 81 4' 175 SX AS I 8896'-8914', 8920'-8940', 6582'-6596', 6601'-6617', 8941'-8957' 6618'-6630R Tubing (size, grade, and measured depth) 2-7/8' J-55 ABM@ 8854' Packers and SSSV (type and measured depth) PKRS: BROWN HB1 ~-8636', BROWN 1-B @ 8825' SSSV: BAKER FVL @ 177~ask~ 13. Stimulation or cement squeeze summary REPERFORATE A3 AND A2 SANDS Intervals treated (measured) 8896'-781 4', 7824;-7844; Treatment description including volumes used and final pressure REPERF A3 SANDS F/8896'-8914' RKB W/4 SPF @ 90° CW. REPERF A2 SANDS F/8924'~8944' RKP W/4 SPF ~ 90° CCW & 4 SPF ~ 90° CW. 14. .Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsec 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations , X 16. status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. I here~ertify that the foregoing is true and correct to the best of my knowledge. ned '~'~-/~"~ Title Sr. Petroleum Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company ~VELL WELL SERVICE REPORT CONTRACTOR ~_.~O/,~&//.- REMARKS PBDT FIELD- DISTRICT- STATE I DAYS OPERATION AT REPORT TIME IDATE /~-,-73 1-3~ z. Gas Con~ r, .... Anchorag-e' ""',,mission [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather J Temp. Chill Factor J Visibility Report j °F °Fi miles Wind Vel. knots REMARKS CONTINUED: DESCRIPTION DAILY ACCU M. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL /~,~ ~ 1 HALLIBURTON . ARCTIC COIL TUBING . FRACMASTER B. J. HUGHES Roustabouts Diesel Z. Methanol Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE ARCO Alaska, Inc -) Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL CONTRACTOR REMARKS JPBDT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME /~e" r -- . ,. KUPARI. JK,°r:Tt'?OLEUM 0 CT ! 2 Alaska Oil & Gas Cons. I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WelthM' JTmP.Report 'F Chill Factor J VliibilltY. F mlle~ J Wind Vel. REMARKS CONTINUED: · · _ DESCRIPTION DAILY ACCUM, TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRAOMASTER B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE _ _ TOTAL FIELD ESTIMATE' /~ 7.50 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed' Operation Shutdown Pull tubing Alter casing Stimulate X , Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 5. Type of Well: Development Exploratory Stratigraphic 99510 Service 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1282' FNL, 823' FEL, Sec. 33, T13N, R9E, UM At effective depth 1382' FNL, 616' FEL, Sec. 33, T13N, R9E, UM At total depth 1417' FNL, 544' FEL, Sec. 33, T13N, R9E, UM 4. Location of well at surface 12. Present well condition summary Total Depth: measured true vertical 9235' 6851 ' X 6. Datum elevation (DF or KB) 68' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-1§ 9. Permit number/approval number 90-747 feet 10. APl number 50-029-21593 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) None feet Effective depth: measured 91 02' true vertical 6745' feet Junk (measured) None feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical Length 80' 4760' 9189' Size Cemented Measured depth True vertical depth 1 6" 249 Sx CS II 1 15' 1 15' 9-5/8" 1350 Sx AS III & 4797' 3637' 350 Sx Class "G" 7" 300 Sx Class "G" & 91 8 9' 6 81 4' 175 Sx AS I measured 8778'-8799', 6488'-6505', Tubing (size, grade, and measured depth) 8896'-8914', 8920'-8940', 8941'-8946', 8947'-8957' 6582'-6596', 6601 '-6617', 6618'-6622', 6622'-6630' RECEIVED 2 7/8", 6.5# J-55 AB mod. tubing with tail @ 8854' Packers and SSSV (type and measured depth) Brown lB pkr @ 8825'; Brown HB-1 pkr @ 8636'; Baker FVL SSSV @ 1773' 13. Stimulation or cement squeeze summary [~C ~ [t 199 'A' Sand Refracture Stimulation. No kill fluids were used. Actual BHP = 2800 p. si. Intervals treated (measured) Alaska.0Jl & Gas Cons. C0mBisS 8896'-8914', 8920'-8940', 8941'-8946', 8947'-8957' Anchorage Treatment description including volumes used and final pressure 62,500# of 16/20 & 15,500# of 12/18 carbo-lite w/ 1300 bbls. gelled water @ 6200 psi final WHP. i4. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 83 24 1 1100 125 273 221 1 1200 107 1 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as' Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELi: 'RAC. T/OR REMARKS PBDT ]FIELD - DISTRICT - STATE IOPERATION AT REPORT TIME IDAYS j DATE z.- //-2- /7?4 /75-o / 7s'7~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. ! Chill Factor.,I Visibility Wind Vel. Signedp/_.~,/ °F ~ °F! miles, knots '~. ~.-'~/~(~ ~ -- ~: L- ORIGIPIA£ STATE O~ ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 12. Name of Operator Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate Change approved program Pull tubing _ Variance Perforate Other 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Development Exploratory Stratigraphic Service Location of well at surface 1561' FSL, 30' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1282' FNL, 823' FEL, Sec. 33, T13N, R9E, UM At effective depth 1382' FNL, 616' FEL, Sec. 33, T13N, R9E, UM At total depth 1417' FNL, 544' FEL, Sec. 33, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 68' RKB f e e t 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-16 9. Permit number 86-91 10. APl number 5o-029-21593 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 9235' feet Plugs (measured) None 6851 ' feet Effective depth: measured true vertical 91 02' feet Junk (measured) None 6745' feet 13. Casing Structural Conductor Surface Intermediate Prod uction Liner Perforation depth: Length 80' 4760' Size 16" 9 -5/8" 9189' 7" Cemented Measured depth True vertical depth 249 SX. CS II 1 15' 1 1 5' 1350 Sx AS III & 4797' 3637' 350 Sx Class "G" 300 Sx Class "G" & 9189' 6814' 175 Sx AS I measured 8778'-8799' 12 SPF 120° phasing; 8896'-8914', 8920'-8940' 6 SPF 0° phasing; 8941'-8946', 8947'-8957' 1 SPF 90° phasing true vertical 6488'-6505', 6582'-6596', 6601 '-6617', 661 8'-6622', Tubing (size, grade, and measured depth 2 7/8", 6.5# J-55 AB mod. tubing set at 8854' Packers and SSSV (type and measured depth) Brown lB pkr. @ 8825', Brown HB-1 pkr. @ 8636', Baker FVL SSSV @ 1773' Attachments Description summary of proposal _ Detailed operation program ~ Hyd. raulically refracture the A sand. 6622'-663O' BOP sketch 14. Estimated date for commencing operation September 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended Service 17. I here~ certify,~that the. foregoing is true and correct to the best of my knowledge. Signed ~'~ ~. ~ Title Sr. Operations Engr. FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require ORIGINAL SIGNED BY Approved by the order of the Commission Form LONNIE C. SMITH 10-403 Rev 5/03/89 I ~ :,+.. '..: ..... : '.-:,. C.ommiss oner Date~:~] ~ ~r---~O ~ ;~';,* i~ '~" -~;. ~: .~' :':'. ;~.* :' SUBMIT IN TRIPLICATE Approved Copy Returned ..- · ~.~ '.~'~ -,. ,:',,,.., . .~ · :. ;::;:. ~,.' Application for Sundry Approval Kuparuk Well 3N-16 September 10th, 1990 1. The estimated bottom hole pressure is 2800 psig at-6200' ss. 2. No workover fluids will be required for refracturing the well. Kuparuk Well 3N-16 Refracture Treatment STAGE CLEAN VOLUME PROPPANT (BBL) (POUNDS) BREAKDOWN 150 0 PA D 65O 0 CUMULATIVE I I DIRTY VOLUME PROPPANT (LBS) (BBL) 0 150 SHUT DOWN FOR ISIP 0 650 SLURRY 2 PPA 46 3860 3860 50 4 PPA 51 8569 12429 60 6 PPA 55 13950 26379 70 7 PPA 61 17974 44353 80 8 PPA 52 17388 61741 70 10 PPA 28 11660 73401 40 DIRTY VOL (BBL] PERFS @ (BBL) (PSI) 150 53 6800 800 203 6800 850 853 6600 910 903 6300 980 963 6100 1060 1033 5900 1130 1033 5800 1170 1113 5600 FLUSH 25 0 73401 25 1195 26 0 73401 26 1221 TOTAL 1144 73401 1221 VOLUME TO PERFS (BBL) = 53.1 56O0 6400 Proppant: 16/20M Carbo-lite or LWP through 8 ppa stage 12/18M Carbo-lite in 10 ppa stage Pump rate = 20 bpm (drop to 16 bpm if necessary) Estimated surface treating pressure = 4650 psi (includes perf friction) Breakdown = GW + 40 PPT silica flour + 8 hour breaker (cut XL during last 50 bbls.) Pad = GW + 40 PPT silica flour + 8 hour breaker Slurry = GW + 8 hour breaker (no silica flour) Flush = 10 bbls. GW + 8 hour breaker (no silica flour) followed by 41 bbls. of slick diesel Kuparuk Well 3N-16 A Sand Refrac Procedure Cost Tracking AFE: # K81328 Pre Refrac 1. Pull Camco WRDP-SSSV from 1773' MD-RKB. 2. Pull C sand CVs from 8671', 8739', and 8811' MD-RKB and run DVs @ same depths. 