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196-112
RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION H_ 2 7 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LOG,r. 1a.Well Status: Oil El Gas 11 SPLUG El Other ❑ Abandoned ❑ • Suspended 1b.Well Class: - ` 20AAC 25.105 20AAC 25.110 Development 11' 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. Aband.: 6/23/2015 196-112/315-316 3.Address: 7. Date Spudded: 15.API Number P. O. Box 100360,Anchorage,AK 99501 7/2/1996 50-029-22684-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 23'FNL, 14'FWL, Sec.29,T12N, R9E, UM 7/9/1996 KRU 3F-18 Top of Productive Interval: 9. KB(ft above MSL): 96' 17. Field/Pool(s): 2592'FNL,332'FEL, Sec.30,T12N, R9E, UM GL(ft above MSL): 42' Kuparuk River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2772'FNL,349'FEL, Sec.30,T12N, R9E, UM 6274'MD/5691'TVD ADL 25643 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 508514 y- 5985800 Zone- 4 6868'MD/6236'TVD 2574 TPI: x- 508180 y- 5983231 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 508164 y- 5983051 Zone- 4 nipple @ 516'MD/516'TVD 1624'MD/1546'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No E 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 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 NONESCANNED .1 ` ?s�l� 23. CASING, LINER AND CEMENTING RECORD WT PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRDE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 62.5# H-40 42' '121' 42' 121' 24" 262 sx AS I 7.625" 29.7# L-80 41.5' 3481' 41.5' 3180' 9.875" 800 sx AS III,290 sx Class G 5.5"x3.5" 15.5x9.3# L-80 37' 6858' 37' 6227' 6.75" 200 sx Class G 24.Open to production or injection? Yes ❑ No a 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): 3.5" 6321' no packer perfs squeezed off 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No El Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 6274-6600' 18 bbls cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 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 -► Form 10-407 Revised 5/2015 Z //5 C INUE N PAGERBDM AUG 2 7 2015 Submit ORIGINIAL onlya �P3i s 28.GORE DATA Conventional ore(s): Yes ❑ No ❑., Sidewall Cor .. Yes ❑ No Q 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. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No E Permafrost-Top surface surface If yes,list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1624' 1546' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Kuparuk C 6411' 5817' Bottom Kuparuk C 6490' 5889' Top Kuparuk A 6601' 5990' Bottom Kuparuk A 6752' 6129' NONE Formation at total depth: 31. List of Attachments: Summary of Daily Operations,wellbore schematic 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 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. pp Contact: Ron Phillips @ 265-6312 Email: Ron Phillips@cop.com 1i` Printed Name: Dan Venhaus Title: CTD Engineering Supervisor Signature: C; � L '`�v` Phone: 263-4372 Date: ZZ i_S 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 1 a: 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 1 b: 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 and Ground Level elevations in feet above mean sea level Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 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 AAC 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 AAC 25.071. Item 31: Pursuant to 20 AAC 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 5/2015 Submit ORIGINAL Only • KUP PROD 3F-18 ' ConocoPhillips i° Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Statusncl(") MD(ftKB) Act Btm(19(B) Con• tt' •l64n 500292268400 KUPARUK RIVER UNIT PROD ' 28.59 3,755.40 6,868.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) -Rig Release Date 3F-18,615/20154:15:55 PM SSSV:NIPPLE 150 _Last WO: 12/4/2008 7/11/1996 Vertzalschematic(actual) Annofatlon Depth(ftKB) End Date Annotation last Mod By End Date -Last Tag:SLM 6,630.0 7/31/2014 Rev Reason:SET PLUG,CEMENT SQZ hipshkf 6/5/2014 HANGER ... 