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187-051
• RECEIVED STATE OF ALASKA MAY 0 9 22017 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT MOGCte 1 a.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned 0 • Suspended ❑ 1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development I] ' Exploratory ❑ GINJ ❑ WINJ❑ WAGE] WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aban .: 4/3/20179 187-051/316-643/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 5/31/1987 50-029-21726-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 950'FNL, 1598'FEL,Sec.25,T13N,R8E,UM 6/4/1987 KRU 3M-14 Top of Productive Interval: 9. Ref Elevations: KB:64 17. Field/Pool(s): 1284'FSL,813'FEL,Sec 24,T13N,R8E,UM GL:27 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1444'FSL,768'FEL Sec 24,T13N, R8E, UM 6930/6231 ' ADL 25522,ADL 25523 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 506270 y- 6016548 Zone- 4 7244/6498 , 2558 TPI: x- 507052 y- 6018783 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 507097 y- 6018943 Zone- 4 N/A 1720/1720 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) ,6939/6231- 22. Logs Obtained: List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to:mud log,spontaneous potential, gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary N/A SCANNED w1UN 0 9 2017, 23. CASING,LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16 62.58 H-40 38 121 38 121 24 200 sx CS III 9 5/8 36 J-55 37 3473 37 3377 12 1/4 1389 sx AS III,371 sx Class G 7 26 J-55 35 7224 35 6481 8 1/2 300 sx Class G, 175 sx CS I 4 1/2 12.6 L-80 6599 7127 5953 6398 6 1/2 175 sx CS I 24.Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 6502 6509/5879 Fill in casing across all perfs 6599/5953 (k(p.NOo sc c COtvIF'tC1101* 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes❑ No ❑ 1i13 Ili Per 20 AAC 25.283(i)(2)attach electronic and printed information VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED L--- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A ABANDONED Date of Test: Hours Tested: Production for Oil-Bbl: ' Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate/ p C r 7 Form 10-407 Revi d 11/2015 1/TL G/1` /1' CONTINUED ON PAGE 2 RBDMS LL- MAY 1 J LUI/ Submit ORIGINIAL only//�� • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E1 Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1720 1720 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval N/A N/A information, including reports,per 20 AAC 25.071. ,14. Formation at total depth: N/A I4 A- 31. List of Attachments: Daily Operations Summary,We bore Schematics Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report.production or well test results.per 20 MC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. /,t / Contact: William Long A263-4372 Email: William.R.Long(g)_cop.com ��•/ Printed Name: J.Ohlinger Title: Staff CTD Engineer Signature:„... ..if °7 Phone: 265-1102 Date: /9/l� INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 MC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results,including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Item 31: Pursuant to 20 MC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • ConocoPh i lli ps Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 MAY 0 9 2017 May 9, 2017 AOGCC Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Please find attached for your review completion reports for 3M-14 and 3M-14A. CTD operations did not go as planned on 3M-14. Unstable hole conditions were encountered immediately outside of the window and did not permit drilling 3M-14A past the build section of the wellbore. The CTD plan for the well included a swell packer and liner top packer to isolate and abandon 3M-14. Well 3M-14 was shut in prior to CTD operations due to rock production. This rock production occurred even after a 4-1/2" scab liner was previously ran and perforated. When 3M-14A encountered unstable hole conditions liner was ran to maintain production from the reservoir. The swell packer was not ran as originally planned. Even though the swell packer was not ran the 10-407 for 3M-14 is being submitted as abandoned for administrative and production tracking purposes If you have any questions or require additional information, please contact me at 907-263-4372. Sincerely, William R. Long Coiled Tubing Drilling Engineer • • 3M - 14 DTTMST JOBTYP SUMMARYOPS 4/2/17 DRILLING Move rig from 1E pad to 3M pad. Spot sub and pits. NU BOPE. Rig accept at SIDETRACK 23:00hrs. Start initial BOPE test. 4/3/17 DRILLING Finish testing BOPE. Troubleshoot high pressure bulkhead. Repair same. Pull BPV. SIDETRACK PU and PD window milling BHA. RIH and displace well to 9.6 milling fluid.Dry tag pinch point at 6933 ft. Begin milling window per procedure. 4/4/17 DRILLING Continued milling window, began observing darker returns to surface at 6,947.5' MD, SIDETRACK increased WHP and continued milling to rat-hole TD of 6,951' MD. Dressed window as per procedure, experienced set-downs 6,947.5' MD when attempting dry drift of window. Continued with additional reaming passes, and again saw tag-ups at 6949' MD, confered with town and decision was made to proceed with plan to kill well (tag- ups thought to be possibly due to fill accumulation). Obtained SBHP with EMW of 12.35 ppg, circulated bottoms up, swapped well over to 13.1 ppg KWF as per procedure. Perform flow check of well. 4/5/17 DRILLING LD BHA#1, PU BHA#2, RIH tie into K1 fora +.5' correction, displaced to 13.1 ppg SIDETRACK KWF, RIH dry tag at 6951' MD,jumping around with tool on tray, PUH to discuss plan forward at 6979' MD, near bit inc not hitting required DLS, tie into K1 for a +.5' correction. RIH to drill and began stacking weight at 6985' high WOB no differential, PUH and unable to get back to bottom. PUH inside cased hole, open EDC and circulate bottoms up, close EDC and RBIH, unable to work past 6972' MD. PUH and get hung up in window. Confer with town, decision made to POOH and PU Crayola mill, displace well to KWF, LD BHA#2. RIH with Crayola BHA#3, tie in for+.5' correction, displace to 9.6 ppg drilling fluid. Begin reaming down-hole HS, difficulty reaming past 6939' MD with a few stalls requiring slow reaming. Back ream up-hole to 6930' MD high-side, ream back down-hole HS. 4/6/17 DRILLING Completed dressing window with Crayola mill, dry drifted window, clean up &down, SIDETRACK unable to work BHA past 6972', circulated 4 bottoms up with significant cutting over shaker, displaced well to KWF, LD BHA#3, PU BHA#4 (2.71°AKO), RIH, tie in for a - .5' correction, displace well to 9.6 ppg PowerPro, tagged up at 6973', drilled build to 7073' . Decision made to POOH for lower bend motor(averaging 56° DLS), displace well to KWF, POOH & LD BHA#4, PU BHA#5 (2.34°AKO), RIH, tie in to K1 for a -1' correction, displace to 9.6 ppg PowerPro. Continue to RIH and unable to work BHA past 6972' working various rates and speeds. Confer with town, decision made to kill the well and allow town time to discuss plan forward. 4/7/17 DRILLING Displace KWF, POOH & LD BHA#5, PU and RIH with BHA#6 (2.71 degree AKO), SIDETRACK tie into K1 for-.5' correction, displace to 9.6 ppg fluid, stack weight at 6871', wash down to MD 7008' MD in bites, appears to be drilling down to 7024' MD, PUH to 6953' MD while restarting MWD database, RBIH and stack weight at 6973', attempt to wash by and stack out at 6974', unable to get past 6974', PU to cased hole, open EDC & circulate. Decision made to run liner, displace well to KWF, RBIH to log K1 • • Operations Summary (with Timelog Depths) ,44.0a:.„--,„„, 3M-14 ConocoPhilllps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start,Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK8) End Depth(ftKE); 4/2/2017 4/2/2017 3.00 MIRU MOVE RURD P PJSM with truck drivers.Get rig 0.0 0.0 00:00 03:00 jacked up and sows hooked up. 4/2/2017 4/2/2017 4.00 MIRU MOVE MOB P Pull modules off of 1E-20.Stage sub 0.0 0.0 03:00 07:00 and pits on access road and wait on feild wide change out. Halfway house and shop remain on 1E pad. 4/2/2017 4/2/2017 8.00 MIRU MOVE MOB P Mobilize sub and pits to 3M pad.Sub 0.0 0.0 07:00 15:00 and pits spotted at 15:00 hrs. 4/2/2017 4/2/2017 6.50 MIRU WHDBOP RURD P Crew working through rig up checklist. 0.0 0.0 15:00 21:30 Move shop and halfway house from 1 E pad.Spot on 3M pad.String up highline.Establish comms. 4/2/2017 4/2/2017 1.50 MIRU WHDBOP NUND P NU BOPE and fill stack. 0.0 0.0 21:30 23:00 4/2/2017 4/3/2017 1.00 MIRU WHDBOP BOPE T Rig accept at 23:00hrs. 0.0 0.0 23:00 00:00 Start initial BOPE test to 4600 psi. State witness waived by Chuck Shelve. 4/3/2017 4/3/2017 9.00 MIRU WHDBOP BOPE P Continue testing BOPE to 4600 psi 0.0 0.0 00:00 09:00 (2,500 psi on the annular).State witness waived by Chuck Shieve.2" lower pipes fail/Pass after cycle 4/3/2017 4/3/2017 3.00 MIRU WHDBOP RURD T Rehead the UQC.e-line would not 0.0 0.0 09:00 12:00 test.Troubleshoot.Problem with high pressure bulkhead. Remove,fix and replace same. 3 hrs Nabors downtime. 4/3/2017 4/3/2017 1.00 MIRU WHDBOP RURD P Rehead UQC.eline test good.PT to 0.0 0.0 12:00 13:00 4000 psi. 4/3/2017 4/3/2017 1.50 MIRU WHDBOP MPSP P RU valve crew lubricator.PT to 2,500 0.0 0.0 13:00 14:30 psi.Equalize pressure.Pull BPV.RD lubricator. 4/3/2017 4/3/2017 2.00 PROD1 WHPST PULD P PJSM. PU and PD BHA#1,window 0.0 0.0 14:30 16:30 milling assembly.Make up 2.80"DSM, 2.79"no-go string reamer,to 1.0°AKO Weatherford motor.Tie-in to the K1 for a+1 foot correction. 4/3/2017 4/3/2017 3.80 PROD1 WHPST TRIP P RIH with milling BHA pumping 0.0 6,900.0 16:30 20:18 seawater,displacing out diesel FP. Chase seawater with 9.6 ppg milling fluid. 4/3/2017 4/4/2017 3.70 PROD1 WHPST WPST P RIH.Dry tag pinch point at 6,933 ft. 6,900.0 6,936.6 20:18 00:00 PUH. Bring up pump to 1.7 bpm.RBIH and mill window per program. 4/4/2017 4/4/2017 10.00 PROD1 WHPST MILL P Continue milling window per 6,936.6 6,946.1 00:00 10:00 procedure, 1.7 BPM @ 4250 PSI FS, BHP=4100 4/4/2017 4/4/2017 1.50 PROD1 WHPST MILL P 6946.1 Call Bottom of window,time 6,946.1 6,947.5 10:00 11:30 mill 2 more feet to let string reamer work, 1.7 BPM @ 4230 PSI FS, BHP=4087 4/4/2017 4/4/2017 1.80 PROD1 WHPST MILL P 6947.5,Started getting dark returns 6,947.5 6,951.0 11:30 13:18 added WHP and prep to take returns out-Never had to.Continue milling. 4/4/2017 4/4/2017 3.80 PROD1 WHPST REAM P Reached end of rat hole start reaming 6,951.0 6,951.0 13:18 17:06 passes,HS,30R,30L, 180°.Attempt dry drift,PUW=31K Page 1/7 Report Printed: 5/3/2017 • .r k Operations Summary (with Timelog Depths) 3M-14 M Phillip ;, Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time` End Time Cur(hr); Phase Op Code Activity Code Time P-T-X Operation. MKS) End Depth(ftKB). 4/4/2017 4/4/2017 0.40 PROD1 WHPST REAM P Dry drift,tag at 6947'MD,ream down, 6,951.0 6,951.0 17:06 17:30 PUH attempt dry drift again,tag at 6947'MD,4K WOB to 6949'MD. Bring pumps up and get right through. 4/4/2017 4/4/2017 1.50 PROD1 WHPST REAM P PUH,ream down,backream up at 180 6,951.0 6,951.0 17:30 19:00 LS,dry drift,tag at 6947',tack 4K to 6949'MD again. Continue to dress window to obtain good dry drift:Begin back ream up LS, ream down HS,back ream up LS, back ream up a bit faster,dry drift at 20'fpm,tag at 6949'MD.Begin back ream up LS,ream down HS,back ream up LS. 4/4/2017 4/4/2017 1.00 PROD1 WHPST REAM P Attempt dry drift and tag at 6949.5' 6,951.0 6,951.0 19:00 20:00 MD,bring up pumps and get right through.RIH to 6951,ream up at 330 ROHS,ream down HS,ream up at 30 ROHS.Attempt dry drift and tag at 6949.9'MD,bring up pumps and get right by.Attempt to RIH with pumps off,again tag weight,bringing pumps on and can go right down. 4/4/2017 4/4/2017 1.50 PROD1 WHPST DLOG P Swap from choke A to choke B,obtain 6,951.0 6,931.0 20:00 21:30 SBHP at 6930'MD.Trap 12.8 ppg, shut in choke,shut down pumps,BHP stabalized at 3972 psi.Using TVD at annular sensor of 6190'TVD gives EMW of 12.35 ppg. Circulate bottoms up. 4/4/2017 4/4/2017 2.20 PROD1 WHPST KLWL P POOH,swap well to KWF(13.1 ppg 6,931.0 77.0 21:30 23:42 Potassium Formate),tag up. 4/4/2017 4/5/2017 0.30 PROD1 WHPST OWFF P Check well for flow,PJSM 77.0 77.0 23:42 00:00 4/5/2017 4/5/2017 1.30 PROD1 WHPST PULD P LD BHA#1 over a dead well,blow 77.0 0.0 00:00 01:18 down 4/5/2017 4/5/2017 1.80 PROD1 DRILL PULD P PJSM,PU BHA#2,build drilling 0.0 72.0 01:18 03:06 assembly(2.6 degree AKO,RB Hughes bit) 4/5/2017 4/5/2017 1.50 PROD1 DRILL TRIP P RIH with BHA#2,tie into K1 for a+.5' 72.0 6,830.0 03:06 04:36 correction,displace well to 9.6 ppg PowerPro 4/5/2017 4/5/2017 0.20 PROD1 DRILL DLOG P Tie into K1 for a+.5'correction, 6,830.0 6,853.0 04:36 04:48 4/5/2017 4/5/2017 1.60 PROD1 DRILL CIRC P Displace well to 9.6 PPG PwrPro, 6,853.0 6,923.0 04:48 06:24 close EDC 4/5/2017 4/5/2017 1.00 PROD1 DRILL DRLG P RIH to drill,dry tag @ 6951',PUH, 6,923.0 6,979.0 06:24 07:24 bring pumps on 1.5 BPM @ 4020PS1 FS,BHP=4122,TF jumping around with tool on tray. 4/5/2017 4/5/2017 0.50 PROD1 DRILL TRIP P PUH to discuss directional plan.We 6,979.0 6,830.0 07:24 07:54 are behind plan at near bit inc. Pull up to tie in while discussing situation with town 4/5/2017 4/5/2017 0.10 PROD1 DRILL DLOG P Log K1 for+.5' 6,830.0 6,855.0 07:54 08:00 4/5/2017 4/5/2017 0.20 PROD1 DRILL TRIP P Trip in hole and log RA marker @ 6,855.0 6,969.0 08:00 08:12 6937.5',TOWS=6930.15 Page 2/7 Report Printed: 5/3/2017 • • sr„ . , g., Operations Summary (with Timelog Depths) M R 3M-14 ConocoPhillips ' Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)' 4/5/2017 4/5/2017 0.20 PROD1 DRILL TRIP P RIH to drill 6,969.0 6,979.0 08:12 08:24 4/5/2017 4/5/2017 0.70 PROD1 DRILL DRLG P Tag up and drill ahead from 6979', 1.5 6,979.0 6,921.0 08:24 09:06 BPM @ 3943 PSI FS,BHP=4128, Started stacking out at 6985.High DHWOB but no differential pressure. BHA is in a bind.PUH attempt to get back on bottom.WOB reacting in both direction.Unable to get to bottom.Pull up above window 4/5/2017 4/5/2017 0.50 PROD1 DRILL CIRC P Back in cased hole,Open EDC and 6,921.0 6,914.0 09:06 09:36 circ bottoms up.Getting back more cuttings then drilled 4/5/2017 4/5/2017 1.20 PROD1 DRILL TRIP P Close EDC and RBIH to drill,Tough 6,914.0 6,920.0 09:36 10:48 going with high WOB after passing window.Stacked out @ 6972 unable to work past.PUH,Get hung up in window.Work up into cased hole. looks OK trip back in.Pushing hard past bottom of window and stack out @ 6970.Work to get back to cased hole.Motor stalling against side of hole 4/5/2017 4/5/2017 0.60 PROD1 DRILL CIRC T Discuss plan forward,decide to trip for 6,920.0 6,898.0 10:48 11:24 crayila mill,Circulate 13.1 PPG K- Formate 4/5/2017 4/5/2017 1.30 PROD1 DRILL TRIP T trip out on KWF. 6,898.0 65.0 11:24 12:42 4/5/2017 4/5/2017 1.30 PROD1 DRILL PULD T Flow check well-Good.Lay down 65.0 0.0 12:42 14:00 BHA#2 4/5/2017 4/5/2017 1.00 PROD1 DRILL PULD T M/U BHA#3 with 1.5°motor and 0.0 63.0 14:00 15:00 crayola mill,Make up to coil and surface test tool 4/5/2017 4/5/2017 1.70 PROD1 DRILL TRIP T RIH BHA#3 63.0 6,825.0 15:00 16:42 4/5/2017 4/5/2017 0.10 PROD1 DRILL DLOG T Log K1 for+.5'correction 6,825.0 6,850.0 16:42 16:48 4/5/2017 4/5/2017 1.00 PROD1 DRILL CIRC T Displace well to 9.6 ppg PowerPro. 6,850.0 6,933.0 16:48 17:48 4/5/2017 4/5/2017 0.70 PROD1 DRILL REAM T Begin to perform reaming passes with 6,933.0 6,939.0 17:48 18:30 Crayola mill as per procedure.Stall twice getting started at 6933.5'MD. Begin time milling to get started at 6933'MD,HS. 4/5/2017 4/5/2017 4.00 PROD1 DRILL REAM T Stalled twice at 6939'MD.PU&RIH 6,939.0 6,940.0 18:30 22:30 to continue time reaming.Observed increased WOB(.45K)with little motor work at 6939.15'.Continue to work area slowly to clean up window, stroking pump often to relax coil and avoid stalls. 4/5/2017 4/5/2017 0.60 PROD1 DRILL REAM T Continue down reaming at 6940'MD, 6,940.0 6,949.0 22:30 23:06 taking small bites and letting motor work drill off. Begin increasing ROP as motor work allows. 4/5/2017 4/6/2017 0.90 PROD1 DRILL REAM T Back ream up-hole HS from 6949'to 6,949.0 6,949.0 23:06 00:00 6927'MD.Observe negative WOB at -6939'MD. Ream down-hole HS to 6949'MD.Much cleaner down-hole pass than first with slight WOB bobble at 6939'MD. Page 3/7 Report Printed: 5/3/2017 . • •. . ,..,,,,,, , ,..,...,,,o,k,,.. : , .... Operations Summary (with Timelog Depths) RA 4 ,°_ F 3M-14 Canar,itiip a;'. Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(Cr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/6/2017 4/6/2017 2.50 PROD1 DRILL REAM T Continue dressing window.Ream up- 6,949.0 6,925.0 00:00 02:30 hole 330 ROHS,down-hole HS,up- hole 30 ROHS,down-hole HS,and up -hole LS. Observed a bit more motor work reaming up-hole low-side. 4/6/2017 4/6/2017 2.30 PROD1 DRILL CIRC T Dry drift window HS,clean up and 6,926.0 6,972.0 02:30 04:48 down. RIH towards drilled depth of 6986'MD at 18 fpm and 1.7 bpm, WOB stacking of 5K at 6971'MD. PUH&RBIH at minimum rate,stack 6K WOB at 6972'MD. PU from 6972'MD,bring rate to 1.7 bpm and slowly PUH to circulate out OH,repeat.Significant sand over shakers from bottoms up.Continue circulating until shakers clean up(4 bottoms up). 4/6/2017 4/6/2017 0.20 PROD1 DRILL DLOG T Obtained SBHP at window to ensure 6,972.0 6,925.0 04:48 05:00 12.8 ppg will kill the well.Observed trend down to 12.7 ppg EMW. 4/6/2017 4/6/2017 2.00 PROD1 DRILL CIRC T Displace well to 12.8 ppg KWF,POOH 6,925.0 63.0 05:00 07:00 4/6/2017 4/6/2017 1.30 PROD1 DRILL PULD T At surface,PJSM,lay down BHA#3, 63.0 0.0 07:00 08:18 Inspect pipe above CTC. 4/6/2017 4/6/2017 0.80 PROD1 DRILL PULD T PJSM,M/U BHA#4 with 2.71°AKO 0.0 62.0 08:18 09:06 motor and new HCC Bi center,M/U to coil and surface test 4/6/2017 4/6/2017 1.40 PROD1 DRILL TRIP T RIH,EDC open 62.0 6,830.0 09:06 10:30 4/6/2017 4/6/2017 0.20 PROD1 DRILL DLOG T Log K1 for-.5' 6,830.0 6,850.0 10:30 10:42 4/6/2017 4/6/2017 0.10 PROD1 DRILL TRIP T trip in to 6911' 6,850.0 6,911.0 10:42 10:48 4/6/2017 4/6/2017 1.00 PROD1 DRILL CIRC T At 6911,Displace to 9.6 PPG Pwr Pro 6,911.0 6,911.0 10:48 11:48 4/6/2017 4/6/2017 0.20 PROD1 DRILL TRIP T Trip in to drill,tag up at 6973 and 6,911.0 6,985.0 11:48 12:00 ream down to 6985 4/6/2017 4/6/2017 3.00 PROD1 DRILL DRLG P 6985',drill ahead, 1.5 BPM @ 4330 6,985.0 7,073.0 12:00 15:00 PSI FS,BHP=4232,At 7055 bring rate up to 1.7 BPM @ 4626 PSI FS, BHP=4248.Call EOB due to high DLS.AVG 56°.Landed at 6234'TVD. Near bit @ 93°when we left bottom 4/6/2017 4/6/2017 2.50 PROD1 DRILL TRIP P 7073'PUH to 6903',Open EDC and 7,073.0 64.0 15:00 17:30 start KWF down coil-Continue out displacing. 4/6/2017 4/6/2017 0.70 PROD1 DRILL PULD P Tag up,30 minute flow check,PJSM, 64.0 0.0 17:30 18:12 LD BHA#4 over a dead well(2.7+ degree AKO build assembly) 4/6/2017 4/6/2017 1.30 PROD1 DRILL PULD P PJSM,PU BHA#5(2.3+degree AKO 0.0 72.0 18:12 19:30 turn assembly,same bit as BHA#4), tag up. 4/6/2017 4/6/2017 1.20 PROD1 DRILL TRIP P RIH with BHA#5,turn drilling 72.0 6,820.0 19:30 20:42 assembly,Start 9.6 ppg PowerPro down coil Page 4/7 Report Printed: 5/3/2017 r 0 ° Operations Summary (with Timelog Depths) t - 3M-14 oPhitlips' ; Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log, Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKH) End Depth(ftKB) 4/6/2017 4/6/2017 0.30 PROD1 DRILL DLOG P Log K1 for-1'correction,momentary 6,820.0 6,850.0 20:42 21:00 difficulty tying in with no values recieved from gamma tool,restart system,good. 4/6/2017 4/6/2017 1.50 PROD1 DRILL TRIP P Continue RIH to bottom,displacing 6,840.0 7,073.0 21:00 22:30 well to 9.6 ppg PowerPro. Experienced position error code when closing EDC,follow trouble-shooting procedure,recallibrate,open&close EDC for verfication of correct functionality. Stacking up to 7K WOB when RIH at -6972'MD. 4/6/2017 4/7/2017 1.50 PROD1 DRILL CIRC T Unable to work BHA past 6972'MD. 7,073.0 6,880.0 22:30 00:00 Attempted.3 bpm at 30 fpm.Confer with town as this is the 3rd BHA to stack at this depth(2nd BHA did not include Res tool).Decision made to attempt RIH at 1 bpm at 35 fpm, 1.25 bpm at 35 fpm,each time coming off pumps and PU to avoid begining to side-track.Continue to stack up to 7K WOB and unable to get by. PUH into cased hole and open EDC to begin circulating as town discusses situation. 4/7/2017 4/7/2017 0.30 PROD1 DRILL DLOG T Decision made to kill the well and 6,925.0 6,925.0 00:00 00:18 allow town to dicuss plan forward. Obtain SBHP to ensure 12.8 ppg flluid will kill well 4/7/2017 4/7/2017 6.00 PROD1 DRILL TRIP T Continue to circulate bottoms up 6,925.0 72.0 00:18 06:18 prepping to pump KWF.Displace well to KWF,POOH as per town request 4/7/2017 4/7/2017 1.30 PROD1 DRILL PULD T At Surface,flow check, PJSM lay 72.0 0.0 06:18 07:36 down BHA#5 4/7/2017 4/7/2017 0.70 PROD1 DRILL BHAH T M/U BHA#6, 0.0 0.0 07:36 08:18 4/7/2017 4/7/2017 1.20 PROD1 DRILL PULD T PJSM, P/U BHA#6 with 2.71°mortor 0.0 62.6 08:18 09:30 and RR HCC bi center,M/U to coil and surface test 4/7/2017 4/7/2017 1.50 PROD1 DRILL TRIP T Trip in well,EDC open 62.6 6,830.0 09:30 11:00 4/7/2017 4/7/2017 0.20 PROD1 DRILL DLOG T Log K1 for-.5' 6,830.0 6,851.0 11:00 11:12 4/7/2017 4/7/2017 0.10 PROD1 DRILL TRIP T Continue in to 6912 6,851.0 6,912.0 11:12 11:18 4/7/2017 4/7/2017 1.30 PROD1 DRILL CIRC T Displace well to 9.6 PPG PwrPro, 6,912.0 6,912.0 11:18 12:36 Close EDC 4/7/2017 4/7/2017 0.30 PROD1 DRILL TRIP T Trip in,clean pass through window, 6,912.0 6,981.0 12:36 12:54 set down at 6971,stack out two more times at different speeds.Wash down through tight spot to 6981 4/7/2017 4/7/2017 0.40 PROD1 DRILL WPRT T PUH to 6955 clean back down to 6,981.0 7,000.0 12:54 13:18 6985,wash down to 7000 Page 5/7 Report Printed: 5/3/2017 • • . Operations Summary (with Timelog Depths) , 3M-14 Conoco Phillips Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/7/2017 4/7/2017 1.80 PROD1 DRILL WPRT T 7000',PUH to 6964,PUW=25K clean 7,000.0 7,024.0 13:18 15:06 back down to 7000',wash down to 7010.At 7008 looks like more steady state drilling then washing, 1.5 BPM @ 4160 PSI FS,BHP=4210.Getting sand back entire time on bottom. 4/7/2017 4/7/2017 0.30 PROD1 DRILL WPRT T PUH wiper trip while restarting 7,024.0 6,953.0 15:06 15:24 database for MWD 4/7/2017 4/7/2017 0.50 PROD1 DRILL WPRT T RBIH,stack out @ 6973 stall @ 6975, 6,953.0 6,913.0 15:24 15:54 try to wash by stack out at 6974. Attempt to get by at min rate.No good 4/7/2017 4/7/2017 1.60 PROD1 DRILL WPRT T PUH through window,Open EDC and 6,913.0 6,930.0 15:54 17:30 jet4 1/2 liner, 1.7 BPM 4/7/2017 4/7/2017 2.50 PROD1 DRILL CIRC T Decision made to run liner.Displace 6,930.0 72.0 17:30 20:00 well to KWF 4/7/2017 4/7/2017 1.00 PROD1 DRILL TRIP T RBIH to log K1 for a-1'correction, 72.0 6,830.0 20:00 21:00 paint EOP flag 4/7/2017 4/7/2017 2.30 PROD1 DRILL TRIP T POOH,tag up 6,830.0 65.0 21:00 23:18 4/7/2017 4/8/2017 0.70 PROD1 DRILL PULD T Flow check,PJSM,Begin LD BHA#6 65.0 0.0 23:18 00:00 4/8/2017 4/8/2017 0.50 PROD1 CASING PULD T Complete LD BHA#6 0.0 0.0 00:00 00:30 4/8/2017 4/8/2017 2.30 COMPZ1 CASING PULD T PJSM,PU BHA#7(Non-Ported bull- 0.0 494.0 00:30 02:48 nose, 11 joints slotted liner,seal bore deployment sleeve),stab on,tag up, open EDC. 4/8/2017 4/8/2017 3.20 COMPZ1 CASING RUNL T RIH with liner,tie into EOP flag, 494.0 6,973.0 02:48 06:00 weight check,get to set depth of 6973' MD,close EDC,bring up pumps, release off liner. BOL=6973'MD, TOL=6524'MD 4/8/2017 4/8/2017 0.90 DEMOB MOVE DISP P POOH displacing well to seawater, 6,973.0 2,500.0 06:00 06:54 diesel freeze protect from 2500'. 4/8/2017 4/8/2017 1.20 DEMOB MOVE CIRC P PJSM,R/T LRS and load 30 BBIs 2,500.0 2,500.0 06:54 08:06 freeze protect diesel in coil,Chase FP with seawater,R/D LRS 4/8/2017 4/8/2017 0.70 DEMOB MOVE FRZP P Continue out of well laying in diesel 2,500.0 42.0 08:06 08:48 4/8/2017 4/8/2017 1.60 DEMOB MOVE PULD P PJSM, PUD BHA#7,Liner running 42.0 0.0 08:48 10:24 tools 4/8/2017 4/8/2017 2.00 DEMOB MOVE WWWH P Skid injector back to floor,Pull checks, 0.0 0.0 10:24 12:24 UQC,M/U nozzle and stab on.Jet stack and flush rig 4/8/2017 4/8/2017 1.60 DEMOB WHDBOP MPSP P PJSM,Rig up and set BPV 0.0 0.0 12:24 14:00 4/8/2017 4/8/2017 1.50 DEMOB MOVE CTOP P PJSM,Boot wire for slack mgmt,Stab 0.0 0.0 14:00 15:30 on well and reverse circulate 4/8/2017 4/8/2017 1.00 DEMOB MOVE CTOP P PJSM,Unstab injector and rig CT 0.0 0.0 15:30 16:30 cutter to injector,Cut 76'pipe to find wire.Trim total 100' 4/8/2017 4/8/2017 3.00 DEMOB MOVE CTOP P Prep coil and install coil connector, 0.0 0.0 16:30 19:30 pull test to 35K,pressure test UQC to 4000 psi 4/8/2017 4/8/2017 2.00 DEMOB MOVE RURD P Flush and blow down lines,methanol 0.0 19:30 21:30 freeze protect well to upper swab (visually verified). Page 6/7 Report Printed: 5/3/2017 S ICfri Operations Summary (with Timelog Depths) &Wens' 3M-14 ConocoPhitihps Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 4/8/2017 4/9/2017 2.50 DEMOB CASING NUND P Grease valves,ND BOPE,continue 0.0 0.0 21:30 00:00 rig down check list. "Rig released at 24:00,4-8-17 Page 7/7 Report Printed: 5/3/2017 . • . 3M-14 Final CTD Schematic Modified by WRL 1-May-17 3W 9.3#L-80 EUE 8rd-Mod tubing DS-nipple at 542' (ID=2 875") 3W Camco gas lift mandrels @ 2523',4115',5272',6113', 16",62.5#,H-40 at & 6423' MD 121'MD .. ` "'' Baker Seal Assembly @ 6479'MD Baker PBR @ 6486'MD Baker FHL Packer @ 6509'MD 9-5/8",36#,J-55 10111D-nipple at 6560'MD(2.813"min ID) at 3473'MD r Baker 80-40 Seal Assembly 6605'MD 1 Liner Top Packer @ 6524'MD 4-1/2"scab liner assembly Northern Solutions { ZXP liner-top packer at 6599'MD 1.78"R Nipple in Seal Assembly Ir.'.' FlexLock liner hanger at 6617'MD = = Baker 80-40 SBE 6627'MD :::11::::I 4-1/2",12.6 ppf,L-80,IBT-Mod scab liner 6599'-7217'MD II ii Top of Whipstock @ 6930'MD `\ Baker Gen II 3-1/2"x 4-1/2" ..i \\ Rocks in 4-1/2"liner at 6948'MD L; ��' • 4. 3M-14A TD @ 7073'MD A-sand perfs(sgz'd) �' 2-3/8"4.6#L-80 STL Slotted Liner @ 6975'MD 6940'-6976'MD . illhk `, (6'Seal Bore Deployment Sleeve,Solid Bull Nose) A-sand reperf ._ Multiple Hole Washout/Ledges Below 6956'-6976'RKB Casing damage in 7" .•• ,L• 4. ,i• 7",26#,J-55 at ,.5055 'ea" 7,224'MD V.Et rtir4r KUP reD 0 3M-14A •COn®COPI1ilhhp5 a Well Attributes Max Angle TD AIBska Inc, Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btrn(ftKB) [anocophilips , 500292172601 KUPARUK RIVER UNIT PROD 83.78 7,044.82 7,073.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-14A,519/20174.04.38 PM SSSV:NIPPLE 125 4/4/2013 Last WO: 41.90 6/5/1987 Vertical schemabc.(actua9 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK,SET LINER TOP pproven 5/9/2017 x ,:... PACKER HANGER,32.8 f ill Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread )1 It: CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H-40 welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len Q...Grade Top Thread ' ' ��■■■ �•'�SURFACE 9 5/8 8.921 37.0 3,473.1 3,376.7 36.00 J-55 BTC CONDUCTOR,38.0-121.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I PRODUCTION 7 6.276 34.8 7,224.0 26.00 J-55 BTC 111 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)... Wt/Len(I...Grade Top Thread NIPPLE;541.7 SCAB LINER 41/2 3.958 6,598.8 7,127.0 12.60 L-80 IBTM Liner Details Nominal ID I. Top(ftKB) Top(ND)(ftKB) Top Incl(°I Item Des Com (in) 6,598.8 5,953.3 33.55 PACKER Baker"2RH"ZXP Liner Top Packer w/10'Tie-back 4.300 al Ext,5"BTC BxP GAS LIFT,2,523.3 frb: 6,617.4 5,968.8 33.47 HANGER BAKER HYDRUALIC FLEX-LOCK LINER HANGER 4.400 in_ 6,627.2 5,977.0 33.42 SBE Baker 80-40 SBE,20'Long,5"BTC 4.000 lir Casing Description OD(in) Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Threatl LINER A 1 3181ID(in)1.9921Top 6,5260(ftKB) 1Set 6,975.01 6,266.71 4.601 L-80 STL Liner Details SURFACE;37.0-3,473.1--• Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 6,526.0 5,892.7 33.61'Deployment Seal bore deployment sleeve(6') 1.920 Sleeve GAS LIFT;4,1151 - Tubing Strings I I Tubing DescriptionMa...1 (in)2992)ID Top(ftKB) Set Depth(ft..Set Depth(ND)I...Wt(Iblft) Grade Top Connection TUBING WO 31/2 32.81 6,502.41 5,873.01 9. 301 L-80 IEUE Completion DiSitring s Details GAS LIFT;5,272.2 ' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Com (in) 32.8 32.8 0.00 HANGER FMC,GEN IV Tbg hanger w/3 1/2"TBG Pup. 2.992 541.7 541.7 0.31 NIPPLE 2.875"Landing Nipple w/'DS'Profile 2.875 6,479.7 5,854.1 33.74 SEAL ASSY Baker 80-40 GBH-22 Production Seal Assembly 2.990 GAS LIFT;6,113.2 , Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(N ..D)(. Wt(Ib/ft) Top Connection PACKER ASSY 'String 3.981 2.9801 6,486.2 6,643.51 5,990.61 1 Grade 1 EUE I I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Gom (in) GAS LIFT;6,423.2 6,486.2 5,859.5 33.70 PBR BAKER PBR 4.000 6,509.3 5,878.7 33.62 PACKER BAKER'FHL'PACKER 2.980 6,559.8 5,920.8 33.58 NIPPLE CAMCO 2.812"Landing Nipple w/'DS'Profile 2.812 4 6,605.6 5,959.0 33.52 SEAL ASSY BAKER 80-40 GBH-22 Production Seal Assembly w/2-ft 2.980 space out SEAL ASSY;6,479.7 1 m'''l Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PER;6,486.2 Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(In) PACKER;6,509.3 6,524.0 5,891.0 33.61 PACKER NS LINER TOP PKR w/POSITIVE TEST SEAL 4/13/2017 1.780 ASSY(1.78"ID/8.25'OAL LIH AFTER PULLING RSG) I ,i Mandrel Inserts -•�..� st PACKER;6,524.0 7'srah.Ir ah ° "ill N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,523.3 2,520.6 Cameo MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,270.0 5/22/2013 10:00 NIPPLE,65508 2 4,115.1 3,905.6 Cameo MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,268.0 5/22/2013 5:00 3 5,272.2 4,863.3 Cameo MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,277.0 5/22/2013 7:00 4 6,113.2 5,551.4 Cameo MMG 1 1/2 GAS LIFT 'OV RD02 0.250 0.0 5/22/2013 1:00 0 i� II w 5' 6,423.2 5,807.2 Cameo MMG 1 1/2 GAS LIFT DMY RK 0.000' 0.0 12/17/2012 6:30 W i; 4" Notes:General&Safety II V&/ End Date I Annotation SEAL ASSY,6,605.6 - 'ii``uu'G'VVii NOTE $ rol 'z R2 WI Liner Cement,6,598.8 ftKB %! 41 i i' LINER A,6,526.0-6,975.0 I 11 T I I SCAB LINER;6,598.8-7,127.0 PRODUCTION;34.6-7,224.0 KUP FD 3M-14 ConocoPhillips Well Attributes Max Angle TD AIOOkEL inn. Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) ConodePhgbps 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 39-14,5/9/20172,38,34 PM SSSV'NIPPLE 125 4/4/2013 Last WO: 12/19/2012 41.90 6/5/1987 vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date , Last Tag'SLM 6,919.0 9/19/2016 Rev Reason:PLUG 8 ABANDON pproven 5/9/2017 g HANGER,326 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) (ND) Top Inc) Top(ftKB) Top(ftKB) p I Des Com Run Date ID(in) e 6,933.8 6,234.5 32.37 WHIPSTOCK BAKER GEN II DELTA 3 1/2"x 4 1/2'WHIPSTOCK, 10/7/2016 3.500 , "" " " " v • . '. •. TOP OF WHIPSTOCK:6933.8', WHIPSTOCK CONDUCTOR,38.0-121.0a ORIENTATION:0 DEG,OAL-12.97 RA TAG 7.35' FROM TOP 11 7,127.0 6,398.5 31.50 FISH ESP motor parts,remnants of ESP motor pushed 12/3/2012 NIPPLE;541.7tat downhole to 7127 RKB w/workover 12/3/2012- should be fill to 7244'drillers TD(FRAC or formation al sand)6/10/2005-ESP motor parts,remnants of MI ESP motor pushed downhole to 7010 w/workover 6/10/2006 4 GAS LIFT;2,523.3 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ROB) (ftKB) (ftKB( Zone Date ft) Type Com 6,940.0 6,942.0 6,239.8 6,241.4 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SQZ liner 2012 i 6,944.0 6,945.0 6,243.1 6,244.0 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SURFACE;37.03,473.1-+J ` SQZ liner 2012 6,948.0 6,949.0 6,246.5 6,247.4 A-2,3M-14 8/16/1998 1.0 CMT Covered by CMT Scab SQZ liner 2012 GAS LIFT;4,115.1 6,954.0 6,992.0 6,251.6 6,283.7 A-1,3M-14 8/16/1987 4.0 CMT Covered by CMT Scab SQZ liner 2012 • • 6,956.0 6,976.0 6,253.3 6,270.2 A-1,3M-14 2/21/2013 2.0 RPERF HSC 2.5"w/180 degree • phasing,Millenium II HMX charges GAS LIFT;5,272 2 - Cement Squeezes Top(TVD) Btm(TVD) Top(ftKB) Btm(ROB) (ftKB) (ftKB) Des Start Date Com 6,598.8 7,127.0 5,953.3 6,398.5 Liner Cement 12/7/2012 Notes:General&Safety GAS LIFT;6,113.2 - - End Date Annotation 7/2/2006 NOTE:WORKOVER 7/28/2006 NOTE:PER CALIPER LOG 6/27/2006,SEVERE 7"CASING DAMAGE @ 6942'-6946' 111 8/17/2006 NOTE:RECOVERED ROCKS TO 1.5"DURING TAG GAS LIFT;6,423.2 a7/21/2008 NOTE:SAND 8 PEBBLES OBSERVED @ 6930' 4 10/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 12/19/2012 NOTE:WORKOVER SET CEMENTED 4.5"SCAB LINER TO COVER 7"PROD CSG DAMAGE SEAL ASSY6,476.2, PBR,6,486.2 NOM PACKER;6,509.3 x�' I iii NIPPLE;6,559.6 • I- w • A 4. w SEAL ASSY;8,605.6 1,4 'A til • w Liner Cement;6,598.6 ftKB S SCAB LINER;6,598.8-7,127.0 4 41 PRODUCTION;34.8-7,224.0. LINER A;6,526.08,975.0 4 • M WHIPSTOCK 6,933.8 A CMT SOZ,6,940.0-6,942.0 A. ti • ti CMT SOZ;6,944.0 6,945 0--- r s, .) V CMT SQL,6,948.0-6,949.0-.. t,' • V V ill w 4 11 RPERF;6,956.08,976.0 fr it CMT SQZ;6954.0-6,992.0 . V 4 • 4 • V A ti 4.4 y FISH;7,127.0 • LOF T� THE STATE Alaska Oil and Gas ofA T Q Conservation Commission _ 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov i11 Gary Eller �I "��? ` "' CTD Team Lead ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-14 Permit to Drill Number: 187-051 Sundry Number: 316-643 Dear Mr. Eller: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, 017 p'")4t..4/4 .Cath .. Foerster Chair DATED this Yjecray of December, 2016. RDDI s C` .jY-.i sLf ] 'i r. j • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION i (` APPLICATION FOR SUNDRY APPROVALS AOGG/2. ��z9�i C 20 AAC 25.280 1.Type of Request: Abandon 1_ I Plug Perforations E Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend 11-433 Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill [ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development E. 187-051, 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service PO Box 100360,Anchorage AK 99510 50-029-21726-00 k 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 04) KRU 3M-14 , 9.Property Designation(Lease Number): 17/0 10.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool ADL 25522 a,5$23 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): 4 j 0 cd Plugs(MD): Junk(MD): 7244' ' 6498' ' 7127' ` 6399' . 1. psi n/a 6954' Casing Length Size MD TVD Burst Collapse Structural Conductor 121' 16" 121' 121' Surface 3473' 9-5/8" 3473' 3377' 3520 psi 2020 psi Intermediate Production 7224' 7" 7224' 6481' 4980 psi 4320 psi Liner 528' 4-1/2" 7127' 6399' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6956-6976' 6253'-6270' 3-1/2" L-80 6502' Packers and SSSV Type: FHL packer at 6509'MD Packers and SSSV MD(ft)and TVD(ft): FHL packer at 5879'TVD ZXP liner-top packer @ 6599'MD ZXP liner-top packer at 5953'TVD 12.Attachments: Proposal Summary ❑� Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q 4 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 1/1/2017 El WINJ ❑ WDSPL 10 Suspended Commencing Operations: OIL 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Gary Eller Contact Email j.gary.eller a@conocophillips.com Printed Name Gary Eller Title CTD Team Lead ( o--?-Zb3- 4ki 2— Signature \ ilk Phone Date COMMISSION USE ONLY Conditions of approval: h.otify tommission so that a representative may witness Sundry Number: LI i1 it I LC . Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ • Other: Bap fi-e-5÷ fo 4 4_,,,5.1- 250o p5if CL \ /}-✓titerViGit-1IA_ yt,ei aipprroved �JZ� a7(J AA-G z,.7, lI 1 Post Initial Injection MIT Req'd? Yes ❑ No L ��� �Z�2-c' �►L Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: I0 -- "L b 7 (� APPROVED BY RBDMS Lt__ i 4152017 Approved by: P27124,1,—...._ COMMISSIONEF(�� T( IS 10 Date: `2 _3i_ l , Form 10-40 Revised 11/2015�tha 6rov,dpplicatio n is valid for 1211y6nf�brid a p al. Submit Form and Attachments in Duplicate j q ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 28, 2016 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad-lateral out of KRU 3M-14 (PTD# 187-051) using the coiled tubing drilling rig, Nabors CDR2-AC`'{rhe work may begin as soon as January 1, 2017. The CTD objective will be to drill four laterals (3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3), targeting the Kuparuk A-sand. The final CTD completion will fully isolate the 3M-14 mother bore, which suffers from damaged 4W liner and _ rock production. - here is insufficient room to properly abandon the 3M-14 mother bore with a plug or cement, so ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for alternate plugging which will isolate/abandon 3M-14 via swell packer and liner-top packer of the final CTD completion. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point of the laterals to be anywhere along the length of the parent borehole instead of being limited to 500'from the original point. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401) for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 — Sundry Application Form (10-403) for abandonment of 3M-14 — Detailed Summary of Operations — Directional Plans for 3M-14A, 3M-14AL1, 3M-14AL2, and 3M-14AL3 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information, please contact me at 907-263-4172. Since ely, A.., Gary Eller ConocoPhillips C " ubing Drilling Team Lead • KRU 3M-14 CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU 3M-14 is a Kuparuk A-sand production well that was worked over to install 4'/" scab liner to remediate rock production from the perfs, but it didn't take long for the 4'/2" scab liner to become damaged and rock production to resume so that the well is still not capable of production. Four CTD laterals will be drilled from the 3M-14 parent well-bore, two to the south and two to the north, to serve as a replacement wellbore and isolate section producing rocks. The mother completion will be isolated/abandoned using a 2%" swell packer and liner top packer—insufficient room exists to plug the mother completion with cement or a mechanical plug. ConocoPhillips requests a variance to the requirements of 20 AAC 25.112(c) for the alternate plugging method which will not risk migration of fluids between strata. Using the maximum formation pressure in the area of 4728 psi in 3M-26, the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 4108 psis CTD Drill and Complete 3M-14 Laterals: January 2017 Pre-CTD Work 1. RU Slickline: Obtain static bottom-hole pressure 2. RU E-line: Drift tubing and tag fill/rocks at 6954' MD 3. RU E-line: Set Baker Hughes whipstock at 6931' MD. 4. Prep site for Nabors CDR3-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. '1'11'3 2. 3M-14A Lateral (A sand - south) �vvdry i. Mill 2.80" window at 6931' MD. ii. Drill 3" bi-center lateral to TD of 9600' MD. iii. Run 2%" slotted liner with an aluminum billet from TD up to 7500' MD. Incbt, 3. 3M-14AL1 Lateral (A sand - south) P lb i. Kick off of aluminum billet at 7500' MD. ii. Drill 3" bi-center lateral to TD of 9650' MD. iii. Run 2%" slotted liner from TD up to 7200' MD. 4. 3M-14AL2 Lateral (A sand - north) i. Kick off of aluminum billet at 7200' MD. ii. Drill 3" bi-center lateral to TD of 10250' MD. iii. Run 2%" slotted liner from TD up to 6981' MD. 5. 3M-14AL3 Lateral (A sand - north) i. Kick off of aluminum billet at 6981' MD. ii. Drill 3" bi-center lateral to TD of 10250' MD. iii. Run 2%" slotted liner from TD up to 6575' MD. Liner will include a swell packer, blank 2%" liner, and a sealbore deployment sleeve to isolate/abandon the mother completion. !/D scar. Pro sed iot*aa(s .,(( be CO fr f °° w;t Page 1 of 2 (i her back ,^t0 ext)7- Weil jive c4,40( / ,f �� QJ� 12/28/2016 aw y fe5erve f reM o,";�f or Cvrrc'fT' 4d1 (6GaTP C", S • 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CDR2-AC. Post-Rig Work 1. Pull BPV. 2. Obtain SBHP. 3. Install liner-top packer onto the 2%" liner 4. Install GLV's. 5. Return to production. Page 2 of 2 12/28/2016 • • W w 2 II o 0 a❑ N Lo 2 Si b NII IIo II au r- _J `° IiI II II a 0— II II N - ❑ d J in 2N 1-,-. O a) (O II C C7 N 3 II II 3° as r Qa o > N J Q O II II ; N C co th I-coN -Q V CO 'CB M N O CO p Y — % /I 2. N m — o N Y c ❑ co to o rcn a) v .-›' >caco 0 2 N _o g�`m N E E M 07 O ' II N VY( a7 a1+' Cr y y 0) N N W uJ N(p U N Cca LI-J Lm J ❑ ❑ CM N LO LO0 .0 Qco Q II N o Q 0.. cO C' O C LO ',1;- ._I II M U E a)a2 Ca o YO ,_ co 0) O M —Oa. N°� U)U LL moo] N C U p0 CO ��`` Y Ilk II m C U EY Y 'ny N a X a) N V C 0 U C Cn \ C (0 co C ca `'X r- d C o N a M 0 M CO 000 ❑(0 V NLL07 V C awl C /� cLO lil0 N --ai as 73 o �'� a v 11 II DIm A ) xr N CO N o_ o I I II II ° r`r ci ILIISI III is . , - ,,. R �IkII, II I,I _ m a ! II ii Z. 1 o r0 I � 't cO c ❑ N I ❑ a)abca r- �La _ co II II .n = c0 N D.r a y 0 y* °'M a a c°'o No c T.3 np my Czo ma N II II o `m Nm2 LoM tA� tn� CO 3 II c Q N Q� <(O 0 N�a O. Y II II Ja�❑ d 0 mifi r c w� OLS II CSO) -2-__1 II M0N(O M O cp ,- C o a) NF- m o_ II II z a a .4 � E-N ° II II °o C co C C 3k co 0_N_ - - N J .i KUP PROD • 3M-14 ConocoPhillips �e&'W Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(-) MD(ftKB) Act Btm(ftKB) rfe,,.,�,lfi,;+,P, 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 .,. Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-14,313120169:22:54 AM SSSV:NIPPLE 125 4/4/2013 Last WO; 12/19/2012 41.90 6/5/1987 Ventral schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ............................__.._..........._......_..___....... .................Last Tag:SLM 6,926.0 3/30/2016 Rev Reason:TAG lehallf 3/31/2016 HANGER;32.8 �{I) ,, Casing Strings - Casing Deserlpdan OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(I...Grade Top Thread `I �', 11 CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H-40 welded - Caning Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.0 3,473.1 3,376.7 36.00 J-55 BTC CONDUCTOR;36.0-121.0 I ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 34.8 7,224.0 6,481.2 26.00 J-55 BTC it Casing Description OD(in) ID(in) Top(ftKB) Set Depth(WKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • NIPPLE;541.7 SCAB LINER 41/2 3.958 6,598.8 7,127.0 6,398.5 12.60 L-80 IBTM ilk 'Liner Details T II Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 6,598.8 5,953.3 33.55 PACKER Baker"2RH"ZXP Liner Top Packer w/10'Tie-back 4.300 GAS UFT;2.523,3 - Ext,5"BTC BxP 6,617.4 5,968.8 33.47 HANGER BAKER HYDRUALIC FLEX-LOCK LINER HANGER 4.400 6,627.2 5,977.0 33.42 SBE Baker 80-40 SBE,20'Long,5"BTC 4.000 Tubing Strings Tubing Description Me...ID(in) Top(ftKB) Set Depth(ft,Set Depth(ND)(...Wt(lb/ft) Grade Top Connection SURFACE;37.03,473.1-4 A TUBING WO 1String 3112 2.9921 32.81 6,502.41 5,873.01 9.301 L-80 I EUE ill Completion Details Nominal ID GAS LIFT;4,115.1Top((KB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 32.8 32.8 0.04 HANGER FMC,GEN IV Tbg hanger w/3 1/2"TBG Pup. 2.992 a 541.7 541.7 0.31 NIPPLE 2.875"Landing Nipple w/'DS'Profile 2.875 6,479.7 5,854.1 33.74 SEAL ASSY Baker 80-40 GBH-22 Production Seal Assembly 2.990 GAS LIFT;5,272.2 Tubing Description 1 String Ma...1ID(In) 'Top(ftKB) 'Set Depth(fL.1 Set Depth(ND)(...1 Wt(1671) 1Grade Top Connection III PACKER ASSY 3.98 2.980 6,486.2 6,643.5 5,990.6 EUE ill Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top incl(") Item Des Com (in) GAS LIFT;6,113.2 - 6,4862 5,859.5 33.70 PBR BAKER PBR 4.000 6,509.3 5,878.7 33.62 PACKER BAKER'FHL'PACKER 2.980 • 6,559.8 5,920.8 33.58 NIPPLE CAMCO 2.812"Landing Nipple w/'DS'Profile 2.812 11 6,605.6 5,959.0 33.52 SEAL ASSY BAKER 80-40 GBH-22 Production Seal Assembly w/2-ft 2.980 GAS LIFT;6,423.2 space out • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) -Top(ND) Top Inc! Top(ftKB) _ (ftKB) (3 Des Com Run Date ID(ie) __ 7,127.0 6,398.5 31.50 FISH ESP motor parts,remnants of ESP motor pushed 12/3/2012 downhole to 7127 RKB w/workover 12/3/2012- SEAL ASSY;6,479.7.E I = should be fill to 7244'drillers TD(FRAC or formation PBR:6,486.2 sand)6/10/2005-ESP motor parts,remnants of =II ESP motor pushed downhole to 7010 w/workover PACKER;6,509.3 6/10/1096 a Perforations&Slots Shot I. Dens Top(ND) Bter(TVD) (shots/f NIPPLE;6,559.6 = Top(ftKB) Btm(RKB) )ftKB) (ftKB) Zone Date t) Type Com 111 6,940.0 6,942.0 6,239.8 6,241.4 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab SQZ liner2012 6,944.0 6,945.0 6,243.1 6,244.0 A-2,3M-14 8/16/1987 1.0 CMT Covered by CMT Scab 17 I SQZ liner 2012 6,948.0 6,949.0 6,246.5 6,247.4 A-2,3M-14 8/16/1998 1.0 CMT Covered by CMT Scab 11 I' SQZ liner 2012 SEAL ASSY;6.605.6 1 ` I 6,954.0 6,992.0 6,251.6 6,283.7 A-1,3M-14 8/16/1987 4.0 CMT Covered by CMT Scab SQZ liner 2012 �#. 6,956.0 6,976.0 6253.3 6270.2 A-1,3M-14 2/21/2013 2.0 RPERF HSC 2.5"w/180 degree phasing,Millenium II HMX charges Cement Squee2(oft)e,s CMT SQZ;6,940.06.942.0 Top(ftKB) Btm(ftKBT(ft D. B(6K(B D) Des Start Date Com 6,598.8 7,127. 5,953.3 6,398.5 Liner Cement 12/7/2012 CMT 602;6,944.06,9450-^ Mandrel Inserts St CMT SQz;6,948.0-6,949.0,948.06,949.0 ati _ on Top(ND) Valve Latch Port Size TRO Run N Top(RKB) B) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com - 1 2,523.3 2,520.6 Camco MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,270.0 5/22/2013 10:00 2 4,115.1 3,905.6 Camco MMG 1 1/2 GAS LIFT GLV R-20 0.188 1,268.0 5/22/2013 5:00 3 5,272.2 4,863.3 Camco MMG 1 112 GAS LIFT GLV R-20 0.188 1,277.0 5/22/2013 7:00 RPERF;6,956.0-6,976.0�� CMT SOZ;5954.06,992.0-� 4 6,113.2 5,551.4 Camco MMG 1 1/2 GAS LIFT OV RD02 0250 0.0 5/22/2013 1:00 5 6,4232 5,807.2 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/17/2012 6:30 Notes:General&Safety End Date Annotation 7/2/2006 NOTE:WORKOVER 7/28/2006 NOTE:PER CALIPER LOG 6/27/2006,SEVERE 7"CASING DAMAGE @ 6942-6946' r I 8/17/2006 NOTE:RECOVERED ROCKS TO 1.5"DURING TAG l 7/21/2008 NOTE:SAND 8 PEBBLES OBSERVED @ 6930' 10/10/2010 NOTE:View Schematic w/Alaska Schematic9.0 SCAB LINER;6,598.8-7,1270 AL 12/19/2012 NOTE:WORKOVER SET CEMENTED 4.5"SCAB LINER TO COVER 7"PROD CSG DAMAGE FISH;7,127.0 PRODUCTION;34.8-7,224.0 S Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work)the initial reviewer will cross out that erroneous entry and initial ,/ then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 Whenthe "Plug Stat Tech receives a Form 10-403 with a check in the Stat Tech for Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July,the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. p To !8i- -6 5 / • • Loepp, Victoria T (DOA) From: Eller, J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday, December 28, 2016 2:19 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 3M-14 (187-051) CTD Sidetrack Follow Up Flag: Follow up Flag Status: Flagged Thanks From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 28, 2016 1:57 PM To: Eller,J Gary<J.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3M-14(187-051) CTD Sidetrack SCANNED APR 2 8 2017; We'll hand correct- From: Eller,J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent:Wednesday, December 28, 2016 1:53 PM To: Loepp,Victoria T(DOA)<yictoria.loepp@alaska.gov> Cc: Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: RE: KRU 3M-14(187-051) CTD Sidetrack Victoria—I just noticed that I checked the wrong box(see below) on the 10-403 for KRU 3M-14—I should have checked the 'Plug for Redrill' box. Is that something that you guys can hand-correct or do you want me to send a corrected version today? -Gary � ._.. F 13 H I J K L' 1 1V O STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMr'vlISSIOIJ APPLICATION FOR SUNDRY APPROVALS 20 Ak,C 25.280 1.-:pe cf Request: Abandon Q Plug Perforations Q Fracture Stimulate 9 Repair Well 9 Operations s ---I I Suspend 9 Perforate 9 Other Stimulate 9 Pull-ubing 9 Change Approved I Plug for Recrill 9 Perforate New Pool 9 Re-enter Susp Nell 9 Alter Casing 9 Other: 2.Operator Name: =. Current Well Class: F. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory 9 Development Q 157-0E1 0 3.Address: Stratigraphic Service E ^PI! umber: 1 PO Lox 10036G,Anchorage AK 99E10 EG-029-2172E-0 2 7. If perforating: S. Vile!!Name and Number: 3 'li hat Regulation or Conservation Order governs well spacing in this pool? KRU 3M-14 4 V,iill planned perforations require a spacing exception? Yes 9 No 9 5 9. Property Designation (Lease Plumber:: 10.Field/Pool(s): Kuparuk River Field Kuparuk Oil Pr 6 ADL 25522 i. From: Loepp,Victoria T(DOA) [ nailto:victoria.loepp@alaska.Rov] Sent:Wednesday, December 28, 2016 10:34 AM 1 • • To: Eller,J Gary<1.Gary.Eller@conochillips.com> Cc: Bettis, Patricia K(DOA)<patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: KRU 3M-14(187-051)CTD Sidetrack Thanx for the heads up- From: Eller,J Gary[mailto:J.Gary.Eller@conocophillips.com] Sent:Wednesday, December 28,2016 10:32 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Starck, Kai<Kai.Starck@conocophillips.com>; Haggerty-Sherrod,Ann (Northland Staffing Services)<Ann.Haggerty- Sherrod@contractor.conocophillips.com> Subject: RE: KRU 3M-14(187-051)CTD Sidetrack Victoria— I have four 10-401's and one 10-403 headed over to you today for KRU 3M-14. In related news, Nabors CDR2 is in the midst of a difficult workover on well 3M-24. We are going to make one last effort to retrieve a packer that has given us substantial trouble already. If we recover the packer, then we'll proceed according to our original plan. But if we fail, we plan to suspend that workover and move Nabors CDR2-AC to well 3M-14 to drill these laterals. That means there is the possibility that we will want to begin CTD operations on 3M-14 as early as January 1, 2017, so I request expedited approval of these drilling permits (at least the first one, 3M-14A). I'm sorry to rush you like that, but events have conspired against us. Thanks much for your help. -Gary Eller From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 28,2016 8:26 AM To: Eller,J Gary<J.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3M-14(187-051)CTD Sidetrack Hi Gary, We will still need a plug for redrill 10-403 for the motherbore to review the proposed abandonment.We will also approve the alternate plug placement approval as a part of that 10-403. Please submit the 10-403 plug for redrill with the PTDs even though the abandonment procedure will be accomplished during the CTD sidetrack. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp[a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 • • From: Eller,J Gary[mailto:J.Gary.Eller@conocophillips.com] Sent:Tuesday, December 27, 2016 3:15 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Burke,Jason<Jason.Burke@iconocophillips.com>; Connelly,Jeff <Jeff.S.Connelly@conocophillips.com>;Starck, Kai<Kai.Starck@conocophillips.com> Subject: KRU 3M-14(187-051)CID Sidetrack Victoria—In just a few days, ConocoPhillips will be submitting 10-401's for CTD sidetrack/laterals from KRU 3M-14 (187- 051). Well 3M-14 is a rock producer that is incapable of production, and the CTD sidetrack will restore this lost productivity. The attached schematic shows that following the sidetrack, the new CTD borehole will be completed with 2- 3/8"swell packer and liner-top packer in order to permanently isolate the existing, rock-producing perfs of KRU 3M-14. I wanted to contact you because the abandonment of the motherbore, 3M-14, is unusual in that we are unable to mechanically abandon the perforated, rock-producing interval prior to CTD sidetrack. There is just sufficient room above the compromised 4W scab liner for a single whipstock exit, and we do not have room for a cement plug or other mechanical isolation. However, the final CTD completion with swell packer and liner-top packer will permanently isolate the mother completion. It is ConocoPhillips intention to do the following: • We will submit the 10-401s as a sidetrack of 3M-14(i.e. 3M-14A)since the mother completion will be fully isolated/abandoned. • The 10-401s will address the completion plan which will isolate/abandon KRU 3M-14 (187-051). We recognize that this isolation method does not meet the requirements of 20 AAC 25.112(c), but we believe it meets the intent of accomplishing the sidetrack and restoring production without risking migration of fluids to other zones. • Since there are no pre-CTD operations that need to be performed to abandon 3M-14, we do not intend to submit a 10- 403 for the isolation/abandonment; that will be addressed in the 10-401s. We do plan to submit a 10-407 post-CTD for the abandonment of 3M-14 (187-051)as permitted under the 10-401s. Please contact me if you'd like to discuss this further. « File: 3M-14 proposed PTD schematic.pdf» 3. Gary Eller CTD Team Lead ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 3 • • PTD 18,7 -65-1 Loepp, Victoria T (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Wednesday, December 28,2016 8:32 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 3M-14 (187-051)CTD Sidetrack Follow Up Flag: Follow up Flag Status: Flagged Victoria— I'm glad to do a 10-403 if that's what you need, but there would be no physical operations covered by the 10- 403. The only abandonment operations would be covered by the completion as described in the 10-401. -Gary From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, December 28,2016 8:26 AM To: Eller,J Gary<J.Gary.Eller@conocophillips.com> Subject: [EXTERNAL]RE: KRU 3M-14(187-051)CTD Sidetrack Hi Gary, We will still need a plug for redrill 10-403 for the motherbore to review the proposed abandonment.We will also approve the alternate plug placement approval as a part of that 10-403. Please submit the 10-403 plug for redrill with the PTDs even though the abandonment procedure will be accomplished during the CTD sidetrack. Thanx, Victoria Victoria LoeppFEB 0 201i7 Senior Petroleum Engineer sC���� State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa,alaska.ciov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Eller,J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent:Tuesday, December 27,2016 3:15 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Burke,Jason<Jason.Burke@conocophillips.com>;Connelly,Jeff <Jeff.S.Connelly@conocophillips.com>;Starck, Kai<Kai.Starck@conocophillips.com> Subject: KRU 3M-14(187-051)CTD Sidetrack 1 • Victoria—In just a few days, ConocoPhillips will be submitting 10-401's for CTD sidetrack/laterals from KRU 3M-14 (187- 051). Well 3M-14 is a rock producer that is incapable of production, and the CTD sidetrack will restore this lost productivity. The attached schematic shows that following the sidetrack, the new CTD borehole will be completed with 2- 3/8"swell packer and liner-top packer in order to permanently isolate the existing, rock-producing perfs of KRU 3M-14. I wanted to contact you because the abandonment of the motherbore, 3M-14, is unusual in that we are unable to mechanically abandon the perforated, rock-producing interval prior to CTD sidetrack. There is just sufficient room above the compromised 4%"scab liner for a single whipstock exit, and we do not have room for a cement plug or other mechanical isolation. However, the final CTD completion with swell packer and liner-top packer will permanently isolate the mother completion. It is ConocoPhillips intention to do the following: • We will submit the 10-401s as a sidetrack of 3M-14 (i.e. 3M-14A)since the mother completion will be fully isolated/abandoned. • The 10-401s will address the completion plan which will isolate/abandon KRU 3M-14 (187-051). We recognize that this isolation method does not meet the requirements of 20 AAC 25.112(c), but we believe it meets the intent of accomplishing the sidetrack and restoring production without risking migration of fluids to other zones. • Since there are no pre-CTD operations that need to be performed to abandon 3M-14,we do not intend to submit a 10- 403 for the isolation/abandonment; that will be addressed in the 10-401s. We do plan to submit a 10-407 post-CTD for the abandonment of 3M-14 (187-051)as permitted under the 10-401s. Please contact me if you'd like to discuss this further. « File: 3M-14 proposed PTD schematic.pdf» 3. Gary Eller CTD Team Lead ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 2 • • — T I I 1 co cu0 o cuco 3 :, ' W V r Q ill 0L o u O L^ 1 V ONW01) N O }' 1 ' r O ¢ m 00 4- -0 y to 1 0 a E a r a-2 o — N r r r r r CD O y a O u a` a vc > Y ro ,., co 'c w4, p v io Q u o • v o cr co Q Y 0 -4 ' U t0 t0 co t0 t0 O 60 t0 t0 w c a) u N • — O w CO u o u t) 0 0 0 0 6 i J N 0 0 0 0 O O O O o c c u L a 2 N t.. FW- N N NA 6 h 00 D7 OU -p r0 O z Q ❑ N > p v P,id (0 a -O N U ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ILOa 0 W J J J J J J J J J J C 4- aWWW W W W W W W W a c ' F"' LL LL LL LL LL LL LL LL LL LL 0 Q J J J J J J J J J J - Y Q Q Q Q Q Q Q Q Q Q v a C O c, o z z z z z z z z z z cu _c a +,ill > LL LL LL LL LL LL LL LL LL LL CC - -0 a 00 Y F Y*' N a _c O _o O E a. u a a u a U z O N c O 4= rro ° N Y u r + — O F 1_ c rao a o .o Z RI O V 3 Y Q a a o c a �p r! u V Ip i, w LL N U- CO U- 7 p 6) N —I br G 1, O 0 O a 0 c 0 Y y C sc CV QJ C o _, a .ca a s o ° a = m \� d+ '0 y 01 4.= (0av u) I- CI. 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November 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 „ r ri RE: Multi Finger Caliper (MFC): 3M-14 Run Date: 10/8/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3M-14 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21726-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: SignedG xtgI 6eduade Image 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. Organization (done) Well History File Identifier RESCA~' [] .olor items: ~ Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: q (~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ Scanned (done) SCANNED BY: (at the time of scanning) BEVERLY B SHERYL MARIA LOWELL RESCANNED BY: BEVERLY BREN VINCEN ARIA LOWELL General Notes or Comments about this file: PAGES: Quality Checked (done) Rev I NOTScanned.wpd STATE OF ALASKA ALL(A OIL AND GAS CONSERVATION CO ISSION - REPORT OF SUNDRY WELL OPERATIONS , °,,� i -N� 1. Operations Performed: Abandon r Repair w ell r Rug Perforations j•` Perforate Ai Other E Alter Casing l Pull Tubing r Stimulate - Frac r Waiver E Time Extension r Change Approved Program rOperat. Shutdow n F Stimulate - Other ;i Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: — ConocoPhillips Alaska, Inc. Development j Exploratory F _ " 187 -051 3. Address: 6. API Number: Stratigraphic r- Service E r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21726 - 00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25523, 25522 -- N 3M - 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7244 feet Plugs (measured) None true vertical 6498 feet Junk (measured) 7127 Effective Depth measured 7129 feet Packer (measured) 6509, 6599 true vertical 6400 feet (true vertical) 5879, 5953 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 121 121 SURFACE 3436 9.625 3473 3377 4 1/2 SCAB LINE 528 4.5 7127 6399 PRODUCTION 7189 7 7217 6475 SCANNED APR 1 6 2073 Perforation depth: Measured depth: 6940 -6942, 6944 -6945, 6948 -6949, 6954 -6992 True Vertical Depth: 6240 -6242, 6243 -6244, 6247 -6248, 6252 -6284 Tubing (size, grade, MD, and TVD) 3.5, L -80, 6502 MD, 5873 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER "FHL" PACKER @ 6509 MD and 5879 TVD PACKER - BAKER "2RH" ZXP LINER TOP PACKER @ 6599 MD and 5953 TVD NIPPLE - LANDING NIPPLE @ 542 MD and 542 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development . Service r Stratigraphic r 16. Well Status after work: .Oil ji Gas E VVDSPL r Daily Report of Well Operations XXX GSTOR J — VVINJ r WAG r GINJ F SUSP F SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce Email John .W.Peirce Printed Name John Peirce Title Wells Engineer Signature / Phone: 265 -6471 Date //� 6 3 Form 10 -404 Revised 10/2012 k 1/7F--- r - Submit Original Only 1 � SDMS MAR 21 20'3 ; � 4/ 1 y,-/) 3M -14 Well Work Summary • DATE SUMMARY • • 2/20/2013 PERFORATED INTERVAL FROM 6956'-6976' WITH 2.5" HSC WITH TOP SHOT ORIENTED AT ZERO DEGREES AND 180 DEGREE PHASING, LOG CORRELATED TO SLB CYBERLOOK 4JUNE87, WILL RETURN NEXT DAY TO FINISH FOLLOWING 2/21/2013 PERFORATED INTERVAL 6956' -6976' USING HSC 2.5" WITH 180 DEGREE PHASING, 2 SPF MILLENIUM II HMX CHARGES, TOP SHOT ORIENTED AT 180 DEGREES, CORRELATED TO SLB CYBERLOOK 4JUN87, PERFORATING . i KUP • 3M -14 ConocoPhillips /= Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API/UWI Field Name Wellbore Status Inc! ( °) MD (ftKB) Act Btm (ftKB) rano 4.h anpfi 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date ••• WeIIConOq: -3M.14, 3/4(2013254.5 PM SSSV: NIPPLE 155 12/7/2005 Last WO: 12/19/2012 41.90 6/5/1987 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 6,993.0 2/15/2013 Rev Reason: TAG, PERF haggea 3/4/2013 c asinq Strings HANGER. 33 Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H welded Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 37.0 3,473.1 3,376.7 36.00 J -55 BTC CONDUCTOR, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 38 -121 PRODUCTION 7 6.276 27.8 7,217.0 6,475.2 26.00 J -55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r SCAB LINER 41/2 3.958 6,598.9 7,127.0 6,398.5 12.60 L -80 IBTM NIPPLE. 542 Liner Details Top Depth (TVD) Top Ici Noml... Top (RKB) (ftKB) ( °) Item Description Comment ID (In) 6,598.9 5,953.3 33.56 PACKER Baker "2RH" ZXP Liner Top Packer w/ 10' Tie -back Ext, 5" BTC BxP 4.300 GAS LIFT, = 2,523 6,617.5 5,968.9 33.29 HANGER BAKER HYDRUALIC FLEX -LOCK LINER HANGER 4.400 r 6,627.3 5,977.0 33.27 SBE Baker 80-40 SBE, 20' Long, 5" BTC 4.000 Tubing Strings Tubing Description String 0... String ID ... (MB) Set Depth (1... Depth (TVD)... String Wt... String ... String Top Thrd TUBING WO I 3 1/2 2.992 I Top 32.8 I 6,502.4 I Set D 5,873.4 I 9.30 I L -80 I EUE SURFACE. A L Completion Details 37 -3,473 Top Depth (TVD) Top Inc] Nomi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) GAS LIFT ,115 ` - -. 32.8 32.8 0.20 HANGER FMC, GEN IV Tbg hanger w/ 3 1/2" TBG Pup. 2.992 541.7 541.7 0.31 NIPPLE 2.875" Landing Nipple w /'DS' Profile 2.875 6,479.7 5,854.1 33.74 SEAL ASSY Baker 80-40 GBH -22 Production Seal Assembly 2.990 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT. PACKER ASSY I 3.98 I 2.980 I 6,486.2 I 6,643.5 I 5,990.6 I I I EUE 5,272 f - Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) GAS UFT ,113 6,486.2 5,859.5 33.70 PBR BAKER PBR 4.000 6 IIIIII _ 6,509.3 5,879.1 33.99 PACKER BAKER 'FHL' PACKER 2.980 6,559.8 5,920.9 33.74 NIPPLE CAMCO .812" Landing Nipple w/ 'DS' Profile 2.812 6,605.6 5,959.0 33.32 SEAL ASSY BAKER 80-40 GBH -22 Production Seal Assembly w/ 2 -ft space out 2.980 GAS LIFT, 6.423 Other In Hole (reline retrievable plugs, valves, pumps, fish, etc.) - Top Depth NM (TVD) Top Incl T op (ftKB)1 (ftKB) (1 Description Comment Run Date ID (In) SEAL Asst, I 7,127.0 6,398.5 31.50 FISH 12/03/12- ESP MOTOR PARTS REMNANTS OF ESP 12/3/2012 MOTOR PUSHED DOWNHOLE TO 7,127- ORKB 6,460 • w/WORKOVER 12/03/2012 SHOULD BE FILL TO 7244' - PBR, 6,486 DRILLER'S TD (FRAC OR FORMATION SAND) 06/10 /2006- ESP MOTOR PARTS REMNANTS OF ESP PACKER, 8,509 MOTOR PUSHED DOWNHOLE TO 7,010 -8 w/WORKOVER 6/10 /2006, SHOULD BE FILL TO 7244' - DRILLER'S TD (FRAC OR FORMATION SAND) Perforations & _ Slots NIPPLE, 6,560 W. Shot Mr Top (ND) Btm (TVD) Dens _ Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Date (sIt Type Comment 1 6,940.0 6,942.0 6,239.9 6,241.6 A -2, 3M -14 8/16/1987 1.0 CMT COVERED BY CEMENTED 4.5" SQZ SCAB LINER 2012 °° 6,944.0 6,945.0 6243.3 6,244.1 A -2 3M - 14 8/16/1987 1 CMT COVERED BY CEMENTED 4.5" I SQZ SCAB LINER 2012 -I SEAL ASSY, I -I 6,948.0 6,949.0 6,246.6 6,247.5 A -2, 3M -14 8/16/1998 1.0 CMT COVERED BY CEMENTED 4.5" 6,606 tiR SQZ SCAB LINER 2012 � __ 6,954.0 6,992.0 6,251.7 6,283.7 A -1, 3M -14 8/16/1987 4.0 CMT COVERED BY CEMENTED 4.5" SQZ SCAB LINER 2012 ? 6,956.0 6,976.0 6,253.4 6,270.2 A -1, 3M -14 2/21/2013 2.0 RPERF Using HSC 2.5" w/180 degree phasing, MILLENIUM II HMX CHARGES, TOP SHOT ORIENTED cmrsoz, __ .I _ AT 180 DEGREES 6,940 -6,942 CMT 60Z, Cement Squeezes 6,944 -6,945 - _ 1 ,' To`Te Depth n e th Bt Depth CMT SOZ, - I • Top (ftKB) Btm (ftKB) (ftKB) (RKB) Description Start Date Comment 9.9466.049 - I 6,598.8 7,127.0 5,953.3 6,398.5 Liner Cement 12/7/2012 Notes: General & Safety End Date Annotation RPERF, ., 7/2/2006 NOTE: WORKOVER 6,956 -8,976 1 CMT SOZ, '&:: 4: - 7/28/2006 NOTE PER CALIPER LOG 6/27/2006 SEVERE 7" CASING DAMAGE @ 6942 6,9546,992 T1 I 8/17/2006 NOTE: RECOVERED ROCKS TO 1.5" DURING TAG 1 '` Mandrel Details Top Depth Top Port (ND) 1561 OD Valve Latch Size TRO Run N... Top (RKD) (ftKB) (°) Make Model (in) Sery Type Type ( (psi) Run Date Com... 1 2,523.3 2,520.6 11.25 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,206.0 1/18/2013 2 4,115.1 3,905.9 34.76 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,217.0 1/18/2013 3 5,272.2 4,863.3 34.95 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 1/18 /2013 4 6,113.2 5,551.3 34.54 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/2012 Liner Cement, 5 6,423.2 5,807.2 34.03 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/17/2012 6,599 SCA9 LINER. 6,599 - 7,127 \) FISH, 7,127 PRODUCTION, 28-7,217 70,7.244 STATE OF ALASKA , AL.A OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell Plug Fbrforations r Perforate P Other r Alter Casing F Pull Tubing rj Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 187 - 051 3. Address: 6. API Number: Stratigraphic r Service r - 50- 029 - 21726 -00 P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25523, 25522 - 3M - 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7244 feet Plugs (measured) None true vertical 6498 feet Junk (measured) 7127 Effective Depth measured 7129 feet Packer (measured) 6509, 6599 true vertical 6400 feet (true vertical) 5879, 5953 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 121 121 SURFACE 3436 9.625 3473 3377 4 1/2 SCAB LINE 528 4.5 7127 6399 RECEIVED PRODUCTION 7189 7 7217 6475 JAN 1 1 2013 AO CC Perforation depth: Measured depth: 6940 -6942, 6944 -6945, 6948 -6949, 6954 -6992 True Vertical Depth: 6240 -6242, 6243 -6244, 6247 -6248, 6252 -6284 SCANNED MAR 01 2013 Tubing (size, grade, MD, and TVD) 3.5, L -80, 6502 MD, 5873 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER "FHL" PACKER @ 6509 MD and 5879 TVD PACKER - BAKER "2RH" ZXP LINER TOP PACKER @ 6599 MD and 5953 TVD SSSV - LANDING NIPPLE @ 542 MD and 542 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): see attached summary Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - in 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p _ Service r Stratigraphic r 16. Well Status after work: ,Oil p' Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -243 Contact Brett Packer 265 -6845 Email J. Brett.Packerna.conocophillips.com Printed Name Brett Packer Title Sr. Wells Engineer Signature ` f Phone: 265 -6845 Date r/(0 , 7 0- / I Form 10-404 Revisefenms JAM 1 11013 ��9�" ( 1 Z - i 3 Submit Original Only At KU P 3M -14 COnOCOPI1ddhp5 [Well Attributes Max Angle & MD TD kK Wellbore APUUWI Field Name Well Status Inc/ (1 MD (ftKB) Act Btm (ftKB) canool„akp, 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "•• Well COn(g' - 3M - 14, 1OR01317:14'51 AM SSSV: NIPPLE 155 12/7/2005 Last WO: 12/19/2012 41.90 6/5/1987 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: CTMD 6,970.0 1/3/2012 Rev Reason: WORKOVER osborl 1/7/2013 Casing Strings HANGER, 33 Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H - 40 welded , r Casg Description ing 0. .. String ID ... Top (B) S et Depth (.. Set Depth (TVD) ... String Wt... String ... String Thrd SURFACE 95/8 8.921 37. 3,473.1 1. 3,37 36.00 J -55 BTC Casining Descriptlon Str String 0. .. String ID ... Top (ftKB) Set Depth (L.. Set Depth (TV ... String Wt... String . .. String Top Top Thrd CONDU PRODUCTION 7 6.276 27.8 7,217.0 6,475.2 26.00 J -55 BTC 36- Casing Description String 0 . .. String ID ... Top (ftKB) Set Depth (1 Set Depth (TVD) ... String Wt String ... String Top Thrd SCAB LINER 41/2 3.958 6,598.9 7,127.0 6,398.5 12.60 L -80 IBTM NIPPLE, 542 - Liner Details Top Depth (TVD) Top Inc/ Nomi... ilill Top (ftKB) (ftKB) (") item Description Comment ID (in) - 6,598.9 5,953.3 33.56 PACKER Baker "2RH" ZXP Liner Top Packer w/ 10' Tie -back Ext, 5" BTC BxP 4.300 GAS LIFT, AWL 6,617.5 5,968.9 33.29 HANGER BAKER HYDRUALIC FLEX -LOCK LINER HANGER 4.400 2.523 ■ 6,627.3 5,977.0 33.27 SBE Baker 80 SBE, 20' Long, 5" BTC Tubing Description String 4.000 Tubing Strings l a' .. ng D IKB) ep.. ( ... g Wt.ring .. Completion Details . String Top Thrd TUBING WO 31/2 Stri 2.992 ... I Top 32(ft.8 I Set 6 4 (1. Set Depth 5 TVD) I Strin 9.3.. 0 I St L -80 I EUE 11 SURFACE. . \ Top Depth 37-3,473 (TV Top In Nomi... Top (ftKB) (ftK ( ° ) Item Description Comment ID (!n) 32.8 3 0.20 HANGER FMC, GEN IV Tbg hanger w/ 3 1/2" TBG Pup. 2.992 GAS LIFT, 4 541.7 54 0 NIPPLE 2. 875" Landing Nipple w /'DS' Profile 2.875 • 6,479.7 5,854.1 3 3.74 SEAL ASSY Ba 80-40 GBH -22 Production Seal Assembly 2.990 Tubing Descri PACKER ASSY ptio Stri 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd I 398 I 2.980 I 6 ,48 6 .2 I 6.643 .5 5,990.6 EU E GAS LIFT, 5,272 Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 6,486.2 5,859.5 33.70 PBR BAKER PBR 4.000 GAS LIFT, 6,509.3 5,879.1 33.99 PACKER BAKER 'FHL' PACKER 2.980 6,113 6,559.8 5,920.9 33.74 NIPPLE CAMCO 2 .812" Landing Nipple w /'DS' Profile 2.812 6,605.6 5,959.0 33.32 SEAL ASSY BAKER 80-40 GBH -22 Production Seal Assembly w/ 2 -1t space out 2.980 GAS LIFT, Other In Hole (Wireline retrievable • lu • s, valves, • um , is, fish , etc.) (TVD) Top Inc! 6. 423 Top Depth Er Top (RKB) (RKB) ( °) Description Comment Run Date ID (In) 7,127.0 6,398.5 31.50 FISH 12/03/12- ESP MOTOR PARTS REMNANTS OF ESP 12/3/2012 MOTOR PUSHED DOWNHOLE TO 7,127- ORKB w/WORKOVER 12/03/2012 SHOULD BE FILL TO 7244' - SEAL ASSY. DRILLER'S TD (FRAC OR FORMATION SAND) 6,480 06/10/2006- ESP MOTOR PARTS REMNANTS OF ESP PBR' 6'486 MOTOR PUSHED DOWNHOLE TO 7,010 -ft w/WORKOVER 6/10/2006, SHOULD BE FILL TO 7244' - DRILLER'S TD PACKER, 6,509 : � (FRAC OR FORMATION SAND) <Perforations & Slots - Shot gam^ Top (T1/0) Btm (TVD) Dens NIPPLE, 6,560 1 lop (ftKB) Btm (flK8) (flK8) (ftKB) Zone Date ( Type Comment i alt 6,940.0 6,942.0 6,239.9 6,241.6 A -2, 3M -14 8/16/1987 1.0 CMT COVERED BY CEMENTED 4.5" SQZ SCAB LINER 2012 6,944.0 6,945.0 6,243.3 6,244.1 A -2, 3M -14 8/16/1987 1.0 CMT COVERED BY CEMENTED 4.5" SQZ SCAB LINER 2012 6,948.0 6,949.0 6,246.6 6,247.5 A-2, 3M -14 8/16/1998 1.0 CMT COVERED BY CEMENTED 4.5" SQZ SCAB LINER 2012 SEAL ASSY, I ;i;:i:; 6,606 \; 6,954.0 6,992.0 6,251.7 6,283.7 A -1, 3M -14 8/16/1987 4.0 CMT COVERED BY CEMENTED 4.5" -i SQZ SCAB LINER 2012 r � Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (RKB) (RKB) Description Start Date Comment CMT SQZ. 6,598.8 7,127.0 5,953.3 6,398.5 Liner Cement 12/7/2012 6,940 -6,942 Notes: General & Safety 1 End Date Annotation CMT SQZ, 7/2/2006 NOTE: WORKOVER 6,944 6 ill 7/28/2006 NOTE: PER CALIPER LOG 6/27/2006, SEVERE 7" CASING DAMAGE @ 6942 CMT SOZ, 8948 949 8/17/2006 NOTE RECOVERED ROCKS TO 1.5" DURING TAG `. 7/21/2008 NOTE SAND & PEBBLES OBSERVED @ 6930' 10/10/2010 NOTE View Schematic w/ Alaska Schemafic9.0 CMT SOZ, 6,954$992 _ - i 12/19/2012 NOTE: WORKOVER SET CEMENTED 4.5" SCAB LINER TO COVER 7" PROD CSG DAMAGE Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (RKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 2,523.3 2,520.6 11.25 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/2012 • 2 4,1151 3,905.9 34.76 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/2012 • 3 5272.2 4,863.3 34.95 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/12/2012 4 6,113.2 5551.3 3454 Camco MMG 11/2 GAS LIFT DMY RK 0.000 00 12/12/2012 Liner Cement, ':: >: 6,599 I:, 5 6,423.2 5807.2 34.03 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/18/2012 SCAB LINER, 8,599 -7,127 FISH, 7,127 PRODUCTION, 28 -7.217 10.7.244 3M -14 Pre Rig Well Work Summary DATE JOBTYF SUMMARY 6/24/12 Drilling : BRUSHED & FLUSI., GAUGED TBG TO D NIPPLE @ 6828' 03. ATTEMPTED SET CA -2 PLUG, FAILED TO FULLY PENETRATE NIPPLE. SET CAT SV IN D NIPPLE, TESTED TBG 3500 PSI. IN PROGRESS. 6/25/12 Drilling :PULLED SV FROM D NIPPLE © 6828' RKB; REPLACED WITH CA -2 PLUG. PUT POSITIVE AND NEGATIVE TESTS ON PLUG, PASSED. SET CATCHER SUB ON PLUG. PULLED GLVs @ 4228' & 2800' RKB, REPLACED WITH DVs. IN PROGRESS. 6/26/12 Drilling : PULLED 1.5" OV FROM STA # 3 @ 5319' RKB, CIRCULATED 200 BBLS OF DIESEL DN TBG TAKING RETURNS UP IA, SET 1.5" DMY VLV IN STA # 3 @ 5319' RKB, MITIA TO 3500 PSI * *PASS ** MITOA TO 1800 PSI * *PASS** JOB COMPLETE 6/29/12 Drilling ; (PRE RWO) : POT -T PASSED, PPPOT -T PASSED, POT -IC PASSED, PPPOT -IC PASSED, FUNCTIONED TESTED LDS'S (ALL GOOD). 7/5/12 Drilling : GAUGE TBG TO 2.85" TO TRMAXX -5E SSSV @ 1998' RKB, EXERCESIE FLOW TUBE AND SEE GOOD MOVEMENT, PULL CATCHER ON PLUG @ 6828' RKB, PULL PRONG f/ 2.75" CA -2 PLUG @ 6828' RKB, PULL PLUG BODY @ SAME, PLUG BODY LEFT IN SSSV @ 1998' RKB. IN PROGRESS. 7/6/12 Drilling ; PULL 2.75" CA -2 PLUG BODY ( NO -GO RING DEFORMED ) f/ SSSV @ 1998' RKB, RAN FLAPPER CHECKER TO CONFIRM SSSV NOT DAMAGED, MEASURE BHP ( 4842 psi ) © 6942' RKB. WELL HISTORY FROM LAST TWO CA -2 PLUGS INDICATES POSS. DAMAGED D- NIPPPLE @ 6828' RKB. IN PROGRESS. 7/13/12 Drilling : RAN 2.85" NO -GO DRIFT TO 1998' RKB, CLEAR. RAN 3 -1/2 DEFORMATION LOCK OUT TOOL. ATTEMPTED LOCK OUT SCSSSV © 1998' RKB, NO SUCCESS. IN PROGRESS. 7/14/12 Drilling ; BRUSHED TRMAXX 5E SSSV © 1998' RKB. LOCKED OUT SSSV FLAPPER. RAN FLAPPER CHECKER, CONFIRMED LOCKED OUT. NEED PULL DV PRIOR TO RIG ARRIVAL. 10/6/12 Drilling : PULLED DV @ 6680' RKB. READY TO LOAD WELL WITH BRINE. 10/7/12 Drilling : BULLHEADED 110 BBLS 10.5 CaCl2 BRINE FOLLOWED BY 66 DIESEL DOWN IA AND 36 BRINE FOLLOWED BY 22 DIESEL DOWN TBG. ONLY ABLE TO LOAD @ 1 BPM DUE TO HIGH BHP; INITAL PRESSURES 2500/2500/450; FINAL 2250/2550/190. RECOMMEND CHECKING PRESSURES AGAIN ONCE WELL STABILIZES. 10/13/12 Drilling : Bled off diesel freeze - protect from tubing (20 -bbl) and IA (66 -bbl) to open -top tank. Attempted to inject into well but unable due to possible covered perfs. Circulated 105 -bbl 10.5# CaCI brine down IA taking returns up tubing to tanks, holding 3500 -psi back pressure on tubing to avoid wellbore influx. 