3. Pull GLVs from 2502', 5020', 7078', 8236', and 8579' MD-RKB and run DVs @ 2502', 5020', 7078', and 8236' MD-RKB. 4. Displace 7" annulus with diesel. 5. Run Petredat gauge if available (set up to record tubing pressure) @ 8579' MD-RKB. Otherwise, run DV @ 8579' MD-RKB. 6. Set standing valve in 'D' Nipple at 8843' MD-RKB. 7. Pressure test tubing to 2500 psi. 8. Pull standing valve from 8579' MD-RKB. Fracture Treatment Quality Control: 1. Check all tanks for cleanliness and check proppant for fines. uncontaminated. Insure water is 2. Insure adequate proppant and water are on location for the frac. 3. Perform pre-frac quality control tests on gelled water using water which has been delivered to the drill site for the frac. Frac Job: 1. MIRU fracturing equipment. Install tree saver and pressure test all surface lines. . Pressure up 2-7/8" x 7" annulus to 3300 psi. Do not allow this pressure to exceed 3500 psi during fracture treatment. Maximum allowable wellhead treating pressures for each fluid stage of the fracture treatment are shown on the attached pump schedule, assuming an annulus pressure of 3500 psi. . Pump 150 barrel gelled water breakdown stage, shut-down for ISIP, and check for excess friction. Check tank straps against flow meter and correct flush volume as necessary. = Pump fracture treatment per attached schedule starting with a 700 barrel gelled water pad. The following gelled water systems (delayed cross-link HPG based gel) are acceptable for the refracture treatment: Halliburton: Hybor Dowell: YF240D B.J. Titan: TFR II 5. The expected treating pressure is 4650 psi. 6. Bleed down annulus to 500 psi. Rig down fracturing equipment. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 13, 1.987 Transmittal #: 6085 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. 3N-9 Kuparuk Weli Pressure Report (Otis) 9-1-87 3N-16 Kuparuk Well Pressure Report (Otis) 9-2-87 Static 'A' Sand Static Both Sands Receipt Acknowledged: DISTRIBUTION: D&M ~ Naska 0il & Gas Cons. Commission Anchorage BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. Is a Subsidiary of AllantlcRichfleldCompany ARCO Alaska, Inc, Post Offic~ ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 9, 1987 Transmittal # 5914 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. 1H-6' 3N-16 3N-15 CET 7-26-86 4700-6818 CET 6-7-86 7498-9090 CET 6-6-86 6942-8395 Receipt Acknowledged:. DISTRIBUTION: NSK Drilling Mobil Chevron Alaska Oil & Anchorage SAPC Unocal Vault ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompan¥ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 10-20-86 TRANSMITTAL # 5802 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final~Prints: Schl: Open Hole Logs: One * of each 2T-~5" DIL/SFL-GR 05-11-86 Run #1 2" DIL/SFL-GR 05-11-86 Run #1 ~5", Den/Neu (poro) 05-11-86 Run #1 ~2" Den/Neu (poro) 05-11-86 Run #1 ~5" Den/Neu (raw) 05-11-86 Run #1 ~2" Den/Neu (raw). 05-11-86 Run #1 ~Cyberlook 05-11-86 Run #1 3N-1~5" DIL/SFL-GR ~2" DIL/SFL-GR "5" Den/Neu-GR '~2" Den/Neu-GR ~'"5" Den/Neu-GR ~"'~2'" Den/Neu-GR '""Cyberlook 3N-1~'~5'' DIL/SFL-GR ~'~" DIL/SFL-GR ~'~5" Den/Neu ~'-2" Den/Neu ~"~5" Den/Neu -'-2" Den/Neu ~Cyberlook 3N-17~5'' DIL/SFL-GR '~2" DIL/SFL-GR ~'~5" Den/Neu ~2" Den/Neu '~5" Den/Neu "'-2" Den/Neu ~Cyberlook (poro) (poro) (raw) (raw) (poro) (poro) (raw) (raw) (poro) (poro) (raw) (raw) 05-10-86 Run #1 05-10-86 Run #1 05-10-86 Run #1 05-10-86 Run #1 05-10-86 Run #1 05-10-86 Run #1 05-10-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 05-18-86 Run #1 2978-7844~ 2978-7844/ 3340-7818~The API#is incorrect 3340-7818( on these logs. 3340-7818\ It should be 3340-7818I 50-029-20067. 7300-7800~ 4319-8498 4319-8498 7600-8471 7600-8471 7600-8471 7600-8471 7600-8460 4796-9236 4796-9236 8400-9210 8400-9210 8400-9210 8400-9210 8400-9180 05-25-86 Run #1 4607-8998 05-25-86 Run #1 4607-8998 05-25-86 Run #1 8200-8972 05-25-86 Run #1 8200-8972 05-25-86 Run #1 8200-8972 05-25-86 Run #1 8200-8972 05-25-86 Run #1 8350-8950 Receipt Acknowledged: AK*bl~/s~ D & M*bl NSK Files*bl Drilling*bi ~ Rathmel~j~t'~ ~ Alaska 0il & Gas Cons. Commission Vault*f ms~// Anchorage ARCO Alllkl. Inc. il a Subsidiary of Atl,,nticRichfieldComplnY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION 'CCMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, lnc, 86-91 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21593 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 30' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1282' FNL, 823' FEL, Sec.33, T13N, R9E, UM 3N-16 At Total Depth 1 1. Field and Pool 1417' FNL, 544' FEL, Sec.33, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk River 0i 1 Pool 68' RKB ADL 25520 ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No, of Completions 05/12/86 05/17/86 09/01/86* N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey I 20. Depth where SSSV set 21. Thickness of Permafrost 9235'MD,6851'TVD 9102 'MD ,6745 'TVD YES7[~ NO []I 1773 feet MD 1700' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/Cal/GR/FDC/CNL, CET, GCT (gyro) ~3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Ih" 62.5# H-40 Surf 115' 24" 249 sx CS II 9-5/8" 36.0# J-55 Surf 4797' 12-1/4" 1350 sx AS Ill & 350 sx Class G 7" 26.0# J-55 Surf 9189' 8-1/2" 300 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD - interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See Attached 2-7/8" 8847' 8636' & 8825' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached addemJum~ dated 9/10/86, for fracture data 8880' - 8882' 300 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.k 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 ()C"i' 0 9 ,,~-.o 0ii .", Gas Cons. f'.n nr.-~i .... ~'-.:.-;~ ,.., . .-- . .'." _ ,'~' _ Form 10-407 * NOTE: Drilled RR 5/19/86. Perf'd well & ran tubing 7/12/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/122 Submit in duplicat~ _. 29. 30. GEOLOGIC MARKEI~S 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 8724' 6444' NA Base Kuparuk C 8788' 6495' Top Kuparuk A 8884' 6571' B~se Kuparuk A 9012' 6673' 31. LIST OF ATTACHMENTS Addendum (dated 9-10-86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ~ .t~/,I/MU., Title Date I 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 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 3N-16 (cont'd) Perforation Depths: MD TVD 8778' - 8799'* 6487' - 6504' 8904' 6587' 8906 ' 6589' 8908' 6590' 8929' 6607 8931' 6609 8933' 6610 8935' 6612 8941' - 8946' 6617' - 6621 8947' - 8957' 6622' - 6630 * NOTE: Perforated w/12 spf @ 120° phasing All others perforated w/1 spf @ 90° phasing WC1:122b:dmr 10-01-86 ADDENDUM WELL: 6/04/86 6/08/86 9/01/86 9/02/86 3N-16 Arctic Pak well w/175 sx AS I, followed by 175 sx AS I. Rn CET log f/9090-7498'. Rn gyro f/9003'-42'. Frac Kuparuk "A" sand perfs 8904'- 8906', 8908', 8929', 8931', 8933', 8935' & 8941'-8957' in 7 stages per 8/26/86 procedure using gelled diesel, 100 mesh & 20/40 mesh. Press'd ann to 250 psi w/diesel. Tst ins to 8000 psi; OK. Stage #1: Pmp'd 15 bbls gelled diesel pre-pad @ 4.4 BPM, 4170'-4020 psi Stage #2:6 bbls gelled diesel w/1 ppg, 100 mesh @ 4.6 BPM, 4020-3660 psi Stage #3:27 bbls gelled diesel pad @ 4.5 BPM, 3660 psi Stage #4:38 bbls gelled diesel pad @ 20.4 BPM, 6080-6010 psi Stage #5:12 bbls gelled diesel w/756# 20/40 mesh @ 20 BPM, 6010-6100 psi Stage #6:23 bbls gelled diesel w/8 ppg 20/40 mesh @ 20.5-1405 BPM, 6100-6800 psi Stage #7:36 bbls gelled diesel flush @ 12.5 BPM, 6800-6600-7000 psi. Screened out. Bled ann to 500 psi & secure well Pmp'd 300# 100 mesh & 4189# 20/40 in formation leaving 4169# in tbg & csg. Load to recover 157 bbls of diesel. Job complete @ 1446 hrs, 9/1/86. MU Fracmaster CTU, RIH wsh'g out 8 ppg slurry, tag PBD @ 9067' CTU, circ well cln, POH. Displ CT w/6700' of 2-7/8" tbg w/clear diesel, RD Fracmaster. Turn well over to Production. Drilling Supervisor - ~ '~Date\ SUB-SURFACE DIRECTIONAL SURVEY ~]UIDANCE r~ONTINUOUS r~OOL l/oo 4]acka Oil & Gas Cons. Gommi..ssk,, Anchorage Company Well Name Field/Location ARCO ALASKA~ INCROPORATED 3N-16 (1561' FSL: 30' FEL~ S29~ KUPARUK? NORTH SLOPE? ALASKA T13N~ R9E,UM) Job Referenc,e No. 71534 Lo(3{3ed By: WARNER Date 19-JUN-86 Computed By: KRUWELL GCT DiRECTI3NAL SURVEY 'USTOMER LISTINg .