3r, 36.8 fi J jj Casing Strings Casing Description OD 0n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread �yT CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED L`J Casing Description 00(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)..."WULen(I...Grade Top Thread SURFACE 75/8 6.875 41.5 3,481.3 3,180.2 29.70 L-80 BTC-MOD Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 51/2 4.950 36.8 6,858.0 6,227.0 15.50 L-80 LTC-MOD Tubing Strings Md./'r ."Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.'Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;42.0-121.0-O. A TUBING 31/2 2992 36.8 6,333.3 5,745.5 9.30 L-80 IBT Completion Details Nominal ID EA Top(ftKB) Top(ND)(ftKB) Top Incl 0 Item Des Com 0.10 HANGER FMC 3 12"x 7 1/16"5M TBG (in) NIPPLE;516.1 36.8 36.8 Hanger w/3 1/2"IBT Pup 3.500 516.1 513.7 13.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 6,277.4 5,694.3 23.45 NIPPLE Camco 2.812""DS"Nipple 2.812 6,320.4 5,733.8 23.57 SEAL ASSY Baker Seal Assembly 80-40 GBH22 w/locator(2.00' 3.000 ' spaceout) GAS LIFT;2,739.9 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top loci __--- Top(ftKB) (ftKB) C) Des Com Run Date ID(in) 6,600.0 5,989.5 23.63 PLUG 'CBP 6/2/2015 0.000 Perforations&Slots I ) Shot Dens SURFACE;41.5-3,481.3- Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com -- 6,412.0 6,419.0' 5,817.6 5,824.0 C-4,3F-18 2/4/1999 4.0 APERF 2 12"HC-DP,180 deg t-� pH,+/-90 deg GAS LIFT;3.9477 g 6,419.0 6,425.0 5,824.0 5,829.5 C-4,3F-18 12/26/1998 4.0 APERF 2 12"HC-DP,180 deg F?i pH,*/-90 deg -- 6,425.0 6,428.0 5,829.5 5,832.3 C-4,3F-18 2/4/1999 4.0 APERF 2 12"HC-DP,180 deg pH,*/-90 deg 6,480.0 6,490.0 5,879.8 5,888.9 C-1,3F-18 5/11/2002 6.0 APERF 2.5"HSD,PJ DP,60 deg GAS LIFT;4,9688 '4 pH 6,621.0 6,641.0 6,008.7 6,027.1 A-3,3F-18 7/27/1996 4.0 IPERF 2 1/2"HSD,180 deg pH 6,664.0 6,684.0 6,0482 6,066.6 A-3,A-2,3F- 3/22/2009 6.0 APERF 2 1/8"PJ,45 deg phase 18 Cement Squeezes GAS LIFT;3696.8 -Ir Top(TVD) Btm(ND) Top(BOB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 6,350.0 6,600.0 5,760.9 5,989.5 Cement Squeeze 6/4/2015 CEMENT SQUEEZE Mandrel Inserts st GAS LIFT;6,223.8 4 on N Top(TVD) Valve Latch PortSizeTRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,739.9' 2,516.0 Camco KBG-2- 1 Gas Lift DMY INT 0.000 0.0 7/11/2011 9 2 3,947.7 3,594.7 Camco KBG-2- 1 Gas Lift DMY INT 0.000 0.0 7/11/2011 9 NIPPLE;6,277.4 - 3 4,960.7 4,500.0 Camco KBG-2- 1 Gas Lift DMY INT 0.000 0.0 7/10/2011 9 4 5,696.8 5,163.7 Camco KBG-2- 1 Gas Lift DMY INT 0.000 0.0 8/10/2009 9 5 6,223.8 5,645.1 Camco KBG-2- 1 Gas Lift DMY 'INT 0.000 0.0 12/6/2008 9 Notes:General&Safety End Date Annotation SEAL ASSY:6,320.4 ': 10/10/2005 NOTE:Surface CSG patch @ bottom of mandrel hgr,39"L X 8"OD,X65 pipe - ' III 4/9/2008 NOTE:NIPPLE @ 517'w/2.812"ID,BUT GAUGED TO 2.80" 12/6/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 7/19/2011 NOTE:RAN VIDEO ON CASING DAMAGE IN 3.5 LINER FROM 6625-6632 APERF;6,4120-6,419.0 1 APERF;6.419.0-6,425.0 12 APERF;6,425.0-6,428.0 APERF;6,480.0-5490.0 PLUG;6,600.0 ��/ IPERF;6,621.0-6,641.0 APERF;6,664.06.684.0 PRODUCTION 5.5-x3.5;36.8- L 6,858.0 018 PRE-RIG WELL WORK DATE ' SUMMARY 5/10/2014 TAG TD @ 6634'SLM; UNABLE TO DRIFT THROUGH KNOWN OBSTRUCTION @ 6384' SLM W/2.69" DMY WRP; PUMP 75 BBLS OF DIESEL W/776; UNABLE TO DRIFT PASS 6384' SLM W/2.69" DMY WRP OR 2.55" CBP; DRIFT CLEANLY W/2 1/8" DMY IBP DOWN TO 6630' SLM. READY FOR E-LINE. 5/27/2014 TAG FILL AT 6668'. LOG MULTIFINGER CALIPER FROM TAG TO SURFACE. LOG CORRELATED TO SLB CEMENT BOND LOG DATED JULY 27 2006. JOB COMPLETE. 7/31/2014 DRIFTED TBG WITH 2" BLR ASS'Y&TAG @ 6630'SLM (EST. 24'OF FILL/NO SAMPLE OBTAINED); MEASURED BHP © 6660' RKB (2968 PSI). BRUSH n' FLUSH KNOWN TIGHT SPOT @ 6380' SLM. DRIFT TBG WITH 17.5'x 2.625" DMY WHIP STOCK(UNABLE TO PASS KNOWN TIGHT SPOT @ 6380' SLM). JOB COMPLETE. 12/6/2014 B&C CTU#1: DRESS 'WRINKLE' IN 3-1/2" LINER AT 6386' CTMD WITH BAKER RH MOTOR AND 2.80" OD DIAMOND STRING MILL WITH 2.80" DIAMOND PARABOLIC MILLS. MULTIPLE PASSES WITH GOOD MOTOR WORK. ABLE TO DRY DRIFT PROBLEM AREA. READY FOR SLICKLINE TO REATTEMPT DUMMY WHIPSTOCK DRIFT. 