3M -14 Post Rig Well Work Summary 12/4/12 Drilling :***RIG JOB*** LOG CALIPER FROM 7126' TO SURFACE. LOG CORRELATED TO CASING DETAIL RECORD DATED 05 JUN 1987. FIELD INTERPRETATION OF DATA SHOWS AREA BETWEEN 6625' -6640' AS CLEANEST SECTION TO PLACE ZXP LINER TOP PACKER. READY FOR SCAB LINER. 12/18/12 Drilling : DRIFT TBG TO DS- NIPPLE @ 6559' RKB; SET CATCHER @ 6559' RKB; PULL SOV @ 6423' RKB AND SET DV; MITIA TO 2500 PSI * *PASS ** PULLED CATCHER SUB © 6559' RKB. IN PROGRESS. 1/3/13 Drilling ; CTU FCO (swap out drilling mud) down to hard tag © 6,970' CTMD. Maintained 1:1 returns. Well freeze protected and ready for E -Line. Perform weekly BOP test. • Conoco Phillips Time Log & Summary Welvfew Web Reporting Report Well Name: 3M - 14 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/29/2012 4:00:00 PM Rig Release: 12/14/2012 2:30:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/29/2012 24 hr Summary MIRU Nordic Rig 3. Pull BPV and VR plug. Load and Kill well with 15.3 PPG KWF. 16:00 18:00 2.00 MIRU MOVE MOB P MIRU and Accept Rig. Shim to level and set down Rig. Rig up hardline and flowback tanks. Berm up around rig. Lubricate out VR plug. 18:00 18:30 0.50 MIRU MOVE SFTY P PJSM. Pre -Spud Review. 18:30 21:00 2.50 MIRU MOVE MOB P Continue to berm up around rig, spot support equipment. Load pits with 15.3 ppg KW mud. 21:00 22:00 1.00 MIRU WHDBO MPSP P Lubricate out BPV, off load lubricator. Continue to load pits. 22:00 23:00 1.00 MIRU WHDBO RURD P RU circulating equipment and test lines 4000 psi. 23:00 00:00 1.00 MIRU WELCTL KLWL P PJSM- Build and circulate 10 bbl high -vis interface pill, circulate 15.3 PPG KWF down the tubing, taking returns out the IA, ICP 1450 psi with 1250 psi back pressure at 2 bpm. 11/30/2012 Continue to kill well. Set BPV. ND Tree. NU BOPE. 00:00 03:30 3.50 MIRU WELCTL KLWL P Continue to circulate 15.3 PPG KWF down the tubing, takin returns out the IA 100 bbls away manual choke needle broke, FCP 360 psi at 2 bpm with 1250 psi back pressure, 143 bbls return, use hydraulic choke, continue pumping 2 bpm, 360 psi with 1300 psi back pressure, 200 bbls shut down 278 return, FCP 400 psi with 900 psi back pressure, continue w/ 15.3 ppg KWF 2 bpm at 800 psi with 600 psi back pressure, 300 bbls away shut down, FCP 1100 psi with 600 psi back pressure, 327 bbls return, tubing 10 psi, IA 130 psi, OA 200 psi, gas infused fluid at surface on IA. 03:30 08:45 5.25 MIRU WELCTL OWFF P Monitor well while blowiing down hard line. Vac out Kill tank. Load pits with KWF. 08:45 09:45 1.00 MIRU WELCTL KLWL P Circulate 15.3 ppg KWF down tubing 3 bpm taking returns until 15.3 ppg KWF at surface. 09:45 14:15 4.50 MIRU WHDBO OWFF P Shut down and Monitor Well for Flow. Waiting on trucks with KWF to Condition Fluid In Pits. Page 1 015 r . • Time Logs Date From To Dur S. Deoth E. Deoth Phase Code Subcode T Comment 14:15 16:30 2.25 MIRU WHDBO KLWL P Circulate 15.3 ppg KWF down tubing 3 bpm taking returns until 15.3 ppg KWF at surface. 16:30 17:00 0.50 MIRU WHDBO OWFF P Shut down and Monitor Well for Flow. 17:00 18:00 1.00 MIRU WHDBO NUND P PJSM. Rig Down Circulating Hoses. Change out manual choke on manifold. 18:00 19:00 1.00 MIRU WHDBO MPSP P Set FMC IS -A BPV. 19:00 00:00 5.00 MIRU WHDBO NUND P ND and Inspect tree. Inspect lift thread s on hanger. Install BIanking Plug. NU BOPE. 12/01/2012 NU BODE. Perform Initial BOP, choke manifold and annular test. Pull BPV and blanking plug. Pull 3 -1/2" de- completion___ 00:00 02:30 2.50 MIRU WHDBO NUND P Continue to NU BOPE. Grease choke manifold, RU test lines. 02:30 10:30 8.00 MIRU WHDBO BOPE P PJSM- Function test, fill stack, choke and kill line. Perform Initial BOP ram, choke manifold and annular test 250 /4000 psi with 3 -1/2" and 4 -1/2" test joints. _ Perform Accumulator draw down test. 10:30 11:00 0.50 COMPZ WHDBO RURD P Rig Down Test Equipment. RU and Pull Blanking Plug 11:00 16:00 5.00 COMPZ WHDBO MPSP T Pull BPV. Having Problems pulling BPV. RU wash assembly and wash on top of BPV at4bpm. 16:00 17:30 1.50 COMPZ WHDBO MPSP T Still Unable to retrieve BPV. Confer with town while making attempt to recover BPV. 17:30 18:00 0.50 COMPZ RPCOM PULL P PJSM. MU Handling Joint and Screw Into Hanger. Pull Hanger to Rig Floor, ice around neckof tubing hanger. Up Wt 155k to Un -seat Hanger 18:00 18:30 0.50 COMPZ RPCOM OWFF P Observe well for flow, well static. 18:30 19:30 1.00 COMPZ RPCOM THGR P Lay down tubing hanger, shear pin in fishneck sticking out 1/4" not allowing pulling tool to enter fishneck completly to engauge profile. RU circulating hoses. 19:30 20:30 1.00 COMPZ RPCOM CIRC P Reverse circulate 2 tubing volumes 2 bpm ICP 800 psi, FCP 880 psi, clean 15.3 ppg returns to surface. RD circulating equipment 20:30 21:30 1.00 COMPZ RPCOM OWFF P Monitor well on trip tank while shuffling DP to ODS. RU control line spooling equipment. no loss to formation for 1 hr, well static. 21:30 22:00 0.50 COMPZ RPCOM SFTY P PJSM with Schlumberger and Nordic 3 crews, discussed hazards associated with pulling completion. change over to pull 3 1/2" completion. Page 2 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 6,796 5,392 COMPZ RPCOM PULL P POOH from 6,796 -ft to 5,392 -ft laying down tubing while spooling control line, removing all jewelry and accounting for SS bands RIH. Up wt 100k, Dn wt 75k. 12/02/2012 Continue to pull 3 -1/2" de- completion. Mill on FB -1 packer until free. Circulate well. TOOH with BHA #1 00:00 06:30 6.50 5,392 0 COMPZ RPCOM PULL P Continue to POOH from 5,392 -ft laying down tubing while spooling control line to SSSV at 4,802 -ft, all 36 SS bands RIH recovered, continue POOH laying down tubing removing all jewelry and kicking out same. All 3 1/2" Completion was recovered from well. 06:30 07:30 1.00 COMPZ RPCOM PULD P Clean & Clear Rig Floor. 07:30 07:45 0.25 COMPZ RPCOM SFTY P PJSM. Discuss Loading Tools Up Beaver Slide. 07:45 08:45 1.00 COMPZ RPCOM PULD P Load Milling Assembly to Rig Floor. 08:45 09:15 0.50 COMPZ RPCOM SFTY P PJSM. Discuss hazard for making up BHA and Reviewing running order of milling assembly. 09:15 10:45 1.50 0 219 COMPZ RPCOM PULD P Set Wear Bushing. PU & MU Milling Assembly. 6 1/2" x 3 7/16" Packer Mill, (2) 4 3/4" Boot Basket, Bit sub, 4 3/4" Jars and (6) 4 3/4" Drill Collars. 10:45 14:15 3.50 219 6,729 COMPZ RPCOM TRIP P TIH with Milling Assembly on Drill Pipe down top of FB -1 Packer at • 6,796 -ft. Tagged Fill at 6,729' MD. 14:15 15:15 1.00 6,729 6,797 COMPZ RPCOM CIRC P Circulate Down to top of FB -1 Packer at 5 bpm, 2,150 psi. 15:15 18:15 3.00 6,797 6,800 COMPZ RPCOM MILL P Clean out fill and tagged top of packer at 6,797' MD, start milling FB -1 Packer at 5 bpm, 2100 psi, 80 RPM, 3200# free torque with 2 -3k WOB. Seeing large amounts of frac sand across shakers. 18:15 20:00 1.75 6,800 6,830 COMPZ RPCOM CIRC P Packer dropped, monitor well for 10 minutes, no flow. Continue circulating while RIH to 6,830 -ft, no tag. Pump 30 bbl high -visc sweep, circulate out out small amount of packer gas thru gas buster, bottoms up pumped monitor well 10 min, no flow or signs of gas. 20:00 22:30 2.50 6,830 6,830 COMPZ RPCOM CIRC P Continue to circulate out sweep 4 bpm at 1450 psi, getting large amounts of metal and rubber across shakers, condition hole until) 15.3 ppg seen at surface. 22:30 23:30 1.00 6,830 6,830 COMPZ RPCOM OWFF P Shut down, BDTD, 15.1 heavy ppg to surface with 15.2 pumping in, equilizing across isolated pits. monitor well, static. Page 3 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 6,830 6,636 COMPZ RPCOM TRIP P PJSM- POOH with BHA #1 Packer Milling Assembly standing back DP from 6,830 -ft to 6,636 -ft. Up wt 133k, Dn wt 95k. 12/03/2012 Continue to TOOH with BHA #1. Wash Stack. Test UPR's. Fish Milled Packer/Tailpipe assembly. TOOH with BHA #2. RIH with Clean Out Assembly. 00:00 03:30 3.50 6,636 219 COMPZ RPCOM TRIP P Continue to POOH with BHA #1 Packer Milling Assembly,standina: hack_DP, from _6 636 -ft to 218 -ft. Up wt 133k, Dn wt 95k. 03:30 04:30 1.00 219 0 COMPZ RPCOM PULD P PJSM- Stand back DC's and lay down BHA #1. recovered approximatly 1+ lb metal, pieces of slips and rings in boot baskets, 50% wear on Packer Mill. 04:30 07:00 2.50 0 0 COMPZ RPCOM OTHR P PJSM- MU wash tool with inline magnet, wash BOP stack. L/D Wash Assembly. 07:00 09:15 2.25 0 0 COMPZ RPCOM PRTS P Pull wear bushing, set test plug, RU test equipment and test UPR's with 3 -1/2" test joints 250/4000 psi on chart. RD test equipment. pull test plug and set wear bushing. 09:15 09:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM. Discuss hazard for making up BHA and Reviewing running order of packer spear assembly. 09:30 10:15 0.75 0 211 COMPZ RPCOM PULD P PU & MU Spear Assembly. 4 3/4" ITCO spear with 3.947" nom. grapple, PumpOut Sub, 4 3/4" Bumper Sub, 4 3/4" Jars and (6) 4 3/4" Drill Collars. 10:15 14:30 4.25 211 6,850 COMPZ RPCOM TRIP P TIH with Packer Spear Assembly on Drill Pipe down to top of FB -1 Packer. 14:30 15:30 1.00 6,850 6,886 COMPZ RPCOM PULL P Set Parameters. Up Wt 120k / Dn Wt 95k. Circulating at 3 bpm, 1260 psi. Continue in hole and located top packer 6,882 -ft, stack 12k down, seen good indication that packer is latched with 7k over pull and pressure increase to 2200 psi. 15:30 16:00 0.50 6,886 6,886 COMPZ RPCOM OWFF P Monitor well for flow, static. Blow down top drive. 16:00 21:00 5.00 6,886 211 COMPZ RPCOM PULL P TOOH with fishing assembly and packer assembly from 6,886 -ft. 21:00 22:00 1.00 211 0 COMPZ RPCOM PULD P OOH. Lay down Fishing BHA and 40.5 -ft Milled Packer / Tailpipe Assembly. 22:00 22:45 0.75 0 0 COMPZ RPCOM OTHR P Clean & Clear Floor. Off load / Load Baker tools to rig floor. 22:45 23:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss hazard for making up BHA and reviewing running order of clean out assembly. Page 4 of 15 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 23:30 0.50 0 231 COMPZ WELLPF PULD P PU MU BHA #3 Clean Out Assembly - 6 1/8" Bladed Junk Mill, 4 3/4" Tandam Boot Baskets, Bit Sub, 6 1/16" Tandem String Mills, PumpOut Sub, 4 3/4" Bumper Sub ,4 3/4" Jars, (6) 4 3/4" DC's. 23:30 00:00 0.50 231 1,390 COMPZ WELLPF TRIP P TIH with Clean Out Assembly on Drill Pipe down to 1,390 -ft. Up wt 60k, Dn wt 60k. 12/04/2012 Continue to RIH with Clean Out Assembly. Clean Out 7" Casing to 6,954 -ft ORKB progress stopped with Bladed Junk Mill. Circulate well clean. TOOH with BHA #3. MU and RIH with BHA #4 Clean Out Assembly. Clean Out 7" Casing to 7,127 -ft ORKB. Circulate well clean. TOOH with BHA #4. 00:00 02:30 2.50 1,390 6,910 COMPZ WELLPF TRIP P Continue to TIH with Clean Out Assembly on Drill Pipe down from 1,390 -ft to 6,910 -ft. Up wt 60k, Dn wt 60k. 02:30 04:00 1.50 6,910 6,954 COMPZ WELLPF FCO P Set Parameters. Up Wt 135k / Dn Wt 100k, 3,800 fUlb free torque at 60 rpm, ROT 115k. Slow pump rates P1= 20 spm at 700 psi, 40 spm at 900 psi, P2= 20 spm at 680 psi, 40 spm at 900 psi. Circulating at 5 bpm, 2200 psi. Continue in hole and located top of fill at 6,924 -ft, wash down with 2k to 3k WOB to 6,947 -ft, 8k to 10k WOB to 6,954 -ft, not making any hole, suspect collapsed casing. 04:00 05:30 1.50 6,954 6,900 COMPZ WELLPF CIRC P Confer with town engineer, PUH to 6,900 -ft and circulate bottoms up or returns clean 5 bpm at 2100 psi, seeing heavy frac sand across shakers. 05:30 06:30 1.00 6,900 6,900 COMPZ WELLPF OWFF P Monitor well for flow, static. Blow down top drive. Crew change out. 06:30 09:30 3.00 6,900 0 COMPZ WELLPF TRIP P PJSM- TOOH with Clean Out Assembly from 6,900 -ft. 09:30 10:00 0.50 0 0 COMPZ WELLPF PULD P OOH. Lay down Bladed Junk Mill and Tandem Boot Baskets. 10:00 10:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Discuss hazard for making up BHA and reviewing running order of clean out assembly. 10:15 11:30 1.25 0 220 COMPZ WELLPF PULD P PU MU BHA#4 Clean Out Assembly - 6 1/8" Window Mill, Bit Sub, 6 1/16" Tandem String Mills, PumpOut Sub, 4 3/4" Bumper Sub, 4 3/4" Jars, (6) 4 3/4" DC's. 11:30 14:00 2.50 220 6,931 COMPZ WELLPF TRIP P TIH with Clean Out Assembly on Drill Pipe 6,931 -ft Page 5 of 15 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 18:00 4.00 6,931 7,127 COMPZ WELLPF MILL P Gather Parameters: 135k up wt, 97k do wt and 115k rot wt. Rotating at 75 rpm's w/ 3,800 ft/lbs off bottom torque, 4,000 to 6,000 ft/lbs on bottom torque w/ 5 to 10k WOM. Circulating at 189 gpm at 2,200 psi. Clean out from 6,948 -ft to 7,127 -ft ORKB Top of ESP motor (Fish from 2006 RWO) Continue to circulate stringing frac sand up annulus. 18:00 20:30 2.50 7,127 7,127 COMPZ WELLPFCIRC P PJSM- Circulate bottoms up ICP 2450 psi, FCP 2320 psi, pump 30 bbl high visc sweep and circulate surface to surface while recip. and rot 15 rpm, ICP 2300 psi, FCP 2320 psi. 20:30 21:00 0.50 7,127 6,930 COMPZ WELLPF TRIP P Tag down at 7,127 -ft ORKB with pumps on /off, PUH to 6,930 -ft 21:00 22:00 1.00 6,930 6,930 COMPZ WELLPF OWFF P Blow down top drive and monitor well 1 hr, well static. 22:00 22:45 0.75 6,930 7,127 COMPZ WELLPF TRIP P PJSM- RIH pumps off, 5k to 10k slack off thru all of perf area 6,948 -ft ORKB to 7,000 -ft ORKB, weight back to 0 to tag at 7,127 -ft ORKB. 22:45 00:00 1.25 7,127 5,648 COMPZ WELLPF TRIP P TOOH from 7,127 -ft ORKB, 5k to 10 k overpull thru perf area 7,000 -ft to 6,948 -ft ORKB, continue to TOOH standing back DP, Up wt. 135k, Dn wt 97k, to 5,648 -ft, Up wt 115k, Dn wt 90k. 12/05/2012 Continue to TOOH with BHA #4. Wash Stack. RU E -line. Obtain 7" casinlevaluation logs. RD E -line. Slip/Cut Drill Line. Run 4 1/2" Liner. �e _.__� 00:00 03:30 3.50 5,648 220 COMPZ WELLPF TRIP P Continue to TOOH from 5,648 -ft, Up wt 115k, Dn wt 90k. 03:30 04:30 1.00 220 0 COMPZ WELLPF PULD P PJSM- Lay down DC's and BHA #4, off load tools. 75% wear on window mill and carbide on both watermelon mills knocked off. 04:30 07:00 2.50 0 0 COMPZ WELLPF OTHR P PJSM- pull wear bushing and set test plug, MU wash tool with inline magnet, wash BOP stack. UD Wash Assembly. pull test plug and set wear bushing. 07:00 08:00 1.00 0 0 COMPZ RPCOM RURD P RU dutch riser. 08:00 08:15 0.25 0 0 COMPZ EVALWESFTY P PJSM with E -line and Nordic 3 crews, rig proceures and hazards associated to wireline work on rig. 08:15 16:00 7.75 0 7,127 COMPZ EVALWE ELOG P RU E -line and RIH to 7,127 -ft, log up to surface. RD Eline and Dutch riser 16:00 16:15 0.25 0 0 COMPZ RPCOM SFTY P Held PJSM on Slip and Cut of drill line 16:15 17:30 1.25 0 0 COMPZ RIGMNTSLPC P Slip and cut 84 -ft of 1 -1/8" Drill line 17:30 22:00 4.50 0 0 COMPZ RPCOM OTHR P Change over floors to run liner, load 4 1/2" shoe trac, SBE, pups and strap all components. install centralizers and stop rings on 11 joints, load cement head, RU to load pipe Page 6 of 16 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with Baker and Nordic 3 crews, rig proceures, running order and hazards associated to running liner on rig. 22:15 00:00 1.75 0 290 COMPZ RPCOM PULD P PU shoe track, baker lock all connections to landing collar, fill pipe, PUH and confirm float collar operational, continue RIH with 5 joints of liner to 290 -ft, fill liner. 12/06/2012 Continue to Run 4 1/2" Liner. Lost integrity to both floats. TOOH with Liner. Upper float stuck open with pieces of metal. Wait on new shoe tract from Prudhoe. Load and strap new 4 1/2" lower liner completion. Run 4 1/2" Liner. 00:00 01:00 1.00 290 560 COMPZ RPCOM PULD P Continue RIH with 6 joints liner, fill pipe, MU SBE. PU ZXP liner top packer, liner hanger with running tool, MU 2 3/8" extentions and install 4 1/2" liner wiper plug, MU ZXP /liner hanger assembly to liner and RIH on 1 joint 3 1/2" DP. 01:00 02:00 1.00 560 560 COMPZ RPCOM CIRC P RU circulating hoses and pump 1 DP, liner volume (8 bbls) to ensure clear. good returns. 02:00 02:15 0.25 560 656 COMPZ RPCOM TRIP T Attempt to TIH with 4 1/2" liner assembly on DP, get 2 joints of next stand in and fluid over the top, TIH slow and set in slips. 02:15 03:00 0.75 656 715 COMPZ RPCOM CIRC T RU circulating hoses and pump 20 bbls at 5 bpm to clear float subs. Attempt to TIH with next stand , same results fluid over the top at 2 joints in on stand. 03:00 04:00 1.00 715 129 COMPZ RPCOM TRIP T TOOH standing back DP, RU circ hoses and pump down ZXP head pin, no leaks in running tool connection, floats bad, confer with town, TOOH laying down ZXP packer, liner hanger, standing back SBE and 2 joints, 3 stands 4 1/2" liner. 04:00 05:30 1.50 129 0 COMPZ RPCOM PULD T PJSM- PU, apply steam to pin end of BTC above float collar, attempt to brake, threads gauld, lay down float collar and float shoe. apply steam and attempt to brake at pin end of crossover joint, same results. flat metal found in float collar. 05:30 16:00 10.50 0 0 COMPZ RPCOM OTHR T Load, drift and tally 3 1/2" completion. load, drift and tally 2 7/8" 511 Hydril. Wait for shoe track to arrive - load in pipe shed and strap. 16:00 16:15 0.25 0 0 COMPZ RPCOM SFTY T Held PJSM on PU and RIH w/ 4 1/2" Scab liner. Page 7of15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 21:30 5.25 0 620 COMPZ RPCOM PULD T MU and TIH with Lower 4 1/2" liner, float shoe + float collar and landing joint (5 3/4" Straight Blade Centralizer installed in middle of all 4 1/2" liner joints) Verify 4 1/2" 12.6# wiper plug installed, continue to MU 5" Seal Bore Extension, 5" Flex -Lock Liner Hanger and 5" ZXP Liner Top Packer. PU 1 stand and TIH to 620 -ft 21:30 22:00 0.50 620 620 COMPZ RPCOM OTHR T PJSM- change over floors. 22:00 22:30 0.50 620 620 COMPZ RPCOM CIRC T PU 1 stand and MU to Liner Completion, Up wt 45k, Dn wt 45k, Kelly up and preform flow test thru Liner 20 bbls, 3 bpm at 320 psi. 22:30 00:00 1.50 620 2,470 COMPZ RPCOM TRIP P Continue to TIH with 4 1/2" Liner Completion on 3 1/2" DP slowing down thru cementer filling pipe every 10 stands, Up /Dn wts every 5 stands to 2,470 -ft. Up Wt 61k / Dn Wt 55k. 12/07/2012 Continue to Run 4 1/2" Liner. Condition well. Cement Liner in lace. Set ZXP Liner Top Packer. Circulate out excess cement. Trouble with WBM. TOOH with running tool. 00:00 02:30 2.50 2,470 4,310 COMPZ RPCOM TRIP P Continue to TIH with 4 1/2" Liner Completion on 3 1/2" DP from 2,470 -ft filling pipe every 10 stands, Up /Dn wts every 5 stands and continuing on to 4,310 -ft. Up Wt 85k / Dn Wt 74k. 02:30 03:30 1.00 4,310 4,310 COMPZ RPCOM CIRC P Kelly up and preform flow test and condition well thru Liner 145 bbls, 3 bpm at 660 psi ICP, 600 psi FCP. BDTD. 03:30 06:00 2.50 4,310 7,120 COMPZ RPCOM TRIP P Continue to TIH with 4 1/2" Liner Completion on 3 1/2" DP from 4,310 -ft filling pipe every 10 stands, Up /Dn wts every 5 stands and continuing on to target depth. 06:00 07:00 1.00 7,120 7,127 COMPZ CEMEN" PULD P PU & MU Baker Plug Dropping Head and Space out same. Up Wt 130k / Dn Wt 100k. 07:00 09:00 2.00 7,125 7,125 COMPZ CEMEN "CIRC P Circulate @ 3 bpm @ 990 psi for 241 bbls. 09:00 09:30 0.50 7,125 7,125 COMPZ CEMEN "SFTY P PJSM with Rig crew, Vac truck drivers, Mud man, SLB cement crew. 09:30 11:00 1.50 7,125 7,127 COMPZ CEMEN "CMNT P Pump 5 bbls of Fresh h2o, PT treating lines at 4,000 psi, mix and pump 17 bbls of 15.8 ppg Class "G" cement, chase with fresh water. Drop dart, and displace with rig pumps for 49 bbls, sheared wiper @ 3,000 psi and bump plug @ 1,158 stks and pressure up to 3,500 psi on plug. Page 8of S • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 7,127 7,110 COMPZ CEMEN' PACK P Slack off 55k to set liner hanger, bleed to 0 psi, floats good, slack off and rotate to release from liner. pressure up DP to 1000 psi and pull up out of liner, start circulatine out excess cement, TIH and set ZXP liner top packer per Baker rep. PUH. 11:30 12:00 0.50 7,110 66 COMPZ CEMEN CIRC P Circulate surface to surface 15.3 WBM 4 bpm at 1,760 psi. 12:00 13:00 1.00 6,582 6,582 COMPZ CEMEN" PULD P Blow down lines. Rig down cement head 13:00 14:00 1.00 6,582 6,582 COMPZ CEMEN" CIRC T Circulate Blackwater pil to clean up lines and well bore of cement, break circulation 8 bpm at 3500 psi, coagulated WBM in pipe, lost reurns. 14:00 14:30 0.50 6,582 5,622 COMPZ CEMEN TRIP T TOOH from 6,582 -ft 5 stands, hole not taking fluids, pull 5 more stands to 5,330 -ft and hole swabing. 14:30 16:00 1.50 5,622 5,622 COMPZ CEMEN" OWFF T Monitor well while recip. pipe, bring on fluid. 16:00 17:00 1.00 5,622 5,622 COMPZ CEMEN' CIRC T RU circulating hoses and reverse circulate 50 bbls, 2 pbm at 1,970 psi. 17:00 18:00 1.00 5,622 5,622 COMPZ CEMEN - PRTS T Attempt pressure test, injectivity at 3,150 psi at 1.5 bpm, shut down and monitor leak off rate, 1162 psi lose in 5 min, 183 psi lose in second 5 min and 103 psi lose in last 5 min. 18:00 22:30 4.50 5,622 5,622 COMPZ CEMEN "CIRC T PJSM- circulate 1 bpm, ICP 1,580 psi, FCP 620 psi at 3 bpm 2X Bottoms up, large amount of coagulated WBM across shakers, but cleaned up good. 1:1 returns. 22:30 23:00 0.50 5,622 5,622 COMPZ CEMEN" OWFF T Monitor well, static. 23:00 23:30 0.50 5,622 0 COMPZ CEMEN TRIP T TOOH from 5,622 -ft to 4,845 -ft on trip tank, pull bushings and hole taking fluid, trip tank fill line plug off with coagulated WBM. 23:30 00:00 0.50 4,845 4,845 COMPZ CEMEN' OTHR T PJSM- pull riser and attempt to clear trip tank fill line. 12/08/2012 TOOH with running tool. Wash stack. Set test plug. open up and clean BOP cavities. Perform weekly BOP test. Pull test plug. TIH with scraper /clean out assembly. P/T liner and liner top packer. TOOH with Clean out assembly. 00:00 01:00 1.00 4,845 4,845 COMPZ CEMEN" OTHR T Continue attempt to clear trip tank fill line, no joy. re- install riser, will monitor hole fill thru kill line. 01:00 03:30 2.50 4,845 50 COMPZ CEMEN "TRIP T TOOH from 4,845 -ft, Up wt 105k, hole displacement per 5 stands pulled good. TOOH to BHA 03:30 04:30 1.00 50 0 COMPZ CEMEN PULD T Lay down liner ruuning tool, lowest 2 3/8" wiper plug extension bent about 4 °, all extensions slightly bent, rotating dog sub sheared, packer is set. Page 9 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 0 0 COMPZ RPCOM OTHR P Clean and clear floors. pull wear bushing, set test plug, MU wash tool and wash BOP stack, trip tank and fill line cleaned out. 06:30 10:00 3.50 0 0 COMPZ RPCOM OTHR P Open up Upper and Lower ram cavities, clean and inspect. 10:00 16:00 6.00 0 0 COMPZ RPCOM BOPE P Perform weekly BOP test. 16:00 16:30 0.50 0 0 COMPZ RPCOM OTHR P Pull test plug and install wear ring 16:30 17:30 1.00 0 0 COMPZ RPCOM PRTS P Held PJSM. Pressure up to 2,000 psi in 60 strokes (2.8 bbls) @ .25 bpm, monitor on chart for 30 minutes, Bleeding off to 1,500 psi before stabilizing. Bled off pressure to zero. 17:30 18:30 1.00 0 0 COMPZ RPCOM OTHR P PJSM- hoisting operations. Load Baker tools to rig floor. 18:30 19:30 1.00 0 0 COMPZ RPCOM OTHR P PJSM- working at heights. Install riser air boot. Change over floors to run 2 7/8" equipment. 19:30 20:30 1.00 0 380 COMPZ RPCOM PULD P PJSM- MU BHA #5, Clean Out Ass'y 2 7/8" Hydril 511 to 380 -ft. 20:30 21:00 0.50 380 380 COMPZ RPCOM OTHR P Change over floors to make up BHA and run 3 1/2" DP. 21:00 22:00 1.00 380 598 COMPZ RPCOM PULD P Continue to MU BHA #5, 2 7/8" Hydril 511, Casing Scraper, P.O.S., Bumper sub, Jars, (6) DC's to 598 -ft. 22:00 23:00 1.00 598 1,180 COMPZ RPCOM TRIP P TIH with BHA #5 on DP to 1,180 -ft, thick cogulated fluid over the top. 23:00 00:00 1.00 1,180 1,180 COMPZ RPCOM CIRC P Kelly up and circulate bottoms up 1 bpm at 200 psi ICP, 2 bpm at 250 psi FCP, large amout of coagulatedWBM across shakers. BDTD. 00:00 01:00 1.00 1,180 1,960 COMPZ RPCOM TRIP P Continue TIH, fluid over the top at 1,960 -ft. Kelly up to CBU. Up wt 60k, Dn wt 60k. 12/09/2012 Continue to run scraper /clean out assembly. Circulate and condition well. TOOH with Clean out assembly. TIH with test packer assembly. Test 7" casing annulus from 7,576 -ft, good. 00:00 01:00 1.00 1,960 1,960 COMPZ RPCOM CIRC P Kelly up and circulate bottoms up 1 bpm at 400 psi ICP, 2 bpm at 300 psi FCP, rotate 20 rpm. BDTD. 01:00 07:00 6.00 1,960 6,779 COMPZ RPCOM TRIP P Continue TIH with BHA #5, Kelly up and CBU 4 bpm, 700 psi while rotating 20 rpm every 1,000 -ft until target depth reached. Set down @ 6779', P/U weight 154K. Hole is cleaning up, started 1800 psi @ 64 spm, current pressure 1420 psi 64 spm. Page 14 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 09:30 2.50 6,779 6,986 COMPZ RPCOM TRIP P Circulate 64spm / 1430 psi. Slowly work string in hole. Down weight 84K Up Weight 155K. Heavy X -link returns over shaker while working string to Bottom. 6830' - 64 spm - 1460 psi - heavy contaminated cement returns over shaker 6983' - 64 spm - 1305 psi - clean mud returns 6984' - 64 spm - 1370psi 6985' - 64 spm - 1370psi 6986' - 64 spm - 1580 psi - taking weight set down 8K. 09:30 10:30 1.00 6,986 6,986 COMPZ RPCOM CIRC P Work String at 20 rpm's w/ 3,000 ft/lbs of torque and CBU until returns clean up @ 3 bpm @ 1,140 psi. 10:30 11:00 0.50 6,986 6,986 COMPZ RPCOM OWFF P Monitor well for flow for 30 minutes, Blow down top drive. 11:00 15:30 4.50 6,986 604 COMPZ RPCOM TRIP P POOH from 6,986 -ft monitoring hole fill (lossing .5 bbl over calculated displacement). Had build up on last 12 joints of drill pipe above BHA. 15:30 17:00 1.50 604 0 COMPZ RPCOM PULD P Stand back 4 3/4" DC's, laydown CSG scraper assy and 13 joints of 2 7/8 511 hydril and mule shoe. 17:00 18:00 1.00 0 0 COMPZ RPCOM OTHR P Change floor equipment over to 3 1/2 DP. Off load Baker tools. 18:00 19:00 1.00 0 210 COMPZ RPCOM PULD P PJSM- PU MU BHA #6- Bull nose, PBR pack -off sub, (3) spacer subs, Rotating dog sub, 7" retrievamatic test pkr., XO sub, handling pup, (6) 4 3/4" DC's. 19:00 21:00 2.00 21 3,400 COMPZ RPCOM TRIP P TIH with BHA #6 on 3 1/2" Dp to 3,400 -ft. Up wt 80k. 21:00 21:30 0.50 3,400 3,400 COMPZ RPCOM MPSP P Set test packer and test IA to 2,000 psi 10 minutes, good. 21:30 23:00 1.50 3,400 6,576 COMPZ RPCOM TRIP P Continue TIN with BHA #6 from 3,400 -ft. 23:00 00:00 1.00 6,576 6,595 COMPZ RPCOM PRTS P Set test packer mid element at 6,576 -ft, Up wt 130k, Dn wt 95k, RU test hoses, pressure test 7" X 3 1/2" DP annulus to 2,650 psi on chart 30 minutes, 2,620 psi in 15 min. 2 in 30 min. Release test packer and sting into Liner Top at 6,595 -ft to test liner down DP. 12/10/2012 Test liner top packer and 7" casing annulus from 7,595 -ft, Inject past liner lap at 1,800 psi, 1/2 bpm. Confer with town engineer. TOOH with test packer assembly. Run FHL packer / DS nipple / Seal assembly on DP due to weather. Spot 20 bbl pill 15.3 ppg corrosion inhibited WBM. Page 11 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 6,595 6,595 COMPZ RPCOM PRTS P Attempt to pressure test IA to liner top packer at 6,595 -ft, bring on pump 1/2 bpm to 2,100 psi, pressure broke over and continue to pump 1/2 pbm at 1,800 psi, shut down IA bled off to 1,180 psi in 10 min., pressure up liner to 1,000 psi down DP for 10 min., good. Slack off 40k and seen Dog Sub shear at 30k, PU and retest Liner packer again with same results. Confer with town engineer for plan forward. 02:00 02:30 0.50 6,595 6,595 COMPZ RPCOM OTHR P PJSM- Off load Baker running tool and Hydril pipe. 02:30 04:30 2.00 6,595 4,960 COMPZ RPCOM TRIP X PJSM- TOOH laying down 3 1/2" DP to 4,960 -ft 04:30 05:30 1.00 4,960 4,960 COMPZ RPCOM CIRC X -35 cutoff weather limitations. Stop and discuss plan forward. Decision to stand back DP to use for packer run instead of completion string. 05:30 10:00 4.50 4,960 152 COMPZ RPCOM TRIP X PJSM - continue TOOH standing back DP. 10:00 11:00 1.00 152 0 COMPZ RPCOM PULD X Lay down Drill collars and test packer assembly. 11:00 12:30 1.50 0 0 COMPZ RPCOM OTHR X Clean and clear the rig. Change out floor equipment. Prep to RIH w/ FHL stacker packer. 12:30 13:30 1.00 0 265 COMPZ RPCOM PULD X PJSM, PU, MU and RIH w/ FHL Packer assy to 265 -ft 13:30 14:30 1.00 265 265 COMPZ RPCOM OTHR X PJSM, Change over equipment 14:30 21:00 6.50 265 6,624 COMPZ RPCOM TRIP X RIH w/ FHL Packer assembly from 265 -ft to 6,624 -ft, Up wt 125k, Dn wt 93k. 21:00 22:00 1.00 6,624 6,624 COMPZ RPCOM CIRC X TIH and locate at 6,645 -ft, PU to 6,624 -ft. 22:00 23:00 1.00 6,624 6,624 COMPZ RPCOM OTHR X Mix up 20 bbls pill! of corrosion inhibited 15.3 ppg WBM, empty cuttings box, off load rinse water, MU visc 15.3 ppg push 23:00 00:00 1.00 6,624 6,624 COMPZ RPCOM CIRC X Circulate 20 bbl CI 15.3 ppg WBM chased with 45 bbls 15.3 ppg WBM push, ICP 1.5 bpm at 960 psi. 12/11/2012 Continue spot 20 bbl pill 15.3 ppg corrosion inhibited WBM. Set FHL packer / Seal assembly. Shear PBR. Test Liner, FHL packer and 7" csg to 3000 psi. Circulate well over to seawater. TOOH with PBR seals. Prep and run 3 1/2" gas lift completion. 00:00 01:00 1.00 6,624 6,624 COMPZ RPCOM CIRC X Circulate 20 bbl CI 15.3 ppg WBM chased with 45 bbls 15.3 ppg WBM push, ICP 1.5 bpm at 960 psi, FCP 950 psi at .5 bpm Page 12 of 15 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:00 1.00 6,624 6,411 COMPZ RPCOM PACK X Sting seals back into SBE and take weight at 6,645 -ft, PU to neutral weight plus 2 -ft to 6,643 -ft for space out, work pressure up in stages to 3,000 psi to set FHL packer, leave 2,650 psi on DP, PU and shear PBR at 135K, run back in and confirm packer set depth at 6,509 -ft, lay down 1 joint, RU head pin and hoses for pressure test. 02:00 03:30 1.50 6,481 6,481 COMPZ RPCOM PRTS X PJSM- Pressure test liner FHL -- - - - - - - - - - packer and 7" csg to 3,00 psi on chart 30 minutes. 03:30 09:00 5.50 6,481 6,481 COMPZ RPCOM CIRC P PJSM- MU head pin and Pump 40 bbls of 127 bbls high -vis 8.5 ppg SW sweep at 1 bpm @ 1,800 psi ICP. Shut down and allow well to utube back till "No Flow ". Break out head pin and mu top drive. Circulate 127 bbl hi -visc sweep and chase with sea water @ 2 bpm @ 2,800 psi while rotating and reciprocating at 30 rpms w/ 2,400 ft/lbs of torque and increase PR to 5 bpm @ 400 psi FCP displacing 15.3 ppg WBM with 8.5 ppg sea water. 09:00 10:00 1.00 6,481 6,481 COMPZ RPCOM OWFF P Monitor well for flow for 30 minutes. No flow. Offload test packer and drill pipe from pipe shed. 10:00 11:00 1.00 6,481 5,945 COMPZ RPCOM PULD P POOH laying down 3 1/2 S -135 DP to 5,945 -ft - -well out of balance. 11:00 11:30 0.50 5,945 5,945 COMPZ RPCOM CIRC P Reverse circulate @ 8 bpm @ 1,300 psi -- well stable 11:30 17:00 5.50 5,945 0 COMPZ RPCOM PULD P Continue to POOH laying down 3 1/2, S -135 Drill pipe and seal assembly 17:00 19:00 2.00 0 0 COMPZ RPCOM EQRP P PJSM, Change out Floor Equip. Pull Wear Ring and prep to run Completion. 19:00 00:00 5.00 0 1,650 COMPZ RPCOM TRIP P PJSM. PU 3 -1/2" EUE Tbg Completion and RIH to 1650'. Up wt _ 49k #, 55k# down. 12/12/2012 Run 3 -1/2" Completion, Reverse circulate CI SW, Land Hanger, RILDS,Test 3 -1/2" Tubing 3000 Goo lest_. 00:00 06:30 6.50 1,650 5,452 COMPZ RPCOM TRIP P Continue RIH with 3 -1/2" EUE Completion from 1650'. Cleaning Threads and Drifting on way in. 06:30 08:30 2.00 5,452 5,452 COMPZ RPCOM TRIP P Crew change - Tried to blow down Kill line. Froze off. Break down line, thaw and blow down & re -test. Circ. 50 bbls of SW through line and blow down again. 08:30 11:30 3.00 5,452 6,108 COMPZ RPCOM TRIP P P/U pipe, RIH with completion string. Cleaning threads and drifting pipe. 11:30 13:30 2.00 6,108 6,108 COMPZ RPCOM TRIP P Hard time drifting final 20 joints with 2.91" drift. K/O last 20 joints and load new 3.5" tubing. Drift and tally. Page 13 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:00 1.50 6,108 6,508 COMPZ RPCOM OTHR P Continue to PU and RIH w/ 3 1/2 ", L -80, 9.3 #, EUE 8RD AB MOD to 6,508 15:00 17:00 2.00 6,508 6,471 COMPZ RPCOM HOSO P Pump 1 bpm - 50 psi, slowly RIH to sting into SBR pressure increase to 310 psi. Shut down pumps & continue RIH to No -go. P/U and space out. 17:00 19:30 2.50 6,471 6,471 COMPZ RPCOM CIRC P Reverse Circulate 30 bbls sweep followed by 250 bbls of 1% inhibited SW down IA. Flush surface lines, choke & gas buster. Blow down lines. 19:30 21:00 1.50 6,471 0 COMPZ RPCOM THGR P PJSM - start landing tubing hanger. 21:00 00:00 3.00 0 0 COMPZ RPCOM PRTS P RU to PT Tubin ag nd IA. PT to 3000 psi and chart for 15 minutes. Ok. 12/13/2012 Perform successful pressure tests on Tubing 3000 psi and IA to 3500 psi. ND BOPE and NU Tree. Shear SOV with Little Red Services and FP Well to 2000' ND. Install BPV. Finish preparing for RDMO. 00:00 01:00 1.00 0 0 COMPZ RPCOM PRTS P Continue Testing Tubing 3000 psi - 15 minutes - OK. No flow from IA. Bleed Tubing to 2500 psi. Prssere test IA to 3500 psi for 30 minutac and c harted. Good Test. Bleed IA to 0, Bleed Tubing to 0 psi. 01:00 02:00 1.00 0 0 COMPZ RPCOM OWFF P Monitor well for 30 minute NFT. No flow detected. RD Test Equip and LD Landing Joint. 02:00 02:30 0.50 0 0 COMPZ RPCOM MPSP P PJSM. Install BPV 02:30 04:00 1.50 0 0 COMPZ RPCOM NUND P PJSM. ND BOPE 04:00 07:30 3.50 0 0 COMPZ RPCOM NUND P PJSM. NU Tree. Tree orientation • discussed with Pad Operator and witness waived. Marks on tree to aid in alignment. 07:30 09:00 1.50 0 0 COMPZ RPCOM MPSP P Pull BPV and install Tree Test Plug. PT Tree and Hanger Packoffs to 250/5000 psi. Pull Tree Test Plug. 09:00 09:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM with rig crew and Little Red on RU, Pt of treating lines and shearing SOV, along with pumping diesel. 09:15 11:00 1.75 0 0 COMPZ RPCOM FRZP P RU pump lines, PT lines @ 3,000 psi, Shear out SOV @ 2,500 psi with 3 bbls pumped and continue to pump the remaining 72 bbls of diesel @ 2 bpm @ 700 psi ICP and 950 psi FCP. SWI. RD little Red Services. 11:00 12:00 1.00 0 0 COMPZ RPCOM OTHR P Open up TBG to IA. Allow well to swap. Begin off loading 3 1/2 drill pipe left in pipe shed due to cold weather issues 12:00 12:30 0.50 0 0 COMPZ RPCOM MPSP P Dry rod ISA BPV in top of TBG hanger. Dress tree. Begin off loading 3 1/2 drill pipe left in pipe shed due to cold weather issues Page 14 of 15 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 17:00 4.50 0 0 COMPZ RPCOM OTHR X Finish offloading 3 1/2 Drill pipe from pipe shed left in pipe shed due to cold weather issues 17:00 00:00 7.00 0 0 COMPZ MOVE MOB P Warm up moving system, Removing fluid from pits and cuttings box (cold weather issues with Vac and super sucker trucks) Tear out auxiliary equipment, pull off well and clean cellar. Clean out Pits, Clean out Pipe Rack Drains, Blow down Hard Line and disconnect, Changout Cuttings Tank. 12/14/2012 Nordiic 3 moved to 3S -19. Rig Released at 02:30. 00:00 01:30 1.50 0 0 COMPZ MOVE MOB P Final rig move preparations and PJSM. Verified with Security airport temperature -31 degF. Call made to AES Support Equipment Foreman to • verify no work shutdowns due to weather. 01:30 02:30 1.00 0 0 COMPZ MOVE MOB P Back off Well. Clear Cellar. Final check of move system and Rig Released from 3M -14. ** *Rig Released at 02:30 * ** Page 15 of 15 • • rr.„12.7mc.? [ �� � � � SEAN PARNELL, GOVERNOR L1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Sr. Wells Engineer ( f'f G 1 ConocoPhillips Alaska, Inc. J P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3M -14 Sundry Number: 312 -243 54tIVINEDJuL 1 8 2011? Dear Mr. Packer: 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 reconsideration. A request for reconsideration 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. Sincerely, Cathy . Foerster Chair DATED this b day of July, 2012. Encl. • 4 STATE OF ALASKA .� jj / . ALA OIL AND GAS CONSERVATION COMSION N �� i APPLICATION FOR SUNDRY APPRO VALS '� 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell 17 Change Approved Program r Suspend r Plug Ferforations r Perforate 1 • Rill Tubing Time Extension r Operational Shutdow n r Re -enter Susp. Well [ Stimulate . Alter casing 17 Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 , Exploratory r 187 - 051 3. Address: 6. API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21726 - 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 r No 3M -14 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25523, 25522 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7244 • 6498 • 7010' Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 16 121' 121' SURFACE 3436 9.625 3473' 3377' PRODUCTION 7189 7 7217' 6475' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6940 - 6942, 6944 - 6945, 6948 - 6949, 6954 - 6992 6240 -6242, 6243 -6244, 6247 -6248, 6252 -6284 3.5 L -80 6810 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER F -2 PRODUCTION PACKER MD= 6796 TVD= 6119 RECEIVED SSSV_ CAMCO TRMZXX -5E MD =1998 TVD =1998 12. Attachments: Description Summary of Proposal ri 13. Well Class after proposed work: JU j 0 3 2 012 Exploratory r D evelopment i� • / r •ce r Detailed Operations Program r BOP Sketch r M r ." 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: l 8/24/2012 Oil i✓ . Gas 1°' WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 - 6845 Printed Name Brett Packer �� Title: Sr. Wells Engineer Signature /' 7 Phone: 265 -6845 Date 1 /44 2-- C o m m i ss i o n Use Only Sundry Number: , �) Conditions of approval: Notify Commission so that a representative may witness 5 '7 3 Plug Integrity r BOP Test / Mechanical Integrity Test r Location Clearance r re 136 P . 