~RC3 ALASK&, INC. 3N-16 KUPARUK NORTH SLOPE,ALASKA SURVEY 3ATE: 07-JUN-86 ENGINEER: W&RNER METHO]S 3F C3~PUTATI:]~ T3OL LO'ATI2N: TANGENTIAL- AVERAGED DEVIATION ~ND ~ZIMUTH INTERP3LATZON: LINEAR VE2TIC~L SECTION: iORZZ, gIST. PROJECTED D~TO ~ T~RGET AZIMUTH OF SOUYH 57 DE~ 28 MIN EAST CSqPUT~TI3N DATE: 19-JJN-85 PAGE 1 ARCO ~LAS~A, INC. 3~-16 N3RTH SLOPE,ALaSKA INTERPOLATED VALJES TRUE SJB-SEA MEASURED VERTIC&L VERTICAL DEPTH DEPTH DEPTH CDdRSE DEVI~TIDq AZIWUTH 3EG WIN DEG 0.00 0.00 -58.00 100.00 lO0.OO 32.00 200.00 200.00 132.00 300.00 300.00 232.00 400.00 399.39 331.99 ',O0.Og 499.99 431.99 ~00.00 599.38 531.98 700.00 699.97 531.97 800.00 799.90 731.90 '300.00 899.53 831.53 1090.00 998.47 930.47 llO0.O0 1096.43 1028.43 1200.00 1193.29 1125.29 1300.00 1289.20 1221.20 1400.00 1383.66 1315.66 1500.00 1475.55 1403.65 1600.00 1568.14 1500.14 1700.00 1657.26 1589.26 1800.00 1744.14 1676.14 1900.00 1829.56 1761.56 2000.00 1912.48 1844.48 2100.03 1992.43 1924.43 2200.00 2089.01 2001.01 2300.00 2141.87 2073.87 2400.00 2211.82 2143.82 ~O0.O0 2278.24 2210.24 ~00.00 2342.16 2274.15 2700.00 1405.93 2337.03 2800,00 2466°36 Z39B,96 2900.00 2528.09 2460.09 3000.00 2588.79 2520.79 3100.00 2650.33 2582.33 3200.00 2711.74 2543.74 3300.00 2773.27 2705.27 3400.00 2834.21 2766.21 3500.00 2894.55 2825.55 3500.00 2954.08 2886.08 3700.00 3013.'37 2945.37 3800.00 3072.30 3004.30 3900.00 3130.39 3062.89 0 0 N 0 9 0 11 S 45 35 0 21 S 5.~ 2 0 20 N 81 3O 0 31 N 72 37 0 37 N 82 59 0 40 S 81 17 1 17 S 72 15 3 3 S 64 38 6 33 S 51 22 9 56 S 58 49 12 57 S 54 8 15 40 S 52 46 17 34 S 54 40 20 34 S 55 41 22 25 S 58 53 25 19 S 60 38 28 28 S 5'9 41 30 28 S 58 32 32 26 S 5.8 0 35 31 S 58 12 38 25 S 58 15 41 38 S 58 40 44 33 S 58 52 46 57 S 58 13 49 27 S 57 50 50 48 S 57 51 51 19 S 57 24 52 0 S 57 4 52 37 S 57 3 52 19 S 56 13 52 4 $ 55 1% 52 11 S 54 14 52 8 S 51 3 52 96 S 54 5 53 10 S 54 3 53 33 S 53 58 53 ~2 S 53 55 54 5 S 53 40 54 9 S,53 32 EVEN 100 FEE T O= V:RTICAL DOGLEG SECTION SEVERITY FEET OEG/IO0 0.00 0.15 0.73 1.27 1.81 2.51 3.47 4.88 8.42 15.77 31.17 51.21 75.93 104.15 136.92 173.68 213.95 259.26 308.72 360.72 415.57 476.63 540.90 609.35 6~0.80 755.53 832.44 910.19 98~.71 1067.85 1147.31 1225.0'9 1304.92 1383.61 1462.76 1542.36 1622.56 1702.94 1783.57 1864.42 0.00 0.19 0.13 0.30 0.14 0.20 0.14 1.23 3.07 3.41 3.08 2.31 1.4B 2.89 2.91 2.50 3.75 2.55 1.57 2.75 2.41 3.55 3.07 2.07 3.56 1.92 0.58 1.21 0.80 0.81 1.45 1.05 0.91 0.83 0.57 0.58 0.24 0.70 0.53 1.11 D&TE DF SURVEY: 07-JJN-85 KELLY BUSHING ELEVATION: 68.00 FT ENGINEER: WARNER MEASURED DEPTH RECTANGULAR COORDINATES HDRIZ. OEP4RTURE ND~TH/SOUTH E~ST/WEST DIST. AZIMUTH FEET FEET FEET OEG MIN 0.00 N 0.00 E 0.00 N O 0 E 0.11 S 0.11 E 0.15 S 45 9 E 0.37 S 0.63 E 0.73 S 59 25 E 0.47 S 1.21 E 1.30 S 68 36 E 0.27 S 1.97 E 1.99 S 82 15 E 0.03 S 2.95 E 2.95 S 89 19 E 0.05 S 4.09 E 4.09 S 89 17 E 0.41 S 5.53 E 5.54 S 85 47 E 1.86 S 8.80 E 8.99 S 73 3 E' 5.58 S 16.33 E 17.26 S 71 7 E 12.B0 S 28.80 E 31.52 S 66 1 E 23.82 S 45.55 E 51.40 S 62 23 E 38.74 S 65.35 E 75.97 S 59 20 = 55.50 S 88.14 E 104.16 S 57 48 ~ 74.31 S 115.00 E 136.92 S 57 7 E 94.16 S 14~.94 E 173.58 S 57 10 E 114.14 S 180.97 E 213.96 S 57 45 E 136.69 S 220.32 E 259.28 S 58 11 E 162.04 S 262.82 E 308.76 S 58 20 E 189.45 S 307.01 E 360.76 S 58 19 E 218.98 S 354.42 E 616.61 S 58 17 E 250.50 S 405.49 E 476.68 S 58 16 E 284.24 S 460.26 E 540.96 S 58 18 E 319.62 S .518.89 E 509.43 S 58 22 E 356.92 S 579.84 E 580.89 S 58 23 E 396.46 S 643.26 E 755.62 S 58 21 E 437.41 S 708.35 E 932.53 S 58 18 E 478.86 S 774.15 E 910.28 S 58 15 E 521.37 S 840.16 E 988.78 S 58 10 E 564.43 S 906.57 E 1067.91 S 58 5 E 608.04 S 973.00 E 1147.36 S 57 59 E 552.42 S 1038.13 E 1226.12 S 57 51 E 698.10 S 1102.49 E 1304.93 S 57 39 E 744.33 'S 1166.34 E 1383.61 S 57 27 E 790.81 S 1230.58 E 1462.77 S 57 16 E 837,66 S 1295.11' 5 1542.39 S 57 6 E 884.83 S 1360.15 E 1522.63 S 56 57 E 932.22 S 1425.25 E 1703.05 S $6, 48 E 979.98 S 1490.43 E 1783.74 S 56 40 E 1028.00 $ 1555.70 E 1864.67 S 56 32 E COMPUTATI]N DATE: 19-JJN-8$ PAGE 2 ARCO ALASKA, INC. 3N-16 KdPARUK NDRTH SLOPE,AL&S(A ME~SURE] DEPTH 4030.00 4130.00 4200.00 4300.00 ~%00.00 :00.00 ~500.00 4790.00 4800.00 4900.00 5000.00 5100.00 5200.00 5300.00 5400.00 5500.0g 5500.00 5700.00 5800.00 5900.00 6000.00 6100.00 6200.00 6300.00 64O0.0O =00.00 ,,00.00 6700.00 6800.00 6900.00 7000.09 7100.30 7200.00 7300.00 7%00.00 7500.00 7600.00 7700.00 7800.00 7900.00 TRUE VERTICAL DEPT4 3138.83 3246.09 3302.92 3359.50 3415.54 3471.58 3527.66 3583.70 3639.29 3695.37 3752.07 3809.59 3867.98 3926.78 3987.49 4052.81 4118.30 4185.10 4251.61 %318.55 %386.17 4455.38 4525'.82 4596.49 4667.54 4739.07 4811.06 %883.52 %956.57 5030.33 5104.28 5178.41 5253.16 5329.%2 5406.54 5484.27 5562.05 5540.15 5718.49 5796.87 INTERPOLATED VA LUES FOR EVEN 100 FE:T OF SJB-SEA CDJRSE , VERTI'AL DEVIATION AZIMUTi DEPTH DEG MIN DEG MIN 3120.83 54 54 S 3178.09 55 19 S 3234.92 55 32 S 3291.50 55 %2 S 3347.64 55 51 S 3403.63 55 57 ~ 3459.66 55 57 S 3515.70 56 6 S 3571.29 55 55 S 3627.37 56 4 S 3584.07 55 5 S 3741.69 54 38 S 3799.98 54 9 S 3858.78 53 %9 S 3919.49 50 20 S 3~84.81 48 50 S 4050.80 48 35 S %117.10 48 22 S ~183.61 48 11 S ~250.55 47 ~1 S 2318.17 47 5 S 4387.38 45 26 S %457.82 45 9 S 4529.49 44 53 S 4599.54 44 29 S %671.07 44 10 S 4743.06 43 ~1 S 4815.62 43 15 .S %888.67 42 40 S 4962.33 42 27 S 5036.28 42 13 S 5110.41 41 57 S 5185.16 41 2 S 5261.42 39 07 S 5338.64 39 10 S 5416.27 38 57 S 549~.05 38 53 S 5572.15 38 23 S 5650.49 38 19 S 5728.87 38 26 S 53 7 E 53 1 E 53 2 E 52 59 ; 52 48 E 52 3% ; 52 25 E 52 12 E 51 59 E 52 17 E 52 48 E 53 25 E 54 27 E 55 17 E 55 34 E 55 21 E 57 6 E 57 ~7 E 5B 30 E 59 % E 58 51 E 58 23 ~ 57 50 E 58 38 E 59 15 E 60 43 E 61 17 E 62 21 E 63 3 E 63 4~ E 62 29 E 61 23 E 62 22 E 63 ¢ E 53 38 E 63 59 E 64 9 ~ 54 4 E VERTICAL D3GLEG SECTIDN SEVERITY FEET DEG/IO0 1945.71 2027.44 2109.48 2191.68 Z27%.18 2355.71 2439.26 2521.75 2504.50 2686.94 t768.99 2850.48 2931.59 3012.38 3091.76 3167.41 ]2~2.52 3317.37 3392.05 3466.34 3539.9B 3612.13 3683.09 3753.84 3824.21 3394.07 3963.43 ~032.14 %100.31 4167.74 %23%.78 ~301.52 4367.62 4432.13 4495.46 ~558.24 ~520.74 4682.79 ~744.52 4805.20 0.33 3.29 0.36 0.35 0.55 0.27 0.38 0.44 2.09 0.63 1.85 1.49 0.74 2.00 5.03 1.34 0.88 0.67 0.62 0.63 1.75 0.92 2.42 0.50 0.86 1.80 0.75 1.07 1 0.82 1.12 0.53 2.29 1.21 0.69 0.83 1.11 1.07 0.42 0.93 DATE 3F SDRV'E¥: 07-JJN-85 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: ~ARNER MEASURED D;PTH RECTANDULAR COORDINATES HDRIZ. DEPARTURE NORTH/SOUTH EAST/WEST DIST. ~ZIMU'TH FEET FEET FEET DES MIN 1076.70 S 1621.05 E 1946.04 S 55 24 E 1126.02 S 1686.54 E 2027.89 S 56 16 E 1175.50 S 1752.29 E 2110.05 S 56 8 E 1225.15 S 1818.12 E 2192.38 S 56 1 E 1275.00 S 1884.17 E 2275.02 S 55 54 E 1325.20 S 1950.03 E 2357.71 S 55 48 E 1375.66 S 2015.77 E 2440.44 S 55 41 E 1426.28 S 2081.32 E 2523.