12/9/2014 UNABLE TO DRIFT THROUGH BAD SPOT W/2.62"WHIP STOCK DRIFT @ 6390' SLM, JOB COMPLETE 1/8/2015 RIH WITH 2.63"WHIPSTOCK DRIFT, MADE IT THROUGH THE PROBLEM AREA OF 6420'WITHOUT NOTICING ANY WEIGHT CHANGES, RIH TO 6600' CTMD, MAKE 3 PASSES FROM 6350'CTMD TO 6600' CTMD TO CONFIRM NO ISSUES THROUGH PROBLEM AREA, F/P TBG TO 6600'CTMD, JOB COMPLETE. 3/13/2015 (PRE-CTD) FUNCTION T LDS ALL OK, T POT PASSED, T PPPOT PASSED, IC POT PASSED, IC PPPOT PASSED 3/19/2015 (PRE-CTD) MITOA- IN PROGRESS 3/20/2015 (PreCTD) : MIT-IA(PASSED)TO 3000 PSI, MIT-OA(FAILED)TO 1800 PSI. 4/4/2015 (PRE-CTD) : SCLD PASSED TO 1400 PSI. 6/1/2015 LATE START DUE TO TRACTOR SWAP AND T-BAR ISSUES, RIH AND DRIFT TBG WITH 2.65" NOZZLE AND NIPPLE LOCATOR, HARD TAG AT 6636' CTMD (A- 3 PERFS), LOCATE NIPPLE AT 6259' CTMD (-18'CORRECTION), F/P TBG, JOB IN PROGRESS. 6/2/2015 PERFORM WEEKLY BOP TEST, RIH FIND "DS"NIPPLE, CORRECT TO MID ELEMENT, SET CBP @ 6600' MID ELEMENT, PERFORM INJECTION TEST, @ 1 BPM= CTP 1576, WHP 798, IA 257, OA 395, 2BPM= CTP 3335, WHP 856, IA 251, OA 396 ****JOB IN PROGRESS**** 6/3/2015 RIH TO CBP, CORRECT TO 6600' PICK UP 5' LAY IN 14 BBLS, TRY TO BUILD SQUEEZE PRESSURE OF 1,000, NOT ABLE TO ACHIEVE PRESSURE. CONTAMINATE CMT AND CHASE OUT OF HOLE. JOB IN PROGRESS 6/4/2015 RIH TO FLAG AT M 6263' E 6260', CORRECT TO 6274' END OF TOOLS. BATCH UP 18 BBLS OF CEMENT 11 OF WHICH HAVE CemNet IN IT, LAY IN CEMENT WHILE GETTING 1:1 RETURNS, DID HESITATION SQUEEZE AND WAS ABLE TO REACH 1000 PSI, DROPPED 7/8" BALL FOLLOWED WITH 60 BBLS POWER VIS. CLEANED OUT DOWN TO 6340', CHASED OUT OF HOLE SLOWING FOR ALL JEWELRY. ****LET SET FOR 72 HRS JOB IN PROGRESS**** 6/10/2015 Initial tubing pressure test pre-milling was 1,252 psi and fell to 1,232 after ten minutes. Correlated depth to DS Nipple and painted flag. Milled cement from 6,340'to 6,380'. Unable to get past this area of known "wrinkle" in pipe. Several stalls then lost circulation pressure. Inspected BHA once on surface and determined that motor was bad. Will return and run a 2.80" Diamond Speed Bit. Well freeze protected. ****Job in Progress**** 6/11/2015 Perform Weekly BOP Test and change pack-offs. Mill out cement with a 2.79" Diamond Speed Bit from 6,380'to 6,420'). Average ROP was < .44 fpm. Will return in morning and drill out remaining170'with bi-center bit if able to now pass through the "wrinkled" area. Well freeze protected. ****Job in Progress**** 6/12/2015 Sussessfully dry drift bi- bit through "wrinkle"area and when PnnH was able to spin bi-center bit back if with no issues. Milled cement from € ) requested ' ' depth of 6,590'. Average ROP = .66 fpm. Wellbore circulated clean with seawater and freeze protected. Communicated with town engineer that Final Pressure Test @ 1,200 psi had leak rate of 1 psi per second. Ready for BPV and DHD. ****Job in Progress****. 6/15/2015 (PRE-CTD):TREE VALVE TEST, DDT MV, SSV, SV(PASSED), PPT MV, SSV, SV (PASSED). S CanocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 3F-18 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 6/21/2015 9:00:00 AM Rig Release: 7/8/2015 6:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/20/2015 24hrsummary RDMO 1F 15:00 20:00 5.00 0 0 MIRU MOVE RURD P Prep for to move sub and pits off of well. 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Leave 1F pad enroute to 3F pad 36/21/2015 Complete MIRU, BOPE test,Witness waived by C. Sheve,AOGCC, PT PDL&TT line.Trim 17'CT and rehead 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Arrive on 3F pad, De jeep units, Status well, Prep cellar 02:00 04:00 2.00 0 0 MIRU MOVE MOB P Spot units on well 04:00 08:00 4.00 0 0 MIRU MOVE RURD P MIRU on 3F-18 08:00 09:30 1.50 0 0 MIRU WHDBO NUND P Nipple up BOP 09:30 10:30 1.00 0 0 MIRU WHDBO RURD P Prep rig to conduct BOP test *"Note: Rig accepted at 09:00 hours 10:30 19:30 9.00 0 0 MIRU WHDBO BOPE P PJSM-Test BOPE **Note: Test waived by Chuck Scheve at 5:54 am on 6/21/15 M/U nozzle, fill coil and PT inner reel iron and packoffs, End of BOPE test, no failures 19:30 20:00 0.50 0 0 MIRU WHDBO PRTS P PT PDL&TT line 