1 c ii-64/0 r 5/. jai c h il- .4 6 c7 cc l vi sr? r C• ,,- Other t� c4 5 ;I/76/1'e el /-r-el - -._) LJ VJ /r . c•� a re °Gi) re-et L / - c fc v J F1 vetc /L k ` .t/L21 L'1G1,1 f c`y"), Subsequent Form Required: I C • "zf z1' , / APPROVED BY Approved by: ' COMMISSIONER THE COMMISSION Date: p [[���Qp� Submit i D hcate ? L,IYlJ3 I� is l�d,1/ ;;,• 7, ir 1 1 7i ORIGINAL /1--- f f • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 July 2, 2012 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover Kuparuk Well 3M- 14 (PTD# 187 -051). Producing well 3M -14 was originally completed in August 1987 as a single 2 ' /8" gas lift completion. This well . came online at over 1500 bopd and has been a good producer throughout the years and is still capable of over 200 bopd. In 1998, after step -rate tests were performed, it was determined that the A -sand was capable of producing at much higher flow rates. Therefore, a workover was done in July to replace the completion with an ESP in hopes to draw down the bottom hole pressure and increase rates. The ESP was brought online and was able to provide an incremental 320 bfpd. The ESP lasted until August 2001 when it experienced a downhole short. The well was converted back to gas lift and placed back on production. In June 2006, another workover ensued, this time to install a new gas lift completion with a packer to optimize gas lift. During this workover, the ESP was stuck downhole and would not pull free. They cut the tubing and then proceeded to fish the ESP. They attempted multiple fishing runs, each time recovering only pieces of the ESP down to the motor section. The ESP eventually started to move downhole and they were able to push the ESP remnants below the bottom perfs to a depth of 7,010' MD. A caliper log was run to analyze the condition of the 7" casing and it was reported that there was minor casing damage in the perforated interval, regardless, a new gas lift completion was installed and the well brought back online. After 10 short days of production, the well had filled up with rocks and sand to 4,760' MD (2,200 ft of fill); some of the rocks being up to 1.5" in diameter, therefore, the casing damage was a little more severe than had originally suspected. The well has been SI ever since. The upcoming workover plans are to pull the 3 '/2" tubing, mill & retrieve the F -1 packer, cleanout to 7,010' MD, run & cement a 4 ' /2" scab liner across the Kuparuk, and run a new 3 'h" gas lift completion. The well will be re- perfed and re- fracced. This Sundry is intended to document the casing repair, the subsequent re- perforating and fracture stimulation, as well as request approval to workover the well. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells . • 3M -14 Rig Workover Pull 3 1 /2" Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & 3 1 /2" Tubing (PTD #: 187 -051) Current Status: This well was brought online 7/30/06 immediately following the last workover, but within 10 days, the well had filled up w/ rocks & sand to 4,760' MD (2,200 ft of fill) due to damaged 7" casing in the perforated zone. A caliper log performed during the last workover had indicated there was damaged casing in the perforated interval, but apparently the damage was worse than expected. The well has been shut in ever since. Scope of Work: Pull the 3 ' /2" tubing, mill & retrieve the F -1 packer, cleanout to PBTD, run & cement a 4 ' /2" scab liner across the Kuparuk, and run a 3 ' /2" gas lift completion. The well will be perforated and fracced, but whether it is perforated on -rig or post -rig is still being decided. General Well info: q ' Well Type: Producer P = �� 66 — c , / (4. 42 I ps MPSP: 2,650 psi (Current SITP as of 6/25/12) Reservoir Pressure /TVD: 4,869 psi / 6,206' TVD (15.1 ppg) from Panex gauges on 11/15/11. Wellhead type /pressure rating: FMC Gen IV, 7- 1/16" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -T, MIT -IA, and MIT -OA passed on 6/25/12 — 6/26/12. Earliest Estimated Start Date: August 24, 2012 Production Engineer: Evan Reilly / Jeremy Mardambek Workover Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Pull 1.5" DV from GLM #5 @ 6,681' MD, leave pocket open. b. Pull catcher sub @ 6,828' MD. c. Pull CA -2 plug in D nipple at 6,828' MD. d. RIH w/ dual Panex gauges, lightly tag fill, obtain 30 min. SBHP, pull uphole 100' MD and obtain 15 min. gradient stop. e. Lock out SSSV. }� �75j) f. RDMO. 5 ' /2 ft's t .2 5 5-� 2. Set BPV w/i 24 hrs of rig arrival. / J p al Proposed Procedure L 1. MIRU Nordic 3. 2. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. A A-G''L7 ( ¥'G 3. Set BPV & blanking plug, ND tree, NU BOPE & test. ! r'S f c-' "GI (•J ,%S t `�' f 1 6 � yKj C ' 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. / )7 j0 (t t ✓' f t 5. POOH laying down 3-1/2" tubing. J b? Gt Gi v a a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the PBR. b. If tubing was cut, MU overshot & single in on 3 -1/2" IF drillpipe, latch onto tubing stub and jar seal assembly from the SBE. POOH standing back drillpipe, lay down fish. c. POOH standing back drillpipe, lay down fish. 6. MU packer mill w/ packer retrieving assy., RIH on 3 -1/2" IF drillpipe to top F -1 packer. Commence milling on packer, POOH w/ packer & tbg tail. • • 3M -14 Rig Workover Pull 3 1 /2" Completion, Cleanout to PBTD Install 4 1 /2" Scab Liner & 3 1 /2" Tubing (PTD #: 187 -051) 7. MU 6" smooth OD concave junk mill w/ 6" string mills, cleanout to top of ESP fish at 7,010' MD or PBTD. POOH standing back drillpipe, lay down milling assy. 8. PU —230' of 4 -1/2" liner (w/ centralizers), 5" x 7" Flex -lock liner hanger, 5" x 7" ZXP liner top packer, HRD running tools, and RIH on drillpipe to 7,010' RKB. 9. RU SLB cementers, establish circulation rate, pump 10 bbl spacer followed by - 10 bbls Class G cement, drop wiper plug and chase w/ KWF until plug bumps. Pressure up to 3500 psi to set liner hanger at 6,760' RKB. Slack off 50K lbs to check hanger is set. 10. PU to expose rotating dog sub and slack off 45K lbs. to set ZXP packer. Pick up and reverse circulate cement out of the hole until clean fluid returns. 11. POOH laying down drillpipe, lay down liner running tools. 12. RU E -line: RIH w/ 10' perforating guns, GR/CCL, tie into casing and perforate the Kuparuk Al & A2 sands. POOH. 13. Offload old tbg, load & strap new 3 -1/2 ", 9.3 #, L -80 8rd EUE tbg into pipe shed 14. Single in w/ new 3 -1/2" tubing to just above the SBE. Sting into SBE, space out 7' from fully located, mark pipe and pull out of SBE. 15. Space out w/ pups, MU hanger. Spot 15 bbls 15.5 ppg corrosion inhibited brine in the IA below the bottom GLM. Land the hanger, RILDS. 16. PT the tubing to 3,000 psi, bleed tubing to 2500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing joint, install two -way check. 18. ND BOPE. 19. NU and test tree. Pull two -way check. 20. Swap well over to 9.6 ppg corrosion inhibited brine. 21. Freeze protect through the SOV, set BPV. 22. RDMO Nordic 3 Post -Rig Work 1. Pull BPV. 2. RU Slickline: Pull SOV, run GLD. 3. RU E -line: Perforate Kuparuk Al & A2 sand (if not done on- rig). c`,,, C;t /� p �' „� c:. 4. RU SLB Frac Crew: Frac the Al & A2 sands. J 5. Turn well over to operations. # KUP 3M -14 GOtIOCOPFIiIli�?S Os . Well Attributes Max Angle & MD TD AIaSka Inc Wellbore API/UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (kKB) coned nips 500292172600 KUPARUK RIVER UNIT PROD 35.63 5,800.00 7,244.0 4 Comment H23 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ° Well Confip: -3M -14 1212/2071 10:56:33 AM SSSV: TRDP 155 12/7/2005 Last WO: 7/2/2006 41.90 6/5/1987 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 6,943.0 11/14/2011 Rev Reason. TAG ninam 12/2/2011 Casing Strings HANGER, 26 &�, Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 38.0 121.0 121.0 62.58 H - 40 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 37.0 3,473.1 3,376.7 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 27.8 7,217.0 6,475.2 26.00 J -55 Tubin Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ( TUBING 31/2 2.867 25.8 6,809.6 6,129.8 9.30 EUE Completion Details CONDUCTOR, Top Depth 39 -t 27 l (TVD) Top Inc! Nomi... Top (RKB) (ftKB) ( °) Item Description Comment ID (Int 25.8 25.8 0.21 HANGER FMC GEN IV TUBING HANGAR 2.867 SAFETY V, 998 f I r y, 1,998.2 1,998.2 0.55 SAFETY VLV CAMCOTRMAXX 5ESCSSV 2.813 9 i 6,797.6 6,119.8 32.81 SEAL ASSY BAKER 80 BONDED SEAL ASSEMBLY Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Packer 5 4.000 6,796.3 6,840.0 6,155.5 Completion Details GAS LIFT, ,!. Top Depth 2,800 (TVD) Top Inc' Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 6,796.3 6,118.7 32.81 PACKER BAKER F -2 PRODUCTION PACKER 4.000 (1 r 6,799.6 6,121.4 32.80 SBE BAKER 80-40 SEAL BORE EXT. 4.000 'I I 6,811.9 6,131.8 32.76 MILL EXT MILLOUTEXTENSION 4.390 J l 6,828.4 6,145.7 32.71 NIPPLE CAMCO 'D' NIPPLE w/2.75" PROFILE 2.750 SURFACE, 6,839.5 6,155.0 3267 WLEG W REL NE ENTRY GUIDE 3.000 37 -3,473 n Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, (TVD) Top Intl e 7,4 T op (ftKB) (RKB) (°) Description Comment Run Date ID (in) all 7,010 6,299.0 32.09 FISH ESP MOTOR PARTS REMNANTS OF ESP MOTOR 6/10/2006 alig - PUSHED DOWNHOLE wIWORKOVER 6/10/2006 SHOULD BE FILL TO 7244'- DRILLER'S TD (FRAC OR FORMATION SAND) s'3;s II 1I � �� Perforations &Slots Shot -_ Top (TVD) Btm (TVD) Dens Top (MB) Btm (RKB) (RKB) (RKB) Zone Date 0 Type Comment 6,940 6,942 6,239.9 6,241.6 A -2, 3M -14 8/16/1987 1.0 IPERF 4" CG, 120 deg. phasing GAS LIFT, z 6,944 6,945 6,243.3 6,244.1 A -2, 3M -14 8/16/1987 1.0 IPERF 4" CG, 120 deg phasing 6,096 6,948 6,949 6,246.6 6,247.5 A -2, 3M -14 8/16/1998 1.0 IPERF 4" CG, 120 deg phasing 6,954 6,992 6,251.7 6,283.7 A -1, 3M -14 8/16/1987 4.0 IPERF 4" CG; 120 deg phasing Notes: General & Safety End Date Annotation GAS LIFT, Ilr 6,681 - 7/28/2006 NOTE. PER CALIPER LOG 6/27/2006, SEVERE 7" CASING DAMAGE @ 6947 -6946' a 8/17/2006 NOTE: RECOVERED ROCKS TO 1.5" DURING TAG II 7/21/2008 NOTE: VIDEO - GLMS 1- 4 = ROCKS, GLM 5 = CLEAR 7/21/2008 NOTE: SAND & PEBBLES OBSERVED @ 6930' 10/10/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 LOCATOR x SUB, 6,797 PACKER, 6,796 'S �p .E"` p v // f v b-1 V7 9 ✓ SEAL ASSY, 6,798 � Y >S SBE, 6,800 ®. / r • 7 ' / C. /� 4- 1 MILL EXT, I �� p i t 8,872 NIPPLE, 6,828 ? `� II 14' IL WLEG, 6,840 J IPERF, 6,940 -8,942 IPERF, 6,944 -6,945 = Mandrel Details Top Depth Top Pon IPERF. (TVD) Intl OD Valve Latch Size TRO Run 6,945 -6,949 Stn Top (RKB) (RKB) P1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 2,800.2 2,787.7 21.10 CAMCO MMG 1 1/2 GAS LIFT V RK 0.188 1,250.0 7/4/2006 2 4,228.8 3,999.4 34.28 CAMCO MMG 1 1/2 GAS LIFT Y RK 0.188 1,255.0 7/4/2006 IPERF, ■ 3 5,319.4 4,901.8 34.72 CAMCO MMG 1 1/2 GAS LIFT RK 0.188 0.0 7/4/2006 6,954 4 6,095.5 5,536.9 34.82 CAMCO MMG 1 1/2 GAS LIFT DMY 'RK 0.000 0.0 6/29/2006 5 6,680.6 6,021.6 33.12 CAMCO MMG 1 1/2 GAS LIFT DMY RKP 0.000 0.0 7/4/2006 FISH, 7,010 PRODUCTION, 8, 7,244 ate 78,7,244 • • ConocoPhillips Well: 3M -14 2012 RWO Proposed Completion viro 16" 62.6# H -40 to 121' MD 9 -5/8" 36# J -55 to 3,489' MD ■ 3 -1/2" Gas Lift Completion 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface. 2.875" Landing Nipple w/ 'DS' profile @ -1800' MD 3 -1/2" Camco MMG gas lift mandrels @ TBD mm: 1 2.813" Landing Nipple w /'DS' profile @XXXX' MD Baker GBH -22 seal assy. @ : "MD (3" ID) 4 -1/2" Scab Liner Baker 5" x 7" C -2 ZXP liner top pkr @ — 6,760' MD Baker 5" x 7" Flex -lock liner hanger @ XXXX' MD Baker 80 -40 SBE (20' length with 4" ID seal bore) 4 -1/2" 12.6# L -80 BTC R3 to 7,010' MD (or pm) A -2 -sand perfs 6940' - 6949' MD — A -1 sand perfs 6954' - 6992' MD 4 4 -1/2" L -80 BTC shoe @ —7010' MD • ESP Fish Remnants from 2006 RWO @ 7,010' MD 7" 26# J -55 BTC shoe at 7217' MD I Updated: 7/2/2012 • • Ferguson, Victoria L (DOA) From: Packer, J.Brett [J. Brett .Packer @conocophillips.com] Sent: Wednesday, July 11, 2012 2:15 AM To: Ferguson, Victoria L (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: 3M -14 Sundry (312 -243) Victoria, The MPSP of 2650 psi stated in my sundry application was the stabilized SITP observed with the well full of diesel on 6/25/12 (sundry was submitted on 7/2/12). Recently we have been doing some pre -rig wireline work in preparation for the RWO. The previously stated SBHP of 4869 psi at 6206' TVD was measured back on 11/15/11, but a more current SBHP was obtained on 7/6/12 and measured 4842 psi at 6242' TVD (in the top A -2 sand perforations) with a stabilized SITP of 2550 psi and the well full of diesel. Based on the current SBHP, using a gradient of 0.1 psi /ft, the MPSP would be 4218 psi were the entire wellbore evacuated to gas. However, this is highly unlikely. According to 20 AAC 25.280(b)(4), a more accurate means of determining the MPSP would be to use the stabilized SITP which is currently 2550 psi. During the workover, we will be exposed to the perforations and subject to the 4842 psi reservoir pressure which is equivalent to 14.9 ppg. ConocoPhillips policy is to use a 125 psi overbalance safety factor, so plans are to use 15.3 ppg drilling mud to perform this workover. The well will be killed with 15.3 ppg mud prior to performing any work on this well, so even after cleaning out the perfs to PBTD, the well will remain dead. The top A -2 perforations are exposed, and we have fill inside the casing covering the bottom two sets of A -2 perforations as well as the A -1 perforations, but the reservoir pressure we are seeing right now is the full reservoir pressure; the rocks and sand in the casing are permeable and are not masking any higher pressure from below. The perforated intervals are only spaced 1 - 3 ft TVD apart and based upon the 2200' of fill we encountered in the wellbore back in 2006, there is likely a large void behind the production casing connecting the perforated intervals together. If you have any further questions, please don't hesitate to call or email. Thanks! J. Brett Packer Wells Engineer ConocoPhillips Alaska Office: 265 -6845 Cell: 230 -8377 From: Ferguson, Victoria L (DOA) jmailto :victoria.ferguson @alaska.govl Sent: Tuesday, July 10, 2012 2:39 PM To: Packer, J.Brett Cc: Schwartz, Guy L (DOA) Subject: [EXTERNAL]3M -14 Sundry (312 -243) Brett, Please provide the MPSP expected and the calculation basis. Using a gas gradient of 0.1 psi /ft and the reservoir pressure provided (4869 psi @6206' TVD) results in a MPSP of 4248 psi. Is there potential to see this pressure once the fill is cleaned out and the perfs uncovered? . . WELL LOG TRANSMITTAL RECEIVED AUG 2 9 2006 PROAcriVE DiAGNOSriC SERVicES, INC. Alaska 011 & Gas Cons. Commission Anchorage To: AoGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1) 2) 3) 4) 5) 6) 7) 3M - 14 Caliper report 27.Jun-06 SGANNED AUG 3 Ü 2005 Signed : elj -~_.~....~.... . Date: a/~ /00 Print Name: -.C-111 r'ï1l1H III-e. (YLtUA 1111R -€'A PRoAcTivE DiAGNOSTic SERvicES, INC., 1 ~o W. INTERNATioNAl AiRpORT Rd SuÎTE C, ANdiORAGE, AK 99518 PhONE: (907)245~8951 FAX: (907)245~8952 E~MAiI: pdSANChQMGE@MEMORY!!:>G·COM WEbsÎTE: MEMORyloG.COM I~T-Cf)1 C:\My Documents\ Work\ DistributionLablesNew\ Transmit_ Original.doc I I I I I I I I I I I I I I I I I I I . tif1-C£ . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. June 27, 2006 7584 1 7" 26 lb. J-55 Production Casing Well: 3M-14 Field: Kuparuk State: Alaska API No.: 50-029-21726-00 Top Log Intvl1.: Surface Bot. Log Intvl1.: 6,946 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the peñoration @ 6,940' (Driller's Depth). This log was run to assess the condition of the 7" production casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 7" production casing is in good to poor condition, with damage so severe the casing appears to have disintegrated below the top perforation (6,942' - 6,946') in joint 162. Multiple holes are recorded in joint 161, directly above the interval of disintegrated casing. A 3-D log plot of the caliper recordings across the perforation interval and missing production casing is included in this report. The damage recorded appears in the form of a line of pits (4,700' - 6,000') that deepens and broadens into a line of corrosion (6,000' - 6,940'). Deposits restrict the I.D. to 5.67" in joint 158 (6,812'). MAXIMUM RECORDED WAll PENETRATIONS: Disintegrated Casing (100%) Jt. 162 @ 6,944 Ft. (MD) Multiple Holes ( 99%) Jt. 161 @ 6,908 Ft. (MD) Corrosion I Possible Hole ( 81 %) Jt. 160 @ 6,901 Ft. (MD) Line Corrosion ( 78%) Jt. 157 @ 6,737 Ft. (MD) Corrosion ( 78%) Jt. 159 @ 6,850 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS : Disintegrated Casing ( 98%) Jt. 162 @ 6,944 Ft. (MD) Corrosion I Erosion Opposite Hole ( 24%) Jt. 161 @ 6,917 Ft. (MD) Corrosion ( 22%) Jt. 159 @ 6,850 Ft. (MD) Corrosion I Poss. Erosion Opposite Hole( 18%) Jt. 160 @ 6,865 Ft. (MD) No other areas of significant cross-sectional metal loss (> 11 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits Minimum I.D. = 5.67" Minimum I.D. = 5.73" Minimum I.D. = 5.76" Minimum I.D. = 5.73" Minimum I.D. = 5.91" Jt. Jt. Jt. Jt. Jt. 158 @ 162 @ 159 @ 161 @ 154 @ 6,812 Ft. (MD) 6,941 Ft. (MD) 6,818 Ft. (MD) 6,921 Ft. (MD) 6,601 Ft. (MD) I Field Engineer: J. Halvorsen Analyst: M. Lawrence Witness: D.Heim ProActive Diagnostic Services, Inc. ! P.O. Box 1369, Staffol-c1r TX 77497 Phone: or 565-9085 Fax: 565-1369 E-mail: PDS@)memorylog.com Prudhoe Bay Field Office Phone: 659-2307 Fax: 659-2314 Joint 160 6880 I I I II II I I I I I I I I Joint 159 Joint 161 1 "~" Max. ReQ, ("/¡¡ WiI1 BOO!! MIl\! 10 (1[101111 10,) 700 ¡ 6860 6890 6900 6910 I 6920 I Joint 162 6930 Dis- I Casing (6,942' - 6940 I I I I I Overview nalysis I Well: Field: Company: Country: 3M-14 Kupmuk ConocoPhillips Alaska, Inc. USA Survey Date: rool Type: rool Size: No. of Fingers: June 27, 2006 tv1FC 40 No. 99494 2.75 40 I I Penetration and Metal loss (0/0 wall) Damage Profile (% wall) I I ol o ¡ metal loss .50 100 penet¡àlion metal loss penetration 150 I 5 ¡ Tìil·-l , I i I 100 50 pene. loss I I Damage ¡OO 80 101 I 60 40 I 20 o I ISol;.1ted pitting genera! line nng hole I )o,;s com)Slon corroSion corroSion ¡ble hole 151 I 2 Bottom of Survey 162 I I Analysis Overview page 2 I I I Correlation Recorded Damage to Borelìole Profile I Pipe 1 7. in (17.4' - 6921.9') Well: Field: Company: Country: Survey Date: 3 M-14 Kuparuk ConocoPhillips Alaska, Inc. USA June 27, 2006 I I I Appro\. Fool Deviation Appro\. Borehole Profile 20 1-1 -r TT ----11 17 I I I I I I I I I I I I I I I 837 I I I I I I i I I I I I 1695 i I I I I i i i I I 2554 I I I 40 I 60 I (¡¡ .D E ::¡ z 80 3413 ,i c: I 100 4272 I 120 5133 I 140 5990 I I 160 162 o 50 6857 6922 100 I Darnage Profile (%, wain I Fool Deviation I Bottom of Su rvey = 162 I I I I I I I I I I I I I I I PDS JOINT TABULATION S Pipe: Body Wall: Upset Wall: Nominal 1.0.: 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: 3M-14 Kuparuk ConocoPhi¡¡ips Alaska, Inc. USA June 27, 2006 I I I I I I joint It. Depth Pen. Pen. I Pern Metal Min. I n .£:L '"'"''' No. Body ID. Comments (%wall) I .) , (Ins.) 0 50 100 1 0 0.01 t~n'" )~. 2 J 0.01 6.27 '\ 1{ () 0.03 - ') '") Shallow Dittirm. I , . b.~.J 4 .~...~-~~~.._..- 14L. n 0.01 ') 'J I ·-O-~ -...... ..)--- --------- - -- -~---_.. _ ~~____._~._M...._'_..~_,__ ..._._~_. ,) ISC 0.03 .22 () r () 0.04 I) ) .24 Shallow nitlimz. 7 21 () 0.04 ( 3 .6.23 Shallow nittincr. --------~------ ~-_.~- _.,..~.. ... 8 31 0 0.04 H 6.26 Shallow nitlil1\z. ^---- -------^ __~ _'M__'" q 359 0 11.04 I ) j'.23 Shallow nitlimz. 10 403 0 0.03 9 ) 6.25 Shallow pitling. 11 447 ii 0.e13 j ." ,,"'uw Ditting. .~~.__..~ e I .. J II 12 491 n )) I Dining. 13 534 0 I I 14 577 n """UW pitting. I 15 618 Ii He I 16 661 ( OJ)4 it ......... ..........~~.~.I ( OJ)5 I 0.02 19 793 ( . 0.04 2 I I 20 837 ( 0.02 2 6.26. I 2 880 Ii (1.06 17 ().24 I I i i 22 924 n 0.05 H ¡ 6.23 I ..- -. 23 5.Jf{J. n 0.02 () : ( ')') ).~~ ... 24 101:) n Ö.Ö3 9 I 6.20 ~5 1057 ___.0. n 0.06 17 6.26 hn own tlímL ~6 110 n 0.06 17 1 6.21 hn ow p tting. 1145 : 0.05 14 4 6.27 h;1 ()w n tlím!. I 1188 I. OJJ1 2 , 62'1 , .._~- I 1230 : 0.05 5 6.2'1 Shallow nitlínQ 1275 "" 1 0.01 :2 6.26 31 1311 : 0.03 9 1 6.19 Shallow pitting. 32 1 ,I : 0.04 i2 6.20 Shallovv pitting. =1~~1=1 L 15 : 0.01 2 ... I 19 : 0.04 10 2 Shallow Ditting. I I 0.05 :4 Shallow pitting. 1 I I I 1 b 1 1 0.01 2 4 1 : 0.01 2 2 (,2 g H ( 0.01 2 I 6.2 :) H Î 0 0.01 2 3 6.24 I 40 .....J!{}5. 0 1.03 9 2 6.21 Shallow DittinlZ. '41 1 0 0.01 " 3 5 6.25 I 42 1 : . '.05 14 2 6.19 Shallow DittinlZ. ,. 4'\ 1 ii ''(J3 7 \ 6.23 !ìI I 44 i .00 I 6.23 45 I II .01 3 ) 6.25 46 141 II 0.03 7 2 6.27 IIIIJ 47 I ()89 II 0.01 2 2 6.25 41) 2032 (I 0.01 \ ) 6.20 49 2075 II ) 6.21 50 2IHI" II 0.01 2 ) 6.21 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT U ON Pipe: BodyWa!l: UpsetWa!l: Nominal 1.0.: 7. in 26.0 ppf )-55 0.362 in 0.362 in 6.276 in 3M-14 Kuparuk ConocoPhiliips Alaska, loe. USA June 27, 2006 Well: Field: Company: Country: Survey Date: Joint It. Depth 1\'1 Pen. Ppn ,\¡\p);¡1 Min. Damage Profile No. I Body In. Comments ('Yo (i ) (Ins.) (Ins.) 0 50 100 51 21(¡L ._. n OJ) 1 ) ) ')) 2205 n 001 i ··········H '2: . n 0.04 'I Line shallow )' n 0.04 I) line shallow "'1 )' 0 0.01 'I '=;h ) 0 0.01 ) :1 "7 ), 0 0.0\ I ~5 58 2467 0 0.02 2 6.25 '" 59 ')S10' 0 0.04 10 ~I 112 ow Dittin&.._~._.. I'" 11 ') ',}54 0 0.05 14 1];1 ow D Ing. I 1 1 2591L 0 0.03 hi! ow n Ing. I I 1 :z.(¡4Im 0 0.03 _624 hi' OWl Ing. I 1 2685 n 0.04 0 h,1 owp Ing. ()4 2729 I ] 65 2772 S line shallow 66 2BH I 9 Shallow pitting _ 67 2RW I ., Shallow pitting. 6B 2904 n 6.25 II I 69 2947 n I 70 29B2 n , Shallow pittim~. I 71 '1026 n CUB " 72 3070 n 0.04 , I I Shallow nittilì\l " , n '11'14 n 0.02 .., ( II 74 '1157 n 0.06 16 6.23 I infO .'-". "1fII r '1201 n 0.01 4 ) , 6.21 J 76 '\245 n 002 6 I 6.27 II 77 :¡2íN (I 0.115 1\ ) 6 )., Shallnw nittinQ !fII! I .-i- J 7B i'i)3 n o.m R ) 6.2S I 79 3373 n O.lB R ; 6.23 " -....-- 80 3413 n 0.03 9 , 6.20 Shallow DitlinQ !fII! 81 3455 0 0.03 , a ¡ 6.23 I'" I ~;; 3499 n om ) I 6.21 RFH~r 0 ci:03 a ) 6.22 Jill 3585 0 0.03 a ¡ ( ')Ie ).~.J 3626 I) 0.03 7 I 621 3670 J 0.06 IS ) 6.20 r. ni t1íl.lg. II II 3713 iJ CL04 12 2 6.14 Shallow DiUing. II 3758 iJ 0.04 12 2 6.23 Shallow nitlinQ. II I 3800 I) 0.07 HI 2 6.22 Shallow DitlinQ. 1111 , 3844__ I) 0.03 a I 6.19 .. fIE I 3888 iJ 0.0'1 9 ) 6.24 Shallow nìtliljQ. 11II I )33 C 0.01 2 ) 6.24 1 )74 C 0.04 ]1 I 6.22 nitti/w. I 8 C (L06 17 ) 6.21 Shallow DiuÌ!ìQ. ( 11__ ..~ ) 6.24 . .,lÍJ}~_.sb<ìil<)_\.'\I cOffQ.sif)ll, _ I q¡, . - . ... ....-...-.........,........., IIIIIIII1 c 2 6.24._ - ~-~~~-~~---------------------------~------------------------ q7 U 4 6.23 qR 41 0 0.031 , 6.23 -_...._._~.._.- 99 42 :1 I) I 6.18 100 42 '2 () (WJ 3 ) 6.18 -- _.~._-----~--- ~---- Body Meta! Loss Body Page 2 I R JOINT U I Pipe: 7. in 26.0 ppf )-55 Wen: 3M-14 Body Wall: 0.362 in Fie!d: Kuparuk Upset Wall: 0362 in Company: ConomPhillips Alaska, Ine I Nomina! I.D.: 6.276 in Country: USA Survey Date: june 27, 2006 I joint it Depth Pen Pen. pen. MeLli Min. Damage Profile I No. (Ft.) I ID. Comments (% wa!1) I (Ins.) I (.) o 50 1 00 I !' )1 43!6 U 0.02 6 .~ 6.21 I I I H2 4360 0 0.03 7 ) 6.22 H3 4404 0 0.02 7 ¡ 6.24 104 0 0.03 9 ) ( ')') Une of Shallow Pits. ).....:. 105 4490 0 0.04 II 4 6.23 Line of Shallow Pits. III I 106 -4534 0 0.03 9 ) 6 ')~ ine of Shallow Pits. 11III ,,¡;..,,) 107 4578 C (l04 Ii ) ( 'n ine oj Shallow Pits. Ii!! --.. ).k... ¡ 108 4622 0 (L06 17 ) 6.24 line () . Shallow Pits. I 109 0 2 2 .. 4665 0.08 6.23 Line (J PitS. ---- -- I 110 4709 0 .. 0.04 10 4 6.22 Line n . Sh"l!n\!\I Pits. I--J-~~=f=~ 51 c I.( 2) ) I 6.21 Line 0 Pits. Jï2' 794 0 I.( 25 ) 6.19 Line 0 Pits. 11'j L 0 I.( ) ) 623 Lme o' Pits. I 114 I 0 I ) 6.20 Line of Shallow Pits. 115 U 3 6.24 Une 0 Shallow Pits I 116 0 2i ) 6.25 Une 0 Pits. I} U 2( ) 6.22 Une 0 Pits. I ¡... - I 0 0 2( ) 6.22 line 0:: Pits. 0 19 ) 6.19 line 0: Shallow Pits. I) .1 3 ) 6.16 Line 0:: Pits. I I) 11 )( 3 p.21 Line 0: Pits. I , I) 1.06 !1 3 6.21 line cl. .11 Pits I p.' 5265 U 11 2' 6 6.22 Line 0: Pits. k_J 124 5308 U 1.06 la 4 6.19 line N." Pits p" 5349 U 0.08 23 4 6.21 Line 0 Pits. ...J 176 ') ¡'(51 U 0.12 n ) 6.23 Line 0' Pits. 177 54i'1 U . 4 6.21 Line 0: Pits. I I 0.08 178 '1479 I 0.12 6.21 line 0 Pits. I 1)9 !:"t:"')<) 0 0.09 6.21 Line 01 Pits. J.)_.) 130 5566 ( 0.13 6.19 Line 01 Pits. I Iii 5609 I U 0.10 6.21 Lme 01 Pits. I·'·) 5653 U 0.11 6F I I )...... ._.J In '16% { 0.1 6.19 Line li4 5740 -.-- ( 0.1 6.20 ...ine 0' Pits. I 11'1 578:?~ { 2 ...ine 0 Pits. 1 i6 5821 U 0(, . .2" ...ine 01 Pits. 117 >:: ( tFf 4 1( Lme u PitS. 11n ( 3 .2: ...ine of PitS. III Ii') 0; l I () .2( I 140 0; () 0.13 V 4 1 ...ine of PitS I 141 60i 0 0.13 -- 15 4 I ...ine of Pits. 142 6077 0 0.11 ') .2' 143 6121 0 0.12 () 6.04 line of Pits. I 144 OO~ 0.12 h 6.25 Corn~slOlI. . 6210 0 012 "7 . 145 6.21 \.. 146 6252 II 0.12 n 6.20 ( orrOSIOl1. . 1 47 _--.l>2()Q. 0 (H.t 29 (, 6.20 Corrosion. I J43 -""- 6339 0.07 0.10 2B 10 6.19 Corrosion. ~~__~_m_~~ ___~~____ _ 149 63ß2 ()06 (lll , 30 4 6.11 !50 6425 0 0.13 36 ") 6.20 Lme lorroslon. I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT I 7. in 26.0 ppf J-55 0.362 in 0.362 in 6.276 in WeD: Field: Company: Country: Swvey Date: Pipe: Body Wall: Upset Wail: Nominal I.D.: 3M-14 Kuparuk ConocoPhillips Alaska, Ine. USA June 27, 2006 I I Joint No. Comments I 151 1""7 J~ I I I I I I I I I I I I Page 4 I I Damage Profile (%wall) o 50 1 00 Body Metal Loss Body .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. P S Rep c 55 S n5 Well: Field: Company: Country: 3M-14 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: June 27, 2006 MFC 40 No. 99494 2.75 40 ft Tool speed = 62 NominallD = 6.276 Nominal OD = 7.000 Remaining wall area = 78 % Tool deviation 360 Finger 26 Penetration = 0.36 ins Multiple Holes! 0.36 ins = 99% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. - - .. .. - .. .. .. .. .. .. .. .. .. .. .. PDS ross S ons Well: Field: Company: Coun try: 3M-14 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: June 27, 2006 MFC 40 No. 99494 2.75 40 67 ft Tool speed'" 63 Nominal 10 '" 6.276 Nominal 00 7.000 Remaining wall area'" 86 % Tool deviation'" 34 ö Finger 26 Penetration'" 0.292 ins Corrosion 0.29 ins'" 81% Wall Penetration HiGH SIDE '" UP Cross Sections page 2 .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: 3M-14 Kuparuk ConocoPhi!lips USA .. .. .. .. .. .. .. .. .. .. .. .. p S ross S ns Inc. Survey Date: Tool Type: Tool Size: No. of Fingers: June 27, 2006 MFC 40 No. 99494 2.75 40 speed = 59 NominallD = 6.276 Nominal OD = 7.000 Remaining wall area = 97 % Tool deviation = 36 0 5 ft Finger 12 Projection = -0.612 ins Deposits Minimum LD. = 5.67 ins HIGH SIDE = UP Cross Sections page 3 I KRU 3M-14 I ~ 131\1I;44 API: 500292172600 We!! Type: PROD Angle @ TS: 132 dea IâJ 6930 Gas Lift SSSV Type: NIPPLE ... Orig 6/5/1987 ---- Angie @ TO: ! 32 deg @ 7244 "'drel/Dummy Completion: I Valve 1 Tag Fill (above j (102-103, """..0. . 'u, r LastW/O: 7/11/1998 Rev Reason: OD:4.750) I pum£L "". Ref Log Da..~ 1 5/25/2006 [ Last T "0: 6726' WLM- .. TD: 7244 ftKB 1 Gas Lift ----_.~-_. Last ~ate: 5/23/2006 Max Hole Analeæ5800 I 'ndrel/Dummy Valve 2 Thread (2641-2642. Size i ID Bottom TVD Wt q~ OD:4.750) .UCIUK 16.000 121 121 62.58 H-40 TUBING ---- I·- . CASING 9.625 3489 3390 'm' 36.00 J-55 (0-6752. ~í 7.000 7217 6475 26.00 J-55 OD:2.875. ID:2.441) 1 Bottom I TVD I ~ Grade 1 Thread c----- 2.875 10 I 6752 1 6081 I J-55 I EUE-ABM Gas Lift Interval NO Zone 81Ji1h1s Ft 8PF Date I TYl>.e ",drellDummy r94Õ =6942 6240 - 6241 A-2 2 1 01 '\)1 ';:101 IIPERF W·CG.-f2o dea. ohasina Valve 3 6944 6945 6243 - 6244 A-2 1 1 8/16/1987tœ 4" CG, 120 deo nhasir¡lL~ (3916-3917, OD:4.750) 6948 - 6949 6247 - 6247 A-2 1 1 01'01';:1;:10 RF 4" CG, 120 deo nhasinç¡ - 6954 - 6992 1 6252 - 6284 A-i 38 4 F 4" CG; 120 ~~~ PROD.~·- ~~D ~~ Man Type CASING (0-7217, V I\IIfr V Type VOD latch Port IRO Date Vlv 00:7.000. Run Cmnt Wt26.00) 102 102 Cameo KBMM CAMCO 1.0 0.000 0 8/22/2001 2641 2635 C"me':; KRMM CAMCO to'" ..... .:..... 0.000 0 --------_.~~ --..... 5/18/2006 Gas Lift --~ =4lil 3741 ~. KBMM... CAMCO 1.0 0.000 0 5/18/2006 mdrel/Dummy 4154 Cameo KBMM CAMCO 1.0 0.000 0 5/18/2006 Valve 4 6005 Cameo ~CAMCO ¡PEN 1.0 BK 0.000 ~ 8/22/2001 (4415-4416, OD:4.750) Depth TV ) T'IDe I ID 6741 6072 NIP , "D" NIPPLE NO GO I 2.250 , 6752 6081 PUMP Series 513 Triple Taper pump I 0.000 6788 w/bolt-on intake and diseh'!ffie heads _~__ .~ 6112 SEAL Centrilift GST3 413 HL PFS Tandem Seal Section 0.000 6803 6124 MOTOR Centrilift 266 HP KMH 2345/69 Series 562 Motor w/motor lead extension' T 0.000 Gas Lift ~~hb : a6" . threaded ontð h~nð MandrelNalve 5 ~ Note (6661-6662, Taooed SDX. 10' offill >- CAT SV IâJ 8/31/2001 II~tßW TO '" _l 2/30/200 I WELL t x A C( -!"I\'- :Tlr", ¡:-~ ¡¡::sp I I ¡ NIP - (6741-6743 005620) I PUMP (6752-6788 002500) SEAL-~·- 00 2 500) MOTOR (6803-6830 002500) Perf .'. (6940-6942) -- .- ....... 1-- Perf (6944-6945) ..- f .-- ¡.... Perf (6948-6949) ...... I· -. -- Perf -- -I (6954-6992) ..... 1 f· I I I I I I I I I I I I I I I I I . . Gary Eller Wells Engineer Drilling & Wells Conoc~illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 August 3, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3M-14 \<01- 06/ Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover of Kuparuk well 3M-14. If you have any questions regarding this matter, please contact me at 263-4172. Cì i?: ~j JGE/skad 1. Operations Performed: Abandon D Alter Casing D RECEIVED · STATE OF ALASKA. AUG 0 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION . . REPORT OF SUNDRY WELL OPERA TIONSl\laska Oil & Gas Cons. Commission D Time Extension D Re-enter Suspended Well D Repair Well 0 . Pull Tubing 0' Operat. ShutdownD Plug Perforations D Perforate New Pool D Stimulate D Waiver D Other Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Perforate D 4. Current Well Status: Development 0 Stratigraphic D Exploratory D D Service 5. Permit to Drill Number: 187-051/306-189 6. API Number: 50-029-21726-00 P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 32.8' 8. Property Designation: ADL 25522; ALK 2558 11. Present Well Condition Summary: 9. Well Name and Number: 3M-14 . 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool' Total Depth measured 7244' 6498' Effective Depth measured 6687' feet feet feet feet Plugs (measured) Junk (measured) 7010' true vertical true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Length Size MD TVD. Burst Collapse 80' 3456' 7184' 16" 9-518" 7" 121' 3489' 7217' 121' 3390' 6475' Perforation depth: Measured depth: 6940'-6942',6944'-6945',6948'-6949',6954'-6992' true vertical depth: 6240'-6241',6243'-6244',6247'-6247',6252'-6284' Tubing (size, grade, and measured depth) 3.5", L-80, 6809' MD. Packers & SSSV (type & measured depth) Baker F-1 pkr @ 6796' Cameo TRMAXX-5D SCSSSV 1995' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Si SI 182 1686 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: Oil0 . GasD WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl SI 186 . Casin Pressure Tubin Pressure 135 Service D Daily Report of Well Operations _X GINJD WINJ D WDSPL D Contact 11(.106 Printed Name Signature Title Phone Wells Engineer ~\){.. "LV\:- ,,"\1.'1_ Date ~ \~\\J~ Pre ared b Sharon Ails -Drake 263-4612 ~8·S·0(. Submit Original onl~ ø"~Pr OR \ G \ N A l R80MS 8Fl AU6 I 6 1DO h\,. . ConocoPhiUips Alaska, Inc. . KRU 3VI-14 3M-14 API: 500292172600 Well Type: PROD Angle @ TS: 32 deg @ 6930 TUBING SSSV Type: TRDP Orig 61511987 Angle @ TD: 32 deg @ 7244 (0-B809, Completion: OD:3.500, ID:2.992) Annular Fluid: Last W/O: 71212006 Rev Reason: GLV CIO Reference Loa: 32.8' RKB Ref Log Date: Last Update: 7/20/2006 Last Taq: TD: 7244 ftKB Last Taq Date: Max Hole Angle: 36 deg @ 5800 r.....¡n'" ~trinn , I Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H-40 SUR. CASING 9.625 0 3489 3390 36.00 J-55 PROD. CASING 7.000 0 7217 6475 26.00 J-55 Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 0 I 6809 I 6129 I 9.30 I L-80 I EUE8rdMOD Interval TVD Zone Status Ft SPF Date Tvpe Comment 6940 - 6942 6240 - 6241 A-2 2 1 8/16/1987 IPERF 4" CG, 120 deg. phasing 6944 - 6945 6243 - 6244 A-2 1 1 8/16/1987 IPERF 4" CG, 120 deq phasinq 6948 - 6949 6247 - 6247 A-2 1 1 8/16/1998 IPERF 4" CG, 120 deg phasing 6954 - 6992 6252 - 6284 A-1 38 4 8/16/1987 IPERF 4" CG: 120 dea phasinq I Gas St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2797 2785 CAMCO MMG GLV 1.5 RK 0.188 1250 7/4/2006 2 4225 3996 CAMCO MMG GLV 1.5 RK 0.188 1255 7/4/2006 3 5316 4899 CAMCO MMG OV 1.5 RK 0.188 0 7/4/2006 4 6092 5534 CAMCO MMG DMY 1.5 RK 0.000 0 6/29/2006 5 6677 6019 CAMCO MMG DMY 1.5 RKP 0.000 0 7/4/2006 Depth TVD Tvpe Description ID LOCATOR 26 26 HANGER FMC GEN IV TUBING HANGER 3.500 (6793-B794, 1995 1995 SSSV CAMCO TRMAXX-5E SCSSV 2.813 OD:4.500) 6793 6116 LOCATOR BAKER LOCATOR SUB 0.000 SEAL 6794 6117 SEAL BAKER 80-40 BONDED SEAL ASSEMBLY 3.000 (6794-B796, 6796 6118 PACKER BAKER F-1 PRODUCTION PACKER 4.000 OD:4.500) 6799 6121 SBE BAKER 80-40 SEALS 4.000 6810 6130 XO CROSSOVER SUB 4.140 6811 6131 Millout Ext BAKER MILLOUT EXTENSON 4.390 6817 6136 XO CROSSOVER SUB 2.990 SBE 6818 6137 TBG SUB 2.992 (6799-B810, 6828 6145 NIP BAKER '0' NIPPLE w/2.75" NO GO PROFILE & LOADED w/CA-2 2.760 OD: 5. 000) BLANKING PLUG w/CATCHER SUB Millout Ex! 6829 6146 TBG SUB 2.992 (6811-B817, 6840 6155 WLEG BAKER WIREUNE GUIDE 3.000 00:5.040) I Fish - F IS-I xo Depth Description Comment (6817-B818, 00:5.560) 7010 ESP MOTOR PARTS REMNANTS OF ESP MOTOR PUSHED DOWNHOLE TBG SUB wlWORKOVER IN 2006 (6818-B828, SHOULD BE FILL TO 7244'- DRILLER'S TD (FRAC OR OD3.500) FORMATION SAND) NIP (6828-B829. OD:4.510) TBG SUB (6829-B840, OD:3.500) Perf - - (6944-B945 ) - - Perf - - (6954-B992) - - - - ~ Conoc;p'hillips WelNíew Web Reporting Time Log Summary · 06/04/200606:00 07:00 1.00 0 0 MIRU MOVE MOB P Prep and back rig off 3s-23a. 07:00 08:00 1.00 0 0 MIRU MOVE MOB P Clean well site and secure cellar for move, while CPF 3 electricians shut dwn electric anels alon roadwa . 08:00 21:00 13.00 0 0 MIRU MOVE MOB P Contact security and move rig off 3S ad enroute to 3M ad. 21:00 00:00 3.00 0 0 MIRU MOVE RGRP T Outer rig tire went flat, removed wheel and re to chan e out. 06/05/2006 00:00 16:00 16.00 0 0 MIRU MOVE RGRP T Position new tire around rig, remove bad tire from rim, install new tire, RU PU and install wheel #8, torque bolts and air u tire. 16:00 21:30 5.50 0 0 MIRU MOVE MOB Cont move rig to 3M pad. 21:30 00:00 2.50 0 0 MIRU MOVE PSIT Spot new well head equipment behind cellar, line up and spot rig over well 3M-14, shim and level ri . 