~3 S 55 34 E 1477.43 S 2146.84 E 2606.09 S 55 27 E 1528.25 S 2212.21 E 2688.~6 S 55 21 E 1578.43 S 2277.53 E 2771.02 S 55 16 E 1527.53 S 2342.86 E 2852.69 S 55 12 E 1575.27 S 2408.61 E 2933.93 5'55 10 E 1721.90 S 2474.70 E 3014.81 S 55 10 E 1767.09 S 2540.03 E 3094.25 S 55 10 E 1810.48 S 2602.09 E 3169.97 S 55 10 E 1352.61 S 2664.30 E 3245.09 S 55 11 E 1893.81 S 2726.80 E 3319.93 S 55 13 E 1933.98 S 2789.75 E 339~.56 S 55 16 E 1~73.34 S 2852.77 E 3%68.76 S 55 19 E 2011.41 S 2915.83 E 3542.29 S 55 24 E 2048.72 S 2977.60 E 3614.33 S 55 28 E 2085.30 S 3038.43 E 3685.18 S 55 32 E 2122.95 S 3098.34 E 3755.88 S 55 34 E 2160.08 $ 3158.12 E 3826.18 S' 55 37 E 2196,26 S 3217.90 E 3895.96 S 55 41 E 2231.45 S 3277.73 E 3965.21 S 55 45 E 2265.50 S 3337.51 E 4033.79 S 55 49 E 22'98.72 S 3397.18 E 4101.82 S 55 54 E 2330.61 S 3456.82 E 4169.09 S 56 0 E 2361.49 S 3516.64 E 4235.96 S 56 7 E 2391.40 S 3576.72 E 4302.52 S 56 13 E 2421.35 S 3636.01 E 4368.47 S 56 20 E 2452.08 S 3692.93 E 4432.88 S 55 24 E 2%81.94 S 3749.00 E 4496.11 S 56 29 E 2510.84 S 3805.03 E 4558.79 S 56 34 E 2538.86 S 3861.29 E 4621.19 S 56 40 E 2566.24 S 3917.42 E 4583.14 S 56 46 E 2593.37 S 3973.34 E 4744.79 S 56 52 E 2520.41 S 4029.24 E 4806.38 S 56 57 E CJ~PUT~TIDX D~TE: 19-JflN-8$ PqGE 3 ARC9 ALASKA, I~C. 3N-16 KUPARUK NORTH SLOPE,ALASKA TRU~ ME&SURE9 VERTICAL DEPTH DEPTH 8000.00 5875.16 8100.00 5953.4'9 8200.00 5031.71 8300.00 5110.10 ~400.90 5188.55 ~00.00 6267.19 .500.00 $346.11 8700.00 6425.35 8800.09 6504.55 89~0.D0 6583.92 9000.00 6663.51 9100.00 5743.26 9200.00 5823.01 9~35.00 5850.92 INT:RPGLAT;D VALOES FDR EVEN 100 FEET OF SJB-SEA V=RTISAL DEPTH C]'JRS~ V:RTICAc DOGLEG DEVT~TTgN. . ~Z~MJTq~ SECTTON. SEVERITY DEG ~IN DE~3 MI~ FEET 3EG/IO0. 5807.16 5885.49 5963.71 5042.10 5120.65 6199.19 527B.11 5357.35 5436.55 ~515.92 38 25 S 54 5 5 4~.58.01 O.2O 38 32 S 64 lg 5 4'929.76 1.52 38 37 S 64 27 E ~991.51 1.85 38 16 S ~4 15 ~ 5053.26 0.67 38 16 S $~ 8 £ 5114.71 1.52 38 2 S 63 5~ E 5176.21 1.50 37 46 S 53 33 E 5237.25 2.00 37 32 S 63 57 E 5297.88 0.~4 37 31 S 6~ 2 E 5358.54 0.70 37 18 S 54 15 E 5418.96 0.22 5595.51 5675.26 6755.01 5782.92 37 5 S 5& 28 E 5479.09 2.71 37 6 S 64 27 E 5538.97 0.00 37 6 S 64 27 E 559B.~5 O.OO 37 6 S 64 27 E 5619.81 O.OO ME~SURE RE'TAN NORTH/ 2547. 2574. 2701. 2728. 2755. 2782. 2809. 2836. 2863. 2890. 2916. 2942. 2968. 2977. ~TE OF SURVEY: 07-JJN-85 ELLY BUSHING ELEVATION: 58.00 FT ENGINEER: WARNER D DEPTH SULAR COORDINATES HORIZ. DEPARTURE SOUTM EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN 59 S 4085.16 E 4868.14 S 57 3 E 83 S 4141.09 E 4929.84 S 57 8 E ~2 S 4197.23 E 4991.65 S 57 13 E 69 S 4253.21 ~ 5053.28 S 57 19 E 57 S 4308.96 E 511~.?1 S 57 24 E 59 S 4364.60 E 5176.21 S 5? 28 E 84 S 4419.69 E 5237.~6 S 57 33 E 88 S 4474.36 E 5297.90 $ 57 37 E 69 S 4529.20 E 5358.58 S 57 41 E 26 S 4583.92 E 5419.03 S 5? 46 E 56 S 4638.47 E 5479.21 S 5? 50 E 56 S 4692.90 E 5539.13 S 57 54 E 57 S 4747.34 E 5599.07 S 57 58 E 67 S 4766.39 E 5~20.06 S 58 0 E COMPUTATI]N DATE: 19-JJN-85 PAGE 4 ARCO ~LAS~A, I~C. 3N-16 KJP~RUK NORTH SLJPE,AL~$KA INTERmOLATED VALJES FOR :VEN 1003 FEET TRUE SJB-SEA ~E6SURE] VERTICAL V~RTIC~L DEPTH DEPTH DEPTH 0.00 0.00 -6a.O0 lOOO.O0 998.37 930.47 2000.00 1912.%8 1~44.48 3000.90 2588.79 2523.79 4000.00 3188.33 3123.83 '00.00 3752. D7 3684.07 JO0.O0 4386.17 4318.17 7000.00 5104.28 5035.28 8000.00 5875.16 5807.16 9030.00 6663.51 $595.51 COJRSE VERTICAL OOGLEG DEVI6T=ON, AZiMUTq S:CTION SEV:RITY. DEG MIN DEG MIN ;EET DEG/103 0 0 N 0 0 E 0.00 D.O0 9 56 S 58 4~ :: 3~..17 3.08 35 31 S 58 1Z E 415.57 2.41 52 19 S 56 13 E 1147.31 1.46 54 54 S 53 ? E 1945.71 0.3~ 55 5 S 52 48 E 2768.99 1.85 47 5 .S 5~ 4 E 3539.9B 1.75 42 13 S 63 3 = ~234,78 1,12 38 25 S 54 5 E ~868.01 0.20 37 5 S 64 28 : 5479.09 2.71 DATE OF SURVEY: 07-JJN-86 KELLY BUSHING ELEVATION: 58.00 FT ENGINEER: WARNER MEASURE O OEPT RECTANGULAR COORDINATES H]RIZ. DEPARTURE NORTH/SOUTH E~ST/WEST DIST. AZIMUTH mEET FEET FEET DEG MIN 0.00 12.80 218.9~ 508.0~ 1076.70 1578.43 2011.~,1 2361.49 2547.69 2~16.56 N 0.00 E O.O0 N O 0 E S 28.80 E 31.52 S 66 1 E S 354.~2 E 416.61 S 58 17 E S 973.00 E 1147.36 S 57 59 E S 1621.05 E 1946.04 S 55 24 E S 2277.53 E 2771,02 S 55 16 E S 2915.83 f 3542.29 S 55 24 E S 3516.64 f 4235.96 S 56 7 E S 4085.15 E 4868.14 S 57 3 E S 4638.47 E 5~79.21 S 57 50 E 9235.00 6850.92 5782,92 37 6 S 64 27 E 5619.81 0.00 2977.67 S' 4766.39 E 5620.06 S' 58 0 E C3MPUT~TZDN DATE: 19-JJN-86 PaGE 5 A~CO ALASKA, INC. 3N-16 KUPARUK NORTH SLOPE~AL&SKA INTERPOLATED VALJES =DR EVE~ 100 FEET TRUE SJE-S=A ME&SURE3 VERTIC&L VERTICAL 35PTd DEPTd DEPTH 0.00 0.00 -58.00 58.33 68.00 0.00 158.00 168.00 100.00 255.00 268.00 200.00 358.01 368.00 300,00 ;58.01 468.00 400.00 568.02 568.00 500.00 558.03 668.00 50D.O0 758.36 768.00 700.00 858.29 868.00 800.00 959.11 958.00 90].00 1070.85 1068.00 1000.00 1173.75 1168.00 110D.00 1277.79 1258.00 1200.00 1383.30 1368.00 1300.00 1490.64 1468.D0 1403.00 1599.8G 1568,00 1500,00 1712.24 1668.00 1600.00 1827.74 1768.00 1700.00 1945.92 1868.00 1800.00 2059.03 1968.00 190g.00 2198.65 2068.00 2000.00 2336.87 2168.00 2100.00 2484.28 2268.00 2200.00 2641.90 2368.00 2300.00 '~01.69 2468.00 2403.00 )55.87 2568.00 2500.00 3128.77 2568.00 2600.00 3291.43 2768.00 2700.00 3655.85 2868.00 2800.00 3523.45 2968.00 2900.00 3792.67 3068.00 3000.00 3953.83 3168.00 3100.00 4138.49 3268.00 3200.00 4315.10 3368,00 3309.00 4%93,42 3468.00 3409,00 4571,89 3568.90 3509,00 4851.09 3668.00 3609.00 5027,73 3768.00 3700.00 5200.0G 3868.00 3800.00 COORS= VE~TISAL DOGLEG DEVI&TION AZIMUTH SECTION SEVERITY ]EG MIN DES MI~ FEET DEG/IO0 0 0 N 0 0 E 0.00 D.O0 0 7 S 53 13 E 0.06 0.27 0 23 S 65 53 E 0.52 0.07 0 19 S 35 21 E 1.13 0.28 0 28 N 72 33 E 1.63 0.11 0 35 N 7:3 39 E 2,26 0,15 0 40 S 85 7 E 3.13 0.19 0 55 S 75 10 5 4.29 1.02 2 15 S 64 23 E 6.97 1,50 5 29 S 63 14. E 13.45 3.92 8 56 S 59 40 E 25.12 2.59 12 22 S 55 31 E 44.81 3.45 15 6 S 52 37 E 68.95 2.97 16 56 S 54 13 E 97,57 3.16 20 B S 55 12 E 131.11 2.63 22 13 S 58 28 E 170.12 2.73 25 19 S 50 38 E 213.89 3.74 23 48 S 59 35 E 265..12 2.81 30 50 S 58 17 E 322.87 1.34 33 ~9 S 5B 3 E 385.82 2.79 37 30 S 55 '15 E 457.59 3.15 41 35 S 53 40 E 540.00 3.19 45 13 S 58 39 E 535.36 2.32 49 8 S 57 54 E 743.62 2.17 51 0 S 57 55 E 864.27 0.43 52 1 S 57 6 E 990.04 0.81 52 34 S 56 3~ E 1120.25 1.23 52 3 S 54 51 E 124~.77 1.47 52 .5 S 5~ 2 E 1376.86 0.72 52 53 S 53 59 E 1507.15 ~.50 53 36 S 53 :59 E 1641.40 0.32 54 2 S 53 39 E 1777.64 0.81 5~ 39 S 53 12 E 1916,22 1.12 55 17 S 53 2 E 2058.99 0.49 55 66 S 53 0 E 2204.12 0.59 55 56 S 52 3~ E 2351'27 0.35 56 2 S 52 17 E 2498.52 0.32 55 56 S 52 9 E 2645.58 0.88 54 51 S 52 58 ~ 2791.61 0.81 54 9 S 5~ 27 E 2931.62 DATE OF SURVEY: 07-JJN-85 KELLY ~USHING ELEVATION: 68.00 FT ENGINEER: WARNER SUB-SEA DEPTH RECTANGULAR COORDINATES H]RIZ. DEPARTURE NORTH/SJUTH EAST/NEST DIST. AZIMUTH FEET FEET FEET DEG MIN 0.00 N 0.00 E 0.00 N 0 0 E 0.05 S 0.05 E 0.06 S 44 43 E 0.29 S 0.44 E 0.52 S 56 38 E 0.48 S 1.03 E 1.1~ S 64 55 E 0.35 S 1.71 E 1.74 S 78 19 E 0.09 S 2.62 E 2.62 S 88 2 E 0.01 S 3.71 E 3.71 S 89 52 E 0.23 S 4.94 E 4.95 S 87 17 E 1.23 S 7.48 E 7.58 S 80 39 E 4.03 S 13.38 E 13.97 S 73 14 E 10. 20. 34. 51. 71. 92. 114. 139. 169. 202. 22 S 24.46 E 26.51 S 67 18 E 11 S 40.31 E 45.05 S 63 29 E 49 S 59,78 E 69,02 S 60 1 E 57 S 82.77 E 97.57 S 58 I E D1 S 110.22 E 131.11 S 57 12 E 31 S 142.90 E 170.13 S 57 8 E 11 S 180.91 E 213.89 S 57 45 E 66 S 225.38 E 265.15 S 58 12 E 47 S 274,87 E 322.91 S 58 20 E 75 S 328,29 E 385,86 S 58 18 E 240. 283. 333. 390. 454. 522, 593, 665. 740 · 816. 