20:00 21:00 1.00 0 0 MIRU WHDBO OTHR P PJSM, R/U and pull BPV. No pressure under BPV 21:00 23:00 2.00 0 0 MIRU RIGMNT CTOP P Cut 17'of CT to remove flat spot, Prep coil and rehead, Pull test to 35K, PT to 4K 23:00 23:30 0.50 0 0 MIRU RIGMNT OTHR P Run valve checklist, R/D test equipment and re heading tools 23:30 00:00 0.50 0 0 SLOT WELLPF PULD P PJSM, P/U BHA#1, BOT under reamer and BOT straight motor and 10'pup. M/U coil track to injector and surface test tool 36/22/2015 RIH with BHA#1 Under reamer. Under ream below damaged pipe section 6416. Set whip stock @ 6540. Unable to get.6°motor past 6416, M/U straight motor. Mill damaged pipe 6416. mill window 6539.6 to 6542 00:00 00:42 0.70 0 63 SLOT WELLPF PULD P Continue making up BHA#1, Surface test MWD 00:42 02:30 1.80 63 6,340 SLOT WELLPF TRIP P RIH, EDC open 02:30 02:36 0.10 6,340 6,370 SLOT WELLPF DLOG P Log K1 for+5.5, PUW=27K Page 1 of 14 ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:36 03:06 0.50 6,370 6,428 SLOT WELLPF TRIP P Trip in to 6428, circ bottoms up, close EDC 03:06 03:54 0.80 6,428 6,490 SLOT WELLPF REAM P Pumps on 1.7 BPM @ 3310 PSI FS, BHP=2835, Ream down 2 FPH 03:54 04:00 0.10 6,480 6,490 SLOT WELLPF REAM P Stop at 6480, S/D pump and P/U, PUW=30K, RBIH to 6490 and start reaming down from there, 04:00 05:00 1.00 6,490 6,590 SLOT WELLPF REAM P 6490, ream down, 1.7 BPM @ 3300 PSI FS, BHP=2860, IA=485, OA=484 05:00 05:12 0.20 6,590 6,590 SLOT WELLPF CIRC P Slowly ream uphole waiting for milling fluid to get to reamer 4BBIs, 05:12 06:42 1.50 6,590 63 SLOT WELLPF TRIP P Open EDC, Trip out 06:42 07:42 1.00 63 63 SLOT WELLPF OWFF P Check well for flow, PJSM, still residual at the shaker, close choke and monitor for another 20 mins. looks good, 07:42 08:42 1.00 63 0 SLOT WELLPF PULD P LD under-reamer BHA#1 08:42 09:42 1.00 0 74 SLOT RPEQPI PULD P MU WS setting BHA#2 09:42 10:57 1.25 74 6,350 SLOT RPEQP1TRIP P RIH with 3.5', Baker Monobore XL WS, 10:57 11:12 0.25 6,350 6,376 SLOT RPEQP1DLOG P Tie into the K1 marker correction of plus 5.5 ft, PUW 26k 11:12 11:42 0.50 6,376 6,550 SLOT RPEQP1TRIP P Continued in hole to 6550.5 ft, ****Note: Seen 6417 ft, 5k bobble RIH with WS through wrinkled tubing. 11:42 11:57 0.25 6,550 6,550 SLOT RPEQPI TRIP P Set TOWS at 6540 ft 20 LOHS 11:57 12:57 1.00 6,550 73 SLOT RPEQP1TRIP P POOH 12:57 13:27 0.50 73 73 SLOT RPEQP1OWFF P Check well for flow, PJSM 13:27 13:57 0.50 73 0 SLOT RPEQPI PULD P LD WS setting tools 13:57 14:27 0.50 0 73 PROD1 WHPST PULD P MU Window milling BHA 14:27 15:27 1.00 73 6,350 PROD1 WHPST TRIP P RIH with 0.6 ako motor and new window mill with used string reamer 2.79 no-go. 15:27 15:42 0.25 6,350 6,376 PROD1 WHPST DLOG P Log into the K1 correction of plus 6.0 ft, 15:42 15:57 0.25 6,376 6,422 PROD1 WHPST TRIP P Continue RIH to TOWS 15:57 16:15 0.30 6,422 6,422 PROD1 WHPST TRIP T Set down 6422 ft, 7k DHWOB, PUW 32k, Discuss with town on plan forward, desicion was made to POOH for a straight motor. 16:15 17:09 0.90 6,422 73 PROD1 WHPST TRIP T POOH 17:09 17:39 0.50 73 73 PROD1 WHPST OWFF T Check for well for flow, PJSM 17:39 19:09 1.50 73 62 PROD1 WHPST PULD T Lay down BHA#3.6°motor, M/U BHA#4 with 2 1/8"BOT straight Motor. M/U to coil and test 19:09 20:15 1.10 62 6,340 PROD1 WHPST TRIP T Trip in hole 20:15 20:21 0.10 6,340 6,360 PROD1 WHPST DLOG T Log K1 for+5.5' Page 2 of 14 ' Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:21 20:39 0.30 6,360 6,430 PROD1 WHPST TRIP T Continue trip in, Set down @ 6418, PUW=27K, Bring on pumps and mill down 6416 to 6430 20:39 21:09 0.50 6,430 6,540 PROD1 WHPST TRIP P Pumps to min rate,continue in hole, Tag TOWS @ 6540. PUH to 6475 and ream down through weight bobbles observered RIH 21:09 00:00 2.85 6,540 6,543 PROD1 WHPST MILL P 6439.6', Start time milling window pre procedure and BOT rep. 1.74 BPM ©3160 PSI FS, BHP=3334, RIW=13.5K X6/23/2015 Complete milling window 6540 to 6545, Drill build, 6545'to 7000'.Trip out for lateral drilling BHA 00:00 03:06 3.10 6,543 6,547 PROD1 WHPST WPST P Continue milling window, 1.7 BPM @ 3160 PSi FS 03:06 05:06 2.00 6,547 6,554 PROD1 WHPST WPST P Goto 2 FPH, 7'down from pinch point. 