06/06/2006 00:00 02:00 2.00 0 MIRU MOVE RURD P Cont to RU on 3M-14, slip and cut 50' of drl line 02:00 05:00 3.00 MIRU MOVE RURD P Spotted Rock washer and bermed same, hooked up hoses to manifold in cellar and rock washer 05:00 06:30 1.50 P Pulled BPV, Checked well pressures, SITP 2,000 psi, IA 2,200 psi and OA 650 si 06:30 12:00 5.50 P Spot 400 bbl blow down tank and berm same, MU hardline to same and took on 8.6 Seawater in the its 12:00 14:30 2.50 P Pressure tested manifold and lines to blow down tank to 3,000 psi, had to change out 1 hose and graylock fitting in cellar, re-tested lines to 3,000 psi and ck ok 14:30 15:00 0.50 P Held PJSM with rig crew, Vac truck drivers and Little Red on circ hole over to Seawater then flushing Annulus with Diesel 15:00 17:15 2.25 P Circ hole with 8.6 ppg Seawater to clean up well and begin to kill same, circ 410 bbls of 8.6 ppg Seawater and recovered 440 bbls fluid. circ thru choke to kill well, pumping at 4 bpm, monitored well and had an initial shut in of 1,450 psi and after 15 min shut pressure was 1,490 psi with 8.6 ppg Seawater. Note Bled OA down from 650 si to 50 si. 18:30 00:00 5.50 COMPZ WELCT CIRC 06/07/2006 00:00 00:45 0.75 COMPZ RPCOfl. CIRC 00:45 01 :15 0.50 COMPZ RPCOfl. OWFF 01 :15 02:45 1.50 COMPZ RPCOfl. CIRC 02:45 03:30 0.75 COMPZ WELCT OWFF 03:30 08:00 4.50 COMPZ WELCT COND Little Red pumped 100 bbls of 90-100deg warm diesel down the Annulus to help clean up the ESP cable and tbg, pumped at an ave rate of 2 bpm at 2,400 psi while holding 1,600 psi back pressure, rig then followed up with 80 bbls of Seawater to clean up tbg to above GLM at 6,661', SITP at 1,590 si, SICP at 1,830 si. P Rig pumped 40 bbl Hi-Vis spacer, followed with 260 bbls 12.7 ppg Potassium Formate off vac truck, taking returns thru choke with approx 1,600 psi back pressure to flow tank, had good 12.7 returns, shut dwn and bled off, SITP at 0 psi, SICP at 0 psi, lined up and bull headed 12 bbls into perfs at 1/2 bpm, from 2,375 psi dwn to 1,600 psi, bled off to 0 psi, SITP at o psi, SICP at 0 psi, lined up and start CBU at 3 bpm, 690 psi taking returns thru choke holding 300 psi back pressure, to pits. Began seeing varied MWs out ranging from 11.5 to 12.1 P Cont CBU at 3 bpm thru choke holding an ICP of 1,600 psi down to 300 psi back pressure, with 12.7 ppg Potassium Formate, 11.5 to 12.2 ppg returns, with 580 psi final tbg circ ressure. P Shut well in and monitor pressures, SITP at 290 si, SICP at 370 si. P Line up and cont circ 12.7 ppg off vac truck at 3 bpm and 800 psi thru choke, holding 1,600 psi to 300 psi back pressure, 12.7 ppg in and 12.0 returns, had 15 bbl gain in pits at shut down, shut in well. P Monitored shut in pressures with initial SITP at 0 psi, SICP at 320 psi, after 30 min pressure increased to SITP of 120 psi and SICP at 400 psi, mud engineer running test on mud return sample to check for oil/diesel or bromide contamination, mud wt in pits at 11.9 to 12.2 ppg, SITP up to 150 psi, SICP up to 420 psi, tests showed no oil or bromide contamination in the mud returns NP Raised MW in pits from 12.2 ppg to 12.7ppg, built 300 bbls of 12.7 ppg Potassium Formate mud, monitoring well with SITP at 260 psi, SICP at 470 si. 09:30 10:15 0.75 COMPZ WELCT OWFF Began circ 12.7 ppg down tbg taking returns thru the choke, holding back pressure to maintain back pressure, circ at 4 bpm with 1,300 psi tubing press holding 360 psi csg press, circ 310 bbls of 12.7 ppg mud around, after calc btms up and surf-surf had 11.5 ppg mw out, (surf -surf 250 bbls)after 300 bbls had 12.5 ppg and after shutting down had 12.5 ppg mw out, final circ rate 4 bpm with 1100 psi tbg pressure and 10 psi csg pressure, no losses while circ 12.7 ppg around, final mw of mud returned to pits was 11.7 ppg with a small trace of oil and no increase in chlorides indicating no bromide contamination P Monitored well after circ 12.7 ppg mw around, initial SITP was 30 psi with SICP of 110 psi, after 30 min had 130 si SITP and 140 si SICP. NP Raised MW in pits from 11.7 ppg to 13.2 ppg, built 372 bbls of volume, used potassium formate to raise MW to 12.2 ppg, then used CaC03 to 13.0 ppg then potassium formate & CaC03 to fin wt up to 13.2 ppg. monitored pressures, final pressures were SITP at 140 psi and SICP at 200 psi, Cont to bleed off OA, keeping pressure below 30 si NP Held PJSM then began displacing well with 13.2 ppg Potassium Formate mud, pumped at 4 bpm thru choke manifold, after pumping 90 bbls of mud (calc 50 bbls into annulus), shut choke and bullheaded 12 bbls of mud into formation, initial rate of 1/2 bpm, formation began taking fluid at 2,220 psi, pressure began to drop and slowly staged pump rate up to 1 bpm, final circ pressure was 1860 psi tbg and 1640 psi csg, after 12 bbls opend choke back up and cont. to circ 13.2 mud around at 4 bpm, ave tbg pressure 1,800 psi tbg and 500 psi csg, ave 12.6 ppg MW out while circ hole, pumped a total of 335 bbls of 13.2 ppg mud, and after shutting down lost a total of 22 bbls, 12 bbls to bullheading and last approx 50 bbls weighted 13.1 ppg out with surf-surf volume of 250 bbls, shut down at 24:00 hrs 10:15 22:00 11.75 COMPZ WELCT COND 22:00 00:00 2.00 COMPZ WELCT CIRC Monitor well after shutting in at 00:15 hrs, SITP 0 psi, SICP 70 psi, bleed csg to 0 psi and shut in, monitor 15 min, SITP 0 psi, SICP 30 psi, after 45 min SITP -0- and SICP 30 psi, bleed tbg and csg to zero and check for flow at well head, had no ress and no flow. 01:00 01:30 0.50 RPCOI\ OTHR P RD circ line and install BPV. 01:30 02:00 0.50 WELCT COND P Blow down all circ lines and RD off tree, start raising MW in pits from 12.7 to 13.2 02:00 03:30 1.50 COMPZ WELCT NUND P ND tree and place outside cellar, FMC rep installed blanking plug and attempted to install retrieving tool, tool bottomed out on ESP penetrator and will not retrieve blanking plug, FMC rep removed blanking plug. Note Will need to set TWC to test BOPE & NORM tree and ck ok 03:30 09:45 6.25 P Installed 7 1/16" x 11" adaptor and NU 11" BOP stack and MU choke and kill lines, installed riser 09:45 14:30 4.75 COMPZ WELCT BOPE P MU 2 7/8" landing jt into hanger with BPV installed, Attempted to test BOP's, tested annular to 250 psi low and 2,500 psi and checked ok, attempted to test VBR's with 2 7/8" tbg and found slight leak out of hanger after trouble shooting and greasing choke manifold. decision was made to attempt to pull hanger to rig floor and install test plug. Hole remained static while attempting to test BOP's NOTE: John Crisp with AOGCC was on location 14:30 15:15 0.75 COMPZ WELCT EQRP T While attempting to back out landing jt, broke jt loose at coupling 4' above hanger, landing jt was made by Baker machine with 4' pup jt and coupling was not thread locked, drained stack and screwed back into landing jt, baked out lock down screws 15:15 16:30 1.25 COMPZ RPCOI\ OTHR P Picked up on tbg string attempting to pull hanger to surface, worked tbg up to 115K st wt up for 80% of 2718" tbg yield, includes 35K for block wt. with 115K up wt had 25" of stretch, PU to 125K 1 time and had 32" of stretch, cont to work pipe at 115K up wt with no add. movement, re-Ianded tbg in hanger, decision made to run e-line for free t and to cut tb 16:30 18:00 1.50 COMPZ WELCT OTHR T Attempted to back out landing jt a 2nd time and broke connection at coupling to 4' u Held PJSM with Schlumberger (SWS) then RU free pointlCCL logging tools, 1 318" OD x 15.5' Ion RIH with free ptlCCL logging tools to 6,740' WLM, no tag or fill, corr to cmp. tall POOH from 6,740' to 2,015' and ran free pt and set tool to 100% free, using 85K for st wt and a max pull of 115K up wt for 80% of 27/8" tbg including 35K block wt. cont. to see 24.5" of pipemovement, no change from initially workin i e on 618106 RIH with FP/CCL tool from 2,015' to 4,015', and had 50% free i e POOH with FPICCL tools from4,015' to 3,100', showed i e to be 82% free RIH from 3,100' to 3,530' and found pipe to be 60-70% free, POOH to 3,325' and found i e to be 82% free RIH with FP/CCL tool from 3,325' to 4,530' and found i e to be 52% free RIH with FP/CCL tool from 4,530' to 6,706', was notified by crew we had approx 20 bbl pit gain, with tool at 6,706' worked pipe up to 85K then to 115K and found tbg to have no movement and with tbg off hanger well was flowing, landed tbg and shut in wellleavin tools below GLM at 6,661' 0.50 6,706 6,706 COMPZ RPCOtl. OWFF T Hooked up circ lines in cellar to choke manifold and monitored well, SITP was 250 si, SICP 230 si. 23:00 00:00 1.00 T 06/09/2006 00:00 00:30 0.50 T 00:30 02 :45 2.25 T 02:45 04:30 1.75 0 6,740 T 04:30 05:15 0.75 6,740 2,015 T 05:15 06:30 1.25 2,015 4,015 COMPZ EVALVI. ELOG T 06:30 07:45 1.25 4,015 3,100 COMPZ EVALVI. ELOG T 07:45 08:30 0.75 3,100 3,325 EVALVI. ELOG T 08:30 09:30 1.00 3,325 4,530 EVALVI. ELOG T 09:30 10:30 1.00 4,530 6,706 EVALVI. ELOG T 10:30 11:00 Removed riser and ND BOP stack, lifted up on stack and backed out and removed 4' pup from hanger, NU stack and re-installed riser, changed to long bails on To Drive Did 3.500 psi shell test on BOP stack, pulled BPV, installed 2 7/8" 8 RD EUE landin 'oint Unseated and pulled BPV Held PJSM then began circ well with 13.2 ppg Potassium Formate mud, pumped at 4 bpm thru choke manifold, after pumping 90 bbls of mud (calc 50 bbls into annulus), shut choke and bullheaded 15 bbls of mud into formation, initial rate of 1/2 bpm, formation began taking fluid at 2,000 psi, pressure began to drop and slowly staged pump rate up to 1 bpm, ave circ pressure was 1660 psi tbg and 1530 psi csg, after 15 bbls opend choke back up and cont. to circ 13.2 mud around at 4 bpm, ave tbg pressure 2,350 psi tbg and 600 psi csg, at calc btms up 13.2 ppg mud was cut to 11.1 ppg, after btms up MW began to increase and after calc surf to surf MW out was 12.8 ppg, pumped a total of 353 bbls of 13.2 ppg mud, and after shutting down lost a total of 34 bbls, 15 bbls to bullheading, last approx 50 bbls weighted 13.1 ppg out with surf-surf volume of 250 bbls, shut down at 13:00 hrs. Ave MW in pits from circ out of hole was 12.7+ 13:00 14:00 1.00 6,706 0 14:00 20:45 6.75 0 0 COMPZ EVALv\ ELOG T Monitored well, SITP -0- psi, csg pressure 20 psi, POOH with FP/CCL 10 in tools from 6,706', LD same. T Shut in well and monitored pressures while raising MW in pits to 13.4 ppg, changed out top drive saver sub from 4" XT-39 to 31/2" IF, Pressures at 15:00 hrs, SITP 20 psi, SICP 60 psi" at 17:00 hrs SITP 100 psi, SICP 100 psi, final pressures at 20:30 hrs, SITP 90 si, SICP 80 si. COMPZ RPCO~ OWFF 22:30 00:00 1.50 0 o Held PJSM then began circ well with 13.4 ppg Potassium Formate mud, pumped at 4 bpm thru choke manifold, after pumping 90 bbls of mud (calc 50 bbls into annulus), shut choke and bullheaded 15 bbls of mud into formation, initial rate of 1/2 bpm, formation began taking fluid at 2,200 psi, ave circ pressure was 1980 psi tbg and 1730 psi csg, after 15 bbls opend choke back up and cont. to circ 13.4 mud around at 4 bpm, ave tbg pressure 2,350 psi tbg and 880 psi csg, at calc btms up 13.4 ppg mud was cut to 13.0 ppg, after btms up MW began to increase and after calc surf to surf MW out was 13.1 ppg, pumped a total of 300 bbls of 13.4 ppg mud, and after shutting down lost a total of 40 bbls, 15 bbls to bullheading, last approx 50 bbls weighted 13.0 to 13.1 ppg out with surf-surf volume of 250 bbls, shut down at 22:30 hrs. Ave MW in pits from circ out of hole was 13.0+ COMPZ RPCO~ OWFF T Shut in well and monitored pressures while raising MW in pits to 13.4 ppg, Pressures at 22:30 hrs, SITP 180 psi, SICP 180 psi, bled off press. at 23:00 hrs SITP 150 psi, SICP 150 psi, bled off and shut in, pressures at 00:00 hrs, SITP 10 psi, SICP 50 psi., bled off pressure at 00:45 hrs and well was static and as of 06:00 hrs 6/10/06 SITP -0- & SICP -0- COMPZ RPCO~ OWFF T Cont monitoring pressures while raising MW in pits to 13.4 ppg, Pressures at OO:OOhrs, SITP 10 psi, SICP 50 psi, bled off and at 00:30 hrs SITP 0 psi, SICP 10 psi, bled off at 00:45 hrs, well static. COMPZ EVALv\ RURD T RD circ line, MU 3 1/2" EUE lubricator, PJSM with SWS and MU string shot 1.69" OD x 30.5' and ack-off COMPZ EVALv\ ELOG T RIH with string shot on e-line to 6,715', fire string shot (6,715' to 6,730' coverage), POOH with SWS string shot & RD lubricator, monitoring well-static COMPZ EVALv\ RURD T Held PJSM, RU & MU SWS tbg chemical cutter, 2.125" x 34.5' long, including jars (10.1' F/shot to CCL), well-static 06/10/200600:00 00:45 0.75 0 o 00:45 03:00 2.25 0 o 03:00 06:00 3.00 0 o 06:00 08:45 2.75 0 o RIH with chemical cutter on e-line and placed on depth at 6,728' WLM, PU to 95K st wt, 10K over calc. and fired cutter, saw 10K drop in st wt after firin cutter, monitored well-static 11:00 14:30 3.50 6,728 6,728 T Began POOH with chemical cutter on e-line and while POOH at 2,400', slips on chemical cutter began hanging up on collars, worked tool with oil jars from 2,400' to 230', as we moved up hole became harder to get thru collars, POOH to 230', last collar took 10-15 min to work thru, attempted to release tool by circ down the tubing with 2,500 si with no movement 14:30 14:45 0.25 6,728 6,728 COMPZ RPCOI\ OTHR T RU & PU on 2 718" tbg, after PU 90K st wt pipe came free, PU 5' to ensure tbg was clear slacked off and re-Ianded tbg, dn wt was 60K, Est TOF @ 6,728' WLM, approx length of fish left in hole 95'. 14:45 16:15 1.50 6,728 6,728 COMPZ RPCOI\ CIRC T Circ 1 complete hole volume thru full open choke at 4 bpm at 1,650 psi, had full returns with no losses and mud wt out throu hout circ was 13.4 16:15 17:00 0.75 6,728 6,728 EVALv\ RURD T RD SWS scheave, clamped off e-line above ack-off and cut off same 17:00 17 :45 0.75 6,728 6,693 RPCOI\ OTHR T POOH with hanger to rig floor from 6,728' to 6,693', cut ESP cable, removed hanger and stripped e-line from landing jt and SWS pack-off, up wt 90-95K 17:45 19:30 1.75 6,693 6,484 COMPZ RPCOI\ TRIP T POOH from 6,693' stripping e-line out of hole to chemical cutter stuck in jt of tbg, POOH 7 jts of 2718" tbg with 1-GLM and 1- 8' pup jt, POOH to 6,484' (tool lodge between jnts 6 & 7, cut a 35' section of tbg and shipped to SWS shop for chem cutter removal, retrieved 4 clamps and 242' cable, up wt 90K 19:30 20:30 1.00 6,484 6,484 COMPZ WELCT BOPE P MU test plug and landing jnt, land lu ,NU choke line 20:30 00:00 3.50 6,484 6,484 COMPZ WELCT BOPE P Began testing BOP's, testing rams, valves and manifold to 250 low- 3,500 psi high, John Crisp with AOGCC waived witnessin of test 06/11/200600:00 03:00 3.00 6,484 6,484 COMPZ WELCT BOPE P Fin testing BOP's, tested rams, valves and manifold to 250 low- 3,500 psi high, tested both 2 7/8" and 3 1/2" test jts, Dart valve failed test, had one del'd to rig from Weatherford. well was static throughtout test. John Crisp with AOGCC waived witnessin of test 03:00 05:00 2.00 6,484 6,484 COMPZ RPCOI\ RURD P Rd testing equip, changed out elevator bales and ulled test lu Circ 1 complete hole volume from 6,484', staged pump rate up to 4 bpm at 1,430 psi with no losses and 13.4 mw throu hout circ 06:30 07:00 0.50 6,484 6,484 Held PJSM on RU ESP cable spool and POOH LD 2 7/8" completion, discussed hole fill and well control issues. Monitored well-static 07:00 08:00 1.00 6,484 6,358 P RU and POOH LD 4jts of 27/8" tbg from 6,484' to 6,358' then RU ESP sheave and strun ESP cable on s 001 08:00 20:00 12.00 6,358 800 P Cont to POOH LD 2 718" tbg, removing clamps, ESP cable and GLM's to 800', strapping tbg and kicking out of pipeshed while POOH, Note John Crisp was on rig for alarm & PVT testin 20:00 21:00 1.00 800 800 COMPZ RIGMN RGRP T Replace trip tank hose, Note, had a 2 bbl spill into secondary containment in the cellar from bad hose while filling tri tank. 21:00 23:00 2.00 800 0 COMPZ RPCOtl. PULD P Fin POOH from 800' and LD a total of 204 jts (6,601') of 27/8",6.5#, L-80, J-55 tbg with 1 cut off, 19.20' long, 5 GLM's, 5 pup jts, 108 LaSalle Clamps, 1 sentry gauge and clamps, Total recovered out of hole 6,695', Calc hole fill 20 bbls, Actual fill 32 bbls, sentry gauge and "I" wire was intact, ESP cable was sheared off 3' below sentry gauge, all 3 cable strands are cut off evenly, and tail end missing 3' of armour, 1 LaSalle clamp still on fish and approx 9' of ESP cable looking up with good even cut on tbg, NORM ED TBG & CK'D OK 23:00 00:00 1.00 0 0 P Strap tubing and unload pipeshed, secure ESP spool, clean floor and RD Centrilift e ui ment 06/12/2006 00:00 02:00 2.00 0 0 P RD tubing equip, RU DP equip, wrap cable and spool with absorb and shrink wra ,off-load drums of clam s 02:00 03:30 1.50 0 221 COMPZ FISH PULD T Load DC's and Baker Fishing tools in shed, PU and MU BHA #1 w/5 3/4" overshot and 2 718" ra Ie 03:30 04:30 1.00 221 221 RIGMN SVRG P Service Top Drive and Draw-works, reset tor ue for 3 1/2" IF connection 04:30 10:45 6.25 221 6,675 FISH TRIP T Cont RIH with Fishing BHA #1 PU 3 1/2" S135 DP from the pipe shed, drifted to 2.125", RIH from 221' to 6,675', calc pipe displacement 37 bbls, actual 36 bbls, st wt up no pump 127K, dn wt 93K Circ 1 1/2X btms up from 6,675' (approx 53' above TOF), circ hole at 84 spm, 4 bpm at 1,030 psi, rotated at 40 rpm's with 2,850 ft-Ibs torque, rot wt 100K, up wt 120K, dn wt 90K, 13.4 ppg MW in and out, took returns over shakers and saw several pieces of soft rubber abck with pieces of plastic coating possibly from the tubing. Circ thru crew change and held PJSM with crew on fishin o 's 12:15 13:30 1.25 6,675 6,721 COMPZ FISH FISH T RIH from 6,675' to 6,715' then washed down at 1 bpm at 410 psi and 10 rpm's, 2,900 ft-Ibs torque, tagged top of fish at 6,719' DPM, (tbg was cut at 6,728' WLM), worked over top of fish and after 2nd attempt saw 7-1 OK drag and 100 psi increase in the pump press., while working fish sat 50K down wt on fish with no movement down using bumper jars, while picking up cont to see 7-12K drag up, at one time we saw the pump pressure increase to 2,000 psi then dropped down to 520-600 psi, which was 100-200 psi increase in pump press from the original off btm press. Decision was made to POOH and look for recove 13:30 16:30 3.00 6,721 4,291 COMPZ FISH TRIP T Monitored well- well static, began POOH from 6,721', st up wt was 135K, up from 127K up wt with no pump, after pulling approx 100' saw st wt climb to 160K, slacked off 30' and PU and wt was back down to 137K, cont to POOH to 4,291', using DP displacement for 31/2" DP 15.5 #/ft hole was 1 bbl short on hole fill. 16:30 17:30 1.00 4,291 4,291 COMPZ FISH CIRC T Circ surf-surf at 4,291 due to being 1 bbl short on hole fill, circ at 71 spm, 3.3 bpm at 880 psi with no gas or change in mud wt, later found out that the DP in the hole was 13.3 #/ft and hole fill was accurate. 17:30 20:00 2.50 4,291 221 COMPZ FISH TRIP T Monitored well- well static, cont to POOH from 4,291' to BHA 221' 20:00 22:00 2.00 221 0 COMPZ FISH PULD T POOH from 221', LD Intensifier jars, stood back 2-stds 4 3/4" DC's, POOH with overshot and rec'd 12.60' of cut jt of 27/8" Tbg, "D" nipple, 4' pup jt with LaSalle clamp and 5.4' of 6' pup jt above pump, total rec'd 22.86' Est top of Fish @ 6,742'. Calc fill on trip out 38 bbls, Actual 37.8 bbls Clear floor, service Top Drive, unload pipeshed and re-Ioad wash shoe and extension, Started MU BHA #2 RIH to 33' 06/13/2006 00:00 01:00 1.00 34 229 PULD T Fin MU Fishing BHA #2 with 6" x 4 3/4" shoe to mill fishing neck on top of um and RIH to 229', 01:00 04:45 3.75 229 6,723 TRIP T RIH with BHA #2 from 229' to 6,723' 04:45 05:00 0.25 6,723 6,742 CIRC T Est circ at 5 bpm at 1,510 psi, 60 rpm's at 3,660 ft-Ibs of off btm torque, 103K rot wt, 115K up wt and 90K dn wt, washed down and tagged top of fish at 6,742' 05:00 13:30 8.50 6,742 6,749 MILL T Milled 4 3/4" fishing neck on ESP pump from 6,742' to 6,749', milled at 60-75 rpm's, 5-15K wt on mill, 104 spm, 200 gpm, 1,580 psi, afte milling 7', set down 30K wt down, PU and set down 40K with no movement, 13.4 ppg MW in & out. Removed ESP cable spool from rig floor and put Camco s 001 with control line on ri floor. 13:30 14:30 1.00 6,749 6,749 COMPZ FISH CIRC T Circ btms up after milling to 6,742', circ at 106 spm, 210 gpm at 1,400 psi, rot wt 103K, up wt 11 OK, dn wt 90K, 40 rpm's 2600 ft-Ibs torque, after circ btms up shut well in and attempted to est inj rate, pressured up to 2,500 psi and held for 2 min with no press loss, bled off and pressured up to 2,600 psi and held for 7 min and pressure bled down 30 psi, bled off pressure. Monitored well-static 14:30 18:00 3.50 6,749 229 FISH TRIP T POOH from 6,749' to BHA at 229' 18:00 19:00 1.00 229 0 FISH PULD T POOH from 229', LD Intensifier jars and stood back 2 stds 4 3/4" dc's and jars, POOH with 4 3/4" wash over shoe and found to have approx 6.5' of the upper ESP pump inside of the extension. im ellers & drive shaft 19:00 22:30 3.50 0 0 COMPZ FISH OTHR T Clear tools and fish off rig floor. Rack and tally 6 - 4-3/4" DC. Finish loading 3-1/2" tubing in shed. Strap and drift tubin . 22:30 23:00 0.50 0 0 COMPZ FISH PULD T Bring in fishing tools: washover shoe, wash pipe extensions, and boot baskets. Stra and cali er same. 23:00 00:00 1.00 0 230 COMPZ FISH PULD T PJSM. PU & MU 6-1/8" X 5" Washover Shoe + XO Bushing + 2 - 5-3/4" Wash Pipe Ext. + Drive Sub + 2 4-3/4" Boot Baskets + Bit Sub. MU to bumper sub, jars, and pump out sub. Start RIH with fishing BHA #3. Monitorin OA and ressure -0- RIH with Fishing BHA #3 from 230' to 6,740', est circ and washed down tagging up at 6,748', washed down and tagged TOF at 6,749', circ at 3 bpm at 740 psi, 80 rpm's, 3,680 ft-Ibs off btm torque, with pump, rot wt 105K, up wt 118K, dn wt 95K, without pump 127K u ,97K dn 06:45 12:00 5.25 6,749 6,831 COMPZ FISH MILL T Cont to Wash over ESP pump with 6 1/8" x 5" ID wash over shoe from 6,749', ran 10-15K w.o.mill, 80 rpm's, 4,600 ft-Ibs on btm torque, washed down to 6,758' then ESP pump began to wash down with no wt dn, washed down to 6,831' when fish stopped, adjusted flow rate from 100 to 200 gpm, while washing down, pressure ranged from 690 psi to 1,550 psi, when setting down wt pressure would increase to 2,000 psi, at 6,831' off btm torque was 3,400 ft-Ibs and on btm was 4,500 ft-Ibs, attended to go deeper and appeared to be spinning on fish. Washed down a total of 82' from 6,749' to 6,831', have 13' extension above shoe, set 25K wt dn with no pump and had no movement 12:00 13:15 1.25 6,831 6,831 COMPZ FISH CIRC T Circ 1 1/2 X btms up at 6,831', circ at 84 spm, 4 bpm at 1,780 psi, seeing small pieces of iron on magnets recovered approx 6-8 gals of shavings while washin down and circ 13:15 13:45 0.50 6,831 6,831 COMPZ FISH CIRC T Attempted to est an inj rate at 6,831', pressured up to 2,530 psi and held for 5 min, pressure bled down to 2,470 psi, bled down and re-pressured up to 2,540 psi and held another 5 min and bled off to 2,500 psi, bled off pressure. Set 50k wt down on to of fish. 13:45 20:00 6.25 6,831 0 COMPZ FISH TRIP T Monitored well- static, blew down top drive, st wt up 130K, POOH. Recovered rest of top section of pump and both lower pump sections. Top pump section wedged in washover shoe and wash i e extension. 23:00 00:00 1.00 0 165 COMPZ FISH PULD 06/15/2006 00:00 05:00 5.00 165 6,853 COMPZ FISH TRIP 05:00 19:30 14.50 6,853 6,869 COMPZ FISH MILL 19:30 21 :00 1.50 6,869 6,869 CIRC 21:00 00:00 3.00 6,869 275 TRIP T 06/16/2006 00:00 02:00 2.00 275 275 RIGMN SVRG P 02:00 04:30 2.50 275 0 PULD T Unbolt & LD lower 2 sections of ESP pump (18.40'), bottom end of housing corroded through. Break out wash over shoe, XO, and WP extension with remains of top ESP pump section (13.67') wedged inside - LD same. LD WP drive sub & upper WP extension. LD & clean out boot baskets - recovered about 2 gallons of metal and copper wire. Remove old fishing tools from rig floor and bring in new tools and one joint of 6" Washover pipe. Stra and cali er fishin tools. T MU FTA #4: 6-1/8" X 5" WO Shoe + 1 joint WO pipe + WP drive sub + XO + 2 boot baskets + BS + bumper sub + jars + pump out sub. RIH on first stand of DC. T Fin MU & RIH with Fishing BHA #4 from 165' to above TOF at 6,853', st up wt with no pump 130K, dn wt 95K, est circ at 63 spm, 3 bpm at 820 psi, 80 rpm's with 3,110 ft-Ibs off btm torque, rot wt 105K, up wt 120K, dn wt 93K washed down and tagged top of fish at 6,853'. T Cont to mill over ESP assembly, milled over top of tandem seal section from 6,853, to 6,865' (took 7 hrs before milling over seals, varied wt on mills from 10-35K, varied pump rates from dry drilling to 1-3 bpm, rpms frm 60 to 100, after breaking thru, milled over 12' to 6,865' in 45 min's, cont to mill on fish at 6,865', figure to be towards btm of seals or top of motor, cont to mill on fish at 6,865' and after several hrs was able to mill ahead ave 3/4-1 '/hr with 20K wt on mill, 100 rpm's, 3 bpm at 1 ,1 00 psi, milled over to 6869', no progress last 2 hours with weights up to 40K, d drillin, etc. T Circulate 2 bottoms up, 91 SPM, 4.3 BPM, 1300 psi. Shut-in and pressure up on DP and casing to 2500 psi, no injection rate, lost 40 psi in 5 minutes. Re eated with same result. POH to 275'. PJSM. Slip & cut 42' of drilling line. Service ri . POOH 2 stands DC. LD jars. LD drive sub, 1 joint WO pipe, and WO Shoe. Approx. 8" of shoe worn off. Clean out junk baskets, recovered about 1/2 gallon of metal. Called for hot shot for new ·ars. MU fishing BHA #5 RIH to 275', MU WO boot basket, 1 joint new wash pipe and new washover shoe. PU new jars. RIH with 2 stands DC then MU intensifier 'ars RIH to 275'. 06:30 10:30 4.00 275 6,869 TRIP T Held PJSM on RIH and using bleeder plug on DP while RIH. RIH from 275' and tagged top of Tandem Seal section at 6,853', st wt up no pump 130K, dn wt 95K, est circ at 63 spm, 3 bpm at 820 psi, 80 rpm's with 2,700 ft-Ibs off btm torque, rot wt 105K, up wt 120K, dn wt 100K, then washed down over seals at 8,653' and tagged up at 6,869' 10:30 18:00 7.50 6,869 6,869 COMPZ FISH MILL T Cont to mill over ESP assembly, milled from 6,869', varied wt on mill from 5-30K, varied pump rates from dry drilling to 1-4 bpm, 600-1300 psi, rpms from 60 to 100. Initially had a fair amount of torque at light mill weights, then torque smoothed out at various weights and pump rates. No progress beyond 6869'. 130K# PU, 95K# SO, 105K# Rot Wt. Torque on btm 5200- 5600 ft-Ib, Torque off btm 2700 - 3200 ft-Ib. 18:00 19:00 1.00 6,869 6,869 FISH CIRC T Circulate bottoms up, 4.5 BPM, 1400 si. 19:00 23:00 4.00 6,869 275 FISH TRIP T Monitor well, static. Blow down top drive. POH from 6,869' to BHA at 275'. 23:00 00:00 1.00 275 0 FISH PULD T LD intensifier jar. Stand back 2 stands DC. LD Shoe, WP extension, 1 jt of WP, boot baskets, and bit sub. About 3-1/2" gone from bottom of shoe, cut-off by junk in hole. Several deep cuts in WP. Recovered a shell of metal (approx. 5" X 9") wrapped around top of WP, just below boot basket, could be a piece of shoe from previous BHA, or a iece of ESP housin . 06/17/200600:00 01:00 1.00 0 0 COMPZ FISH PULD T Clean out boot baskets, recovered about 1/2 gallon of metal pieces, mostly from bottom junk basket. Clear old tools off floor and bring in new fishin tools. Stra and cali er same. 01:00 02:00 1.00 0 235 COMPZ FISH PULD T MU Fishing BHA #6: Overshot Bowl & Guide (5" Grapple) + XO Bushing + 10' WP Extension + boot basket + bumper sub, jars, and pump out sub. RIH on 2 stands DC. MU intensifier. 02:00 05:30 3.50 235 6,826 COMPZ FISH TRIP T RIH with Fishing BHA #6 to 6826'. PU single of DP. Circulate slow, 23 SPM, 1 BPM, rotate over top of fish at 6853'. Slide overshot over fish to 6855', pressure increased from 420 psi to 540 psi. PU second single of DP, push overshot down to 6857' with 30K# set down on fish. PU about 10' and appear to have fish, maintained the extra 120 si ressure. 06:30 10:00 3.50 6,857 235 COMPZ FISH TRIP T POOH from 6,857' to BHA at 235' 10:00 12:00 2.00 235 0 COMPZ FISH PULD T POOH from 235' LD intensifier jars, stood back 2 stds 4 3/4" DC's, POOH to overshot and rec'd 14.98' of Tandem Seal sections, had pump intake on top of seals with approx 3" of shaft below seals, LD fish and BHA, cleared rig floor 12:00 15:45 3.75 0 3,650 COMPZ RPCOf1. TRIP P RIH with 3 1/2" mule shoe and 3 1/2" DP to 3,605', MU Baker storm packer & RIH setting same at 45' with mule shoe at 3,650', st wt up 85K, dn wt 75K 15 :45 19:00 3.25 3,650 3,650 RPCOf1. NUND P Drain stack. PJSM. ND riser, choke, kill lines and BOP stack. 19:00 21:30 2.50 3,650 3,650 RPCOf1. NUND P ND 11" 3M X 7-1/16" 5M FMC Tubing Head. Lift off stack and head, 7" casing stub rose about 4" while removing head. Remove old packoffs. Set down on stub to be sure casing sli s were still full seated, OK. 21:30 00:00 2.50 3,650 3,650 COMPZ RPCOf1. NUND P Cut off 4" of 7 " casing stub. Dress stub. Install new packoffs on 7" and MU new FMC Gen 4,11" 3M X 7-1/16" 5M Tubing Head. Test seals to 2500 si for 15 minutes, OK. 06/18/2006 00:00 03:30 3.50 3,650 3,650 RPCOf1. NUND P Fin NU BOP stack, choke and kill lines and installed riser 03:30 07:30 4.00 3,650 3,650 WELCT BOPE P RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,500 psi, tested VBR's with 3 1/2". Note: John Spaulding with AOGCC waived witness in of test 07:30 08:00 0.50 3,650 3,650 COMPZ P Installed wear bushing 08:00 08 :45 0.75 3,650 3,605 COMPZ RPCOf1. PULD P MU storm packer retrieving tool and RIH to 45' latched onto same, checked for pressure and well was static, released acker and POOH LD same 08:45 10:00 1.25 3,605 0 COMPZ RPCOf1. TRIP P POOH with 35 stds of 31/2" DP and 2 stds of 4 3/4" Dc's, LD mule shoe 10:00 11:00 1.00 0 228 FISH PULD T MU BHA #7 with 6 1/8"-6 bladed junk mill, 3-boot baskets, jars 2-stds 4 3/4" Dc's and intensifiers, RIH to 228' RIH with BHA #7 from 228' to 6,807', st wt up no pump 130K, dn wt 97K, est circ at 127 spm, 6 bpm at 2,300 psi, 100 rpm's, off btm torque 4,000 ft-Ibs, rot wt 105K, up wt 11 OK, dn wt 103K, no rot up wt 118K, dn wt 95K, washed down and tagged top offish at 6,862', (Est TOF @ 6,868', last shoe depth 6,869' set 20K st wt dn. 14:00 18:00 4.00 6,862 6,862 COMPZ FISH MILL T Attempted to mill on fish at 6,862', worked wt on mills from 1 0-30K with 100 rpm's, after 1.5 hrs set 45K wt down on fish and pumped a 20 bbl hi vis sweep, with sweep out of mill, cent to work mill on fish, varied pump rates from dry drilling for 1 hr to 7 bpm at 2,900 psi, saw no increase in torque and saw no signs of junk from sweep, only a very few pieces of very fine metal , cont to work mill with no progress. Spudded down several times while milling with no change and set 55K dn prior to POOH with no change in tor ue or um ressure 18:00 21:30 3.50 6,862 0 COMPZ FISH TRIP T Blow dn top drive and POOH from 6,862' to 228'. LD intensifier. Stand back DC. POH, LD boot baskets and junk mill. Mill showed a wear pattern across full face. Also had wear at center that may be spinning on junk. Mill in good condition and few or no 'unk marks on strin above mill. 21:30 22:30 1.00 0 0 COMPZ FISH PULD T Clean out junk baskets, only a 1/4 cup of metal in baskets. Recovered a 1" X 4" piece of iron wedged in a water course just above face of junk mill. Mill also had black plastic imbedded in teeth. Clear tools off floor. Bring in new tools, stra & cali er same. 22:30 00:00 1.50 0 56 COMPZ FISH PULD T MU Fishing BHA #8: 6-1/8" x 5" Washover Shoe + XO Bushing + 10' WP Extension + XO + 3 boot baskets + BS + Bumper + Jars + Pump Out Sub. PJSM. Pre are to RIH. 06/19/2006 00:00 00:45 0.75 56 252 FISH PULD T Fin MU BHA #8 with 61/8" x 5" ID washover shoe RIH to 252' 00:45 04:30 3.75 252 6,869 FISH TRIP T RIH with BHA #8 from 252' and tagged up on fish at 6,869', (did not see previous tag with mill at 6,862') st wt up no pump 130K, dn wt 98K, est circ at 3 bpm, off btm pressure 740 psi, on btm 900 psi, 80 rpm's off btm torque 3,700 ft-Ibs, rot wt 109K, up wt 121 K, dn wt 97K Cont to mill on ESP motor from 6,869' with 10-15K wt on mill, 80-100 rpm's, varied pump rates from 1-3 bpm, milled 3' to 6,872' when pressure increased while circ and wasn unable to make anymore hole, possibly the fish tagging up inside WO shoe causing pressure increase and bottoming out not allowin us to mill on fish 10:30 11 :30 1.00 6,872 6,872 COMPZ FISH CIRC T Pumped a 20 bbl hi vis sweep and circ around fish, circ 2X btms up at 147 spm, 7 bpm at 2,700 psi and from sweep saw several pieces of wiring and clear plastic possibly from the ESP motor along with very fine pieces of metal 11:30 15:15 3.75 6,872 252 FISH TRIP T Blew down top drive and POOH from 6,872' to BHA at 252' 15:15 17:00 1.75 252 0 FISH PULD T POOH from 252', LD intensifiers, stood back 2 stds of 4 3/4" DC's, then POOH to shoe, found shoe to be worn approx 1" leaving approx 2" of cutright upinside shoe, water courses were worn but visible, LD shoe and cleaned out boot baskets, recovered approx 1/2 cup out of each basket, small ieces of metal and wire 17:00 18:00 1.00 0 229 COMPZ FISH PULD T MU BHA #9 with 5 7/8" Overshot with 5" grapple & RIH with boot basket, LBS jars, 2-std 4 3/4" dc's and Intensifiers RIH to 229' 18:00 21:15 3.25 229 6,870 COMPZ FISH TRIP T RIH with BHA #9 from 229' to 6853'. Rotate slow and wash down over fish at 22 SPM, 1 BPM. Caught top of fish at 6869', set down 10K# with guide to 6870', pressure increased from 420 psi to 600 psi. PU and pressure dropped to 420 psi. Set back down 30K#, pressure back up to 600 psi. PU, no overpull and no sign of grapple slipping, pressure dropped back to 420 si. 21 :15 00:00 2.75 6,870 2,940 COMPZ TRIP T Monitor well, static. POH from 6870' to 2940'. 06/20/2006 00:00 03:00 3.00 2,940 0 COMPZ TRIP T POH with fishing BHA #9 (5-7/8" Overshot with 5" ra Ie and fish. 03:00 04:00 1.00 0 0 COMPZ PULD T Break out and break down overshot to recover fish from same. Recovered top of motor housing/power cable plug-in with 1-5/16" I D shaft bushing/wire guard, l' overall. Top of piece showed bladed mill cut wear pattern. Expect to have 1-1/4" motor shaft stub looking up, based on bushing ID and Centrilift drawin s. 04:00 05:00 1.00 0 0 P PJSM. Slip & cut 42' of drilling line. Clear fishing tools off rig. tools. 05:30 06:30 1.00 0 0 P Service rig. 06:30 11:30 5.00 0 6,775 TRIP T MU fishing BHA #10 (5-7/8" Overshot w/1-1/4" ra Ie. RIH to 6775'. 11:30 12:00 0.50 6,775 6,775 CIRC T Circulate bottoms up, 160 SPM, 7.5 BPM,2900 si. 12:00 12:30 0.50 6,775 6,869 FISH T Rotate and circulate slow over top of fish. Tag fish at 6869', set down about l' to fully engage grapple, set 30K# down on fish, saw pressure increase. PU and appear to have fish. Pulled 30K to free shaft. Had 15k drag till shaft was above motor. 12:30 16:00 3.50 6,869 0 COMPZ FISH TRIP T POH with fishing BHA #10 (5-7/8" Overshot with 1-1/4" grapple). Recovered ESP motor shaft, 21.73' long, 1-1/4" OD for top 11", 1-3/8" OD for rest of shaft. Also recovered several lengths of 1/8" square keystock along length of shaft. Shaft pulled out of rotor, leaving rotor sections in hole, recovered entire shaft. 16:00 17:00 1.00 0 0 COMPZ FISH PULD T Break out overshot, cut off top 16" of shaft to remove same from grapple. LD rest of shaft on skate. 17:00 19:30 2.50 0 6,869 COMPZ TRIP T MU fishing BHA #11 (5-7/8" Overshot with 2-3/4" ra Ie. RIH. 19:30 20:00 0.50 6,869 6,869 COMPZ FISH T Rotate and circulate slow over top of fish. Tag fish at 6869', set 30K# down on fish and saw pressure increase each time. 20:00 23:30 3.50 6,869 0 COMPZ FISH TRIP T POH with fishing BHA #11 (5-718" Overshot with 2-3/4" grapple). LD overshot. No recove 23:30 00:00 0.50 0 40 COMPZ FISH PULD T PU & MU BHA #12 (6-1/8" Junk Mill + 3 boot baskets + BS + 6-1/8" stabilizer + bumper sub + jars + pump out sub . 06/21/200600:00 00:30 0.50 40 40 COMPZ RIGMN SVRG P Service crown. Prepare to RIH. 00:30 05:00 4.50 40 6,869 COMPZ TRIP T RIH with BHA #12 (6-118" Junk Mill). Ta TOF 6869'. 05:00 14:30 9.50 6,869 6,872 COMPZ MILL T Mill on remains of ESP motor from 6869' to 6872'. Milled with 2K#-3K# WOB, 100RPM, 3500-4200 ft-Ib Torque on btm, 104-114 SPM, 4.9-5.4 BPM, 1600-1750 psi, for -5 hrs of total. Varied WOB from 5K#-30K#, pump from 45-112 SPM, 2.1-5.3 BPM, 650-1800 psi. Dry drilled a total of-1 hr, 5K#-20K# WOB, 100 RPM. Last 1 hr, 125 RPM, 3K#-25K# WOB, 110 SPM, 5.3 BPM, 1800 psi, made a few inches. Attempt to inject into well, pressured u to 2500 si, no in·ection. 15:00 18:30 3.50 6,872 0 TRIP T POH with BHA #12. LD junk mill, boot baskets, stabilizer. Found 3 of 5 water courses on face of mill packed with what looks like waded up cable armor, copper, brass, & plastic. Teeth also packed with same. Cleaned off mill, estimate 10% wear, maximum. Cleaned out junk baskets, recovered about 2 cups of thin metal pieces, copper, wire strands, and metal cuttin s. 18:30 21:30 3.00 0 6,872 TRIP T MU BHA #13 (6-1/8" Reverse Circ Junk Basket + XO + 2 Boot Baskets + BS + bumper + jars + PO Sub). RIH 2 stands DC & MU accelerator. RIH. 21:30 22:00 0.50 6,872 6,872 COMPZ FISH CIRC T Break circulation and establish parameters. 20 RPM, 3500 ft-Ib Torque off bottom, 115K# PU, 90K# SO, 100K# Rot. Wt, 148 SPM, 7 BPM, 3100 psi, after 7/8" ball on seat in Reverse Circ Junk Basket. Tag bottom at 6872', circulating 7 BPM, 3100 psi, set down 15K# WOB, 20 RPM, 2500 ft-Ib Torque on bottom. Work DP & RCJB about 3' several times to PU 'unk from bottom. 22:00 00:00 2.00 6,872 2,367 FISH TRIP T POH with BHA #13, to 2367' at midni ht. 06/22/2006 00:00 02:00 2.00 2,367 0 FISH TRIP T POH w/ BHA #13. LD Reverse Circ Junk Basket, recovered only 2 small wafers of metal. Cleaned out boot baskets, recovered about 1 cup of metal, copper, and wire strands and some metal cuttin s. 02:00 05:30 3.50 0 6,872 TRIP T MU BHA #14: 6-1/8" MM Junk Mill (rerun from BHA #12) + 3 Boot Baskets + BS + bumper + jar + 6 DC + Accelerator. RIH. Break circulation, ta TOF 6872'. 05:30 06:30 1.00 6,872 6,872 CIRC T Wash & ream on bottom to stir up any loose junk & CBU, 104 SPM, 4.9 BPM,1550 si. 06:30 12:00 5.50 6,872 6,873 MILL T Mill on ESP motor from 6872' to 6873'. Started at 2K#-10K# WOB, 100 RPM, 4000 ft-Ib Torque, 85 SPM, 4 BPM, 1125 psi for first 1-1/2 hours. Then varied milling conditions 25K#-45K# WOB, 65K# Max WOB, 50-125 RPM, 2500-8500 ft-Ib Torque, 40-162 SPM, 1.9-7.7 BPM, 625-3050 psi. Also set weight on mill with no rotary, then brought up rotary. Very little to no chan e in ROP. Continue milling on ESP motor from 6873' to 6874'. Varied milling conditions: 2K#-20K# WOB, 5-15 RPM, 7000-9000 ft-Ib Torque, 51 SPM, 2.4 BPM, 700 psi; 1 OK#-20K# WOB, 50K# Max WOB, 50 RPM, 2500 ft-Ib Torque, 94 SPM, 4.4 BPM, 1425 psi; 40K#-45K# WOB, 100 RPM, 3500-4500 ft-Ib Torque, 51 SPM, 2.4 BPM, 725 psi; 10K#-40K# WOB, 100 RPM, 3500 ft-Ib Torque, 83 SPM, 3.9 BPM, 1250 psi. Very little to no chan e in ROP. 17:00 20:00 3.00 6,874 0 COMPZ FISH TRIP T POH wI BHA #14. LD Junk Mill. Clean out boot baskets. Face of mill had 3 of 5 water courses packed with wadded up thin metal, which looks like cable armor, as on previous run. Center of mill and teeth packed with debris, center shows sign of rotating on shaft hole in ESP motor rotor section, and wear across face. Mill still in good condition. Recovered about 1-1/4 gallon of metal cuttings and debris from ESP motor, iron, co er, brass, etc. 20:00 20:30 0.50 0 0 COMPZ FISH OTHR T Rack & tally 6 DC in pipe shed. Drift same. Bring in WO Shoe, extensions, and 'unk basket. 