58 S 389.30 E 457.64 S 58 17 E 77 S 459.49 E 540.05 S 58 18 E 11 S 541.13 E 635.44 S 58 23 E 12 S 633.17 E 743.71 S 5;3 21 E .32 S 735.33 E 864.36 S 58 17 E 09 S 861.28 E 990.11 S 58 10 E 05 S 950.46 E 1120.30 S 58 2 E 42 S 1055.74 E 1248.79 S 57 48 E 36 S 1'160,87 E 1376,86 S 57 28 E 94 S 1266.56 E 1507.17 S 57 10 E 895. 976. 1058. 1145. 1232. 1321. 14.12. 1503. 1592. 1575. 92 S 1375.41 E 1641,47 S 55 55 E 66 S 1485.64 E 1777.81 S 56 41 E 97 S 1597.38 E 1916.51 S 55 27 E 05 S 1711.~2 E 2059.48 S' 56 13 E 55 S 1828.08 E 2204.84 S 56 0 E 89 S 1945.70 E 2352.26 S 55 48 E O1 S 2062.87 E 2699.84 S 55 36 E 62 S 2180.17 E 2548.29 S 55 24 E i1 S 2295,63 E 2793,70 S 55 15 E 29 S 2408.64 E 2933.96 S 55 10 E CO~PUTATIDN DATE: 19-JJN-$5 6 ARCO ALASKA, I~C. 3N-16 NORTH SLOPE,ALASKA PAGE DATE OF SJRVEY: 07-JJN-86 KELLY 5USHIN$ ELEVATION: ENGINEER: WARNER 6~.00 FT INTERPOLATED VALUES FOR :VEN 100 FEET OF SUB-SEA OEPTH TRUE SJB-SEA COURSE VERTICAL DOGLEG RE'TANSULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTI'AL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. &ZIMUTH DEPTH OEPT~ DEPTH DEG MIN DEG MIN FEET D;G/IO0 5358.84 3968.00 2900.00 52 6 5523.03 4058.00 4000.00 48 ~2 5674,25 4168.00 ~100.00 48 26 5324.55 4268.00 4200.00 48 3 ~973,22 4368.00 ~300,00 47 20 117.97 4468.00 ~03.00 45 ~259.79 4568.00 4500.00 44 57 6400,65 4669.00 4500.00 44 28 65~0,26 4768,00 4702.00 6618,50 4868.00 ~800,00 43 26 5815.39 ¢968.00 4900.00 42 37 6~50.99 5068.00 ~000,00 42 20 7085.99 5168.00 5100.00 42 3 7219.61 5268.00 5209,00 7350,09 5368.00 5300.00 39 25 7479,08 5468.00 5400,00 39 0 76D7.55 5568.00 5500.00 38 55 7735.59 5668.00 5600.00 38 28 7863.15 5768.00 5700.00 38 20 7990.85 5868.00 5800.00 38 25 8118.52 5968.00 5900.00 38 25 82~6.2~ 5068.00 5000.00 38 27 8373.74 6168.00 610~.00 38 12 ~501.04 6268.00 '5200.00 38 1 8527.59 5368.00 5300.00 37 30 ~753.85 5468.00 5400.00 37 38 J79.97 5568.30 5500.00 37 24 ~005.63 6668.00 560~.00 37 6 9131.03 5768.00 5700.00 37 6 9235.00 6850.~2 5782.92 37 6 S 55 15 5 3067.47 S 55 41 E 3184.72 S 55 ~? E 3298.12 S 57 50 E 3410.34 S 59 3 ~ 3520.32 S 59 0 E 3624.92 S 57 46 E 3725.46 S 5~ 38 5 3824.66 S 59 19 E 3922.04 S 50 34 E 4017.41 S 5t 22 E 4110.71 S 52 44 E %201.97 S 63 44 E 4292.21 S 52 5 E g380.39 S 61 57 E g463.98 S 62 55 E g545,15 S 63 39 E ~625.52 S 6¢ 7 E 470~.80 S 64 15 E 4783.45 S 54 4 E %~62.36 S 64 15 E 4941.19 S 64 21 E 5020.15 S 54 20 E 50'98.59 S 63 55 E 5176.84 S 63 24 E 5253.95 S 63 5~ E 5330.56 S 64 15 E 5405.89 S 64 27 E 5482.46 S 54 27 E 5557.55 S 5~ 27 E 5619.81 4.35 0.60 1.30 :].32 0.6~ 1.24 0.97 0.82 0.70 1.21 0.84 0.20 1.03 2.25 0.85 0.79 0.81 0.76 0.68 0.73 0.87 1.40 1.57 2.33 1.50 0.70 0.00 O.OO 3.00 FEET FEET FEET DEG MIN 1753.20 S 2520.08 E 3069.94 S 55 10 E 1820.24 S 2616.38 E 3187.28 S 55 10 E 1383.31 S 2710.65 E 3300.69 S 55 12 E 1943.?1 S 2805.23 E 3~12.82 ~ 55 16 E 2001.31 S 2898.95 E 3522.66 S 55 22 E 2D55.33 S 2988,56 E 3627.10 S 55 28 E 2107.80 S 3074.34 E 3727.52 S 55 33 E 2160.32 S 3158.51 E 3~26.63 S 55 37 E 2210.54 S 3241.98 f 3923.89 S 55 42 E 2258.27 S 3324.64 E 4019.09 S 55 48 E 2303.72 S 3406.32 E 4112.19 S 55 55 E 2346.43 S 3487.32 E 4203.23 S 5~ 3 E 2387.26 S 3568.31 E 4293.23 S 56 13 E 2427.30 S 3647.36 E 4381.22 S 55 21 E 2~67.18 S 3721.07 E 4~64.68 S 56 27 E 2504.87 S 3793.31 E 4545.72 S 55 33 E 2541.00 S 3865.59 E 4525.96 S' 56 40 E 2575.93 S 3937.35 E 4705.12 S 5& 48 E 2610,44 S 4008.62 E 4783,66 S 56 55 E 2545.20 S 4080.04 E 4862.50 $ 57 2 E 2679.82 S 4151.45 E 4941.26 S 57 9 E 2714.28 S 4223.14 E 5020.18 S 57 16 E 2748.51 S 4294.34 E 5098.60 S 57 22 E 2782.97 S 4365.18 E 5176.84 S 57 28 E 2817.34 S 4434.?1 E 5253.96 S 57 34 E 2851.36 S 4503'88 E 5330.59 S 57 39 E 2884.98 S 4572,97 E 5406.96 S' 57 45 E 2918.02 S 4641.53 E 5~82.57 ' S 57 50 E 2950.63 S 4709.79 E 5557.73 S 5? 55 E 2977.67 S 4755.39 E 5620.06 S 58 0 E ARCO ALASKA, l~C. 3~-16 KJPARJK N3RTH SLgPE,ALASKA MARKER TOP KUPARUK ' BASE KUPARUK C TOP ~UPARUK A BASE KUPARUK A PBTD TO C3,~PUTATI ]N INTERPCLATED VALdES F3R ~EASURE3 DE~TH BELOW KB 8724.00 8788.00 8884.00 9012.00 9102.00 9235.00 OAT=_: 19-JJN-~6 -HDS=N H3RIZDNS 3RIGIN: FROM KB 6444.38 6495.04 6571.21 56?3.08 6744.$5 6850.92 1561 SJB-SEA 5375.38 5~27.04 6503.21 5505.08 6576.85 5782.92 PAGE 7 DATE OF SURVEY: 07-JJN-86 KELLY BUSHING ELEVATION: 58.00 ENGINEER: WARNER :SL, 30 SURFASE LOCATIgN FEL, SEC 29, T13N, RUE, RECTANGULAR COORDINATES NORTH/SgUT~ EAST/WEST 28~3.31 S ~487.69 E 2~60.~8 S 4522.62 E 28~6.0~ S 4575.1B E 2919.68 S 4644.99 E 29~3.08 S 4593.99 E 2977.67 S 4756.39 E FT dM COMPUTATI3q DATE: 19-JJN-$5 PAGE 8 3N-16 KUPARU( N3RTH SL3PE,ALASKA TOP BASE TOP BASE PBTD TD MARKER KUPARUK ~ KUPARUK C KUPARUK A KU>ARUK A ~EASJRED DEPTH BELOW KB 8?24.02 87BB.O0 8884.00 9012.00 9102.00 9235.00 DATE 3F SURVEY: 07-JJN-85 KELLY BUSHING ELEVATION: 5B.O0 FT ENGINEER: WARNER SUMMARY "' ~=X~, ~ .... ~ ...... '~'~ FROM ORIGIN= 1561 TVD KB SUB-SEA FSL, SJ 30 FEL, RECTA WORT RFACE LOCATION SEC 29, T13N, RDE, NSULAR COORDINATES H/SOUTi EAST/WEST 5444.38 8495.04 5571.21 5673.08 6744.85 6850.92 8378.38 5~27.04 5503.~1. 5605.08 5676.85 5782.92 284 285 288 291 294 297 3.31 S 4~,87.~,9 E 0.48 S 4522.62. E 6.04 S 4575.18 E 9.68 S 4,544.99 E 3.08 S 4693.99 E 7.67 S 4766.39 E 3M FINAL WELL LOCATI3N AT TD: TRUE SiS-SEA MEASJRED VERTICAL V~RTICAL DEPTH DEPTH DEPTH 9235.00 5850.92 5782.92 ~DRIZONT&L ]EPARTURE DISTANCE AZIMUTH FEET ]EG MIN 55Z0.05 S 58 0 E SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL F I ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOEO 07 - dUN - 88 REFERENCE 000071S34 WELL' 3N-16 (1561' FSL, 30' FEL, S29, T13N, R9E,UM) · VERTICAL PROJECTION - ~ ooo o o I o00 2o00 ~o00 4000 SOOO Sooo ?ooo ..+-~-+-?..-?~..++..,.+++ .... ]]~ ......... ~L.~-~ ..... ~ ~ ~ ~ ..... ~4---~ ..... ~ ..... ~ .... '-Y~"T"~' "g'~'"T"F"'~.. ~. 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Comm,~oio:~' Ancfiora~o WELL' (1561' , 3N-16 FSL, 30' FEL, S29, T13N, R9E,UM) HORIZONTAL PROJECTION NORTH 2000 1000 - ! 000 -2000 -9000 -4000 SOUTH -SO00 WEST REF 0000"/IS94 SCALE = 1/1000 IN/FT -t-T-'Sm'' ..-T-K: i i ; ~ ;'T- ;= ; i ~ j i ; i i i ..' t ..'r~ -.'.-f-.-j-.'P-~. i i .~-+--' :'h' ~ [ ! i-,~-..~--.' '.,--,---~-~-,. :.,.--.~:~4-- '"T" rTT'--*.,--.,.-?-t- T'?"?'-:-'.'.*"~-? ~-'?"T"? .... .?'-~T "T... TT'T.' -':"r-?-T-t-' Tr~---?'t-.f'T" -i.;'"f'?f"l-..'h'~-i'?'-"~i"-;"-"t'".'k' ~.: -f'i" .+"~--F-f--..'H- :Z:Li.-4-'.. i ~--~-i.-iii 'F'TT-T! !! ~ ii iLL~i-L !! !!- ii iJL~ H -TTTT' '~*'"fm-.-r",7',.'FT-'~ .... 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L.L..L..i_.L.~,..i..L..L..-"... s.-i...i-.!--.h-!.-i---i--x--~..i-i.-!-.i+i.--i ....... !-..¢+.i.!-.i---f--i---i--~--~--H+-J.-!--i--i--~-.-i--f-.i+i--~-i-.-i.-+--~--!--i--14-+-~----i---i--.!--t-+-~--i--~-+~---~---f-{-~--i.-~--.f--f--f.i---f-i--.i-- ...i..~ 4 ..'L.,...i..; ~ ! ~_L.~ ..... L L ~ ~ ...L_L..~.; i. ~ ~ ~-..~ ...... L.L_L.i ~ L.L..L..~ .... ; ;.~,':--.L-~--~.--~.-~ ..... ~ .i_.L..L..~...L.i_L.~..i ....... 4...;...~ ...... ;...~...~...; ....... ~...;.-~..., ..... ~...;.-.~-..~ ....... ~...~...;.-.;...'.-;---~-..~...~ ...4...,..-~...~-.- -~-4...;...~.. -.4...;.--;.--¢...1.-~-,-.,...,....4...~..4-~...~...~.. ....... ~"~'"N' i ~..-i.-.~.-k-~-'i.~..~.i-.-5-~---f-'~. ..... f?f"f"i'-'i-'f-~--!-'i-'!"'f-'-!--'~"[±'f-'f"¢ ...... ~'-'~-'-f-i--i?-f-'f-'¢'l'"+'-'f -2000 - 1000 0 1000 2000 9000 4000 SO00 6000 STATE OF ALASKA ALAS,.,-~ OIL AND GAS CONSERVATION COM .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ,~ Perforate }E Pull tubing Alter Casing ~ Other ~ Comp'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. 