6544.2 weight started coming down estimate BOW 05:06 05:51 0.75 6,554 6,554 PROD1 WHPST REAM P 6554',cut rathole short due to straight motor, Back ream and dry drift window 05:51 06:06 0.25 6,554 6,395 PROD1 WHPST REAM P PUH,to 6395 ft, dry drift down through tight spots to top of window 6530 ft 06:06 07:21 1.25 6,395 72 PROD1 WHPST WPST P POOH 07:21 07:36 0.25 72 0 PROD1 WHPST SFTY P PJSM, Undeploy window milling BHA#4 07:36 08:36 1.00 0 0 PROD1 WHPST PULD P Undeploy milling BHA#4 08:36 10:30 1.90 0 73 PROD1 DRILL PULD P MU build BHA#5, PD BHA#5, test MWD. Stab on wellhead. 10:30 12:36 2.10 73 6,554 PROD1 DRILL TRIP P RIH w/BHA#5,tie-in to K1 for+6' correction, PUW=28K, small bobble through tubing buckle @ 6,430', continue in hole. 12:36 15:00 2.40 6,554 6,620 PROD1 DRILL DRLG P BOBD: 1.50 BPM©3,055 PSI, BHP=3,645 PSI, CTW=10K, WOB=1.75K, ROP=50. 15:00 16:15 1.25 6,620 6,689 PROD1 DRILL DRLG P Continue drilling same parameters, change tool face to 30-40 left. 16:15 16:27 0.20 6,689 6,340 PROD1 DRILL WPRT P PUH for K1 tie-in, log RA. 16:27 16:57 0.50 6,340 6,688 PROD1 DRILL DLOG P Log K1 for +.5', RBIH to 6550 and log RA marker @ 6546.5, TOWS=6540' 16:57 17:03 0.10 6,688 6,689 PROD1 DRILL WPRT P RBIH to drill build 17:03 19:21 2.30 6,689 6,811 PROD1 DRILL DRLG P 6689', Drill, 1.5 BPM @3011PSI FS, BHP=3708 19:21 19:51 0.50 6,811 6,811 PROD1 DRILL WPRT P Wiper to window, PUW=26K 19:51 21:45 1.90 6,811 7,000 PROD1 DRILL DRLG P 6811', Drill 1.66 BPM @ 3220PSI FS, BHP=3660 21:45 23:03 1.30 7,000 76 PROD1 DRILL TRIP P 7000', Call EOB/Turn POOH, PUW=26K 23:03 23:51 0.80 0 0 PROD1 DRILL PULD P At surface, PJSM, PUD build BHA# 5 23:51 00:00 0.15 0 PROD1 DRILL PULD P M/U BHA#6, prep for PD Page 3 of 14- Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/24/2015 24 hr Summary Drill lateral 7000'to 8524', Swap Mud 00:00 02:24 2.40 0 72 PROD1 DRILL PULD P M/U BHA#6, lateral section BHA with.5°ako motor and rebuilt bi center. PD into well, M/U coil and surface test tools 02:24 03:54 1.50 72 6,350 PROD1 DRILL TRIP P Trip in hole EDC open 03:54 04:00 0.10 6,350 6,369 PROD1 DRILL DLOG P Log K1 for+7', PUW=24K, Close EDC 04:00 04:24 0.40 6,369 7,000 PROD1 DRILL TRIP P Continue in well, Clean pass through window and krinkle area, RIW=12K 04:24 07:06 2.70 7,000 7,360 PROD1 DRILL DRLG P 7000',drill ahead, 1.66 BPM @ 3390 PSI FS, BHP=3681,WHP=240 07:06 07:48 0.70 7,360 7,360 PROD1 DRILL WPRT P Wiper to 6,650', PUW=26K, RBIH. 07:48 10:00 2.20 7,360 7,600 PROD1 DRILL DRLG P Start pumping new mud system, 9.4 ppg Flo-Pro. Drill ahead: 1.60 BPM @ 3,760 PSI, BHP=3,835 PSI, CTW=8K,WOB=1.5K, ROP=110. New mud at bit 7,430'. 10:00 11:00 1.00 7,600 7,600 PROD1 DRILL WPRT T GEO called for wiper trip,slow wiper 5 fpm to 7,290', GEO challenged. RBIH @ 10:50. 11:00 12:24 1.40 7,600 7,710 PROD1 DRILL DRLG P Drill ahead: 1.60 BPM @ 3,890 PSI, BHP=3,820 PSI, CTW=8K, WOB=1 K, ROP=80. 12:24 13:03 0.65 7,710 7,710 PROD1 DRILL WPRT P Wiper to 6,800', PUW=27K, RBIH @ 12:50. 13:03 16:36 3.55 7,710 8,060 PROD1 DRILL DRLG P Drill ahead: 1.57 BPM @ 3,990 PSI, BHP=3,815 PSI, CTW=6.2K, WOB=1.5K, ROP=100. 16:36 17:12 0.60 8,060 6,565 PROD1 DRILL WPRT P Wiper for tie-in, PUW=27K 17:12 17:18 0.10 6,565 6,585 PROD1 DRILL DLOG P Log RA Marker for+.5' 17:18 17:54 0.60 6,585 8,060 PROD1 DRILL WPRT P Wiper trip back to bottom 17:54 21:36 3.70 8,060 8,360 PROD1 DRILL DRLG P 8060', Drill, 1.6 BPM @ 3810 PSI FS, BHP=3780 21:36 22:18 0.70 8,360 8,360 PROD1 DRILL WPRT P Wiper to 7300', PUW=25K 22:18 00:00 1.70 8,360 8,524 PROD1 DRILL DRLG P 8360', Drill, 1.6 BPM @ 3880 PSI FS, BHP=3870 X6/25/2015 Drill to 8623', Out of target. POOH for billet. Run OH anchored billet to 7750. Trip out for drill by BHA. Trip in and start kicking off 00:00 00:24 0.40 8,524 8,546 PROD1 DRILL DRLG P 8524', Drill 1.6 BPM @ 3880 PSI FS, BHP=3838 00:24 02:12 1.80 8,546 8,546 PROD1 DRILL WPRT T 8546, Geo wiper, PUW=25K 02:12 04:00 1.80 8,546 8,600 PROD1 DRILL DRLG P Options discussed with town, Turn down to 80°inc.to P/U pay zone, 1.60BPM @ 3880PSI FS 04:00 04:24 0.40 8,600 8,600 PROD1 DRILL WPRT P Wiper trip through HRZ up to 8500, re run res tool through interval, PUW=25K Trip looked good. Page 4 of 14 41IP ' Tirhe Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:24 06:39 2.25 8,600 8,623 PROD1 DRILL DRLG P 8600', Drill 1.6 BPM @ 3838 PSI FS, BHP=3936, BHA wiper @ 6,817', ratty drilling, several restarts. Got alarm at shale shaker, one shaker motor had vibrated loose and was laying shaker pan. Divert returns to tiger tank. Decide to POOH for plug back assembly. 