20:30 21:30 1.00 0 240 COMPZ FISH PULD T MU BHA #15: 6" X 4-3/4" MM WP Shoe + 10' WP Extension + XO Bushing + 5' WP Extension + WO Boot Basket drive sub + Dbl Pin XO + 2 Boot Baskets + BS + bumper + jars + PO sub. RIH PU 6 more 4-3/4" DC. 21:30 00:00 2.50 240 4,607 COMPZ FISH TRIP T PJSM on RIH using vent plug on stands. RIH 2 stands DC. MU Accelerator. RIH with BHA #15. 06/23/2006 00:00 01:30 1.50 4,607 6,800 FISH TRIP T RIH with BHA #15 to 6800'. 01:30 02:30 1.00 6,800 6,800 RIGMN SVRG P Slip & cut 42' of drilling line. Reset crown-o-matic. 02:30 03:00 0.50 6,800 6,800 RIGMN SVRG P Service rig. 03:00 12:00 9.00 6,834 6,879 FISH MILL T Wash down & tag TOF @ 6874'. Washover/Mill on ESP motor housing from 6874' to 6879'. 5K#-17K# WOB, 100 RPM, 4200-5000 ft-Ib Torque, 88 SPM, 4.1 BPM, 1250 psi. 128K# PU, 97K# SO, 110K# Rot wt. Continue Wash over/Mill from 6879' to 6884'. 15K#-25K# WOB, 100 RPM, 4400-5200 ft-Ib Torque, 88 SPM, 4.1 BPM, 1250-1500 psi. 128K# PU, 97K# SO, 11 OK# Rot wt. Pumped 15 Bbl sweeps with nut plug at 0830, 1200, and 1700 hrs. At 6883' to 6884', the ESP motor started pushing down hole. Pushed and milled down to 6891'. Pressure increase of -250 psi indicates WO shoe worn out about time junk started moving down. Set down up to 45K# while trying to push down hole. Worked pipe and got pressure increase to 2500 psi, and kept some pressure when picked up, appear to have have chunk of ESP motor tra ed in WO ass . 19:30 20:00 0.50 6,891 6,804 COMPZ FISH OTHR T Monitor well. Blow down top drive. Slow flow, gain 0.1 Bbl in trip tank in 15 minutes. 20:00 22:30 2.50 6,804 6,804 COMPZ FISH CIRC T Drop dart for pump out sub, MU top drive, pressure up and pump out sub opened at 2500 psi. Circulate 4 BPM, 1350 psi, 13.4+ ppg MW In, 13.3 ppg MW Out. Continue circulating 2 hole volumes while weighting up light mud, until 13.4+ In & Out. 22:30 23:00 0.50 6,804 6,705 COMPZ FISH OTHR T POH 1 stand to 6705'. Hole swabbing slightly. Pull another 30', swabbing increased. Set back down & MU top drive. 23:00 00:00 1.00 6,705 6,705 COMPZ FISH CIRC T Circulate 85 SPM, 4 BPM, 1330 psi. Had gas cut mud at bottoms up, 475 Units Max, down to 185 Units at midnight and decreasing. Mud still 13.4+ In & Out, no water or oil cut. 06/24/2006 00:00 01:00 1.00 6,705 6,705 COMPZ FISH CIRC T Continue circulating out gas cut mud, 85 SPM, 4 BPM, 1330 psi. Gas fell from 185 Units to 25 Units (Had 475 Units Max at bottoms up). No water or oil cut. 13.4+ In & Out. 01:00 01:30 0.50 6,705 6,705 FISH OTHR T Monitor well, slow flow. 01:30 09:00 7.50 6,705 6,705 FISH CIRC T 16:30 18:00 1.50 55 o COMPZ FISH PULD 18:00 18:30 0.50 0 50 COMPZ FISH PULD 18:30 19:00 0.50 50 50 RIGMN SVRG P 19:00 20:00 1.00 50 50 FISH WOEQ T 20:00 23:30 3.50 50 6,877 FISH TRIP T 23:30 00:00 0.50 6,877 6,891 FISH MILL T Monitor well. POH w/ BHA #15 (6" X 4-3/4" Washover Shoe & WP). Initially, hole not taking proper fill. Worked pipe, worked & rotated pipe, then added circulation at 6.4 BPM, 2600 psi. Closed bag and pressured up to 2250 psi, bled slowly to 1900 psi in 1-1/2 minutes. Bled off pressure, opened bag. Got hole to take some fill. Continue POH slow, -7 minutes /stand, to maintain proper hole fill, to 2500'. POH to 440', top of BHA, sped up gradually to -3 minutes/stand and maintained proper hole fill. LD Accelerator. POH 4 stands DC. T LD WO Shoe & WP Extensions. Caught 16.5' of ESP Motor & Rotor in WO shoe, milled stator down to 4-3/4". Clean boot baskets, recovered about 3 gallons of iron, brass, & copper cuttings. Remove old tools from rig & bring in new tools. Call for hot-shot of new pump out sub, unable to redress ins in one used. T MU BHA #16: 6" X 4-3/4" Washover Shoe + XO Bushing + 5' WP Extension + WP Boot Basket Drive Sub + XO + 2 Boot Bakets + 2 - 7" Casing Scrapers + BS + bumper sub + ·ars. Service top drive. Wait for delivery of fresh pump out sub. Remove fish from ri . MU pump out sub. RIH 4 stands DC. MU Accelerator. RIH with BHA #16. Tag up at 6877'. Break circulation, wash and ream down to TOF at 6891'. MiIIlWashover remnants of ESP motor at 6891'. 5K#-10K# WOB, 80 RPM, 4500 ft-Ib Torque, 106 SPM, 5 BPM, 1850 psi, 123K# PU, 93K# SO, 105K# Rot wt. Gas increased to 315 Units at midnight (peaked at 400 Units, then dro ed back . Washover/MiII on remnants of ESP Motor at 6891', broke loose and pushed down hole, hung up at 6948' and 6958'. Continue WO & push to 6971'. No progress last 3 hours. Circulated sweep with nut plug around at 6971'. 5K#-25K# WOB, 80-100 RPM, 4500-6500 ft-Ib Torque, 106 SPM, 5 BPM, 1850 psi. 123K# PU, 93K# SO, 105K# Rot Wt. After progress stopped at 6971', tried various combinations of weight, rotary, and pump: 25K#-65K# WOB, 60-100 RPM, 4500-8000 ft-Ib Torque, 3-6.5 BPM, 850-2500 si. T Blow down top drive. POH wI BHA #16. Left WP Extension + XO Bushing + WO Shoe in hole, box end on top of WP Extension broke off and came out on bottom of 5-3/4" Boot Basket Drive Sub, 9.25' left in hole. 4 stand-offs on boot of lower boot basket broken off, recovered 2 in boot. Also recovered a few pieces of iron and formation rocks. Boots on 4-3/4" boot baskets broken free from bottom weld. 7" scra ers OK. T Pull wear ring. Set test plug. PU wash tool and flush out BOP stack to remove an milled cuttin s. P Test BOPE: Blinds, Upper and Lower Pipe Rams, and Annular to 250 psi & 3000 psi; Choke Manifold valves, choke and kill lines, HCR to 250 psi & 3000 psi. Accumulator drawdown test, OK. TRack & tally 12 DC. Pull test plug. Set wear bush in . T MU BHA #17: Spear wI 5" grapple + Spear Extension + XO + 6-3/16" Stop Sub + Bumper + Jars + Pump Out Sub. RIH 4 stands DC. MU Accelerator. RIH to 6876'. T Circulate bottoms up, 106 SPM, 5 BPM, 2050 psi. Had a peak of 597 Units gas, fell to 25 Units. 123K# PU, 95K# SO with um . 09:30 13:30 4.00 6,971 0 COMPZ FISH TRIP 13:30 14:30 1.00 0 0 COMPZ FISH OTHR 14:30 17:30 3.00 0 0 COMPZ WELCT BOPE 17:30 18:00 0.50 0 0 COMPZ FISH OTHR 18:00 22:00 4.00 0 6,876 FISH TRIP 22:00 22:30 0.50 6,876 6,876 COMPZ FISH CIRC Wash down with spear at 63 SPM, 3 BPM, 870 psi. Saw some drag before spear got to fish, probably 6-3/16" Stop going thru perfs. Tagged fish and set down 30K#, to 6965'. Estimated TOF @ 6863', Saw a 30 psi increase as spear engaged fish. PU 35K# over & SO 30K# on fish. PU 30K# over, no movement, PU 45K# over and hold for light jar hit, PU 45K# over and fish moved up -7'. SO 30K# on fish, PU -16' and pulled 25K# over, then came free. 23:00 00:00 1.00 6,965 5,809 FISH TRIP T POH with BHA #17 (5" Spear), to 5809' at midni ht. 06/26/200600:00 04:30 4.50 5,809 0 FISH TRIP T POH wI BHA #17 (5" Spear). Recovered 4.53' of WP Extension, bottom rolled in from turning on junk, probably pin end snapped off in top of XO. WP XO Bushing & WO Shoe still in hole. Cut fish off grapple. Redress spear with new 5" grapple. LD spear extension. 04:30 08:30 4.00 0 6,965 COMPZ FISH TRIP T MU BHA #18: 5" Spear + XO + Stop Sub + bumper + jars + PO Sub. RIH 4 stands DC. MU Accelerator. RIH to 6965'. 08:30 09:00 0.50 6,965 6,968 COMPZ FISH FISH T PU single, MU top drive. Circulate at 63 SPM, 3 BPM, 900 psi. Wash down & tag fish at 6968'. Set 25K# down on fish, PU, had 8K# overpull, then pulled free. Increase pump rate to 106 SPM, 5 BPM, 2000 psi. Worked spear 3 more times, set down 35K#, 50K#, then 65K#. Saw 4K#-8K# overpull each time. 09:00 09:30 0.50 6,968 6,933 FISH CIRC T PU to 6933' and finish CBU, 106 SPM, 5 BPM, 2000 si. 09:30 13:30 4.00 6,933 0 FISH TRIP T POH wI BHA #18. No recovery. LD sear, XO, & sto sub. 13:30 14:30 1.00 0 400 FISH PULD T PU BHA #19: 6-1/8" MM Junk Mill (6 blades, flat bottom) + 2 Boot Baskets + BS + bumper + jars + Pump Out Sub. RIH PU 12 more DC. 14:30 17:00 2.50 400 6,965 FISH TRIP T RIH 4 stands DC. MU Accelerator. RIH. 17:00 00:00 7.00 6,965 6,984 FISH MILL T Tag junk at 6965'. Mill junk & remnants of ESP Motor from 6965' to 6984' & milling ahead. 10K#-15K# WOB, 100 RPM, 4000-5000 ft-Ib Torque, 129 SPM, 6.1 BPM, 2650 psi. 130K# PU, 98K# SO, 113K# Rot Wt. 06/27/2006 00:00 07:00 7.00 6,984 7,010 COMPZ FISH MILL T Cont milling from 6,984' to 7,010', 6 bpm at 2,740 psi, torque on btm 4,500 ftllbs, wob 15 to 30K, up wt 130K, dwn wt 98K, rot wt 113K. 06/27/2006 07:00 08:00 1.00 7,010 7,010 COMPZr FISH CIRC T CBU 1 1/2 x, 6 bpm. 08:00 08:30 0.50 7,010 5,535 COMPzr FISH TRIP T Blow dwn Top Drive and POOH from 7,010' to 5,535'. 08:30 11:30 3.00 5,535 5,535 COMPzr FISH TRIP T Troubleshoot top drive electrical problem. 11:30 15:00 3.50 5,535 0 COMPZr FISH TRIP T Cont POOH from 5,535', LD DC's and milling assembly. 15:00 21:30 6.50 0 0 COMPZr EVALv\ OTHR P RU Haliburton slickline and RIH with PDS 40-arm caliper to 6,953', POOH performing caliper log. Log indicates no siqnificant casing damaae. 21:30 00:00 2.50 0 3,379 COMPZI RPCOtl. PACK P PU and MU model "F" packer with 3 1/2" Baker wireline re-entry guide and 31/2" D nipple, pre-loaded with slickline retrievable CA-2 plug and junk catcher, RIH to 3,379'. 06/28/2006 00:00 01:30 1.50 3,379 6,796 COMPZr RPCOtl. PACK P Cont RIH with Baker Model F-1 prod packer, from 3,379' to 6,796', tail pipe at 6,840', up wt 120K, dwn wt 90K. 01:30 02:30 1.00 6,796 6,796 COMPZr RPCOtl. PACK P Drop ball, kelly up and pressure up to 2,000 psi, PU 20K over and release from packer. 02:30 03:30 1.00 6,796 6,763 COMPZr RPCOtl. DHEQ P LD single jnt, RU and test packer x 7" to 2,500 psi for 30 min, test OK, RD and blow dwn. 03:30 04:00 0.50 6,763 6,275 COMPZr R,PCOtl. PULD P POOH LD 15 jnts 3 1/2" DP to 6,275'. 04:00 06:30 2.50 6,275 6,275 COMPZr RIGMN SVRG P Slip and cut 42' drill line, service rig and Top Drive. 06:30 07:30 1.00 6,275 6,275 COMPZr RPCOtl. OTHR P Clear pipe shed and prep for LD 3 1/2" DP. 07:30 14:00 6.50 6,275 0 COMPZr RPCOtl. PULD P Cont POOH LD 3 1/2" DP, LD packer runninq tool. 14:00 14:30 0.50 0 0 COMPZr RPCOtl. OTHR P RU and pull wear ring. 14:30 15:30 1.00 0 0 COMPZr RPCOtl. RURD P RD DP handling equipment, RU tubing equipment. 15:30 00:00 8.50 0 6,796 COMPZr RPCOtl. RCST P PU RIH with 3 1/2" completion string, MU SSSV at 4,820', RIH with control line, space out, MU hanqer. 06/29/2006 00:00 01:00 1.00 6,796 6,796 COMPZr RPCOtl. OTHR P MU landing jnt, MU control line to hanqer, land hanqer, RILD's. 01:00 02:30 1.50 6,796 6,796 COMPZr RPCOtl. DHEQ P RU and test tubing to 2,500 psi for 15 min, bleed tubing to 1 ,500 psi and shut in, RU and test 3 1/2' x 7" at 2,500 psi for 30 min on chart, bleed tubing and sheared valve in lower GLM. 02:30 03:00 0.50 6,796 6,796 COMPZr RPCOtl. DHEQ P RU and test closed SSSV at 1,000 psi for 15 min. 03:00 06:00 3.00 6,796 6,796 COMPZr WELCT NUND P Blow dwn circ lines, RD test equip, set BPV, ND flow riser, mud cross and BOP stack. 06:00 10:00 4.00 6,796 6,796 COMPZr WELCT NUND P NU adaptor spool and tree, pull BPV, set test plug and test tree and pack-off at 5,000 psi. Open SSSV, RU and displace well to sea-water. 12:00 14:30 2.50 6,796 6,796 P RU Little Red and freeze protect well with 100 bbls diesel and U-tube. SITP 0 si, SICP 0 si. 14:30 15:00 0.50 6,796 6,796 P RU and install BPV. 15:00 00:00 9.00 6,796 6,796 P Secure well, clean cellar, blow dwn all circ and surface lines, clean all pits, prep rig and equipment for well to well move, Released ri at 24:00 hrs Re: BOP Configuration for 3M-14 Workover e e Subject: Re: BOP Configuration for 3M-14 Workover From: Thomas Maunder <tom_maunder@admin.state.ak.~ t % ~ - 05' Date: Thu, 08 Jun 200608:37:41 -0800 To: "Eller, J Gary" <J.Gary.ElIer@conocophillips.com> cc: "Gober, Howard" <Howard.Gober@conocophillips.com>, winton _ aubert@admin.state.ak.us, Nordic 3 Company Man <nI433@conocophillips.com> Gary, Good news about the VBRs. Based on the available surface pressure information as discussed previously, an API 3K stack arrangement is acceptable. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 6/612006 5:46 PM: Tom - Sundry 306-189 was recently approved for the workover of well 3M-14 at Kuparuk. We would like to modify the BOP configuration from what I submitted to you in that sundry application. It was my plan that we would run a 3-ram BOP stack since I thought that we did not have the option of running variable bore pipe rams. It turns out that variable-bore rams are available which will cover all planned tubing sizes. Therefore, we plan to run a 2-ram BOP stack with the variable-bore pipe rams on top and the blind rams underneath. Your letter of April 21, 2006 confirms that a 2-ram stack (i.e. 1 pipe ram and 1 blind ram) is acceptable for the workover of this well. Thanks and please contact me if you have any questions. J. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 ~jr:AÌ\.\i\lËf) ....\¡,:';.~ .....,õJ_~ ,,~ I ..L IL fax: 907-265-1535 1 of 1 6/8/2006 2: 19 PM . . 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Gary Eller Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 ~^NNSÐ ...;. '~~ ,l .j Re: Kuparuk River Field, Kuparuk River Oil Pool, 3M -14 Sundry Number: 306-189 š\ \~1~O Dear Mr. Eller: 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 ~y of June, 2006 Encl. t ift--DS-' . Conoc~illips . Gary Eller Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4172 May 24, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 3M-14 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk well 3M-14. We are planning to workover this well to pull and replace ,/ the tubing. If you have any questions regarding this matter, please contact me at 263-4172. ,~S.in~ly,.reIY' "" ~ >~,~ .~ J.~Elle~ Wells Engineer CPAI Drilling and Wells JGE/skad Of)\G¡\~'\¡~L r"\j' ~ t \Å ~ ()~fi/3//6STATEOFf!!sf1¥Þ ~/''>Ò ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA't 20 MC 25.280 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 187-051 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21726-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 63' 3M-14 8. Property Designation: 10. Field/Pool(s): ADL 25522, ALK 2558 Kuparuk River Field 1 Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7244' 6498' 6687' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 121' 121' SUR. CASING 3426' 9-5/8" 3489' PROD. CASING 7154' 7" 7217' 6475' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6940'-6942', 6944'-6945'. 6948'-6949', 6954'-6992' 6240'-6241',6243'-6244'.6247'-6247'.6252'-6284' 2-7/8" J-55 6752' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch 0 Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2006 Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL D Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263-4172 Printed Name Garv Eller Title: Wells Engineer Signature Phone 263-4172 Date Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 00'--/$'9 Plug Integrity D BOP Test .~ Mechanical Integrity Test D Location Clearance D Other: "5tJoO \>~ '\ "'" ~,:\ "'" \,) "" ~ C:J ~ \<t'> \- RBDMS BFL JUN 0 6 2006 U~MISS!9N_ER APPROVED BY Date: I..z ,{)6 Approved by: THE COMMISSION -- V' tj~ Ilj I !\J A L ~ í"2.f'.b~ Form 10-403 Revised 7/2005 S~Fl;~ · 3M-14 Workover Procedure. Major steps: 1. MIRU Nordic #3 rig. ? 3DOO~s, ~I\.'"^,-...:)"",, ~Ç> ~+ 2. Kill well. ND tree, NU and test BOP. ~?yV¡ 6V ~~ 3. Pull 2Ys"(;6mpletion. If tubing does not pull free, e-line cut will be required. 4. Rig will clean out the wellbore only if need to fish junk left over from the existing completion. 5. E-line run caliper log in 7", 26 ppf, J-55 casing. 6. E-line set permanent packer with plug in tailpipe. 7. Begin running 3W' completion. Set storm packer. 8. ND BOPE and tubing head. Replace leaking packofffor 9%" casing. NU tubing head and test packoff. 9. NU and test BOPE. Pull storm packer. 10. Finish running 3W' completion. 11. Space out and land completion. Pressure test tubing and IA. 12. ND BOP, NU and test tree. 13. RDMO workover rig. 14. Circulate out and recover heavy brine. 15. Slickline install GLVs. Pull plug in tailpipe of packer. 16. Coil tubing clean out fill to 7108' MD unless done so previously by rig. Gas Lift I ndrel/Oummy Valve 1 (102-103, 00:4.750) Gas Lift MandrelNalve 2 (2641-2642, TUBING (0-6752, 00:2.875, 10:2.441) PROO. CASING (0-7217, 00:7.000, Wt:26.OO) Gas Lift MandrelNalve 3 (3916-3917, Gas Lift MandrelNalve 4 (4415-4416, Gas Lift MandrelNalve 5 (6661-6662, NIP (6741-6743, 00:5.620) PUMP (6752-6788, 00:2.500) SEAL (6788-6803. 00:2.500) MOTOR (6803-6830, 002.500) Perf (6940-6942) Perf (6944-6945) Perf (6948-6949) Perf (6954-6992) ConocoPhillips Ala'a, Inc. 13M-14 -". or 01 D' D D Well Tvoe: PROD Orig 6/5/1987 Completion: Last W/O: 7/11/1998 Ref Loa Date: TO: 7244 ftKB Max Hole Angle: 36 deg @ 5800 API: 500292172600 SSSV Type: NONE Annular Fluid: Reference Loa: Last Tag: 6687 Last Tag Date: 1/28/2005 "'..:. - ALL \:) Description CONDUCTOR SUR. CASING PROD. CASING I UDma Strina - UOINl::I Size I Toe 2.875 I 0 Size 16.000 9.625 7.000 I Bottom I I 6752 I Zone Status A-2 A-2 A-2 A-1 . KRU 3VI-14 \ Anale @ TS: 32 dea @ 6930 Angle @ TD: 32 deg @ 7244 Rev Reason: TAG FILL Last UPdate: 2/7/2005 Grade H-40 J-55 J-55 Thread Top o o o Bottom 121 3489 7217 TVD 121 3390 6475 Wt 62.58 36.00 26.00 TVD I Wt I Grade I 6081 I 6.50 I J-55 Thread EUE-ABM Ft SPF Date Tvee Comment 2 1 8/16/1987 IPERF 4" CG, 120 deg. phasing 1 1 8/16/1987 IPERF 4" CG, 120 dea phasina 1 1 8/16/1998 IPERF 4" CG, 120 dea phasing 38 4 0/10/1::101 IPERF 4" CG: 120 dea phasina V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.0 BK 0.000 0 8/22/2001 GLV 1.0 BK 0.156 1300 8/2212001 GLV 1.0 BK 0.188 1354 8/22/2001 OV 1.0 BK 0.250 0 812212001 OPEN 1.0 BK 0.000 0 Interval TVD 6940 - 6942 6240 - 6241 6944 - 6945 6243 - 6244 6948 - 6949 6247 - 6247 6954 - 6992 Eì252 - 6284 I~âìlîft. St MD TVD Man Man Type V Mfr Mfr 1 102 102 Cameo KBMM CAMCO 2 2641 2635 Cameo KBMM CAMCO 3 3916 3741 Cameo KBMM CAMCO 4 4415 4154 Camco KBMM CAMCO 5 6661 6005 Camco KBMM CAMCO !~th$~DlIlaS,eaUlD;:$tc ;1.. . n:;;;W :iIQ-.y: Deeth TVD Tvee Descrietion ID 6741 6072 NIP CAMCO "0" NIPPLE NO GO 2.250 6752 6081 PUMP Centrilift 20 GCNPSH/36GC3500/82GC2900 Series 513 Triple Taper pump 0.000 w/bolt-on intake and discharge heads 6788 6112 SEAL Centrilift GST3 4B HL PFS Tandem Seal Section 0.000 6803 6124 MOTOR Centrilift 266 HP KMH 2345/69 Series 562 Motor w/motor lead extension 0.000 cable. Motor has a 6" centralizer threaded into base. fi.Jºtêš Date Note 7/11/1998 Tagged apx. 10' offill on top of CAT SV (àJ 6741' RKB. 8/31/2001 PACKERLESS COMPLETION: FLOW TO SURFACE WELL 12/30/200 WAIVERED WELL: T x A COMMUNICATION, PACKERLESS COMPLETION, FAILED ESP ~\() /1?,> V - -- I- - I- - I- - I-- - I- - I- - I- - I-- - I-- - I-- . Conoc;r;hillips API: 50-029-21726 AOGCC: 187-051 Lift thds: 3W' 8rd BPV: FMC ISA Wellhead: FMC Gen-IV Completion Jewelrv Tubing = 3W', 9.3 ppf, L-80, EUE 8rd Mod Camco TRMAXX-5E SCSSV at 2000' w/ 2.813" X-profile Locator sub at 6808' OD = 4.5" Baker F permanent pkr at 6810' with 4" SBE and millout ext. D-nipple at 6830' ID = 2.750" PD plug & catcher pre-installed Wireline re-entry guide at 6840' Directional: Max hole angle: 36° at 5800' Angle at top perf: 33° at 6940' Max doglegs: 5.2°/100' at 2350' 4.6°/100' at 3000' PROPOSED x J Coil tubing cleanout (post-rig) to 7108' TD = 7244' . Well: 3M-14 Field: Kuparuk Conductor: 16",62.58 ppf, H-40 at 121' Surface Casinq: 9%",36 ppf, J-55 at 3489' Gas Lift Mandrels MD 2816' 4238' 5325' 6110' 6662' TVD 2800' 4000' 4900' 5550' 600T Type MMG-dummy MMG-dummy MMG-dummy MMG-dummy MMG-DCR Perfs A-2: 6940' - 6942' (1 spf, 8/16/87) A-2: 6944' - 6945' (1 spf, 8/16/87) A-2: 6948' - 6949' (1 spf, 8/16/98) A-1: 6954' - 6992' (4 spf, 8/16/87) Surface Casinq: 7", 26 ppf, J-55 at 721T Last Updated: 20-Mar-06 Updated by: JGE . ConocoPhillips We1l3M-14 Workover Planned BOP Stack Flow Nipple I ------. 11" 5M Annular Preventer 11" 5M Double Ram Preventer . -----. []I[]]]QI0II]QI0II] ŒTID I~ 111" 5M Cross 11"5M Single Ram ~ Preventer I Pipe Ram I I Blind Ram I . I Flow Line I Choke I [II@IIJQI0II] Pipe Ram I 5/24/2006 e e FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 April 21, 2006 Mr. J. Gary Eller Wells Engineer ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 1 ~ 2005 Re: Kuparuk River Unit ("KRU") 3M-14 (187-051) Waiver to 20 AAC 25.285(c)(2)(B)(i) Dear Mr. Eller: ConocoPhillips Alaska ("CPA") requested by letter dated April 10, 2006 a waiver of 20 AAC 25.285(c)(2)(B)(i) which requires 2 sets of pipe rams fitting the size of tubular in use. The Alaska Oil and Gas Conservation Commission has reviewed your request and finds that no waiver is necessary. When conducting work with the tree removed, regulation 20 AAC 25.285 (b) requires "That the rated working pressure of the BOPE ... exceed the maximum potential surface pressure to which it may be subjected." KRU 3M-14 has a non-operable ESP and produces some 1400 barrels of fluid per day with an 83% water-cut via gas lift. According to the information you have provided, the actual surface pressure when the well is shut-in is about 1600 psi. With the mixed production fluid column, this should represent the worst-case surface pressure the well is capable of developing. Since this pressure value allows the rated working pressure of BOPE to be less than API 5K, we believe that 20 AAC 285 (c)(2)(A)(i) requiring 1 set of pipe rams applies rather than 285 (c)(2)(B)(i). questions on this matter, please contact Tom Maunder, PE at QJ~ Daniel T. Seamount, Jr. Commissioner e e ~ ConocoPhillips Alaska K 1 JL '.. "'. Con..s Commiss\ûí\ :\ !J\as .. Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 10, 2006 Tom Maunder Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 RE: Variance Request for BOP Configuration, We1l3M-14 Dear Mr. Maunder: ConocoPhillips is preparing to perform a workover on we1l3M-14, Kuparuk River Unit, in order to complete the well as a gas lifted producer with tubing and packer. Attached is an existing and proposed wellbore schematic for we1l3M-14. This workover is expected to begin in the summer 2006. In performing this workover, ConocoPhillips requests a variance from the requirements of20 AAC 25.285(c)(2)(B)(i), which state the following: (B) for an operation requiring a BOP stack equal to or greater than API 5K, at least four preventers, including (i) two equipped with pipe rams that fit the size of the drill pipe, tubing, or casing being used, except that pipe rams need not be sized to BHAs and drill collars; At the start of the workover, ConocoPhillips will use a BOP stack with two sets of pipe rams for 2~" tubing. ConocoPhillips plans to run 3 W' tubing after the 2~" tubing is pulled, and a variance is requested to run a single set of3Y2" pipe rams for this portion of the workover. This is a reasonable request given the following: · Although gas gradient calculations show a maximum potential surface pressure exceeding 3000 psi, the production and history ofwe113M-14 shows that the actual shut-in pressure is closer to 1600 psi. We1l3M-14 produces 1400 bfpd with 83% water and a GLR of 113 scf/bbl, so it is extremely unlikely that it could ever achieve a surface pressure exceeding 3000 psi. · Two sets of 2~" pipe rams will be used at the start of the workover when the risk of a well control event is the greatest. · There is no simple, cost effective means of adding a second set of 3W' pipe rams to the BOP stack. Variable bore pipe rams are not made for the Hydril11", API 5000 psi BOP stack that is planned for this workover. . e e Mr. Tom Maunder Variance Request for BOP Configuration, We1l3M-14 April 10, 2006 . ConocoPhillips' internal well control policies allow the use of a single set of pipe rams for a work over when the maximum expected surface pressure is less than 3000 psi, such as exists with we1l3M-14. Please contact me at 907-263-4172 if you have any questions. Page 2 of2 . e . ConocJPhi II ips API: 50-029-21726 AOGCC: 187-051 Lift thds: 3W' 8rd BPV: FMC ISA Wellhead: FMC Gen-IV Completion Jewelry Tubing = 3W', 9.3 ppf, L-80, EUE 8rd Mod Camco TRMAXX-5E SCSSV at 2000' w/ 2.813" X-profile Locator sub at 6808' 00 = 4.5" Baker F permanent pkr at 6810' with 4" SBE and millout ext. D-nipple at 6830' 10 = 2.750" PO plug & catcher pre-installed Wireline re-entry guide at 6840' Directional: Max hole angle: 36° at 5800' Angle at top perf: 33° at 6940' Max doglegs: 5.2°/100' at 2350' 4.6°/100' at 3000' PROPOSED x Coil tubing cleanout (post-rig) to 7108' TO = 7244' e Well: 3M-14 Field: Kuparuk Conductor: 16",62.58 ppf, H-40 at 121' Surface Casinq: 9%", 36 ppf, J-55 at 3489' Gas Lift Mandrels MD 2816' 4238' 5325' 6110' 6662' ., , TVD 2800' 4000' 4900' 5550' 6001' Type MMG-dummy MMG-dummy MMG-dummy MMG-dummy MMG-DCR Perfs A-2: 6940' - 6942' (1 spf, 8/16/87) A-2: 6944' - 6945' (1 spf, 8/16/87) A-2: 6948' - 6949' (1 spf, 8/16/98) A-1: 6954' - 6992' (4 spf, 8/16/87) Surface Casinq: 7", 26 ppf, J-55 at 7211' Last Updated: 20-Mar-06 Updated by: JGE r e e ....<t{ . ~ -'" ConocoPhillipsAlaska, Inc.. KRU 3M-14 3M~14 ....... ....... D API: 500292172600 Well Tvne: PROD Anale !âJ TS: 32 dea (ã) 6930 Gas Lift SSSV Type: NONE Orig 6/5/1987 Angle @ TD: 32 deg @ 7244 mdrel/Oummy Comoletion: Valve 1 (102-103, Annular Fluid: Last W/O: 7/11/1998 Rev Reason: TAG FILL 00:4.750) Reference Loa: Ref Loa Date: Last Uodate: 2/7/2005 Last Taa: 6687 TD: 7244 ftKB U Last Taa Date: 1/28/2005 Max Hole Anale: 36 dea !âJ 5800 Gas Lift CasinaStrina-ALL MandrelNalve 2 DescriDtion Size Too Bottom TVD Wt Grade Thread (2641-2642, CONDUCTOR 16.000 0 121 121 62.58 H-40 TUBING SUR. CASING 9.625 0 3489 3390 36.00 J-55 (0-6752, PROD. CASING 7.000 0 7217 6475 26.00 J-55 00:2.875. 10:2.441 ) l.uPlmrStrinC/" PROO. Size I Too I Bottom I TVD I Wt I Grade T Thread CASING 2.875 I 0 I 6752 I 6081 I 6.50 I J-55 T EUE-ABM (0-7217, 00:7.000, WI Perforations Summa", .... Wt:26.00) Interval TVD Zone Status Ft SPF Date TVDe Comment Gas Lift MandrelNalve 6940 - 6942 6240 - 6241 A-2 2 1 8/16/1987 IPERF 4" CG, 120 dea. Dhasina 3 6944 - 6945 6243 - 6244 A-2 1 1 8/16/1987 IPERF 4" CG, 120 deg ohasina (3916-3917, 6948 - 6949 6247 - 6247 A-2 1 1 8/16/1998 IPERF 4" CG 120 deg phasing 6954 - 6992 6252 - 6284 A-1 38 4 8/16/1987 IPERF 4" CG; 120 dea phasina Ga lift St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 102 102 Cameo KBMM CAMCO DMY 1.0 BK 0.000 0 8/22/2001 . 2 2641 2635 Cameo KBMM CAMCO GLV 1.0 BK 0.156 1300 8/22/2001 Gas Lift 3 3916 3741 Cameo KBMM CAMCO GLV 1.0 BK 0.188 1354 8/22/2001 MandrelNalve 4 4415 4154 Cameo KBMM CAMCO OV 1.0 BK 0.250 0 8/22/2001 4 5 6661 6005 Cameo KBMM CAMCO OPEN 1.0 BK 0.000 0 8/22/2001 (4415-4416, Other rDluas eauiD.,etd - JEWELRY Depth TVD TVDe DescrTDtion ID 6741 6072 NIP CAMCO "D" NIPPLE NO GO 2.250 6752 6081 PUMP Centrilift 20 GCNPSH/36GC3500/82GC2900 Series 513 Triple Taper pump 0.000 w/bolt-on intake and discharae heads 6788 6112 SEAL Centrilift GST3 4B HL PFS Tandem Seal Section 0.000 6803 6124 MOTOR Centrilift 266 HP KMH 2345/69 Series 562 Motor w/motor lead extension 0.000 Gas Lift . cable. Motor has a 6" threaded into base. MandrelNalve Notes· 5 Date Note (6661-<3662, 7/11/1998 Taaaed aox. 10'offill on too of CAT SV!âJ 6741' RKB. 8/31/2001 PACKERLESS COMPLETION: FLOW TO SURFACE WELL 2/30/200 WAIVERED WELL: T x A COMMUNICATION, PACKERLESS COMPLETION, FAILED ESP NIP (6741-<3743, 00:5.620) PUMP (6752-6788, 00:2.500) SEAL , (6788-6803, 00:2.500) MOTOR (6803-<3830. 00:2.500) I-- Perf (6940-<3942) - I- - I- - I-- Perf (6944-<3945) - I-- - I- Perf (6948-<3949) - I- - I-- Perf (6954-<3992) - I-- - I- - I-- ) ~", iRLJ] :r.:;-;:J" ' t,~ [! \, ,', I: \ ¡ I, i I.~...J 'j I¡::--~ ?, i,P I: :!PE" u~ i"7=:1 . 'I ¡¡? : II ,~""j ,il-,','I ' , I ' . II ! ~I..:;j 'na, ' -"",:' t'_Wo, ~¡III, '/,'ii, \, !, \ : ß 1\ i I, ':, ~ ;".-, "~ .\J...ij IW / ,/ I ; J I / FRANK H. MURKOW5KI, GOVERNOR AlASKA. OIL AM) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brad Gatham Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~~I G" ,/' l}-' \-0 / Re: Kuparuk 3M-14 Sundry Number: 305-295 ~^NNEÛ NO" 0 [) 20'05 Dear Mr. Gatham: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. -- Sincerely, DATED this~~ of October, 2005 Enc!. Cf}" {O.//7/--,OŠ STATE OF ALASKA /YíS ~((?-I S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 1. Type of Request: Abandon 8. Property Designation: Kuparuk River Unit Signature ) o o o Suspend 0 o o REGÊW~Q SE,tfó'2~;5 Alaska Oil & Gas C Lln h ons. COmmis~iOj Waiver Ot: urageOther 0 Time Extension 0 Re-enter Suspended Well 0 Perforate 0 D Stimulate 4. Current Well Class: Development 0 Stratigraphic 0 5. Permit to Drill Number: 187-051 6. API Number: 50-029-21726-00 9. Well Name and Number: 3M-14 Exploratory 0 Service 0 Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 63' Repair well Pull Tubing Immediately Date: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7244' 6498' Casing Length Size CONDUCTOR 121' 16" SUR. CASING 3426' 9-5/8" PROD. CASING 7154' 7" Perforation Depth MD (ft): 6940'-6942', 6944'·6945', 6948'-6949', 6954'·6992' Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Brad Gathman ?r1~ Perforation Depth TVD (ft): 6240'-6241',6243'-6244',6247'-6247',6252'-6284' Packers and SSSV MD (ft) no packer no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ D 121' 3489' 7217' Tubing Size: 2-7/8" Contact: Title: Phone 659-7224 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test D Mechanical Integrity Test 0 Location Clearance 0 Burst Collapse Tubing Grade: J-55 Tubing MD (ft): 6752' Service D Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Brad Gathman, 659-7224 Problem Wells Supervisor Date 'r z..~r' o$' Sundry Number: 303-282 '3 D 'S:-- r9-C(S- Other ~c¿C~~~ \ \<ë\\e..,- ~~ ~R.\~~ lCJ{¡-a., ~\O ~~ "<Lf'..~ u \- '-\-\'<ê &eÇ>e:s..'\- C:, LM . RBDMS BFl OCT 1 3 2005 Form 10-403 Revised 7/2005 " n D L C APPROVED BY t9~sfltj+N A L THE COMMISSION Date: l(r{ø( Submit in Duplicate ) ,) ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk We1l3M-14 (PTD 1870510) September 28, 2005 This application is for an extension of Sundry 303-282 for well3M-14 (PTD 1870510) and to document that the AOGCC and ConocoPhillips concur the well maybe produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. We1l3M-14 was originally completed in June 1987 as a gas lifted producer. The well was re- completed with an ESP in July 1998. The well produced via ESP until August 2001, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well has the capability to flow without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completion will be for standard gaslift with tubing and a packer. A casing inspection log will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gas lift mandrel at 6661' measured depth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 2641', 3916' and 4415' to keep annular fluids to the lowest possib Ie depth. The well is equipped with a wellhead Safety Valve System as per regulations. As per this request, ConocoPhillips intends to produce 3M-14 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ) . ·COn()C~~hÎlli~~··~·laSka,·t~C. .' : .::~ 3M~14 - API: 500292172600 andre"~~~~r f' 1;;;:;:::,11' SSSV Type: NONE (102-103, I .. Annular Fluid: 00:4.750):: Reference Log: ~ Last Tag: 6687 ~ Last Tag Date: 1/28/2005 Casinq String ~ ALL STRINGS Description Size I CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 Tubing String.. TUBING Size I Top I 2.875 0 Perforations Summary Interval TVD 6940 - 6942 6240 - 6241 6944 - 6945 6243 .. 6244 6948 - 6949 6247 - 6247 6954 - 6992 6252 - 6284 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 1 102 102 Cameo KBMM CAMCO 2 2641 2635 Cameo KBMM CAMCO 3 3916 3741 Cameo KBMM CAMCO 4 4415 4154 Cameo KBMM CAMCO 5 6661 6005 Cameo KBMM CAMCO 'Other (plugs, equip., etc.) .. JEWELRY Depth TVD Type 6741 6072 NIP 6752 6081 PUMP Gas Lift MandrelNalve 2 (2641-2642, TUBING (0-6752, 00:2.875, 10:2.441) PROO, CASING (0-7217, 00:7.000, Wt:26.00) Gas Lift MandrelNalve 3 (3916-3917, 11'::::::::;'1:::::" ..II~ " " ~I":':' J:1¡1I:::"; :.;.:.;"'...... ......,.. ..'....~ ::::::::..:::::1 Gas Lift MandrelNalve 4 (4415-4416, II~.::::::::'I:::::·· :~¡¡¡r:" ~.. ¡iiii!:.,::i " Gas Lift MandrelNalve 5 (6661-6662, 11,' ..d ": ~ ' .::' :1 NIP (6741-6743, 00:5.620) PUMP (6752-6788, 00:2.500) SEAL (6788-6803, 00:2.500) MOTOR (6803-6830, 00:2.500) Perf (6940-6942) Perf (6944-6945) ---.:~ Perf (6948-6949) 1 =t =I_ Perf (6954-6992) ) KRU 3M-14 Well Type: PROD Orig 6/5/1987 Completion: Last W/O: 7/11/1998 Ref Log Date: TD: 7244 ftKB Max Hole Angle: 36 deg @ 5800 CAMCO "D" NIPPLE NO GO Centrilift20 GCNPSH/36GC3500/82GC2900 Series 513 Triple Taper pump w/bolt-on intake and discharge heads Centrilift GST3 4B HL PFS Tandem Seal Section Centrilift 266 HP KMH 2345/69 Series 562 Motor w/motor lead extension cable. Motor has a 6" centralizer threaded into base. Bottom 6752 Zone A-2 A-2 A-2 A-1 6788 6803 6112 6124 SEAL MOTOR Angle @ TS: 32 deg @ 6930 Angle @ TD: 32 deg @ 7244 Rev Reason: TAG FILL Last Update: 2/7/2005 Top o o o Bottom TVD Wt Grade Thread 121 121 62.58 H-40 3489 3390 36.00 J-55 7217 6475 26.00 J-55 TVD Wt Grade Thread 6081 6.50 J-55 EUE-ABM Ft SPF Date Type Comment 2 1 8/16/1987 IPERF 4" CG, 120 deg. phasing 1 1 8/16/1987 IPERF 4" CG, 120 deg phasing 1 1 8/16/1998 IPERF 4" CG, 120 deg phasing 38 4 8/16/1987 IPERF 4" CG; 120 deg phasing Status V Type VOD Latch DMY 1.0 BK GLV 1.0 BK GLV 1.0 BK OV 1.0 BK OPEN 1.0 BK Description Port TRO Date Vlv Run Cmnt 0.000 0 8/22/2001 0.156 1300 8/22/2001 0.188 1354 8/22/2001 0.250 0 8/22/2001 0.000 0 8/22/2001 ID 2.250 0.000 0.000 0.000 Gen~rålNåtes :. Date Note 7/11/1998 Tagged apx. 10' of fill on top of CAT SV @ 6741' RKB. 8/31/2001 PACKER LESS COMPLETION: FLOW TO SURFACE WELL 12/30/2003 WAIVERED WELL: T x A COMMUNICATION, PACKERLESS COMPLETION, FAILED ESP Re: Failed ESP sundries Subject: Re: Failed ESP sundries Date: Mon, 10 Nov 2003 11:29:27 -0900 From: Tom Maunder <tom_maunder@adm in.state.ak.us> To: Jerry C Dethlefs <Jerry. C.Dethlefs@conocophillips.com> CC: NSK Problem Well Supv <N1617@conocophillips.com> Jerry, MJ and Nina: Sorry about the confusion on those wells. I went back and checked your applications as well and you are correct. I also noted in the letter that 3H-16 is mentioned at point 1 in the text, but not in the well list. I have made an edit of the original letter and can fax that to you for your files. The plans as stated in the sundry applications are appropriate for the wells. I think this is the easiest way to fix this. Thanks for reading closely. I need to improve. Tom Maunder, PE AOGCC Jerry C Dethlefs wrote: Tom: I reviewed the cover letter again as compared to the submitted Sundry Notices. As MJ mentioned below, we could re-submit the Sundry's for_3B-14_ and 3M-14 for correction. Alternatively, you could just correct the details on your cover letter and send that to us. We are going to attach the cover letter to each Sundry for our files and there is more detail in that than on the 10-403. Your choice, just let us know how we can help fix the discrepancy. This is just to prevent confusion in the future-- Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska ..... Forwarded by Jerry C Dethlefs/PPCO on 10/26/2003 02:40 PM ..... NSK Problem Well Supv 10/24/2003 08:40 AM To: tom_maunder@admin.state, ak. us cc: n1617@conocophillips, com@Phillips, Jerry C Dethlefs/PPCO@Phillips Subject: Re: Failed ESP sundries Tom: While reviewing the signed 10-403's on 3B-14 (Sundry # 303-278) and 3M-14 (Sundry # 603-282), we noticed that the Commissioners comments and attached documentation appear to be miss matched. 3M-14 has a failed ESP and is currently gas lifted and 3B-14 currently has a functioning ESP, while the Commissioners comments on the 10-403's and accompanied documentation have them vise versa. Please review your copy of the Sundries and let us know how you would prefer we fix the discrepancy. We can re submitted the 10-403's if you would like. Thanks MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. 1 of 3 11/10/2003 11:29 AM ALASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVEF~NOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Wells Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 \\{ I0 Re: KRU Kuparuk PoOl. Wells Equipped with Electric Submersible Pumps (ESPs) KRU 2C 09 184-221 303-274 ESP KRU 2C 16 184-202 303-275 ESP KRU 3B 13 185-023 303-276 ESP KRU 3A 01 185-186 303-277 ESP KRU 3B 14 185-024 303-278 ESP KRU 3H 04 187-076 303-279 ESP KRU 3J 10 185-250 303-280 ESP KRU 3M 13 187-040 303-281 ESP ~ KRU 3M 14 187-051 303-282 ESP Dear Mr. Dethlefs: failed flowing well failed flowing well failed gas lifted well failed ~ ql qrv gas lifted well operating failed gas lifted well failed gas lifted well You recently submitted Sundry Notices (Form 403) for the above nine (9) wells. Each sundry requested an exception to Commission regulation 20 AAC 25.200(d) where wells capable of unassisted flow are required to be equipped with tubing and a packer. It has been determined from examination of Commission records that the installation of ESPs in the wells was approved either by a Commission letter to ARCO Alaska (dated November 11, 1996) or individual sundry notices for some of the wells. No further exception is necessary. As shown in the table listing, two (2) of the pumped wells have operating pumps, five (5) of the wells have failed pumps and are being gas lifted and two (2) of the failed pump wells are flowing. After examination of the sundry applications and the Commission well files, we have determined the following actions with regard to those Kuparuk Pool wells equipped with ESPs: 1. Until the ESPs fail, 3H-04 and 3,1~1~ should be allowed to continue production with no restrictions. 