4. Location 1561 At top of 1282 Box 100360 Ancnoraqe, AK 99510 of well at surface 'FSL, 30'FEL, Sec.29, T13N, RgE, UH productive interval ' FNL, 823'FEL, Sec.33, T13N, RgE, UM At effective depth 1382'FNL, 616'FEL, Sec.33, T13N, RgE, UH At total depth 1417'FNL, 544'FEL, Sec.33, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 68 ' 6. Unit or Property name I~,oar,,l~ R~v~r llnif 7. Well number 3N-16 8. Approval number 151 9. APl number 50-- 029 -21 593 10. Pool Kuparuk River Oi 1 Pool Fee~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Ca~sing, conouctor Surface Length 80' 4760' 9189' Production 9235 feet 6851 feet feet 9102 feet 6745 Plugs (measured) None Junk(measured) None Size Cemented Measured depth 16" 249 sx CS I I 115'MD 9-5/8" 1350 sx AS Ill & 4797'MD 350 sx Class O 7" 300 sx Class G & 9189'MD I 75 sx AS I True Vertical depth 115'TVD 3637 'TVD 6814 ' TVD 'Perforation depth: measured true vertical (see attachment) (see attachment) ~bing(size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8847' Packers and SSSV (type and measured depth) HB-1 pkr (~ 8636', lB pkr ~ 8825', & FVL SSSV t~ 1773' RECEIVED AUG- ]986 12. Stimulation or cement squeeze summary Intervals treated (measured) 8880' - 8882' Treatment description including volumes used and final pressure 300 sx Class G cmt Alaska Oil & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History w/Addendum, dated 6/11/86) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~;~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-8~ Title Associate Engineer (DAM) SW0/076 Date Submit in Duplicate REPORT OF SUNDRY WELL OPERATIONS 3N-16 (cont'd) Perforation Depths: MD TVD 8778' - 8799 6487' - 6504' 8904 6587' 8906 6589' 89O8 6590' 8929 6607' 8931 6609' 8933 6610 ' 8935 661 2 ' 8941' - 8946 6617' - 6621' 8947' - 8957 6622' - 6630' RECEIVED SWO/O76a:tw AUG- .1 1986 Alaska 011 & 6as Cori~,, Commls~io.~ Anchorage Well History - Initial Report - Daily ARCO Oil and Gas Company Instructions: Prepare and submit the "initial Report" on the first Wednesday after a weil is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1231 Nordic 4 Operator ARCO Alaska, ' Inc. ___ Nort____~ Slop_~ Borough ADL 25520 mp let Ion IState Alaska IWell no. 3N-16 API 50-029-21593 7/7/86 w.I. -- IPrior stat--'us if a W.O. 0200 hrs. ~ 56.24% Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. Complete record for each day reported 7/07/86 7" @ 9189' 9102' PBTD RIH tO perf f/squeeze 9.9 MIRU Koll'N 4. Accept ri~ @ 0200 hrs., 7/7/86~. ND tree. NU - . BOPE & test. RIH w/squeeze gun to perf 8880'-8882' 7/08/86 7" @ 9189' POH w/3-1/2" DP 10.0 NaC1/BR RIH & Perf 8880'-82', POH RD SOS. RIH w/R-3 Pkr set @ 8629' est ins rate @ 2 BPM. 2800 PSI. RU Dowell & squeeze w/150 sx Class G cmt. Reverse out. POH w/3-1/2" DP. 7/09/86 7" @ 9189' POH w/6-1/8" bit 10.0 NaC12/Br POH w/R-3 pkr. WOC. RIH w/6-1/8" bit & 7" scrpr, tag cmt @ 8721', drl soft cmt f/8790'-8901'. Att to tst; sqz did not tst. POH w/3½" DP. 7/10/86 7" @ 9189' 10.0 NaC12/Br RIH, set sqz pkr @ 8629'. M&P & sqz 150 sx cmt, POH. bit & scraper on D.P. RIH to 8152'. WOC. 7/11/86 7" @ 9189' 9.8 ppg NaC1 RIH, drl cmt f/8585'-8882' Tst perfs to 2000 psi; OK. · Clean out to PBTD @ 9078' WLM. Filter brine, POH, LD DP. RECEIVED AUG- i 1986 Alaska 0il & Gas Cons. Commission Anchorage The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ~ [ Title Drilling Supervisor 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 test is not 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 Alaska Field Kuparuk River Auth, or W.O. no. AFE AK123 l Nordic 4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m. 7/12/86 County or Parish Lease or Unit ITte North Slope Borough ADL 25520 Accounting cost center code State Alaska Completion API 50-029-21593 Well no. 3N-16 A.R.Co. W.I. 56.24% Date 7/7/86 Complete record for each day reported I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our IPrior status if a W.O. I 0200 hrs. 7" @ 9189' 9078' WLM PBTD, RR 6.8 ppg Diesel RU Schl, perf w/4 SPF 90° phasing f/8947'-8957' f/8941'-8946', & w/1SPF 8904', 8906', 8908', 8929', 8931', 8933' & 8935'. Perf w/5" gun, 12 SPF, 120° phasing f/8798'-8799' & 8778'-8298'. Make gage ring/JB rn to 8880'. Set WL pkr @ 8895'%w~D Schl. Rn 280 jts, 2-7/8", J-55, 6.5#, 8RD AB Mod tbg w/SSSV @ 1773', HB-1 pkr @ 8636', lB pkr @ 8825' & TT @ 8847'. Tst pkr; OK. ND BOPE, NU & tst tree; OK. Displ well to diesel. Set BPV. RR @ 1500 hrs, 7/12/86. RECEIVED AUG- 1 !986 Alaska 0il & Gas Cons, Commission Anchorage Old TD New TD 9078 ' ?B'~ Released rig Date 1500 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data PB Depth Kind of rig 7/12/86 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Rotary 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/~ . A ~. · For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. DateI~ ~1/~'~j JTitle Drilling Supervisor ADDENDUM WELL: 6/04/86 6/08/86 3N-16 Arctic Pak well w/175 sx AS I, followed by 175 sx AS I. Rn CET log f/9090-7498'. Rn gyro f/9003'-42'. Anchoraoe Drilling Supervisor Date ARCO Alaska, Ir-, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 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. return one signed copy of this transmittal. DATE 05-27-86 TRANSMITTAL # 5676 Please acknowledge receipt and Open Hole LIS Tape plus Listing: Schl: One copy of each 3N-16 05-18-86 .... 3N-15 05-10-86 .... 2T-14 05-03-86 ---- 2T-13 05-11-86 Run #1 1-990~5-9269.0 Run #1 2186.5-8523.0 Run #1 7600.0-8215.5 Run #1 1491.0-7878.0 Open Open Open ~,laska Oil ~ G~s Cor~s. Commission Anchorage Receipt Acknowledged: Date: State of Alaska* · ~13t't% AIt.k. I,',," i. · ~.hlii'iiJIl'V A! AIIinlicRichfilldComDIn¥ STATE OF ALASKA ALASN,, OIL AND GAS CONSERVATION COMN..,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend - Operation Shutdown/~ Re-enter suspended well ~ Alter casing . Time extension i% Change approved program-~ Plugging © Stimulate ~ Pull tubing- Amend order '-: Perforate '- Other ' 2. Name of Operator ARCO Alaska, Inc 3. Address 4. Location of well at surface 1561' FSL, 29' FEL, Sec. 29, T13N, R9E, UM ~ 5. Datum elevation (DF or KB) 68' RKB 6. Unit or Property name L/,,~ ~ ,,1¢ N-I~ At top of productive interval 8. Permit number 1289' FNL, 840' FEL, 5ec.33, T13N, R9E, UM (approx) 86-91 At effective depth 9. APl number 1288' FNL, 561' FEL, Sec.33, T13N, R9E, UM (approx) 50-- 029-21593 At total depth 10. Pool 1320' FNL, 487' FEL, Sec.33, T13N, R9E, UH (approx) Kuparuk River 0il Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 9235 ' feet Plugs (measured) None feet 6850' feet Junk (measured) 9102 ' feet None 6744' Casing Length Size Conductor 80' 16" Surface 4760' 9-5/8" Production 9189' 7" Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Cemented Measured depth 249 sx CS II 1350 sx AS Ill& 350 sx Class G 300 sx Class G True Vertical depth 115' MD 115' 4797'MD 2598' 9189'MD 6813' VD VD VD 12.Attachments Well Hi story Description summary of proposal rq.. Detailed operations program r- BOP sketch 13. Estimated date for commencing operation July, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (/~U¥,J' ~/U~t,.~' Title Associate Engineer Date Commission Use Only Conditions of approval Plug integrity ~ BOP Test ~ Location clearance Approved by ......... ~-'C'ommissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on Ihe first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding shouJd be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1231 Doyon 9 Operator ARCO Alaska, Inc. ICounty. parish or borough North Slope Borough Lease or Unit ADL 25520 Title Drill API 50-029-21593 IDate 5/12/86 IHour 0045 hrs. IState Alaska JWell no. 3N-16 ARCO W.I. Pr or sta us if a W.O. Spudded or W.O. begun Spudded 56.24% Date and depth as of 8:00 a.m. 5/11/86 thru 5/12/86 5/13/86 5/14/86 5/15/86 5/16/86 Complete record for each day reported 16" @ 115' 698', (583'), Drlg Wt. 9.3, PV 19, YP 21, PH 9.5, WL 14.2· Sol 6 Accept rig @ 2230 hfs, 5/11/86. NU diverter. 