06:39 07:51 1.20 8,623 76 PROD1 DRILL TRIP T POOH w/BHA#6 07:51 09:27 1.60 76 0 PROD1 DRILL PULD T PJSM. PUD BHA#6, LD BHA. Continue making repairs to shaker motor. 09:27 11:21 1.90 0 73 PROD1 STK PULD T PJSM. MU/PD BHA#7 plug back assembly. Shaker work completed. 11:21 14:00 2.65 73 7,776 PROD1 STK TRIP T RIH w/BHA#7 OH anchored billet, tie-in K1 for+6'correction, continue in hole, no issues through tight spot @ 6,420', RIH to set depth© 7,776.4, OH anchor orientation 170 deg, PUW=24, release from billet, set down 3K on billet,TOB @ 7,765'. 14:00 15:45 1.75 7,776 76 PROD1 STK TRIP T POOH w/BHA#7 15:45 19:09 3.40 76 73 PROD1 STK PULD T PJSM, PUD BHA#7, M/U and PD BHA#8 with .7° motor and RB bi center. M/U to coil and surface test tool 19:09 20:21 1.20 73 6,350 PROD1 STK TRIP T RIH BHA#8, EDC open 20:21 20:33 0.20 6,350 6,376 PROD1 STK DLOG T Log K1 for+5.5', Close EDC, PUW=24K 20:33 21:03 0.50 6,376 7,765 PROD1 STK TRIP T Continue in hole, Dry tag TOB @ 7765.4 21:03 00:00 2.95 7,765 7,765 PROD1 STK MILL T Bring pumps on 1.5 BPM @ 3698 PSI FS, BHP=3750, tag up at 7760.6.very sticky, stacking out and stalling. Run different pump rates. Hanging up before getting on billet. finally get going 06/26/2015 Drill"A" lateral to plan TD @ 9334, Pump sweeps perform swab wiper 00:00 01:54 1.90 7,765 7,780 PROD1 STK DRLG T Drilling-stalling 1.55 BPM @ 3880PS1 FS, BHP=3813 01:54 02:00 0.10 7,780 7,780 PROD1 STK WPRT T PUH to drift billet area, Looks good, PUW=24K 02:00 04:06 2.10 7,780 8,065 PROD1 DRILL DRLG T 7780', Drill ahead, 1.55 BPM @ 3730PSI FS, BHP=3800 04:06 04:54 0.80 8,065 8,065 PROD1 DRILL WPRT T Wiper to 7065 with 5 X 5 sweeps, PUW=25K 04:54 07:00 2.10 8,065 8,360 PROD1 DRILL DRLG T 8065', Drill ahead, 1.45BPM @ 3664PSI FS, BHP=3775, RIW=11K 07:00 07:51 0.85 8,360 8,360 PROD1 DRILL WPRT T Wiper to window, PUW=26K, RBIH. 07:51 11:09 3.30 8,360 8,622 PROD1 DRILL DRLG T Drill ahead:1.54 BPM @ 3,900 PSI, BHP=3,915 PSI, CTW=6K, WOB=1.3K, ROP=80. BHA wiper @ 8,487'.Start pumping new mud, new mud at bit 8,550'. Off trouble time. I✓lmm Paga 5 of 14 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:09 11:36 0.45 8,622 8,665 PROD1 DRILL DRLG P Drill ahead:1.54 BPM @ 3,710 PSI, BHP=3,920 PSI, CTW=4K, WOB=1.7K, ROP=80. 11:36 13:27 1.85 8,665 8,665 PROD1 DRILL WPRT P Wiper for tie-in, PUW=26K,tie-in RA tag for+2.5'correction, RBIH. 13:27 15:27 2.00 8,665 8,965 PROD1 DRILL DRLG P Drill ahead:1.55 BPM @ 3,650 PSI, BHP=3,825 PSI, CTW=8.5K,WOB= .7K, ROP=150. 15:27 16:18 0.85 8,965 8,965 PROD1 DRILL WPRT P Wiper trip, PUW=25.5K, RBIH. 16:18 18:00 1.70 8,965 9,200 PROD1 DRILL DRLG P Drill ahead:1.50 BPM @ 3,650 PSI, BHP=3,895 PSI, CTW=6K,WOB= 1.1K, ROP=145. 18:00 18:54 0.90 9,200 9,200 PROD1 DRILL WPRT P Wiper to 8400', PUW=26K 18:54 20:24 1.50 9,200 9,334 PROD1 DRILL DRLG P 9200', Drill 1.55 BPM @ 3650 PSI FS, BHP=3920, 20:24 23:24 3.00 9,334 72 PROD1 DRILL WPRT P 9334', Call TD, 10 X 10 Sweeps heading down, Chase sweeps to swab 23:24 00:00 0.60 72 3,741 PROD1 DRILL WPRT P At surface, Reset counters, RIH 06/27/2015 Complete wiper trip, Lay in liner running pill, M/U Completion non ported bull nose,64 jts liner and shorty deployment sleeve. Did not get to TD. POOH and shorten liner to 26 jts, 790', RIH 00:00 00:24 0.40 3,741 6,330 PROD1 DRILL WPRT P RIH after chasing sweeps to swab valve 00:24 00:30 0.10 6,330 6,385 PROD1 DRILL DLOG P Log K1 for+12.5'correction 00:30 00:48 0.30 6,385 6,570 PROD1 DRILL WPRT P RIH to 6459, Close EDC 00:48 00:54 0.10 6,570 6,582 PROD1 DRILL DLOG P Log RA to double check 12.5' correction, No correction 00:54 02:00 1.10 6,582 9,335 PROD1 DRILL WPRT P Continue in to confirm TD 02:00 04:36 2.60 9,335 105 PROD1 DRILL TRIP P Tag TD @ 9335, POOH on beaded liner pill followed with 11.8 PPG completion fluid, Paint EOP flag @ 7200&4400 04:36 05:06 0.50 105 105 PROD1 DRILL OWFF P At surface, perform 30 Min no flow, PJSM to lay down BHA#8 05:06 06:33 1.45 105 0 PROD1 DRILL PULD P Lay down BHA#8. Prep floor to run liner. 