2. The sundries for wells 3M-14, 3M-13, 3J-10, 3A-01 and 3B-13 are approved for a 2-year period. Production entry into the tubing should remain at the deepest mandrel as presently configui'~l. 3. In order to remain in production, the tubing entry configuration of wells 2C-09 and 2C-16 should be changed to be similar to the other failed ESP wells with the fluid entry <~,fJaNNE[. 0ui I ~ 20~3 Jerry Dethlefs Problem Wells Supervisor October 2, 2003 Page 2 of 2 nominally at the deepest gas lift mandrel. With the fluid entry changed, the sundries are approved for 2 years. 4. You should submit form 404 to document the completion of the work on 2C-09 and 2C- 16. Please contact Tom Maunder at 793-1250 with any questions. Sincerely, Randy Ruedrich Commissioner ConocOphillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 14, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Encl. osed please find 1.0-403 Sundry Notices regarding an exemption from 20 AAC 25.200 (d) for Kuparuk producing wells that do not have an isolation packer. The purpose of these requests is to document AOGCC approval to continue production from these wells as agreed in the meeting between the AOGCC and ConocoPhillips on July 15, 2003. Please call Nina Woods, MJ Loveland or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Problem. Well Supervisor ConocoPhillips Alaska Attachments ORIGINAL ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon [~ Alter casing [~ Change approved program ~--] Suspend [~ Operation Shutdown [] Perforate Repair well E~ Plug Perforations ~] Stimulate Pull Tubing ~ Perforate New Pool [~ r--] Variance [-~ E~] Time Extension [~ Re-enter Suspended Well E~ Annular Disp. E] Other E~] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 4. Current Well Class: Development__[] Exploratory E~ Stratigraphic ['-] Service E~] 5. Permit to Drill Number: 187-051 6. APl Number: 50-029-21726-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 63' 3M-14 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): 7244' Total Depth TVD (ft): 6498' Effective Depth MD (ft): 7217' Casing Length Size CONDUCTOR 121' 16" SU R. CAS I NG 3426' 9-5/8" PROD. CASING 7154' 7" Perforation Depth MD (ft): 6940'-6942', 6944'-6945', 6948'-6949', 6954'-6992' Packers and SSSV Type: no packer no SSSV Effective Depth TVD (ft): 6475' MD 121' 3489' 7217' Perforation Depth TVD (ft): 6240'-6241', 6243'-6244', 6247'-6247', 6252'-6284' Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal r-~ Detailed Operations Program [~ BOP Sketch [] 14. Estimated Date for Commencing Operations: Immediately 16. Verbal Approval: Date: Plugs (measured): Junk (measured): TVD Burst Collapse 121' ' 3390' 6475' Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" J-55 6826' 13. Well Class after proposed work: Exploratory E~ Development Service E~] 15. Well Status after proposed work: oil [] Gas I--I WAG [~] GINJ ~ Plugged WINJ Abandoned r-~ WDSPL E] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ~Jerry Dethlefs /,.--.~ ~ _ Signature ,~'~'-~ ~ Commission Use Only Contact: Jerry Dethlefs, 659-7043 Title: Problem Well Supervisor Phone.659-7043 Date ~'",,,,~d..~--'-~ Conditions of approval: Notify Commission so that a representative may witness ISundry Number: Plug Integrity E~ BOP Test E~ Mechanical Integrity Test F-] Subsequent Form Required: ~-~) Form 10-403 Revised 2'2003' t G I N" A L Location Clearance ,~ (~ E ~, \/E D SEP ;t, 2083 Alaska 0ii & Gas Cons. Commission Anchorage BY ORDER OF THE COMMISSION Date: SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. SUNDRY NOTICE 10-403 Kuparuk Well 3M-14 (PTD 1870510) September 11, 2003 This application for Sundry approval for well 3M-14 (PTD 1870510) is to document that the AOGCC and ConocoPhillips concur the well may be produced with a variance from 20 AAC 25.200 (d) Production Equipment. Due to the configuration of the completion with an Electric Submersible Pump (ESP), the well does not have an isolation packer between the tubing and annulus. Approval for an exemption from 20 AAC 25.200 (d) was not documented at the time of the ESP completion. ConocoPhillips met with the AOGCC on July 15, 2003, at which time verbal permission was received to continue production from the well. The intent of this Sundry is to document AOGCC approval of the variance from the regulation. Well 3M-14 was originally completed in June 198_7 as a gas lifted producer. The well was re- completed with an ESP in J~ The well produced via ESP until ~, at which time the pump failed. The AOGCC was notified of the pump failure on August 31, 2001. The well h~as the c~apability..to flo~w without the ESP operating and has been kept on production with the ESP deactivated. There are no plans to run another ESP completion in the future. Should the well have another workover the expectation for the completioll will be for standard ga~ ~ith tubing ~tnd-a packer. A ~ log Will be run as part of a workover. Since the well does not have an isolating packer there is some annular flow (IA) of produced fluids. Wellbore fluids bypass the pump and enter the tubing through a gaslift mandrel at ~6661 ~easured_d~.epth. From that point produced fluids flow up the tubing and out the wellhead to production facilities. Gaslift is maintained on the well through gaslift valves at 2641', 3916' and 4415' to k~ fluids,~ t.o the 19.west POssible .dept_.h. The well is equipped with a wellhead Safety Valge System as per regulations. Recent well test data shows the following results: WELL TEST SUMMARY REPORT ~-~TOTAL FORM TOTAL LIFT GAS DS WL LENGTH CHK FTP FTT OIL WATER FLUID GAS GOR GLR RATE 3M 14 12:00 176 123 113 275 674 '1 ) 949 187 681 780 553 3M 14 20:00 176 118 111 228 632 -'3 ~ 860 145 637 647 412 3M 14 18:16 176 115 111 229 634 '3 1863 126 548 434 250 3M 14 16:47 176 111 111 265 727 ~3 ) 992 232 875 1243 1001 3M 14 18:00 176 106 112 236 706 ~// 942 163 692 699 495 LIFT GAS "~ PRES [1050 [x \ / As per this request, ConocoPhillips intends to produce 3M-14 for an unspecified duration with an exemption to 20 AAC 25.200 (d) Production Equipment. ~~ ConocoPhillips Alaska, Inc. mdrel/Dummy Valve 1 (102-103, 0D:4.750) Gas Lif VlandreINalvE 2 (2641-2642, 0D:4.750) TUBING- (0-6826, OD:2.875, ID:2.441) Gas Lift VlandreINalvE 3 (3916-3917, 0D:4.750) PROD. CASING (0-7217, OD:7.000, Wt:26.00) Gas Lift VlandrelNalvE 4 (44154416, 0D:4.750) Vlandrel ', ~. ,,." 5 (666' ,~ ':'.':' ;' 0D:4.750) KRU 3M-14 3M-14 APl:1500292172600 SSSV Type:I NONE Annular Fluid:I Reference Log:I Last Tag:17217 Last Tag Date:17/7/1998 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING Tubing String - TUBING Size I T~P 2.875 Perforations Summary Interval TVD 6940-6942 6240-6241 6944-6945 6243-6244 6948-6949 6247-6247 6954-6992 6252-6284 Gas Lift Mandrels/Valves Well Type: PROD Orig 16/5/1987 C°mpleti°n:l Last WlO:1711111998 Ref Log Date:I TD:17244 ffKB Max Hole Angle:136 deg (~ 5800 Angle ~ TS: 132 deg (~ 6930 Angle @ TD:I32 deg @ 7244 I Rev Reason:lFTS WELL Last Update:J5/25/2003 Size 16.000 9.625 7.000 Top 0 i 0 BottomI 7217 TVD Iwt IGrade I 121 162'58 I H-40 I 3390 36.00I J-55 I 6475 26.00 J-55 I Thread Bottom I TVD Wt Grade Thread 6826I 6144 6.50 J-55 I EUE-ABM Zone Status Ft SPF Date Type Comment A-2 2 1 8/16/1987 IPERF 14" CG, 120 deg. phasing A-2 1 1 8/16/1987 IPERF 14" CG, 120 de,(] phasing A-2 I 1 I 1 18/16/19981 IPERF 14"CG, 120 deg phasing A-1 38 4 8/16/1987 PERF 14 CG; 120deg phasing st I MD I TVDI Man I Man I V Mfr Iv Type Iv OD I Latchl Port I TROI Date I Mfr Type Run 2 I 26411 26351Camc°l KBMM I CAMCOI GLV I 1.0 I BK 10.156 1130018/22/20011 3139161 374110amcoI KBMM I CAMCOI GLV I 1.0 IBK 10.188 1135418/22/20011 414415141541cam0oI KaUU I CAMCOI OV I 1.0 I BE 10.250 0 18/22/20011 5 I 6661i 6O051Carnco I KBMM I CAMCO I OPEN I 10 I BK I 0000 I 0 .-"'222001 Other (plugst equip., otc.) - JEWELRY Depth/TVDI Type / Description 6741 160721 NIP / CAMCO "D" NIPPLE NO GO 6752 16081 I PUMP lCentrilift 20 GCNPSH/36GC3500/82GC2900 Series 513 Triple Taper / I 1pump w/bolt-on intake and discharge heads 6788 16112 I SEAL lCentrilift GST3 4B HL PFS Tandem Seal Section 6803 16124 I MOTOR ~Centrilift 266 HP KMH 2345/69 Series 562 Motor w/motor lead extension ! I ~ cable. Motor has a 6" centralizer threaded into base. Vlv Cmnt ID 2.250 0.000 0.000 0.000 Note 10' of fill on top of CAT SV (~ 6741' RKB. PACKERLESS COMPLETION: FLOW TO SURFACE WELL NIP (6741-6743, OD:5.620) PUMP (67524~788, 0D:2,500) SEAL (6788-6803, 0D:2.500) Perf (6940-6942) Peri (6944-6945) (6948-6949) Peff (695*6992) PHmLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 16, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 3M- 14 (187-051) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation operations on the KRU well 3M-14. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad Oil & Gas Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 63 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 950' FNL, 1598' FEL, Sec. 25, T13N, RSE, UM (asp's 506270, 6016549) 3M-14 At top of productive interval 9. Permit number / approval number 1284' FSL, 813' FEL, Sec. 24, T13N, R8E, UM 187-051 / At effective depth 10. APl number 50-029-21726 At total depth 11. Field / Pool 3834' FNL, 765' FEL, Sec. 24, T13N, R8E, UM (asp's 507097, 6018943) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7244 feet Plugs (measured) true vertical 6498 feet Effective depth: measured 7217 feet Junk (measured) true vertical 6475 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 200 sx CS ~ 121' 121' SUR. CASING 3426' 9-5/8" 1389 sx AS III & 371 sx Class G 3489' 3390' PROD. CASING 7154' 7" 300 sx Class G & 175 sx CS I 7217' 6475' Perforation depth: measured 6940'-6942', 6944'-6945', 6948'-6949', 6954'-6992'RECEIVED true vertical 6240'-6241', 6243'-6244', 6247'-6247', 6252'-6284' ~?C T _~ ~' 200 1 Alaska Oil & Gas Cons. Co~missio, Tubing (size, grade, and measured depth) 2-7/8",6.5#, J-55 Tbg @ 6826' MD. Anchorage Packers & SSSV (type & measured depth) No packer No SSSV 13. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 291 19 639 - 158 Subsequent to operation 468 169 1318 168 .... 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574 Signed ~',/' ~':;/,~ ~ ,/~,~'hy Title Staff Engineer Date //~f/J/,;//",~/' Michael Mooney Prepared by Sha~On Al/sup-Drake 283-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 3M-14 Event History 08/04/01 08/21/01 08/22/01 RIH W/VORTECH, WASH TO PUMP AT 6736' CTM. PUMP 5 BBL DIESEL LEAD, 10 BBL 12% HCL, 4 BBL DIESEL TAIL AT 1 BPM. POOH PUMPING FILL RATE. TURN WELL OVER TO DSO AND CENTRILIFT TO START PUMP AND FLOWBACK ACID. BLOW DN COIL WITH NITROGEN FOR REEL SWAP. ATTEMPTED START ESP; FAILED, DOWNHOLE GROUND FAULT. SET CATCHER @ 6741' RKB. PULLED DV @ 4415' RKB. IN PROGRESS. [ESP WORK, GLV] INSTALLED NEW GAS LIFT DESIGN. CATCHER PULLED @ 6741' RKB. TBG P/T 2500 PSI, GOOD. DV PULLED & LEFT OPEN @ 6661' RKB. [GLV, PT TBG-CSG, SCALE] Page I of I 10/15/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing __ Stimulate_ Plugging_ Perforate_ Alter casing __ Repair well __ Other X Install ESP completion 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 950' FNL, 1598' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1284' FSL, 813' FEL, Sec. 24, T13N, R8E, UM At effective depth At total depth 1444' FSL, 768' FEL, Sec. 24, T13N, R8E, UM 12. Present well condition summary 5. Type of Well: Development X Exploratory __ Stratigraphic _ Service 6. Datum elevation (DF or KB) Rig RKB 32' 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-14 9. Permit number/approval number 87-51/398-110 10. APl number 50-029-21726 11. Field/Pool Kuparuk River feet Total Depth: measured 7244' true vertical 6498' feet feet Plugs (measured) Effective depth: measured 7129' true vertical 6400' feet feet Junk (measured) Casing Length Size Structural Conductor 80' 16" Surface 3438' 9-5/8" Intermediate Production 7182' 7" Liner Cemented 200 sx CS I 1389 sx AS III & 371 sx Class G 300 sx Class G & 175 sx CS I Measured depth 115' 3473' 7217' True vertical depth 115' 3377' 6475' Perforation depth: measured true vertical 6940'-6942',6944',6948',6954'-6992' 6240'-6241' 6243',6246',6251'-6283' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55 @ 6826' Packers and SSSV (type and measured depth) RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL Alaska 0il & 6as Cons. C0mmis~io~ Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.~ j /,,~_~_ Title Drilling Engineer Form 10L'/4"04 Rev 05¢I¢/89 v --~ Date SUBMIT IN DUPLICATE Date: 7/24/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-14 WELL_ID: 999202 TYPE: AFC: 999202 STATE:ALASKA 21726-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:07/03/98 RIG:NORDIC # 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029- 07/03/98 (C1) TD: 7217' PB: 7129' Circ well MW:ll.0 BRINE SUPV:MCH Move rig over well 3M-14. Accept rig @ 1800 hrs. 7/3/98. Pump seawater down tubing and out annulus to production line. 07/04/98 (C2) TD: 7217' PB: 7129' Rigging down SWS w/1 tool MW: 0.0 BRINE SUPV:MCH Kill well w/ll.0# brine. Well static. N/D tree. Well began flowing. N/U Tree. CBU. Well static. N/D tree, N/U BOPE and test. Attempt to pull tubing to floor, OEJ would not release, work pipe and circ. 07/05/98 (C3) TD: 7217' PB: 7129' RIH w/BHA #2 MW:ll.1 BRINE SUPV:MCH RIH w/2-1/8" chemical cutter and cut tubing @ 6795' Pump hi-vis pill. Tag fish @ 6784' 07/06/98 (C4) TD: 7217' PB: 7129' POH, laying down DP. MW:ll.1 BRINE SUPV:MCH POH with fish. RIH w/fishing assembly bha #2. POH with fish, hanging up, no swabbing. Recovered complete fish. Attempt to break circ., work pipe, attempt to unplug, no success. Wash to bottom @ 7108. 07/07/98 (C5) TD: 7217' PB: 7129' 07/08/98 (C6) TD: 7217' Spot kill pill MW:ll.1 BRINE SUPV:DLW Spot hi-vis pill on bottom. POOH swabbing work pipe. Well flowing. Shut in monitor well. Appear to be out of balance. Circulate. Well started taking fluid. Shut down. Monitor well dead. RIH w/bit. _FCFIVFD SUPV: DLW JUL 2 1998 Alaska Oil & Gas Cons. Commissiort Anchorage PB: 7129' Spot hi-vis pill, well dead. Well continue to flow gained 50 bbls. 07/09/98 (C7) TD: 7217' PB: 7129' Rig moving to 3K-31 MW: 0.0 DOILW SUPV:DLW While RIH w/2-7/8" ESP completion, well flowing. Shear out GLM DKV valve @ 4513' Kill well w/ll.1 brine. Well taking fluid. Continue to run 2-7/8" ESP. N/D BOPE, N/U tree, test packoff to 5000 psi, OK. 07/10/98 (C8) TD: 7217' PB: 7129' Released rig @ 0600 hrs. MW: 0.0 DOILW SUPV:DLW Continue to clean pits. Move rig off well. Release rig @ 0600 hrs. 7/10/98. Move to 3K-31. End of WellSummary for We11:999202 Prepared by: S. ALLSUP-DRAKE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Joh~ Chairman Blair Wondzell, P. !. Supervisor Petroleum inspf~ctor DATE' July 4, 1998 FILE NO' .DOC BOP Test Nordic 2 KRU 3M-14 PTD 87-051 July 4,1998: I arrived at Kuparuks 3M pad at 0330 hrs just in time to see the roughnecks reinstalling the tree on the well as it wasn't completely killed. The BOP test started at 1300 hrs. We started testing but we had a leaking Whitey valve on the test pump. It was replaced and then the test pump broke. We finished testing the rest of the components with the rig mud pump. The hydraulic controlled choke on the choke manifold failed. They are to repair it within 24 hrs. SUMMARY: I witnessed a BOP test on Nordic 2, 5 hours; 1 failure. ~ __ Attachments: acvggdfe.xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: X ~/ DATE: Nordic Rig No. 2 PTD # 87-51 Rig Ph.# ARCO Rep.: Dink Helm 3M- 14 Rig Rep.: Shane McGeehan Set @ 7,217 Location: Sec. 25 T. 13N R. 8E Meridian Urniat Weekly Other Test Pressures 7/4/98 659-7565 Test MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location X Standing Order Posted X Well Sign X Drl. Rig ok Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 0 0 I 0 P I 0 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 300/3000 I 0 0 I 0 0 I 0 2 0 0 P/F P P P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 12 No. Flanges 36 0 Manual Chokes I Functioned Hydraulic Chokes 1 Functioned Test Pressure P/F 0 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 462200 3000 2200 minutes 22 sec. minutes 13 sec. X Remote: X Psig. Number of Failures: I ,Test Time: 4.0 Hours. Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Hydraulic choke repaired and retested 7/4/98. Distribution: odg-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12294) acvggdfe.xls 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon _ Suspend _ Operation Shutdown Alter casing _ Repair well _ Plugging __ Change approved program _ Pull tubing ~ ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 950' FNL, 1598' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1284' FSL, 813' FEL, Sec. 24, T13N, R8E, UM At effective depth At total depth 1444' FSL, 768' FEL, Sec. 24,-1'13N, R8E, UM 5. Type of Well: Development Exploratory _ Stratigraphic _ Service 12. Present well condition summary Total Depth: measured 7244' feet Plugs (measured) None (approx) true vertical 6498' feet Effective depth: measured 7129' feet Junk (measured) (approx) true vertical 6400' feet Casing Length Size Cemented Structural Conductor 80' 16" 200 sx CS I Surface 3438' 9.625" 1389 sx AS III Intermediate & 371 sx Class G Production 7182' 7" 300 sx Class G & Liner 175 sx CS I e-enTer suspenoeo we ___ ' -,; ~'~'m e extension Stim ~ate'~Lql~0~e Variance_ Pe-rforate_ Other X -~nstall [::SP Measured depth 115' 3473' 7217' 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-14 9. Permit number 87-51 10. APl number 50-029-21726 11. Field/Pool Kuparuk River feet Perforation depth: measured 6940'- 6942', 6944', 6948', 6954'-6992' true vertical 6240'-6241', 6243', 6246', 6251'-6283' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55 @ 6862' Packers and SSSV (type and measured depth) , L Camco HRP-I-SP Pkr @ 6836' MD, Camco TRDP-1A-SSA @ 1791' Trueve~icaldepth 115' 3377' 6475" 13. Attachments Description summary of proposal X Contact William Isaacson at 263-4622 with any questions_. Detailed operation program __ BOP sketch _ 14. Estimated date for commencing operation May 15, 1998 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas_ Service Suspended _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~'~_ .~._~_,... ~. ~,~'~? Title Kuparuk Drilling Team Leader FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test ~ Location clearance __ Mechanical Integrity Test_ Subsequent form require 10-/~.~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 original Signecl By Oavid W. Johnston Commissioner IApproval No.~~? ..// I Date SUBMIT IN TRIPLICATE 6. Datum elevation (DF or KB) 63' RKB KRU 3M-14 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. RIH with wireline. Pull valve from bottom GLM leaving an open pocket. Dummy off all other GLM's. 2. Set BPV in tubing. Install VR plug in annulus valve. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig. Lay hard-line to tree. Pull BPV and VR plug. Load pits w/sea water. Displace tubing and annulus w/sea water. SI well and determine kill wt fluid required. 2. Load pits w/kill wt brine (expected kill wt = 10.9 ppg). Circulate well to brine. Ensure well is dead. Set BPV. 3. ND tree. NU and test BOPE. 4. Screw in landing joint. POOH standing back 2-7/8" tubing, lay down all jewelry. 5. PU DP and RIH with overshot. Latch on to 'slick-stick' and pull retrievable packer free. POOH with packer and tail-pipe assembly. 6. PU bit and scraper and RIH cleaning out well to PBTD. Circulate hole clean. POOH standing back DP. 7. RIH w/Electric Submersible Pump completion on 2-7/8" tubing as per attached schematic. MU ESP cable penetrator system and conductor for downhole pressure gauge through tubing hanger. Test wellhead penetrators, tubing, and both cable conductivity's as needed. 8. ND BOPE. NU and test tree. Flush well with diesel. Lower Limit: 5.0 days Expected Case: 6.0 days Upper Limit: 8.0 days No problems pulling or re-mnning completion Difficulties encountered pulling completion, or running ESP completion WSI 04/17/98 !' 3M-14 Proposed Completion K. 2-7/8" 5M FMC Gen IV Eccentric tubing hanger with 'BIW' penetrators for ESP cable (100 amp) and downhole gauge conductor wire. 2-7/8" L-80 tubing pup on bottom. Round #2 power cable with tech wire in double armor wrap J. Rerun 2-7/8" J-55 EUE 8rd Mod IPC tbg to surface. Space-out 2-7/8" x 1" Camco 'KBMM' mandrels w/ DV's as follows: GLM# MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD NOTE: Install LaSalle cable protectors over the cplg of each of the first 6 joints above the bottom GLM, followed by every other joint to surface. (With the exception of each GLM as noted below.) Each GLM should be made up with a 8' pup below and a LaSalle cable protector placed on cplg below pup. LaSalle ESP Cable Protectors spaced out as procedure ~ Cable splice from flat to round cable adjacent to 10' pup above pump I. 2-7/8" X 1" Camco 'KBMM' mandrel with DCK-2T-1 dump kill valve (pinned for 3500 psi tubing to casing differential). H. Pup jt, 2-7/8" x 8' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg between 8' pup and full jt. G. 1 jt Rerun 2-7/8" J-55 EUE 8rd Mod IPC tubing with LaSalle cable protector on cplg below joint. F. 1 jt Rerun 2-7/8" J-55 EUE 8rd Mod IPC tubing with annulus sensing Baker 'Sentry' gauge clamped to OD of tubing. Conductor Wire for gauge will be run to surface with-in the 2nd Armor wrap of ESP cable. E. 2-7/8" Camco 'D' landing nipple with 2.25" No-Go profile. Standing Valve to be set as nipple is made-up. D. Pup it, 2-7/8" x 4' L-80 EUE 8rd Mod tubing with LaSalle cable protector on cplg below pup. LaSalle ,~ Protectolizers at each flange of ESP assembl C. Centrilift '20 GCNPSH/36GC3500/82GC2900' Series 513 Triple Taper Pump with bolt-on intake and bolt-or discharge head. 2-7/8" x 10' L-80 handling pup on top. B. Centrilift 'GST3 4B HL PFS' Tandem Seal Section. A. Centriliff '304 HP KMH 2290/81' Series 562 Motor with Motor Lead Extension Cable. Motor has a 6" centralizer threaded into base. Bottom of motor set at +/-6625' MD RKB. A Sand Perfs 6940' - 6949' 6954' - 6992' 7" 26# J-55 @ 7217' PBTD @ 7129' WSI 3/31/98 4" 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 X ,, Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska. Inc, 3, Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4, Location of well at surface 950' FNL, 1598' FEL, Sec. 25, T13N, At top of productive interval 1284' FSL, 813' FEL, Sec. 24, T13N, At effective depth 1386' FSL, 785' 'FEL, Sec. 24, T13N, At total depth 1444' FSL~ 768' FELT Sec. 24~ T13N~ 12. Present well condition summary Total Depth: RSE, UM R8E, UM RSE, UM R8E~ UM measu red 7 2 4 4 true vertical 6 4 9 8 6. Datum elevation (DF or KB) RKB 63 Unit or Property name Kuparuk River Unit 8. Well number 3M-14 9. Permit number/approval number 87-51 feet 10. APl number $0-029-21726-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 71 2 9 feet Junk (measured) None true vertical 6400 feet Casing Length Size Cemented Measured depth Structural Conductor 80' 1 6" 200 Sx CS II 1 1 5' Surface 3436' 9-5/8" 1389 Sx AS III & 3473' Intermediate 371 SX Class G Production 7189' 7" 300 Sx Class G & 721 7' Liner 175 Sx CS I Perforation depth: measured 6940'-6945' ,6948'-6949' ,6954'-6992' true vertical 6240'-6244',6246'-6247',6251 '-6283' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 6862' True vertical depth 115' 3377' 6475' ORIGI AL Packers and SSSV (type and measured depth) Packer: Camco HRP-1-SP @ 6836'; SSSV: Camco TRDP-1A-SSA @ 1791' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 9/11/97. Intervals treated (measured) 6940'-6945',6948'-6949',6954'-6992' Treatment description including volumes used and final pressure Pumped 261 Mlbs of 20/40 and 12/18 ceramic proppant into formation~ fp was 6200 psi. 14. ReDresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 337 318 603 1240 623 424 1230 1246 Prior to well operation Subsequent to operation Tubing Pressure 191 195 15, Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed Title Wells Superintendent Form lf~4 {' ~e~ d6/15/81~-' - Service ,ARC~O Alaska, Inc. ' KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(3M-14(W4-6)) WELL JOB SCOPE JOB NUMBER 3M-14 ,, FRAC, FRAC SUPPORT 0901972258.4 DATE DAILY WORK UNIT NUMBER 09/1 1/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O NoI ® Yes O No DS-GALLEGOS JOHNS, ~ , FI ELD AFC~ CC# DAILY COST ACCUM COST S~~ ESTIMATE KD1500 230DS36M L $1 82,700 $206,068 Initial T~b.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer ~nn I Final O~r Ann " 0 PSl i 1500 PSI 0 PSI 1000 PSII 400 PSII 500 PSI DAILY SUMMARY PUMPED 'A" SANDS REFRAC WITH 261,000# PROPPANT TO 13 PPA 12/18 AT PERFS, LEFT 450# PROP IN PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LIq-rLE RED AND APC VAC TRUCK. 09:00 HELD SAFETY MEETING, DISCUSSED WELL HOUSE PLATFORMS 10:00 PRESSURE TEST TREATING LINE TO 11,000 PSI. 0:20 · ~; ~'~ 12:16 12:37 12:47 13:24 13:51 14:00 PUMP BREAKDOWN , SCOUR AND FLUSH STAGE AT 17 TO 26 BPM AND 8400 TO 7600 PSI. SHUTDOWN FOR ISIP AND PULSE TEST. PUMP DATA FRAC AND FLUSH AT 5 TO 15 BPk -,~., .,_-., ,-. ,~ S~-~UTDOWN ISIP 2719 PSI AND FIGURE CLOSURE PRESSURE. PUMPING PAD 230 BBLS AT 5 TO 15 BPM AND 5760 PSI. PUMPING 2 PPA 20/40 PROPPANT A 15 BPM AND 6029 PSI. 50# GEL SYSTEM. 150 BBLS. PUMPING RAMP UP FROM 2 PPA TO 10 PPA 12/18 AT 15 BPM AND 5475 PSI. PUMP FLAT 10 PPA FOR 400 BBLS , 40 # GEL 12/18 AT 15 BPM AND PUMP RAMP UP FROM 10 PPATO 13 PPA, 15 BPM AND 6200 PSI. SHUT DOWN AFTER FLUSHING TUBING, 261,000 # TO 13 PPA 12/18 TO PERFS. LEFT 450# IN TUBING. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $756.00 APC $7,000.00 $12,800.00 ARCO $300.00 $300.00 DOWELL $175,400.00 $181,419.00 HALLIBURTON $0.00 $7,054.00 LITTLE RED $0.00 $3,740.00 TOTAL FIELD ESTIMATE $182,700.00 $206,069.00 '--"" STATE OFALA 0 R !GI A ~ OIL. AND GAS OONSERVATI~ COIVlI'v,,v,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown m Pull tubing Alter casing .). Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at sudace 950' FNL, 1598' FEL, Sec. 25, T13N, R8E, UM At top of productive interval 1284' FSL, 813' FEL, Sec. 24, T13N, R8E, UM At effective depth 1386' FSL, 785' FEL, Sec. 24, T13N, R8E, UM At total depth 1444' FSL, 768' FEL, Sec. 24, T13N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7244' 6498' Stimulate X Plug{~ing , Perforate Repair well .., Other 5. Type of Well: ~ 6. Datum elevation (DF or KB) Development X I Exploratory _ Stratigraphic Service feet Plugs (measured) feet 63' RKB fee~ 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-14 9. Permit number/approval number 87-51 10. APl number so-029-21726 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 71 2 9' true vertical 6400' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 8O' 16" 3436' 9 5/8" 721 7' 7" measured 6940', 6942', true vertical 6240', 6241', Cemented 200 sx CS II 1389 Sx AS III & 371 Sx Class G 300 Sx Class G 175 sx CS I 6944', 6948', 6954'-6992' 6243', 6246', 6251;-6283' Measured depth 115' 3473' 7217' True vertical depth 115' 3377' 6475' Tubing (size, grade, and measured depth) 2 7/8" 6.5#, J-55, ABMOD, 6862' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA~ 1791', Packer: Camco HRP-1-SP~ 6836' 13. Stimulation or cement squeeze summary A-Sand Seawater Gel Fracture Treatment Intervals treated (measured) 6940', 6942', 6944', 6948', 6954'-6992' Treatment description including volumes used and final pressure Pumped 159MIbs in perfs-16/20 Carbolite .... followed by 12/18 Carbolite (see Well Service Report) 14. Reoresentatlve Dally Average ProductIon or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Alaska Oil & Gas Cons. Comm'tss'~o~ 'Anchorage Prior to well operation 1750 770 -0- 1150 150 Subsequent to operation 2 0 0 0 1 1 0 0 2 2 1 1 5 0 15. Attachments /16' Status of well classification as: Copies of Logs and Surveys run m Water Injector t Daily Report of Well Operations X Oil , X, Gas Suspended --.-- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 150 Form 10-404 Rev 09/12/90 Title Kuparuk Petroleum Engineer Date qh4/ Z' SUBMIT IN DUPLICATE _ ,.a. HL;U AlasKa, inc. Subsidiary of Atlantic Richfield Compar~--~, -WELL dDT 3H-I~( CONTRACTOR ~"5' "C~"t,,, ~ -G;Jl REMARKS FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT I~ O,S- i~'o o I~0o Iv., ooo ~ L%.Li V L,~' .., s E P ? ~ ,,0.92 Alaska Oi! & Gas r_.ons_ Commission ;Anchorag~ I-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I TemP'Report 'F j Chill Fac'tor J Vl.lbllltY. Fj mile. Wind Vel. -- STATE OF ALASKA ALASKA O1~ AND GAS CONSERVATION L, OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-51 3, Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21726 4. Location of well at surface 9. Unit or Lease Name 950' FNL, 1598' FEL, Sec.25, T13N, RSE, UM Kuparuk River Unit At Top Producing Interval 10'. Well Number 1284' FSL, 813' FEL, Sec.24, T13N, R8E, UM 3M-14 _ At Total Depth 11. Field and Pool 1444' FSL, 768' FEL, Sec.24, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 63'I ADL 25522 ALK 2558 I ' 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 05/31/87 06/04/87 09/22/87*I N/A feet MSL 1 17. TotalDepth(MD+TVD) 18. Piug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7244'MD, 6498'TVD 7129'MD, 6400'TVD YES ~ NO [] 1791 ' feet MD 1600' (approx) 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL, Cal, FMS, CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD · , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 62.5# H-40 Surf 115' 24" 200 sx CS II 9-5/8" 36.0# J-55 Surf 3377' 12-1/4"' 1389 sx AS Ill & 371 s~ Class G 7" 26.0# J-55 Surf 7217' 8-1/2" 300 sx Class G & 175 s> CS 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) Perforated w/1 spf, 120° phasing 2-7/8" 6862' 6836' 6940 'MD 6240 'TVD 6942'MD 6241 'TVD "26· ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6944'MD 6243 'TVD DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED 6948'MD 6246'TVD See attached Adden.!um, dated 9/28/~7,. for fracture di ta. , Perforated w/4 spf, 120° phasing 6954 ' -6992 'MD 6251 ' -6283 'TVD , , , 27. N/A PRODUCTION TEST Date First ProductionI Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested pRoDuCTiON FOR OII"~BBL GAS-MCF WATER-BBL CHOKE SIZE 'iGAS-OILRATIO TEST PERIOD ~I ... Flow Tubing Casing 'Pressure CALCULATED OIL-BBL GAS-M'CF WATER-BBL.. OIL GRAvI'Ty-API ('corr) Press. 24-HOUR RATE ~ ~ ~ r ,,~ :~'8. CORE DATA ~'~ ~- ~' ''~ ' -- - Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chip's. · None ~_ik., i' ~L .M.ss~-: 0~ & Gas GoDs. oommissi ~cb0m~ *Note: Drilled RR 6/5/87. Well perforated & tubing run 8/17/87. Well fractured 9/22/87. ,,, Form 10-407 WC3/85':DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ! 29. ! '"" 30. ', -' '- . .. GEOLOGIC MARKERS ' '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 6929' 6230' N/A Base Kuparuk C 6935' 6235' Top Kuparuk A 6935' 6235' Base Kuparuk A 7014' 6302' ,, . 31. LIST OF ATTACHMENTS Addendum (dated 9/28/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~) ~ ~~,~ Title Ass°el ate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6/25/87 9/22/87 3M-14 Arctic Pak well w/175 sx CS I & 60 bbls Arctic Pak. Frac Kuparuk "A" sand perfs 6940'-6942', 6944'-6948' & 6954'-6992' as follows per procedure dated 9/14/87: Stage 1: 100 bbls gel diesel f/10-20 BPM, 4000-4265 psi Stage 2: 460 bbls gel diesel @ 20 BPM, 4300-4155 psi Stage 3: 30 bbls gel diesel 2 ppg 20/40 sand @ 20 BPM, 4088-5980 psi Stage 4: 50 bbls gel diesel 4 ppg 20/40 sand @ 20 BPM, 4180-4150 psi Stage 5: 50 bbls gel diesel 6 ppg 20/40 sand @ 20 BPM, 4235-4375 psi Stage 6: 50 bbls gel diesel 7 ppg 20/40 sand @ 20 BPM, 4375 psi Stage 7: 40 bbls gel diesel 8 ppg 20/40 sand @ 20 BPM, 4400-4576 psi Stage 8: 40 bbls gel diesel 9 ppg 20/40 sand @ 20 BPM, 4600 psi Stage 9: 25 bbls gel diesel 10 ppg 20/40 sand @ 20 BPM, 4400 psi Stage 10:41.3 bbls gel diesel @ 4430-4277 psi Fluid to Recover: Sand in Zone: Sand in Csg: 802 bbls 58,745# 886# Job complete 9/22/87. · Drmllmng S~upervzsor ~ / ~ate August 10, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70048 Well: 3M-14 Field: Kuparuk ~ Survey Date: August 3, 1987 Operator: T. McGuire Mr. Ruedrich: please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NL Sperry. Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ~;"~1 I V ~ll'::~Tkll~ ~1 ~) = 4.~ ~-~-~ g~[ ...... ~ ............ VERTICAL 'SEI::TII]IN CALCi_:.,....: ONG CLOSURE ....................... TRLIE .............. $UB=.=S~ ................................... COURSE ........... COURSE ..................... ~=~. ....... ", :~S. LI.RED ............. VEIK.'I, iCAL .............. kt~.T.I~ ...........I.NCL.INA:[.i. ON ........... D I.REC~..ION ...... S~I TY -~ ..... -' - - D! NATES .: ~ BgR.T...ICAI~ ........... 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S.L!B.-...SE~-'.'-~ ...................................................... -['.O'[[.-~L ............................................................................................................................................................................................................................................................................ .' i ....... , ..... i-' ."', .~E,,~ 1.t.,_...~-:~L ...... .~2E~:L]"II-:AL RF~_.'-~L!=..~-~£!:: ...... J:20D_BE I'NATF::; MFI-TVF~ vF_A'.T!C:AL D F.':'. F' T H DEF'TH NORTH/SF.)LITFI E~L:;T / WE._'ST DIFFERENCE.' .UORRE!~.TI UN .... '"'~=' ._ '"'=:'-' /.~.:. N '7.1. 0 0 ~.:,..:, 7 ..., ,, 0:1. 6:2: :1. :2 ("):1. .,:: .... : :1., -"-' 71 .':..'.-t'F~ ./..:, :'_:: '..:-~ '.-:~ ,, 7:2i: /_-, ::.:.': :.:i: & . 73 :2 7.': :.:.: 6 ,, :"2,0 N '7 ".=',~;L LL /-. Z~ '=? '}' "7 "2' /-.ZL"::'. ,4!. "7'7 ..... ............... i_l ...in . . ................................................................... !~!.ERI~[fL.22',.-:.iI~J.--:~ .[i~!.K..~.DE...EI.~..'f:__Z-~ND ~F, ERRY SUN SURVEY DATA MAr~::ER ....... ,. MEASUREn gEF'TH -TVD :" :,::' Bi<B , '-* I-' '-" ~ ' "" "' '-' - ...................... ].'.0l~:....t:..".L!I!~:r:::~.i!!',:!.J.I'::.......C .................. ,"-,':~'-:":'~ /-,";:::c~ 01 6 'i/-,7. C) ~1 :..-.,:;~,::-'~. Zl.(')N '7:.::zl. ',":h-~F'. :~ -1 J~: ,~ .................. :,...,: ,~ .:..,:.:,:: ,-. _ :~. ..... J[!~F~'.B.F_ i.::]l...IF:'~'hFi:l I1-:] (":/_ ,-.,..:,c: ,":,.~:.: .... 07 TOF' I<UI::'ARI ~i-::: ~'4 6'.-.':~::x=, 62::)5.07 ~17:2, N: ,-, - .", :-i:.-., : ~::::~: :'~::: ii::::: ::':::: :: ~?. :::~: ::.:.Cf: :.: : :: :: '7 ? A .. 9.41= :.: B~: ..~:_E_.J::.'UF.!'i.'.::~[~_UI::-__Zi. ...... 7014 .: ::: . 6301 ....-..:'(..:, .......... ~,~.:~,~:. ~.o: I::'1_ I I '"-i.[:'~ I:.'~ '-: I':: '"" '1 ,. ~,'( 7 .'1, ::-,,.:.:)? ..................................................................................... 6:3.??.. 7..3 .................. 6;2~;3/.:,,....Z13 ........................................................................................................................... 233E,....3.C).bl ....................... 8.1:::;..,3.('!E .................... ................... 'l'.'.O-I"AI .... DE:I:!'CI'iH i:i!F:~.I L.L :EI!~:~ ........ 'Z2~:I:.~ ................................................................................ .6.4:'F..77 SPERRY -SUN SCALE :- 1 INCH TO 500.00 /' 500.0 KUPRRUK FIELD 3H-14{SEC25 T13N ROSE) RK-BO-70048 TRUE NORTH -2000.00 -1500.00 -1000.00 7244 500.00 l_SO0. O0 RBCO RLRSKR, INC. -RUGU5~ 3, 1987 I-iOR ! Z ONT 12IL PF~OJE C l I ON SPERRY -SUN 0.00 5CALE :- 1 INCH TO 1500,00 KUPARUK FIELD 3M-14($EC25 T13N ROSE) AK-BO-70048 1500,00 3000.00 4500.00 7500.00 .,7244 3o'0o. oo INC. 1987 V ER T _~ c,,q L PROJECT]SON STATE OF ALASKA -~ ALA,.,r.. OIL AND GAS CONSERVATION CO. ...~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing ~ OtherX~ Stimulate [] Plugging [] Perforate I~ Pull tubing CONPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 63' Feet 3. Apd.d0r.eSl~ox 100360 Anchorage, AK 99510-0360 6. Unit or Property name Kuparuk River Unit 4. Location of well at surface 950' FNL, 1598' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1284' FSL, 813' FEL, 5ec.24, T13N, R8E, UM At effective depth 1386' FSL, 785' FEL, Sec.24, T13N, R8E, UM At total depth 1444' FSL, 768' FEL, Sec.24~ T13N~ R8E~ UN 11. Present well condition summary Total depth: measured 7244 'MD true vertical 6498 ' TVD Effective depth: measured '7129'MD true vertical 6400'TVD Casing Length Size Conductor 80 ' 16" Surface 3436 ' 9-5/8" Producti on 7217 ' 7" 7. Well number 3M-14 8. Approval number 7-442 9. APl number 50-- 029-21726 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) None feet Perforation depth: measured Cemented Measured depth 200 sx CS II 115'MD 1389 sx AS III & 3473 'MD 371 sx Class G 300 sx Class G & 7217'MD 175 sx CS I True Vertical depth 115'TVD 3377 'TVD 6475 ' TVD true vertical 12. 