5/12/86. Drl 12¼" hole to 698'. Spud well @ 0045 hrs, 16" @ 115' 2718', (2020'), Drlg Wt. 9.3, PV 14, YP 12, PH 8.5, WL 11.2, Sol 8 Drl & surv 12¼" hole to 2718'. 498', .7°, S73.5E, 497.99 TVD, 2.92 VS, 832', 3.9°, S70.7E, 831.82 TVD, 10.16 VS, 1196', 15.3°, S51.1E, 1189.92 TVD, 71.69 VS, 1728', 28.9° 2429', 47.9° .86S, 2.92E 1.53S, ll.08E 32.71S, 64.18E , S59.2E, 1683.02 TVD, 267.89 VS, 140.56S, 228.09E , S56.9E, 2233.01TVD, 697.27 VS, 370.17S, 590.92E 9-5/8" @ 4797' 4817', (2099'), Rn'g 9-5/8" csg Wt. 9.5, PV 15, YP 9, PH 8.0, WL 8.4, Sol 9 Drl & surv 12¼" hole to 4817', short trip, CBU, POOH. RU & rn 9-5/8" 2748', 52.0°, S58.5E, 2438.22 TVD, 941.39 VS, 500.62S, 797.27E 3315', 52.2°, 854.7E, 2784.92 TVD, 1389.94 VS, 745.29S, 1173.24E 4261', 55.7°, S54.4E, 3341.85 TVD, 2153.59 VS, 1186.26S, 1797.74E 4784', 56.5°, S53.3E, 3633.67 TVD, 2586.58 VS, 1444.13S, 2146.83E 9-5/8" @ 4797' 5288', (417'), Drlg Wt. 8.6, PV 11, YP 7, PH 10, WL 13.6, Sol 2 Fin rn'g 120 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 4715', FS @ 4797'. Cmt w/1350 sx AS III w/10#/sx Gilsonite & 350 sx Cl "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. ND diverter. NU & tst BOPE. TIH, tst csg to 2000 psi. DO flt equip + 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 5288'. 5169', 54.7°, S55.1E, 3851.17 TVD, 2903.71VS, 1629.94S, 2404.46E 9-5/8" @ 4797' 7998', (2710'), Drlg Wt. 9.9, PV 17, YP 5, PH 9.0, WL 7.2, Sol 10 .. Drl & surv 8½" hole to 7998'. ~..~ 5436', 49.3°, S57.1E, 4015.49 TVD, 3113.96 VS, 1747~,..2~$~'2579.J02~'~ 6255', 45.3°, S60.4E, 4566.36 TVD, 3719.40 VS, 2057.37S, 3099.33~.~-- 6909' 42.4° S63.1E, 5036 77 TVD, 4172.78 VS 2278.8~S[?.~9~}.1~4~/''-~: · , ~ · ~ '-_.~' , '.~ . csg. The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor AR(~O 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 test is not required upon completion, raped completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the 6ntire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O, no. AFE AK1231 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 5/17/86 thru 5/19/86 County or Parish Lease or Unit ITte 5/20/86 Old TD Released ng North Slope Borough ADL 25520 Drill API 50-029-21593 A.R.Co. W.I. 56.24% Date 5/12/86 Accounting State Complete record for each day reported Iotal number of wells (active or inactive) on thisI est center prior to plugging and I bandonment of this well our Prior status if a W.O. 0045 hrs. 9-5/8" @ 4797' 9235', (1237'), Displ'g cmt Wt. 9.9, PV 20, YP 9, PH 8.5, WL 4.2, Sol 10 Drl & surv 8½" hole to 9235', short trip, CBU, POOH. RU & rn DIL/SP/SFL f/9235'-4795', GR f/9235'. Rn FDC/CNL f/9235'-8400', CAL f/9235'-4795'. RD Schl. Make cond'g trip. Chg rams to 7" & tst. RU & rn 223 its 7", 26#, BTC csg & 1 mkr jt 26#, w/FS @ 9189'. Cmt w/lO0 sx 50/50 C1 "G" w/4.0% D-20, .2% D-46 & .5% D-65. Tail w/200 sx C1 "G" w/3% KCl, .9% D-127, 3% D-13 & .2% D-46. Displ using rig pmps. cost center code Alaska 7" @ 9189' 9235' TD, 9102' PBTD, RR 10.0 ppg Brine Displ cmt w/10.0 ppg brine, bump plug. Chg rams to 7". BOPE, instl packoff & tbg head. Tst flange to 3000 psi. 1100 hfs, 5/19/86. RR @ IWell no. 3N-16 New TO I PB Depth 92325' TD I 9102' ?BTD Date Kind of rig 1100 hrs. 5/19/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time iProduction 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor MEMO.RAMDUM TO: TH RU: FROM: Stat', of Alaska ALASKA OIL ,~-~D GAS CONSERVATION CO},-R:iISb-ON Co. V. (Ih n. DATE: Hay 21, 1986 Chairman~NX----~ FI LE NO.: D. EWS. 18 Lonnie C. Smith "~/~ii.~ ~} Commissioner Edgar W. Sipple Petroleum Inspector TELEPHONE NO.' SUBJECT: BOP Test ARCO KRU 3N- 16 Permit No. 86-90 Kuparuk River Field Wednesday, May 14, 1986: I traveled this date from ARCO's Prudhoe Oil PoOl DS 1-28', sub]:'ect of another report, to ARCO's Kuparuk River Field Doyon Rig 9 to witness a BOP test. The drilling contractor was in the process of nippling up. test commenced at 4:00 p.m. and was concluded at 5:00 p.m. were no failures. The BOP There I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the BOP test on ARCO's Kuparuk River Field 3N-16 Doyon Rig 9. Attachment 02-001 A ( Rev 10-84) - &G (/4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector Operator Location: Sec,?~? Drilling Contractor Location, General ~/~ General Housekeeping ~)~ Reserve Pit Mud Svstems Ri~ # Well Sign Rig. Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE S t a, ok An~l~tar ~P. zevent er Pip~Rams Blind,,,../~ ~ ~ Shm~ ~ Va~es H. C. R~ Valv~ ~{1~ Line Valves Check Valve ~ ,,~.~,¥.. - Test Results: Test Pressure 3ooo ~ooo Failures ----- Date Well Representative. 0--- Permit # ~ 9~ ~Casing Set @ ~'7 ft'~Z~'~ fi' ~e~resenta~iv~ ~. ~0/~ / ' ACC~ATOR SYSTEM Full Charge Pressure ~ ~ psig Pressure After Closure~~ psig ~ump incr. c~os. p~es. ~00 psig ~ ~i~f~ec~ ~u~ C~ge ~s~=e Attained: ~ min~s~c/ Controls: Master ~~ ~~F~ Remote~:J Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ~~Test Pressure . Lower Kell)I~K ~st Pressure Ball Type ~R. ~est Pressure Inside BOP O~Test Pressure Choke Manifold ~~est Pressure Valves No. f~anges Adjustable Chokes I ~ J~ Hvdrauicall¥ operated choke Test Time / hrs. Repair or Replacement of failed equipment to be made within-- ~--days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspectcr May 6, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3N-!6 ARCO Alaska, Inc. Permit No.'86-91 Sur. Loc. 156t'FSL, 29'FEL, Sec. 29, T13N, RgE, U~.~. Btm~hole Loc. 1429'FNL, 622'FEL, Sec. 33, T13N, R9E, lrM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. 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 test~.ng of the equipment before the surface casing shoe is drilled. I~ere 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. ~. ~ truly C. V. Chatterton: Chairman of Alaska Oil and Gas Conservation Co~.~nission BY ORDER OF _THE CO~iMISSION dtf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~ STATE OF ALASKA ALASKA ,alL AND GAS CONSERVATION C ,¢IMISSION PERMIT TO DRILL 2O AAC 25.O05 I la. Type of work Drill ,~ Redrill EI lb. Type of well. Exploratory -- StratigraphiU Test "- Development Oil Re-Entry ~ Deepen~1 Service ~ Developement Gas - Single Zone -- Multiple Zone '' 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A1 aska, I nc. RKB 68 ' , PAD 34 ' feet Kuparuk Ri vet Fi el d ;~. Address 6. Property Designation Kuparuk River 0i 1 Pool P.0. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1561'FSL, 29'FEL, Sec.29, T13N, RgE, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number 1289'FNL, 840'FEL, Sec.33, T13N, R9E, UM 3N-16 #8088-26-27 At total depth 9. Approximate spud date Amount 1429'FNL, 622'FEL, Sec.33, T13N, R9E, UM 05/13/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 91 24 'MD 29' ~ surface feet 3N-15 25'~ surface feet 2560 (6840'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 700 feet Maximum hole angle46 0 Maximum surface 2980 psig At total depth (TVD) 3422 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2~.'' !6" 62.5# H-~.O We~.d ~O' ~5' ~5' !15' 1!5' -.zi 200 of HF-ERW ~,2n ¢~ ~.1.,~ ~ l'.,l~,nrt 8~" 7" 26.0# .,I-55 BT(; ~0_9_0' 34' 34' 9124' 6840' 200 sx Class (](minimum HF-ERW TOC 50( ' above top of Kuparuk i9. To be completed for Redrill, Re*entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch ,;~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis ~ Seabed report [] 20AAC25.050 requirements 21. I hereby//certif'~that the foregoi,ng is true and correct to the best of my knowledge Signed / /~.,~z,¢/.¢/,~ _~(,,(,~,.-/ Title Regi°nal Drilling Engineer Date r~/~r_- ~6/ /~/~''' Commission UsiOnly (HRE) iD/PD256 '~/ APl number Approval date See cover letter Permit Nu 9]. 