06:33 10:33 4.00 0 1,970 COMPZ CASING PUTB P PJSM. MU Lower liner assembly: bull nose,one pup,64 jts slotted, and shorty deployment sleeve. PJSM. MU BHA#9. 10:33 13:15 2.70 1,970 8,205 COMPZ CASING RUNL P RIH w/BHA#9 liner assembly,tie-in EOP flag @ 4,400'for+4.5' correction, continue in hole,started stacking @ 8,138',work down to 8,187'set down,work down to deepest depth 8,205'. Cycled pipe 20 times up/down, heaviest PUW=40K, unable to get back down to 8,205', tag up @ 8,186'. Call townfor plan B. 13:15 15:15 2.00 8,205 1,970 COMPZ CASING PULL T POOH w/liner assembly,waiting on plan B. 15:15 15:45 0.50 1,970 1,970 COMPZ CASING OWFF T No Flow Check L____ __ Page 6 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 18:00 2.25 1,970 1,000 COMPZ CASING PULL T PJSM. Prep floor to LD liner. LD 38 jts slotted liner. 18:00 20:18 2.30 1,000 790 COMPZ CASING PULL T Crew change,Valve checklist, PJSM lay down liner 20:18 20:54 0.60 790 834 COMPZ CASING PULD T PJSM, M/U Coil track to loner, M/U to coil and surface test 20:54 21:54 1.00 834 5,230 COMPZ CASING TRIP T Trip in well, EDC closed 21:54 22:00 0.10 5,230 5,234 COMPZ CASING DLOG T Stop and correct to flag, +4.5', PUW=22K 22:00 22:30 0.50 5,234 7,120 COMPZ CASING TRIP T Continue in hole 22:30 22:36 0.10 7,120 7,138 COMPZ CASING DLOG T Tie into K1 for+3'correction 22:36 00:00 1.40 7,138 8,734 COMPZ CASING TRIP T Continue in hole, Clean trip through window and past 8100 to 8205 area. Set down and start working liner from 8667. Get to hard bottom @ 8734. Deployment sleeve @ 7942 06/28/2015 Run"A"liner in 3 segments, 9335 to TOLB@ 7397, Drill off liner top billet to 7399 00:00 01:06 1.10 8,734 9,335 COMPZ CASING TRIP P Bring pumps on in compression .75 for 30 seconds.Work pipe past 8734 to 9016 set down.work to 9020 roll pump in compression. set down @ 9132 work pipe, roll pump get to 9293 work pipe, roll pump, get to 9339 in compression, Call bottom 9335', Pump off liner 01:06 02:12 1.10 9,335 6,330 COMPZ CASING TRIP P release from liner, PUH pumping across top, Reset depth to liner left in hole, Paint EOP flag @7600' 02:12 02:18 0.10 6,330 6,348 COMPZ CASING DLOG P Log K1 for+.5' 02:18 03:30 1.20 6,348 58 COMPZ CASING TRIP P Continue trip out, Paint EOP flag @5600' 03:30 04:00 0.50 58 58 COMPZ CASING OWFF P At surface,30 Min flow check 04:00 04:30 0.50 58 0 COMPZ CASING PULD P PJSM, Lay down BHA#10"A" lateral lower liner segment running tools 04:30 07:00 2.50 0 855 COMPZ CASING PUTB P PJSM, P/U BHA#11, ported deployment sleeve, 27 jts slotted liner,shorty deployment sleeve 07:00 10:00 3.00 855 8,545 COMPZ CASING RUNL P RIH w/middle liner assembly,tie-in EOP flag for+4.5'correction, continue in hole to set depth, PUW=34K,set down 3K @ 8,545', release from liner, PUW=27K, subtract 810'from counter. 10:00 11:00 1.00 8,545 66 COMPZ CASING TRIP P POOH w/BHA#11, paint EOP flag @ 6,000', continue OOH. 11:00 11:30 0.50 66 66 COMPZ CASING OWFF P Flow check, no flow. 11:30 11:51 0.35 66 0 COMPZ CASING PULD P PJSM. LD BHA#11 11:51 13:09 1.30 0 398 COMPZ CASING PUTB P PJSM. MU Upper liner assembly: bull nose, 11 jts slotted, OH anchored billet. MU BHA#12,test tool. Page 7 of 14 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:09 15:39 2.50 398 7,735 COMPZ CASING RUNL P RIH w/BHA#12,tie-in EOP flag for +5.2'correction, continue in hole to set depth, PUW=27.5,set down 2.5K, release from liner assembly, PUW=27K. PUH to 7,300', reset depth. 