6940'MD, 6942'MD, 6944'MD, 6948'MD, 6954'-6992'MD 6240'TVD, 6241'TVD, 6243'TVD, 6246'TVD, 6251'-6283'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail ~ 6862' Packers and SSSV (type and measured depth) HRP-I-SP nkr- G GS_~F,' & TRDP-IA-g~A ~c,c;~/ ~ 1791, Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation 14. Attachments Representative Daily Average Production or Injection Data · Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure (Compl eti on Wel 1 Hi sto~y w/Addendum, dated 7/21/87) Daily Report of Well Operations [~ Copies of Logs and Surveys Run ~ Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85~/ ~ TitleAssociate Engineer (Dani) SW02/72 Date 9-17-~7 Submit in Duplicate~ ARC~J ,~il 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 ia nol required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used tot reporting the entire operation if space is available. District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25522 Auth. or W,O. no. ~Title AFE AK2149 I Completion Nordic #1 API 50-029-21726 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W,O. begun Date Complete 8/16/87 8/17/87 Date and depth as of 8:00 a.m. 8/18/87 Complete record for each day reported Old TD I New TD Released rig ~ Date I 0845 hrs. Classifications {oil, gas, etc.) Oil Producing method Flowing Potential test data I Accounting cost center code State Alaska no. 3M-14 Iotal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well our I Prior status if a W.O. 1445 hrs. I 7" @ 7212' 10.0 ppg NaCl/NaBr Accept rig @ 1445 hrs, 8/16/87. ND tree, NU &tst BOPE. RU & perf 6954'-6992' @ 4 SPF & 6940', 6942', 6944' & 6948' @ 1 spf. RU & begin rn'g 2-7/8" compl. 7" @ 7217' 7129' PBTD, RR 6.8 ppg Diesel Tst tree to 250/5000 psi. Tst packoff. Displ well w/diesel. RR @ 0845 hrs, 8/17/87. (Ran 207 jts, 2-7/8", 6.5#, J-55 EUE AB Mod 8RD tbg w/SSSV @ 1791', HRP-1-SP Pkr @ 6836', TT @ 6862') 8/17/87 rig Rotary IType completion (single, duel, etc.) Single. Official reservoir name(s) Kuparuk Sands W"ll no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day P~mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct , _ , I ~.J/~//~;z Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no. Dlvlllon of AtlantlcRIchfleldCompany ADDENDUM WELL: 6~25~87 3M-14 Arctic Pak well w/175 sx CS I & 60 bbl$ Arctic Pak. ? Dat~ ARCO Alaska, In!1 Pos! Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal 4:6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thru9-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well'Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk'Well Pressure Report(Otis) Static A Sand 9-1-87 IY-14 Kuparuk Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well PresSure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well PresSure Report (Otis) Static C Sand 7-18-87 2Z-1 Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: D&M ka 0il & Gas Cons. Commission Anchorage .... ~'Stateof-'Alaska BPAE Chevron Mobil SAPC ARCO Alaska, Inc. Is a Subsidiary of AllanticRIchlleldCompany Unocal ARCO Alaska, In Post Office I~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 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. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement~ Bond Log 8-21-87 7689-8410 3M-14 Cement'Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt Acknowledged: DISTRIBUTION: NSK Dri~ State of Alaska(+sepia) Yault(film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfleldCompany ARCO Alaska, Inc~...~ .... . Pos! Offic~r 90360 Anchorage...l~Ka 99510-0360 Telephone 907 276 1215 Date: July 22, 1987 Transmittal # 6003 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 ~ransmitted herewith are the following items. Please acknowledge ~receipt and retur~ one signed copy of this transmittal. 3M-15 OH Lis Tapes 6-19-87 #72365 3M-16 OH Lis Tapes 6'11-87 #72361 3M-13 OH Lis Tapes 5-28=87 #72348 3M-17 OH Lis Tapes 6-30-87 #72405 3M-18 OH Lis Tapes 6-24-87 #72375 3M-14 OH Lis Tapes 6-4-87 #72353 3M-12 OH Lis Tapes 5-21-87 #72329 Receipt Acknowledged: DISTRIBUTION: M. Stanford .?:,state .,of Alaska?~'~. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALA,,,,,~ OIL AND GAS CONSERVATION COMM,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown E~ Re-enter suspended well [] Alter casing Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing [] Amend order ~ Perforate L~ Other 2. NaA~:(~f QDerator 5. Datum elevation (DF or KB) ATaska, Inc RKB 64' feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 950' FNL, 1598' FEL, $ec.25, T13N, R8E, UM At top of productive interval 1297' FSL, 800' FEL, Sec.24, T13N, R8E, UM (approx) 7. Well number 3M-14 8. Permit number 87 -_~1 At effective depth 1378' FSL, 823' FEL, Sec.24, T13N, R8E, UM At total depth 1436' FSL, 808' FEL, Sec.24, T13N, RSE, UM 11. Present well condition summary Total depth: measured true vertical 7244 ' MD feet 6507 ' TVD feet (approx) (approx) Plugs(measured) 9. APl number 50-- 029,21726 10. Pool Kuparuk River Oil Pool None Effective depth: measured 71 29 'MD feet true vertical 6408'TVD feet Casing Length Size Conductor 80' 16" Surface 3436' 9-5/8" Production 7217' 7" Junk (measured) None Cemented 200 sx CS !i 1389 sx AS III & 371 sx Class G 300 sx Class G Measured depth 115'MD 3473'MD 7217'MD Rue Verticaldepth 115'TVD 3380'TVD 6484'TVD Perforation depth: measured None true vertical No ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED Alaska Oil & Gas Cons. C0mmissi0~ Anch0r~g¢, 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed--,t~~~_/,t4jL~ Title Associate Enqin~r Commission Use. Only {Dani ) $42/6? approval Notify commission so representative may witness I Approval Conditions of No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date Commissioner 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 the first Wednesday after a-well 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 AK4129 Doyon 9 ICounty, parish orbor~hrth Slope Borough Lease or Unit ADL 25522 Title Drill IState Alaska IWell no, 3M-14 API 50-029-21726 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate IHour 5/31/87 Date and depth as of 8:00 a.m. 6/01/87 6/02/87 6/03/87 6/04/87 The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Complete record for each day reported IARCO W.I. Prior status 56.24% if a W.O. 0600 hrs. 16" @ 115' 3230', (3115'), Drlg Wt. 9.1+, PV 13, YP 26, PH 8.5, WL --, Sol 5 Accept rig @ 0500 hrs, 5/31/87. 'Nu ~iverter. Spud well @ 0600 hfs, 5/31/87. Drl 12¼" hole to 3230'. 531', .5°, S60.9E, 530.98 TVD, .77 VS, S 2.25, E 4.05 1514', .6°, S 3.2W, 1513.96 TVD,--- 5.75 VS, S 6.26, E .45 2382', 7.0°, N38.9E, 2381.35 TVD, 3.94 VS, S 3.12, E20.57 2950', 23.9°, N24.9E, 2927.84 TVD, 149.32 VS, N127.13, E88.23 9-5/8" @ 3473' 3495', (265'), Circ Wt. 9.0, PV 8, YP 4, PH 8, WL --, Sol 6 Drl to 3480', short trip, C&C, POOH. RU & rn 87 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 3390', FS @ 3473'. Cmt w/1389 sx AS III & 371 sx C1 "G" w/2% S-1 & .2% D-46. ND diverter. NU & tst BOPE. RIH, tag FC, tst csg to 2000 psi. DO cmt, flt equip & 15' new formation. Circ to chg mud. 3139', 28.1°, N24.4E,'3097.71TVD, 231.84 VS, 202.43N, 122.79E 3405', 34.3°, N27.5E, 3324.17 TVD, 370.97 VS, 330.91N, 176.78E 9-5/8" @ 3473' 6140', (2645'), Drlg Wt. 9.2, PV 5, YP 2, PH 9.5, WL --, Sol 6 Chg over to 8.5 ppg Polymer. Tst formation to 12.5 ppg EMW. Drl 8½" hole f/3495'-6140'. 3707', 34.5°, N18.7E, 3573.35 TVD, 541.55 VS, 490.59N, 236.80E 4485', 33.6°, N15.SE, 4217.26 TVD, 977.96 VS, 905.97N, 371.21E 5373', 34.7°, N16.9E, 4952.45 TVD, 1475.14 VS, 1384.04N, 510.70E 5944', 35.4°, N17.2E, 5338.04 TVD, 1745.37 VS, 1642.64N, 590.01E 9-5/8" @ 3473' 7214', (1074'), Logging Wt. 10.1, PV 14, YP 6, PH 9.5, WL 4.4, Sol 11 Drl to 7214' TD, short trip, CBU, spot diesel pill, POOH. RU Schl, RIH w/triple combo. 6162', 34.7°, N15.5E, 5598.37 TVD, 1927.71 VS, 1817.87N, 641.41E 6634', 33.3°, N14.2E, 5989.66 TVD, 2190.75 VS, 2072.98N, 709.06E 7109', 31.2°, N14.6E, 6391.36 TVD, 2443.17 VS, 2318.47N, 772.09E 7214', 30.8°, N14.7E, 6481.36 TVD, 2497.05 VS, 2370.79N, 785.77E Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after altowable 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. Accounting cost center code State Alaska JWell no. 3M-14 District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25522 Auth, or W.O. no. ITitle AFE AK4129 I Drill Doyon 9 API 50-029-21726 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% Spudded or W.O. begun j Date Spudded J 5 / 31 / 87 Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and ~ bandonment of this well I our ~Prtor status if a W.O. 0600 hrs. Date and depth as of 8:00 a.m. 6/05/87 6/06/87 9-5/8" @ 3473' - 7244', (30'), Rn'g 7" Wt. 10.1, PV 18, YP 10, PH 9.05, WL 4.8, Sol 11 Log DIL/GR/SP/SFL f/7214'-3472', FDG/CNL f/7214'-6200', CAL f/7214'-3472', FMS f/7214'-6750'. TIH, DO 30' of rathole to 7244', circ, spot diesel pill, POOH, LD DP. RU & rn 7" csg. 7" @ 7217' 7244' TD, 7129' PBTD, RR 10.0 NaC1 Rn 166 its, 7", 26#, J-55 BTC w/FC @ 7129', FS @ 7217'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46 & 200 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.O ppg brine, bump plug to 3500 psi. ND BOPE, instl lower packoff. NU tbg spool & lower tree. Tst packoff to 3000 psi. RR @ 1500 hrs, 6/5/87. Old TD Released rig 1500 hrs. Classifications (oil, gas, etc.) Oil JNew TD Date PB Depth 7244' TD 7129' PBTD 6/5/87 Kind of rig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Rotary ~'ell 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date j I Title Drilling Supervisor 3M-14 SA TD PBTD 71 09 6391 71 09 ..6_~91 7214 6481 7129 ~ ~ -68-63~ 7244 6506.7143 7214 ' 7244 2386.1429 7214 2596.25 71 09 772 71 09 ~Z.2 _ 7214 786 7129 ~78~) / "'7'--/~ 7244 790 7214~ ' 845.5 9-5/8" 3405 3324 3473 X 3380.0662 3707 3573 7 ' 7109 6391 7214 6481 7217 6483.5714 btJIl~,, ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure Oil & Gas Cons. Anchor~rje ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany . 24 t9 ,_.. _ _ _/~-~--~- -- _ - _ .- ~,~ ! · SCALE I" .OT£ $: ~.L.~ COORDINAT£$ ARE A'$'P' ' ZONE 4' DISTANCE'SHOWN'ET'LIE' VICINITY M~P I ~: MILES ALL WELLS LOCATED IN SEC. 25, TISN, R8E, UMIAT MERIDIAN. SItlP$ON LAGOO. $.ELEVATIONS ARE B.P.M.S.L. 4.REF. FIELD BOOK LgT-$, PgL 7-1~4 Lt/-I, R/; L87-$,PSI - 55; 5.O.6.ELEVATIONS FROM F.R. BELL & ~SSOCIATES. 6.HORIZONTAL POSITIONS BASED MONUMENTS PER LHD ~ ASSOCIATES. A__SPs 'X__.: LATITUDE LONGITUDE Dist. F..N.L. Dilt. F.E.L. ,1:02:.11 SO~,tZ6-~)! 70027'1t.700" 49o5'1 1296' 1741 2:$.1' E6.6' 6,~a5.10 506,156.45 70027',;0-005', 9~5~ IZ?$' 1752 Z$.~' ~6.6' 16,248.21 506,145.98 70°27.~'0'252, 9°5~ 1l~50: 17E2 E$.3', Z6.9: 16,271.24 506,155.57 70°27'20-459, 9°5! 1227' 1715 E$.4 26.8 16,294.28 506,165.07 70°27:20.685 9°5~ 1204*. iTo3 23.4** ~6.0~, 16,317.42 5~,174.63 70~7 20.91S' ,9~q till 1694 E3.3 Z6.~, 6,016,340.4 S~,~84.13 T0°27'21-1~ FO°S6*S8'316 ll58~ 1684 23.2: 26. 6,016,36~.4 5~,193.52 70°27'21. 366 ~9°5 1135 1675 ~3.1 ~6.6' 6.D~6,386.9 506,203.14 T0°27:21·596 L9°5 II IZ* 1665 ES.O** 26.4* 6 0J6,456.1 506,232.02 T~27,22.277 L9°5 1~2', 1636 Z I.T, 26.5: 6 016,47sJ 506,Z41.52 7~27 22.5~ ;9°5 IOIO 1626 ZI.5 26.5 n,~ 502; 5~,251.07 '.7',22.7~ ~9°5 996', 16 17: El.4: 26.4: 07~ i6o7 ~,.~ v.v I 016~5~5., 506~60.~ :7 ~2.959 ~9°5 ' ~6.4~ 016,548.~ 5~,Z70.~0 .7',~,1 ~ 950', 1598~ Eli 5~, Z-7 9.T7 :7 23.410 lET, 1586, Z ~.O', teA, 5~,289.40 7'23.639 904, 1578, Eo.9, Z6.5, 506,t99.05 7*23.868 881 1569 ~0.9 Z6.5 858' J559' 20.8* 6,016,~1.0a 5~,308.76 .7*24.094 14~56'54.647 , , 7~'Z7' /';/. $50' /.~¢'57'o~. 7,~'Z7'/~. ]25" ///q~ST 'OP. g;/~ z I HEREBY CERTIFY THAT I AM PROPERLY REGISIERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY M&D[ BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS ,&ND OTHER D~TAILS ARE CORRECT AS OF :5/8/87 / :~ Z.,P ' / 7 ~ / ' Z :~.~ ' ~.3 , / 7/,.~' Z ~.O ' ARCO Alaska Inc. D.S. 3M WELL CONDUCTOR AS-BUILT ARCO Alaska, Inc. Post Offic~'~ '100360 Anchorag,. .~ska 99510-0360 Telephone 907 276 1215 Date: June 9, 1987 Transmittal #5999 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. 3M-14 3M-14 3M-14 3M-14 3M-14 3M-14 3M-14 3M-14 5" DIL 5" Raw Data FDC 10" High Resolution Pass 5" Dual Dipmeter 2" DIL 2" Porosity FDC Cyberlook 5" Porosity FDC 996-7202 6196-7176 6-4-87 6749-7176 6-4-87 6750-7207 6-4-87 7150-7202 6-4-87 6196-7176 6-4-87 6700-7150 6-4-87 6196-7176 6-4-87 6-4-87 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Da te: Rathmell D&M Vault(film) L. Johnston(vendor pkg.) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany May 28, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: KUparuk River Unit 3M- 14 ARCO Alaska, Inc. Permit No. 87-51 Sur. Loc. 95.0'FNL, 1598'FEL, Sec. 25, T13N, RSE, LR~. Btmhole Loc. 1446'FSL, 747'FEL, Sec. 24, T13N, RSE, UM. 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 testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Ch['~te~toh Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery _~ " STATE OF ALASKA ALASKA ,- AND GAS CONSERVATION C~,,,,IvllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Dr, ll~ Redrill F~I lb. TypeofwelI. Exploratory F1 StratigraphicTest ~J .DevelopmentOilF[~/ Re-Entry [] Deepen Service [] Developement Gas [] Single Zone ~r Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64', PAD 27' feet Kuparuk River Field Kuparuk River Oil Pool 3 Address 6. ~P.rop~e_rty~D. esionation P.'O. Box 1007,60 Anchorage, AK 99510-0360 AUL zz:,:)zz ALK 2558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20AAC 25.025) 950'FNL, 1598'FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit iStatewide 7At ~to~p. ,of productive interval 8. Well number Number 129 rbL 800'FEL, Sec.24, TI?,N, R8E, Uti] ?,M-14 ' #8088-26-27 At total depth 9. Approximate spud date Amount 1446'FSL, 747'FEL, Sec.24, TI?,N, RSE, UM 05/25/87 $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 3M-1:3 7247 'MD 747'~ Surface feet 18' @ 740'TVD feet 2560 (6476'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2 2 7 9 feet Maximum hole angle 350 Maximum surface 2 00 2 psig At total depth (TVD) 31 8 0 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) 24" 16" 62.5# H-40 Weld 80' ?,5' 35' 115' 115' +200 cf 12-1/4' 9-5/8" :56.0# J-55 BTC 3421 ' :35' :35' ?,456' :3?,8?,' 1200 sx AS I I I & HF-E[W 350 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 7217,' ?,4' ?,4' 7247' 6476' 200 sx Class G(minimum HF-EFW TOC 5,)0' above top of Kuparuk 19. 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 R~C~IV~D I n termed i ate Production IVlAY 1 9 !.987 Liner Perforation depth: measured Alas!(a 0il & Gas ......... r- ........ ,;..,...,. true vertical 20. Attachments Fil(np fee ~ Property plat [] BOP Sketch J~' Diverter Sketch ~ Drilling program ~ Drilling fluid pro~.a-~ ~(] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ,j~ 21.1 hereby ceC{ify Cst'the :: I '/fore/~..~ true and correct, to the best of my knowledge (FCIC/~ Si'*ned /// ~',/ ' //~/~* - ,. // Title Regional Drilling Engineer ~ '. / Z.,~//MZ//,~_ J',~_,.~.~_¥'~//'f.~;L~' Date / - / (,/ / /- ~ Commission Use Only (HRE) PD2/25 Permit Number_ / I APl number I Apprp, v~al¢C,a~e¢o-., I See cover letter ~., ¢ -_j ~ I ""'--" '~'~ '- :"-' / '~' "~ I for other requirements I Conditions of approval Samples required [] Yes ~ No Mud Icg require,d E3 Yes 'J~ No Hydrogen sulfide measures [] Yes [] No Directional survey required J~,'Yes [] No Required worki~~/~/~,~~M; [] 10M; [] 15M Other: by order of Approved by Ik~ ~,. ,.../ ..- t~.__~. f~_~,/~~ Commissioner the commission Dat Form 10-401 Rev. 12-1-85 ate KUPARUK RI VER UNIT 20' DIVERTER SCHEMATIC J L DESCRIPTION 1, 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD FMC DIVERTER ASSEMBLY WITH TWO 2-1 / 16" :2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/10" OUTLETS S. 1 O" HCR BALL VALVES W/10" DIVERTED LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION I 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER AN.Y CIRCUMSTANCES JG I1-5-86 i. 7 6 4 2 i i i I DIAGRAM #1 15-5/8' 5000 PSI RSRRA BOP STACK 1. 16" -'2.000 PSI TAN(CO STARTING FEAD 3. II' - 3000 PSI X 15,-5/8= - 5000 PSI SPACER SFK)OL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. I],.-,5/8' - 5000 PSI DRILLING SI:KX3L W/OO(E AI~ KILL LII~E~ 6. 13--5/8' - ~ PSI DOLSLE R.Nul W/I::IPE ~ ON TOP, 7. 13,-5/8' - 5(XX) PSI ~ ACQ.IV[JLATCR CAPACITY TEST I. (~Ea( ~ FILL ACO.MULATCR RESEI~OIR TO PR(PER LEVEl. WITH ~IC FLUID. ASSURE THAT A~TCR PR[SSURE IS 3~300 PSI WITH 1500 PSI ~ Cl' ~ REGI,LATOR. 3. ~ TI~Eo ~ Cl.__cJ~_ ~ UNITS SINU..TN~CiJS. Y ~ LI~iITS ARE CLOSED WITH Cl.i~q~IN~ ~ C~:'. 4. REO~ ON N~C REPC~o THE ACC~tr~',e~LE LC~R LIMIT IS 45 ~~ ~I~ T~ ~ ~ ~I ~I~ 13-5/8" BOP, STACK TIS.T. I. Fill ~ STA(]( AI~ CHO(E MN'~FO.D WITH ~IC DIESS. o 2. (I-ECl( THAT ALL LOa( ~ ~ IN ~=11 HEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN WITH RIJNqI~ JT ~ RIJN IN L(X](IX3~ LIllE VALVES ADJA~ TO BOP STAa(. ALL OTHER 4. PRESSI.RE UP TO 250 PSI ~ HCLD FDR I0 MIN. IN- (]~.ASE ~ TO 34300 PSI ~ FELD FDR I0 MIN. BLEED PRE~ TO 0 PSI. LIllE VALVES. CLOSE TOP PII:~ RAMB ~ ~ VALVES ON KILL A~D CHO<E LI~ES. 6.TEST TO 250 PSI ~ 3(XX) PSI AS IN STEP 4. 7. CCNTINLJE TESTING ALL VALVES, LI~.~o ~ CHO(ES WITH A 250 PSI LC~ AND 3000 PSI HIGH. TEST AS IN STEP 4. ex3 NOT pf~SSLR~ TEST ~ C~3KE TH~T NOT A FULL CLOSING POSITIVE SEAL Q-EKE. CN_Y FUNCTZCN TEST CliO(ES THAT DO NOT FUU.Y CLOSE. 8. OPEN TOP PIPE RAMS AN:) CLO~E BOTTCM PIPE RAMS. TEST BOTTOM PIPE PJV4S Ta 25e PSi AN) 3OOO PSI. 9.OPEN BOTTCIa PIPE RNaSo BA(X OUT RUI~NING Jl' I0. CLOSE BLIi~D RAMS ~ TEST TO 250 PSI PSI. MANIFCLD ~ LIliES ARE FULL CE NON-FRFF?ING FLUID. SET ALL VALVES IN DRILLING POSITICI~L 12. TEST STAI~I]:~IPE VALVES, KELLY, KELLY COCKS. DRILL PIPE SAFETY VALVE, ~ INSIEE BC~ TO 250 PSI MN) 3000 PSI. 13. RECCRD TEST II~FCRVlATION ON BL(]NOJT PREVENTER TEST FORM, SION. ~ SE]~) TO DRILLING SUPERVISDR. 14. PERFORM Q3VI:~ETE BOPE TEST AFTER NIPPLING UP WEEKLY TYEREAFTE~ F1JNCTIONALLY OPERATE B(]=E DAILY. II 510084001 REV. 2 MAY 15. 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 Y? 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 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 using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore,'ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5 / ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS i. Move in rig. 2. Install Tankco diverter system. 3. Drill 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. 10. 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 ~mas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. 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, set and test packer. 18. Nipple dorm blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKER:~ .~ ST IIUD CLEANER IIUD CLEANER ,, ..~ STIR _~ STIR CENTRI TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih Company ~ CO CHECK LIST FOR NEW ~L PERMITS ~ APPROVE DATE ----- 1 Is the permit fee attached (1)_--Fee ~ f-- ;f-~ ? ........................................... (2) Loc f/F --- (2 Chru 8) (3) Admin '"'~'Q~ ~'-;~-;7 9. (g 'thru 13) 10. ~f~, 13~) ~r 11. [10 and 12, 13. (14 thru 22) 3 thru 28 (5) BOPE (2 Lease & Well No. YES NO 2. Is well to be located in a defined pool ............................. ~ 3.. Is well located proper distance from prop~_rty line .................. ~ ' 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ ~ Is well to be deviated and is wellbore plat included .... ~. IS operator the only affected party ................. ...........[[l[-[l[-:[[lll[~ i'i' 8. Can pemmLt be approved before fifteen-day wait ......... __ 14. 15. 16. 17. 18. 19. 20. 21. Does operator have a bond in force .................................. 4~ Is a conservation order needed ...................................... Is administrative approval-needed ................................... Is the lease r~her appropriate ..................................... Does the well have a unique name and number ......................... Is conductor string provided ........................................ ~Z Will surface casing protect fresh water zones A~ Is enough cemmnt used to circulate on conductor and surface ......... ~A~ ... Will cement tie in surface and intermmdiate or production strings ... ~ Will cement cover all known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension and burst.. ~ IS this well to be kicked off from an existing wellbore ............ ~ ~_ IS old wellbore abandommnt procedure included on 10-403 ............ 22. Is adequate wellbore sepgration proposed ............................ /b~ 23. Is a diverter system required .......................... - ............. ~ 24. Is the drilling fluid program schematic and list of equi~t adequate ~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. ~.. 26' Does BOPE have sufficient pressure rating - Test to 30~ psig .. ~ 27. Does the choke m~m4fold comply w/API RP-53 ~May 84) .................. 28. Is the presence of ~S gas probable ................................. . For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .... = = Zoo., =e ·, 32. Additional requirements ............................................. ~ Geology: WWB WVA ! rev: 01/28/87 6.011 · INITIAL GEO. UNIT ON/OFF POOL CLASS STAIUS AREA NO. SHORE ~ ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. M ,VP OlO,H02 VERIFICATION LISTING PAGE 1 ;ERVIC~ NAME tRIGIN : IEEL NAME :72~5~ ~ONTINUATION 'REVIOU$ REEL TAPE HEADER ~ ~ERVICE NAHE =ED[T )ATE ~87/0~/26 IRIGIN ~F~IA ~APE NA~E ~ :ONTINUATION # lOl 'REVIOU$ ~APE : ~O~MENT$ ~b~$ TAPE, ARCO ALASKA, INC. 3M-14, APl 50-02~-21720 C{hE NAME {EDI~ ;ERVICE NAME ~ERSION # )ATE ~ ~AXIMUM LENGTH I 102~ ~iLE TYPE ~REVIOU$ FILE ~NEM CONTE~T$ :N I ARCO ALASKA, INC, ~N I KUPARUK /ANGI BE rOWN~ 13N ~ECT: 25 ~TATI ALASKA ~NE~ CONTENTS UNIT ~g'Pg CATE SIZE CODE 000 000 0~8 000 000 006 000 000 005 000 000 002 0~5 OUO OUO OU4 000 000 002 0~5 OOO 000 012 Ob5 000 000 006 Ob5 UNIT TYPE CATE ~I~E CODE ~RESI g ~* COa~ENT5 ** 000 000 OO! O05 :O~PAN¥ m ARCO ALASKA, INC, IELL = 3M014 :OUNT¥ = NORTH SbOPE OORUOGH iTATF = AbASKA lOB NUMBER AT AKCC: 72353 :UN #1. DATE LOGGEDI 04 JUN 87 ,DP~JIM KOMRING . :ASING = 9 625" ~ ~472' - BI~ $~zg g 8,5" ~:0 7208' ~¥PE FLUID = L~ND POLYMER ~ENSITY · 10,1 LH/G RM m ~ ~4 ~ 60 DF 'H = 9,5 ~C = 3,98 ~ ~0 OF 'bUID LOSS = 4,~ C3 NM ,A'f BHT m 2,401 ~ 142 DF IAXIMUM RECORDED TEMPERA~fORE = 142 DF IATRIX 8AND8TON~ <SEE FILE gDIT,O02 FOR 1,2" SAMPLED DENSI>T¥ DATA, INDUCTION SPHERICALLY FOCUSED bOG DAfA AVAIbABbE~ 7202 TO $~72'' FORMATION D~NSI~¥ COHPENSATED bUG (FDN) DATA AVAILABLE{ 717b' ~O 6194' COIPENSATED NEUTRDN BOG (FD DATA AVAILABLE{ 71 ' TO 6194" GA~HA RA2 IN CASING (CHL) DATA AVAILABLE{ 3490' TO 99~' DATA FORMAT RECORD ~NTRY BLOCKS ~YP~ SiZE REPR CODE ENTRY 2 1 66 0 4 I 66 I 8 4 '1~ 60 16 I 66 O. 1 6b 0 ~VP 010,H02 VER[FICA~IDN b1ST~NG PAG~ 4 NE~ SERVIC~ SERVIC~ U,'~IT APl APl API AP1 FIbE SIZ~ SPb R~FM 1D 'EDT .FbU DIL, bD [.,~ DIL ,P ;R DIb ;~ FDN :HOB FDN ~RHO FDN ~PHI FDN :A~I FDN ~PHI ~RAT FDN ~NRA FDN ~CN~ 'tNb FDN ;R CHL ~ENS CHh ORI)E~ ~ bOG T~P£ CbAS$ MOD ~U, COD~~OCTAb) F~ O0 000 O0 0 0 4 I 68 00000000000000 OHM~ O0 220 Ol 0 0 4 1 ~8 00000000000000 ~ O0 ~20 46 0 0 4 ! 68 OOO00000000000 u,,~ oo 12o ~4 o u 4 ~ 6~ ouooouoooooooo ~v oo o~u o~ o 0 ~ 1 e8 ooouououooooou ~A~Z O0 ~tO 01 o 0 ~ S 60 OUOOO0000UO00U ~ O0 ~3~ ~1 o u ~ ~ ~e ououououoooooo ~z oo ~1,~ ot o o e ~ ~ 00000000000000 ~/c~ oo ~su o~ o u 4 t 68 ooououooooooou ~zc~ oo a~e ol o u 4 ~ 60 uuououooouooou vu oo ~9o oo o o 4 1 ~ ououooououooou ~ oo 200 ol o u 4 I 68 ooooouooouoooo ~u oo ~o oo o o 4 ~ oe ouououououooou uo 420 ol, o u 4 j be ououououoooooo uo ooo oo o o 4 I ee ooououououooou c~ oo ~o ~1 o o ~ 1 6~ ououououoooooo CPS O0 330 JO 0 0 4 1 ~8 00000000000000 bB O0 635 21 0 0 ~ I 68 00000000000000 GAPI O0 310 Ol 0 0 4 1 68 O00OOOO0000000 bB O0 635 21 e 0 4 I 68 O00OO000000000 ~EPT tHOB ipHI P T IpH! ' C N L /HOB tPHI )EPT [P IHOB ~PHI ~EPT ~P ~PHI 722~,~000 '3 , OOO GR 2,~078 ORHO 33 ~4'15 NRAI' b77~ 000 TENS 7200,~000 srbu -36'28~3 GR 2,5:0 8 ORHO 3~,44~3 NRAT 2 412I DRHO 37 9883 NRAT 591 5000 TE~S 7000 0000 SFbO ~34 21,87 OR 2 3535 b4g 5000 6900,00~0 '30,'t813 GR 2,30bb ~RHO 49085J5 NRAT 3,b IbD 3 108,31~ 2484 TENS 0.1147 ~PHI 8 2' 97~6 ~NRA 3 2484.0000 GR '999 4,~. 709 iL, P 108.3125 TENS 0.1t49 L)PHI 2,9766 RNRA 5044,0000 GR 5028 2749 lbo 3125 TE~$ 0464 DPHI 2500 RNRA 0000. GR 7 2135 '78 ~750 -0 0034 OPHI 3 2363 4840 '0000 GR 1.5909 ibp 108,1875 TENS 0.0112 OPHI 3.9453 RNRA 0000 UR ~174 CAb! 1602 NCNb 2500 TE~$ 2,8346 ibm 50128.0000 OR 3.2891 NCNb "999.2500 TENS 5,8332 4840.0000 OR 17;968i8 CAbI 3,5645 N C N L, -999,2500 TENS ! 5009 ibm 4840 O000 OR '20 ~Og7 CAbI 4,3008 NCNb 108'3 214o,0000 ,,~99,2500 -999,2500 .. ,. i875 · 1~2'~,0000 ,VP OlO,H02 VER/IflCAT,LU~ 4IS'I'ING PAGE: 5 ~EPT ;P [~01~ 'C:N L P IHOB tPH! ):lip T 424.25~0 TENS 45 0664 NAAT 537 UOOO TENS 6700 0000 SFbL) -41 UO00 GR 42 ~99 NAA~ 446 5000 TEhS 6600 0000 SFbU =40 ~6S7 G~ 526 5000 TENS 4840.000U GR 1 9594 lbo 108 1875 TENS -0 0103 DPH! 3 5645 RN~A 4784 0000 GR 4 130 0 3 4600 75O TENS 5527 0000 GR -99V,2500 TENS 4784,0u00 GR 11'221b CAb! ~.5508 aCNb -999,2500 2'ENS 2,9490 AbM 4600,0000 GR 17,61~6 CAb! 4.159~3 NCNb '999, 0 i'ENS 3,~190 IbP ~:2797 Lb~ 215, O0 T6NS 144 ~2 0 ~,0044 ~PH! lj, ~0 GR 06 CAb! ,4512 RNRA 3,7441 NCNb · 4444e0000 GR 9990 500 TENS )EPT 6400 0000 ~P ,,52:46b~ GR tHOB 2 ,: .4.648 DRHO IPH! 3b~liBB NRAT 'CNb 557,0000 tPH! ~CNb )EPT ~P tHOB {PHI )EFT ~HOB ~PHI 4,1~20 lbo 9400 3 754 RNRA 4,~474 103,937 0,004~ TENS 3,3340 RNRA 4224,0000 GR 2.9828 117 ~ 1250 O, 0410 3,5879 RNRA 4180.0000 GR 12 '50'00 T~NS 0,0186 DPHI 3.5195 RNRA 4224,0000 OR 3 3460 lbo 93 0000 TENS 0 0591 PPal 3 4063 RNRA 6100 O0 SFbO .6 1o o 0000 GR 2,::J8B7 ORHO 42,0898 NRAT 530;0000 Tg~S 6000,0000 SFbV -6506875 GR 39,2090 ~RAT 4348j,1131 AbM ,0000 O R 11,2216 CAb! ...99.~'b527 NCNb ,2500 TENS 4272 9 ~bM 25 NCNb oo ~EN$ 4224, OR ; CAb]: '99 :'' TENS 3 -999 0000 OR 1809 CALl 6465 NCNb 3 4224 '999 381 CALl · 2~0o .C b 3.4158 IbM 4090,0000 GR 11.4583 CAb! 3,1699 NCN~ '999.2500 2 197 lOU 1871 ~ ~750 1901 ~000 0~9~ 250~ 13~ 9587 ~7~0 1~74 0000 ~99~ 2500 2,42~7 a,9141 1971,0000 -~9 ,2500 -99),.2~00 · 3 9442 -~ ~ 2500 1o! 2094 ~00 .999 2500 · 99~.2500 3g'7 1~ O0 ~ gOO $ 4274 93 ~000 ~B46 0000 VP 010,H02 VFRIFICATION bI$2'ING ~AGE ~ 582,0000 TENS 4090,0000 GR EPT 5~00,0000 SFhU 0 66,5000 GR S 2,5234 DRHO PHI 37,402J NRAT CNh 54~,b000 "£E~S 4 1326 98 0625 177 0~ ~047 4024 0000 EPT 58~0 gOO0 SFbO P -12 2500 GR HOB 2 4297 DRHO PHI 36 2305 NRAT 'CN~ 531 0000 TENS 0000 'EP']' 5700,0000 SFblJ ~P "1.2.,265~ GR HOB 29:41b0 OR"O PHI 3 30bb NRA'r ~CNb 566,5000 TENS 106 0 3 3924 0244 4688 0000 'EPT 560.0,0o00 SFbU .P O,OOOb GR ;HOB 2793. DRHO 0 59{)3 117 6250 0 0479 3 4160 3884 0000 ~gPT 5500,0000 SFbO ,P -12,257~ GR ::HOB 204043 DRH:O 'tNb 516,'5000 TEN6 9 0625 O 566 4219 OOO0 :HOB 2 6 DRHO 15 374 0,1250 O, 0303 4,2500 0; 0000 !EPT 5300,0000 ~FbU H 10 !PHI 42,43Ib NRAT *CNb 506;2500 TENS 369 2,6~95 0,0'2 3,5625 4,0000 )EPT 5200,0000 SFbO ~P' ,,7,0039 GR IHOB 2,3984 ORHO IPHX 44.3848 NRAT 'CNb 487,2500 TENS 367 3,42 e 3 9,4375 O547 4;0000 5100,0000 ,5FL, L{ 2536 DPHi RNRA RNRA GR UPH! RNRA GR TENS DPHI RNRA GR R~RA ib:D E ~t 8 PHi RNRA T~b:D OR RNRA -999,2500 IEN$ 0000 GR 13,3523 CAb! ~:1d750 NCNb 2500 TENS 3 46.53 3924 0000 14 1809 3 4121 -999 2500 CAbI NCNb 1,7063 IbM 38~4,0000 GR ~,4669 CAbI ,8203 NCNb "'999 ;2500 TENS 3890,0000 (jR 14,891! CibI 3,8047 N.~Nb *999~2500 TEN~, 3694,000~ GR 16,666 CAb! . 3;8320 NCNb 999,2500 3674':~030 OR 15'2462 CAb! 4 ~ !{67 NCN -999 ' 2500 2,~664 lb~ 3740*0000 GR 20,3362 CAbI 4,0664 NCNb -999,2500 ~,8582 9~9766 ~4~eO000 2999,~500 i !";oooo 9,2500 10~,8125 1933,0000 , 113 040 U000 2500 · -9;9~, ~0 ~00 -'9 i O 0 I 0:~ 194O ,:00 · ' 999 ,00 ,. 191~ 0000 ,VB OIO.H02 V£AIFICATiO~ LISTING PaGE 7 'CNb 470, 3740,0000 GR 5 8 2'2]1~5 , 3 695 4, o.,] iPHI 44 'tNb 482 0000 SFbU 7500 GR !896 000 ~0 010 3 7012 3514 0000 I~PT 4800 [HOB IPHI 44 '¢Nb bO{ UOOu SFbU 250o OR 3262 DRHO 5801 NRAT OOOO TENS 2 -U 3 3424 7168 o000 )EPT 4700 iP '14 ~HOB 4~ iPHZ 'tNb 552 000o &FLU 7656 GR 000o TEN8 2 97 0 336~ ,8972 .~750 ,0000 EPT 4600 ~HOB 2 ONE, 50i O00U &FbU 2613 GR 3770 DRHO 7480 NRAT OOUO TENS 2 10{ 0 3 3454 2 0586 0~000 t~OB 0:l,~;4844 Ga ,j 3027 DRHO IPHI 4 ~,ii51e, NRAT 'CNG 598,0000 TENS 3460,0000 I~PT 440 {PHI 39 'CNb 563 o0oo SFbO " DRHO 20 NRAT UO00 TENS 3 3323~ 4375 0000 )EPT 4300 I~0~ -22 2 {PHI 41 ~CNb 470 68 DRHO 74 NRAT 5000 T£N~ 2 108 0 3 3!74 ~2 5 5 0~02 0 Pit 4200,0000 .S. FbO { -24,75o0 GR iPHI 42.b270 NRAT 2 101 -0 3 7619 8750 0024 5859 lbo DPHZ RNRA GR DPH! RNRA GR TENS OPHI RNRA GR TENS DPHI RNRA GR DPH]: RNRA GR IbD DPHi ENRA TENS DPHI RNRa GR ILO DPHI RNRA '999,2500 2,5169 3530,0000 1b,5483 '"999, O0 .1514, 0 20, 13 °o 2 19 ~596 -999 ~J 0230 CAb! NCNb CAbI CAb]: NCNb TENS OR NCNb 3,0~01 Ib~ 34~4,~ O0 GR 16, 483 CAbl 3,6{20 NCNb '999,2500 TENS 3,4953 ~LbM 33)14,0000 rjr 3,b172 NCNb -999,2500 TENS "99 2500 2994, 24 0057 3 4199 CAb{ NCNb GR '999.2500 .. ,5000 ,0000 '9 ~,2500 1895 0000 -99{ 2500 I9429 10 9315 64~4 oooo 9 2500 25.80 ,.999 lO0 ~4 29 ~00 O~ 08 l 99 2500 10~,u919 , ti 750 ~,~1297 :1.770,0000 blT,bO00 TENS ~EPT 4100,O009 SFbO IHO8 2,2422 DRHO -L 448,0000 TEhS ~P tHOB iPHI 'CNL [P ~HOB {PHI 'CNb tpH! ~CNb [p [HOB ~CN~ )~PT IHOB }PHI ~CNb )EPT {HOB 2994,0000 2,7032 93 ,~125 O: 083 3010 000 3 5147 93 6250 0 0093 3 5977 2944 0000 3700,0000 SFbU 2500 GI~ "31'2%872, ORHO 47~ bSO NRAT 414,~500 TEN& 3600O'~ U -36 2 ~0 2 ~ 9o 4O 46J ~ O0 3500,0000 -41,0~625 2,2168 43~5059 520550O0 DRHO NRAT TENS S[bU G DRHO NRAT 34O0 -999 -999 -999 -999 0000 2500 2500 2500 25O0 NRAT TENS 3300 -999 -999 -999 5FLU G~ NRAT OOUO 2500 2500 2500 4,,] 99 98, ')50 2754, :0000 -0 ~0 3 8691 2764 0000 71~· ' o 078 3 5449 2730 0000 9] 8857 4375 0 0073 3 ~OJl 2534 000 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 -999 2500 GR TENS RNRA RNRA DPHI RNRA OPHI RNRA GR ILD TEN5 DPH! RNRA GR DPHZ RNRA GR NS DPH ! GR TENS DPHI RNRA GR ZLD RNRA '999,2500 3,0173 3010,0 4,1 ,i45 '999,2500 '9 2,50~7 2 44~00 0 '999, 0 2754~ 0 24 '1241 99~ 0000 - 2500 2 7649 2754 0000 26 ,1364 4 -999 t§00 0000 b3 7282 8555 '999 2500 ~R GR NCNb CAbl NCNb CAbl TENS CAb! NCNb UR CAb! NCNb TENS 3¸ 7 ,70~0 NCNb ,, 750 TENS -999 2500 -999 2500 -999 2500 '999 2500 5'0 4063 -999,,2500 '999,2500 '999'2500 '999,2500 OR CAbI NCNb CAbl NCNb -999,2500 9 1 -99 ,74215 ,2500 2,9t7) 94.4101 . ooo ,2500 .¥P 010.H02 VERIFZCA'I'[UN bJST.[NG PAGE 9 -999,2500 TENS -999,2500 GR 'EPT ~200,0000 SFbU -999 'P .999,250V GR -999 iHOB 999. S ORHO -999 I -999,~50 O0 NRAT '999 'EPT 3100,00o0 SFbU ,,999 'P -999,2500 GR -999 'HOB ,,,999,2500 DRHO ,,999 PHI -999,2500 NRAT '999 ~CNb -999.2500 TENS -999 ~EPT 2900,0000 SFbU -999 'P -999,2500 GR -999 :HOB '999,2500 DAHO -999 'PHI '999,2500 NRAT '999 'CHh -999;2500 TENS -999 500 IbiJ 500 TENS 2500 DPHI 2500 RN~{A 2500 GR 500 lbD $00 iENS 500 DPHI 2500 GR ~ O0 I~00 TENS 500 DPftI 500 RNRA 2500 GR 2500 TENS 500 DPH[ 500 RNkA 2500 GR ~ 0 ,H B "999 500 DRHO iPHI ~999 ~SUO NRAT 'CNb -999 2500 TENS -999 '999 "999 T~NS iO0 RNRA i:~PT 2600,0000 SFbU -999,~500 -999,2'500 GR -999'2500 TENS iHOB ~999~2500 DRHO ~999;2500 DPH! ~PH! -999,2500 NRAT -999,2500 RNRA 'tNb -999,2500 TENS -999,2500 ,.EPT 2500,0000 ~FbU ~:P -999,2500. GE TENS ~PH! -999,~5o0 NRAT RNRA ~CNb -999.2500 TENS GR 'EPT 2400,0000 SFDU ip '999,2500 GR :HOB ~999.2500 DRHO ipH! -999,2500 NRAT , -999 2500 IhD -999 2500 TENS -999 2500 ~PHI -999 2500 RNRA 5b.3125 ~ENS IbM GR CAb! NCNb TENS -999 ,,,999 -999 ,.999 58 UR 2500 CAb[ 500 NCNb 938 TENS -999 -999 -999 '"999 40 2500 UR 2500 C~bI 2500 N NM 0313 TENS -999,2500 IbM -999'Z$00 UR .,999.Z$00 CAbX -999.2500 NCNb 54,5625 TENS -999,~_500 ZbN '999,,~00 GR '999,~$00 CAbI '"999.~500 NCNb 31.$125 TENS '9 ,00 OR -999 500 CAb! -999 )0 NCNb 99,~500 CAb! NCNb TENS -999 2500 ibm '999 ~$O0 GR -999 500 CAbI -999 2500 2~9~,0000 -99~ SO0 2~50 000 O0 -~9~,Z500 -~9{,2500 · ~ - ~00 , O0 -~ 00 -! O0 2015 ~000 500 .,II 20 ~000 =~ I500 -99 }00 "99 }00 ~91 OOUO '~9~,2500 -99~'2500 '999,2500 ,VP OlO,H02 VEi. ilFICAI'ION LISTING PAGE 'CNL -999.25U0 TENS ~EPT 2300,00uo &FLU -999,2500 ! -999,2500 NRA'~ 'CNL -999,25U0 TENS ~EPT 2200,0000 SFbU ip -999,2500 GR :HOB -999,2500 DRHO fPHI -999;~500 NRA~ 'CNh -999, 500 TENS ~EPT 2100,0000 ~FSU :HOB -999,2500 DRHO ipH! -999,~500 NRAT 'CNL =999, 500 TENS iHOB -999,~500 DRHO ',tNb .999,' "00 AT IHOB ."-- ,2500 GR -999~2500 TENS ,,999,2500 GR - 99' 9,2'5 O 0 D R hO~ ~P:HI .,999.2500 Nt~A 'CNb -999,2500 TENS ~PT 1600 ;P '999 ',HOB ,.999 ~PHI -999 ~CNL, -,999 ~EPT :HOB ~PH I 25.00 GR SOO DRHO 1500,0000 "999,2500 -999,2500 GR N~AT 'g99.2500 GR -999 2500 -999 2500 =999 2500 -999 2500 -999 2500 DPHI ,.999.2500 iLD "999;~500 TENS '999, 500 DPHI -999,2500 GR -999 2500 "999 2500 -999 2500 -999 2500 -999 2500 -999 2500 '999 2500 "999 2500 "999 2500 "999 2500 -g99 ~500 '"999 2500 "999 2500 "999 2500 "999 2.500 iO0 ~00 '999 ,00 '999 "999 '9 -9.~ "999 iO0 '999 ~00 "'9'99 '~500 -999 2500 '"999 2500 2500 '"999 2500 -999 2500 -999 2500 -999 2500 -999 2500 DP~I GR IUD DPHI RNRA GR TENS DPHI X6D TENS DPH RNRi G~. tENS DPH! RNRA GR DPHI RNRA GR TENS DPHI RNRA 36.4375 -999 2500 -999 2500 -999 2500 37 GR CAL, I ' 0 -999.25 0 I~ -999.2500 OR -999.2500 CA~I -999~2500 NCN~ 43,0313 ~ENS -999 2500 IbM =999 2500 OR -999 2500 CAb! -999 2500 NCN~ 37 2500 TENS -999 2500 "999, 500 -999,, 5 0 42; l~? NCN ..999 2500 '999 ~500 '999 500 '999 ~6500 30 563 '999,1500 =999, 500 -999, 500 33, 938 ~1500 ~ O0 -99~ 2500 41 250o -999 ~500 -999 2500 O0 -999 ~00 0999 23 0469 IbM GR CALl NCN~ TENS ~R CAbI TENS CAI,! NCNb R C t.,! lalb,O000 -9992500 500 0 ~0 1740,0000 -99{~ 500 -99~ 500 -99~ 2500 lb85~0000 '999'{100 -999, O0 -999, O0 1645,9000 '999 500 '99~t 0 =99~ 0 1595 000 -999. O0 ~, O0 -~9~ ~500 1550 0000 -999 O0 -~99 ~0 -999 0 1490 0000 2 {00 !°° 5OO -99~t ' 500 145~ 000 0 -999,2500 ibm -99~1,I 0 -999,2500 NCNb -999, 0 -999,25U0 TEN5 teT i, ou, ouo SEbO P 999,25V0 GR HOB -999'2500 DRHO tnb -999,2500 TENS £PT i'O0 P HOB -999 PHI -999 CNb -999 'EPT P HOB PHI UOUO SFbU 2500 GR 1200 0000 SFbO -999 2500 GR -999 2500 DRHO -999 2500 NRAT -999 2500 TENS SFbU GR :HOB DRHO iPH! NRAT ':CNb 'EPT i000,0000 ~rbU i,,p '999,2500 GR JPHI '999.2500 NRAT 'CNB -g99.:2500 TENS ;HOB -999 500 DRHU -:999 ~500 NRAT -999,2500 G~ -999 2500 lED -999 25~0 TENS -999 2500 ~PH! -999 2500 ~NRA -999 2500 GR -999 °999 -999 -999 -999 i500 5O0 2500 UPHI 2500 GR '999.2500 lbD '999,2500 TENS '999,~500 DPHI "999e 500 RNRA '999,2500 GR -999,2500 lbo '999"2500 TEN~ '999,2500 DPH! '999.22~00 RNRA -999; O0 GR -999, 500 lbo -999,~500 ~999t~500 DPHI '999, 500 RNRA ~999~ 500 RNRA ,.999 2500 GR ;~RVICE 'ILE TYPE 'Ibg NA~ :EDIT ,002 32.2500 -999 ~500 GR '9~2 1500 NCN 750 TENS -9 500 IbH -9~9' 500 OR -991! 500 CAb! e99 2500 NCNb 3 1562 TENS -999 2500 IbM · ,999 2500 UR =999 500 CAbl · ,999 500 NCNB 31 063 TENS -999,2500 '"999,2500 OR -999,2500 CAB/: ..999 -999 ,.,999 ,.,999 0 C ~ BI O0 NCNb '999 O0 GR -999 O0 CAbl -999 O0 NCNb 355938 ~ENS PAGE 11 .,,, .,,, ° 0 -999 2500 1315 0000 -99~ 2500 -~9~ ~500 -~9~ 2500 -~9~ ~500 I280 0000 -~99 2500 -~9~ 2500 -99~ 2500 12~b 0000 '~ '~00 -~9~;2500 ~0000 -~99'2500 l~JO~OO00 ~9~ ~'9~ ~00 -999 1130 )00 VP 010,H02 VERtFICATIDi~ 1,~$1'I~i~ PAGE 12 ATE : AXIeUm LENGTH : 1024 IbE TYPE : REVIOU$ FILE; : ERi'T,O01 FOR 6" SAMPLED DIbtFDCtCNLtGR DATA) ~ FORmAtION DENS[~¥ COMPENSATED bOG (FDH~ ~ DATA AVAIbAB.~E~ 7176e TO 67~8 ~ * DATA FOR~A? RECORD ** 2 ! 66 0 S 4 7~ 12 9 4 65 ,lIN 0 1 6b 0 ~VP OlO,H02 VERIFICATI[Ia LI$I'ihG PAGE 13 ~ATU~ SPECIFICATIbN ID ORDE~ ~ LOG ~¥PE CLASS aOD NO, ~EPT FT O0 00~ O0 U 0 4 ;R FDH GAPI O0 319 91 0 O 4' :HOB FOH G/C3 O0 3~ 02 0 O 4 'RHO FDH G/C3 O0 356 Ol 0 0 4 ~PHI FDH PU O0 890 O0 O O 4 iAbI FDH IN O0 280 01 0 0 4 'ENS FOH LB O0 b35 21 0 g 4 CUDE 0 TAb 1 b~ O0000OOiO~O00~ I 68 OOOOOUOOO00000 1 68 OUOOOOOOOOOUO0 1 68 O00OOOO0000000 1 68 O0000UO~OUOOOU I 68 O00000000UO000 I ,80UOOOOO00OOO00 ~EPT 7221.3994 GR ,882b CAb! 7200,2998 G~ 3,8826 CALl 7100,2~98 GR 14,7727 CAbI 7000.~v8 GR 17, So CALl 690U,299~ GR ~9,~b27 CALl 6800,299~ GR 7,4337 CALl 6748~29~ GR 17~25U5 CAbI 'EPT ~EPT ~EPT {PH! ~EPT iPHI ~EPT ~EPT ~,PH ! 92.3125 RMOB 8,b172 IE~S 92 RHOB 97,b875 RHOB 8.8125 TENS 85,1250 RHOB B,6250 TENS 11~.~125 RHOB , 688 ~E~S 9,27 TE~8 114,b250 RHOB 9,3750 TBN$ 2,5859 ~RHO 2130,0000 2,5859 4952,0000 2,~06.3 URHO 5044. 000 , 3591 DRHU 474 ,0000 4064, 2,5273 DRHU 4588,0000 2,3652 DRHO 4524,0000 0,1582 0,15~2 0,0195 0,0200 O,OlLb O,OO~9 'XbE_NA~E IEDIT .002 ;ERVICE NA~E ; ~ATE ~ tAX1MU~ LENGTH ; 102¢ 'ILE TYPE { {EXT FILE NA~E = :* TAPE TRAILER ;ERVICE NAAE :EDIT ,ATE =87/06/26 )RIGIN :FSIA 'APE ;O~TINUATION ,VP OlO,H02 VERIFICAI'IUN LISTING PAG~ 14 'OMME~TS l~IS TAP~v A~CO AbA~KAv I~C, 3M-l~ API 50-029-2172b tgB~ NAMB ~72~53 :ONTINUA~ION # 201 tEXT REgL ~AM£ = 'DMMENTS ~6IS TAPE, ARCO A6ASKA, IN'C, 3M-14, APl 50-029'2172b