50-- 029-21593 0.5/06/86 for other requirements Conditions of approval Samples required ,~, Yes ~ No Mud Icg required ,'Z,' Yes ~ No Hydrogen sulfide measures ,~ Yes ~ No Directional survey required ~ Yes ~ No Required working~;zr.e~ssure for~lg.l~ ~2M;~,'~3M; ~ 5M; ~,' 10M; g 15M Other: ~/"~/,~(//~ ~~ e/~~/~ " -~ by order of Approved by Commissioner the commission Dat I:r~rm 1n-4n1 Rc.v.%'"~-1-8~ , / / St iplicate / .Q 1000 2000 ~o00 t .. ~ oo i [ " i I l i -1 · , i KUPRRUK R I VER UN I T 20" D I VERTER SCHEMAT I C DE$CR I PT I ON 1. i6" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TaNKO LOWER QUICK-CONNECT ASSY. S. TaNKO UPPER QUICK-CONNECT FSSY. 6. 20" 2000 PSI DRILLINQ SPOOL W/lO" OUTLETS. T. lO" HCR BALL VALVES W/lO" DIVERTER LINES, a SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION· 8. 20" 2000 PSI ANNULAR PREVENTER· ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM. 20 AAC2S 03S(b)~"' ?'' ' "' M/~i NTENMN~E;,._ &i Oe~Rj~T '! ON" 1 · UPON I NIT I AL I NSTALLaT I ON, CLOSE PREVENTER aND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO aCHIEVE DONNWIND DIVERSION, DO NOT SHUT IN NELL UNDER /~NY C I RCUMST~NCES. 510084002 R1( i i iii i i ii ii i :. 6 ACCL/vt)LATOR C¢~ACITY T~ST i. Q4ECX AND FILL AO2LM,,LATOR ~OIR TO ~ L~ W~ ~~C ~U~D. 3. ~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ PSI ~INI~ 5 i . 4 3 h ,> 2 . . . 13. .,. 13-5/8" B..,C¢ FILL BC~ STACX Ah~ C~ MANIFCI~ WlTM ARCTIC DIESEL° C~CX 'F~T ~ L~ ~ ~ IN ~~ ~ ~Y ~RA~. ~T ~ ~ IN ~~ WI~ ~I~ ~ ~ ~ IN L~ S~. LI~ V~VES ~ TO ~ STA~ ~ ~ ~ ~ TO ~~ F~ ~0 ~IN. ~ ~~ TO~ ~ F~ lO ~IN. ~ ~~ TO 0 ~I. LI~ VALVES. ~ T~ PI~ ~ ~ ~ V~VE~ TEST TO 2~ PSI ~~ ~ IN ST~ 4. ~I~ TESTI~ ALL~~, LI~, ~ ~S WI~ A ~ PSI L~ ~ ~ PSI HI~. TEST AS ~ A ~L ~I~ P~ITIVE ~ ~ ~Y ~ T~ PI~ R~ ~ ~ BO~ PI~ ~. TEST ~~ PI~ R~ TO ~ ~I ~ ~ ~I. ~ ~I~ ~ ~ ~ST TO ~ ~I ~ PSI. ~IF~ ~ LI~S ~ ~L ~ ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~. TEST ST~I~ V~VES, K~LY, ~ly ~S, PI~ ~E~ VALVE, ~ I~I~ ~ TO ~ PSI ~ PSI. ~~ TEST I~~TI~ ~ ~~ ~~ ~ST 'F~, SI~, ~ ~ TO ~I~I~ ~I~. P~~ ~ B~ ~ST ~ NI~I~ ~ ~Y T~~~ ~I~Y ~~ B~ ~ILY. 510084001 REV. N~AY 15, 1~5 Density~ PV DRILLING FLUID PROGRAM Spud to · 9-5/8" S~rface Casing 9.6-9.8 Drill out to Weight Up 8.7-9.2 15-30 5-15 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7' Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. After 200' of departure, there are no well bores within 200' of this proposed well. GENERAL DRILLING PROCEDURi KUPARUK RIVER FIELD DEVELOPMENT WELLS 1o Move in rig. ~ '2. Install Tankco diverter system. 3 DriltI 12¼" hole to'9-5/8" surface casing point according to directional plan. 4~. RUn and cement 9-5/8" casing. 5'. Install and test blow out-preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½,, hole to provide 100' between plug back total depth and bottom of Kuparuk sands.. 10o Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15~ Move in workover rig. Nipple up blow out preventer. 16o Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel and set packer. 20. Flow well to tanks. Shut in o 21. Secure well and release rig. 22. Fracture stimulate. , E LWK4 / ih -r'yPl¢,~l_ rrll~D .$¥$T~'r~ SC. NEmlI:ITIC: ARCO Alaska, In( Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 Mr. C. V. Chatterton Commi ssioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If ARCO Alaska. inc. is a Subsidiary of AtlanticRichfi~.' -' ;omp,3n¥ " ~ 20~L,2I IN PROTRACTED SEC'$ 28 .Cj, Tl$ N, R 9E,U.M. 29Y28 4 0 LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. 29, TISN~ RgE~ U.M. SEC. 29,TISN,RgE, U.M. ~ - Y - 6,0~3,799.67 LAT. 70°26'55.9615'' 10 - y = 6,013,799.37 LAT. 700~6'55.9519'' X - 5~7,946.~9 LONG. 149°51'12.938'' X = 518,22~.07 LONG.[49o51'04.865" 454' FEL, 1562' FSL 0G ' 28.2 PAD = 33.7 ~79' FEL, ~56~' FSL 0G ' 28.5 PAD = 34.0 2 - Y ' 6,0~3,799.65 LAT. 70026'55.9606'' Il - Y = 6,0~3,799.32 LAT. 10~26'55.9508" X = 517,97~.21 LONG.14905['[2.203" X - 518,246.03 LONG.[49°51'04.132'' 429' FEL, 1562' FSL 0G = 28.2 PAD = 33.8 [55' FEL, ~56~' FSL 0G ' 28.5 PAD = 33.8 3 - Y = 6,013,799.54 LAT. 70~26'55.9590" ~2 - Y = 6,0~3,799.45 LAT. 70~26'55.95~5' X = 517,996.25 LONG. 149°5['l[.468" X = 5~8,270.89 LONG.149o51'03.403'' 404' FEL, 1562' FSL 0G = 28.4 PAD = 33.9 [30' FEL, ~56~' FSL 0G = 28.5 PAD = 34.0 4 - Y = 6,013,799.50 LAT. 70~26'55.9580" ~3 - Y = 6,013,799.41 LAT. 70°26'55.9505'' X = 518,02[.16 LONG.149o51'[0.736" X = 5~8,295.97 LONG-149051'0~.666" ~ , 379' FEL, 1562' FSL 0G = 28.4 PAD = 33 7 ~05 FEL, 156~' FSL 0G ' 28.5 PAD 34.~ ' 5 Y 6,0~3,799 ~ LAT. 70"26' 55. 9572" - - . ~ 14 - Y ' 6,013,799.33 LAT. 70°26'55.9491" X = 518,046.18 LONG. 149°51' 10.002" '~ X = 518,320.91 LONG. 149051'01.934" 354' FEL, 1562' FSL OG = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG = 2B.5 PAD ~ 34.0 o 6 - Y = 6,013,799.44 LAT. 70026'55.9562'' ~ LO 0 15 - Y = 6,013,799.28 LAT. 70026'55.9480" x: s~,0?~.~ L0,~.~5~'0~.2~'' ~ x: 5~s,~,s.?? LO"~.~°5~'O~.~O"'' ~Z~' ~EL, ~S~' ~SL O~ : ~.~ ~ : ~.~ ~~ E ~ ~S' ~EL, ~S~' ~SL O~ - ~.S ,~ : ~.0 7 - Y : 6,013,799.44 LAT. 70°26'55.9556'' ~ ~ ~ ~ 16 - Y = 6,013.799.25 LAT. 70°26'55.9471'' X = 518,096.21 LONG. 149°51'08. 533'' ~ ~ ~ ~ X = 518,370.74 LONG. 149°51'00.470" 304' FEL, 1561' FSL OG = 28.5 PAD : 33.9 ~ ~ ~~ 30' FEL, 1561' FSL OG = 28.5 PAD = 34.1 8 - Y : 6,013,799.45 LAT. 70°26'55.9551" ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70026'55.9466" X = 518,121.15 LONG. 149°51'07.800" ~ X = 518,395.63 LONG. 149~50' 59-739" 279' FEL, 1561' FSL OG = 2B.6 PAD : 33.9 ~ ~ ~ 5' FEL 1561' FSL OG : 28.5 PAD : 34.1 , 9 Y = 6,013,799.42 LAT. 70026'55.9542" - ~ X = 518,!46.!5 LONG. 149051'07.066'' c) SEC. 28,TISN, RgE, U.M. 254' FEL, 1561' FSL 0G = 28.6 PAD = 34.0 ~ 18 - y = 6,013,799.15 LAT. 70~26'55.9449'' X : 518.420.80 LONG.!49050'59.000" NOTES ~0' Fw'L, i56i' FSL 0G = 28.5 PAD = 34.0 I. ALL COORDINATES ARE A.S.P.,ZONE4. ~.SECTION LINE DISTANCES ARE TRUE. 5. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD ~ ASSOC. 4. VERTICAL POSITIONS BASED ON MODULE PILES ~JOI-8 ~ )JOI-4. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3OgO rev.~. . ~EglStE~E~ ~ND LICENSED tO =~CtlCE 2~ND ~ ~ -- ~' I ~,~,,~n ~r,o ~ A~UU AlaSKa, I~C. ~%_ . ~-. ~/~.;., ~-- '' ~ : ~ ~ KUPARUK PROJECT ¢, ~ ff~flE ,; ~,~: ~ ~oo~ ~. ~ ~ AS- BUILT LOCATIONS t, % .~/:.'~;,,~ """""' {:~ ..... . ,Iz~,~0'---~ ........................ llDWG. NO. NSK 86-3 ~ FEES ArCtiC Bou/evarq Su/~e 20. ~nc,qorage, ;fa.s~,a Yy;~'J IS~ NOT TO SCALE ~~ - ]!~~ ~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc ~ ~-'~_. f'~'"/~ (Zthru 8) ,,/:-// '(8) ' (3) Admin/, ~""f~ < 9. "~ru 13) . 10. '(10 and 13) Z 12. 13. (4) Casg ~.~F~. ~___~_~ (14 thru 22) (5) BOPE (23 thru 28) (6) OTHER .A,/. (29 thru 31) (6) Add: Company YES 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 .......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26 27. 28. For 29. 30. 31. Does operator have a bond in force ................................... Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .................................... ~ Does the well have a unique name and n~ber . g~ Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known Productive horizons ..................... Will al1 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 ............................ Lease & Well No. NO Is a diverter system required ................ ' ....................... Is the drilling fluid program, schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached.,~F,F Does BOPE have sufficient pressure rating - Test to ~O(D(p psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Geology: Engin,~gring: WVA MTM ~ rev: 04/03/86 6.011 POOL INITIAL CLASS STATUS GEO. AREA UNIT NO. . /'/ ON/OFF SHORE REMARKS 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. ;',~ .... 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