15:39 17:03 1.40 7,735 80 COMPZ CASING TRIP P POOH w/BHA#12 17:03 17:33 0.50 80 80 COMPZ CASING OWFF P Flow check, no flow. 17:33 18:45 1.20 80 0 COMPZ CASING PULD P PJSM. LD BHA#12. Perform BOP function test. 18:45 20:00 1.25 0 72 PROD2 STK PULD P PJSM. M/U BHA#13 Lareral drilling with.7°AKO motor and re built Hycalog bi center 20:00 21:18 1.30 72 6,350 PROD2 STK TRIP P RIH with EDC open 21:18 21:24 0.10 6,350 6,379 PROD2 STK DLOG P Log K1 for+6'correction 21:24 21:48 0.40 6,379 7,397 PROD2 STK TRIP P RIH, Dry tag billet @7397, PUH roll hole to 9.4PPG FloPro 21:48 22:48 1.00 7,397 7,200 PROD2 STK CIRC P Displacing well to 9.4 FloPro 22:48 23:06 0.30 7,200 7,397 PROD2 STK TRIP P RIH 23:06 00:00 0.90 7,397 7,399 PROD2 STK MILL P Mill off billet, 1.5BPM @ 3460 PSI FS, BHP=3735 36/29/2015 Drill AL1 lateral 7399 to 8910, Perform mud swap 00:00 00:42 0.70 7,399 7,450 PROD2 DRILL DRLG P 7399, See loss of DH weight, P/U speed, 1.5 BPM @ 3460 PSI FS, BHP=3742 00:42 00:48 0.10 7,450 7,450 PROD2 DRILL WPRT P Drift billet area, PUW=26K, Looks good 00:48 03:36 2.80 7,450 7,700 PROD2 DRILL DRLG P 7450', Drill, 1.5BPM @ 3460 PSI FS, BHP=3820 03:36 04:36 1.00 7,700 7,700 PROD2 DRILL WPRT P 7700',Wiper to 6600', PUW=27K 04:36 08:00 3.40 7,700 8,010 PROD2 DRILL DRLG P 7700', Drill 1.5 BPM @ 3460 PSI FS, BHP=3810 08:00 08:45 0.75 8,010 8,010 PROD2 DRILL WPRT P Wiper trip, PUW=27, RBIH. 08:45 13:30 4.75 8,010 8,310 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3750 PSI, BHP=3,825 PSI, CTW=8.5K, WOB=1.4K, ROP=65 13:30 15:00 1.50 8,310 8,310 PROD2 DRILL WPRT P Wiper trip for tie-in, PUW=27K,tie-in for+3'correction, RBIH. 15:00 19:18 4.30 8,310 8,610 PROD2 DRILL DRLG P Drill ahead: 1.50 BPM @ 3750 PSI, BHP=3,815 PSI, CTW=8.5K, WOB=1.3K, ROP=55. Start mud swap, new mud at bit 8,434'. 19:18 20:12 0.90 8,610 8,610 PROD2 DRILL WPRT P 8610',Wiper to 7610, PUW=27K 20:12 23:12 3.00 8,610 8,910 PROD2 DRILL DRLG P 8610 Drill, 1.52 BPM @ 3400 PSI FS, BHP=3840 23:12 00:00 0.80 8,910 8,300 PROD2 DRILL WPRT P 8910 Wiper to 7710'with 5 X 5 sweeps, PUW=26K 36/30/2015 Drill AL1 lateral from 8,910-ft to extended TD at 9,400-ft. Pump sweeps,wiper to swab. Lay in liner running pill from 9,300-ft. M/U non ported bull nose,42 jts slotted and shorty deployment sleeve to BHA#14. RIH with lower AL1 liner assembly. Page?)f 11 1 111/11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:48 0.80 8,310 8,910 PROD2 DRILL WPRT P Continue wiper from 8910 00:48 03:54 3.10 8,910 9,210 PROD2 DRILL DRLG P 8910', Drill ahead, 1.54 BPM @ 3550 _ PSI FS, BHP=3875 03:54 04:54 1.00 9,210 6,570 PROD2 DRILL WPRT P 9210 Wiper to window with tie in, PUW=26K, Pumped 5 X 5 sweeps 04:54 05:00 0.10 6,570 6,586 PROD2 DRILL DLOG P Log RA marker for+3.5' 05:00 06:09 1.15 6,586 9,212 PROD2 DRILL WPRT P Continue wiper trip back to bottom 06:09 08:42 2.55 9,212 9,400 PROD2 DRILL DRLG P Drill ahead: 1.53 BPM @ 3,750 PSI, BHP=3,940 PSI, CTW=8K, WOB=2K, ROP=75. Extended TD to 9,400'. Pumped 10 X 10 sweep. 08:42 11:36 2.90 9,400 72 PROD2 DRILL WPRT P Chase sweeps to swab, logged MAD pass 6,800'to 6,560', continue OOH. 11:36 14:18 2.70 72 9,400 PROD2 DRILL TRIP P Reset counter. RBIH for corrected TD,tie-in K1 for+6.5'correction, tag TD @ 9,400'. Start pumping completion fluid. PUH to 9,300'. 14:18 17:24 3.10 9,400 72 PROD2 DRILL DISP P POOH laying in liner pill/completion fluid 17:24 18:09 0.75 72 72 PROD2 DRILL OWFF P At surface, monitor well for flow, crew change out, PJSM. 18:09 18:45 0.60 72 0 PROD2 DRILL PULD P LD BHA#12 18:45 19:30 0.75 0 0 COMPZ CASING PUTB P PJSM-Prep floors to run liner, service top drive. 19:30 21:30 2.00 0 1,262 COMPZ CASING PUTB P PJSM-MU AL1 lower liner assembly,bull nose,42 jts slotted and shorty deployment sleeve. Tripping drill performed, safety joint inspected by Baker rep. 21:30 22:33 1.05 1,262 1,306 COMPZ CASING PULD P PJSM-MU AL1 lower liner assembly to BHA#14, MU to CoilTrak, surface test. 22:33 00:00 1.45 1,306 6,960 COMPZ CASING RUNL P RIH with BHA#14,tie in at EOP flag at 5,100-ft for plus 5-ft correction, PUW 28k at window. 37/01/2015 Ran"AL1"liner in 3 segments 9,300-ft to top of anchored aluminum liner top billet at 6,662-ft. Drill off billet to 6,667-ft, drilling AL2 build section in progress. 00:00 01:21 1.35 6,960 9,300 COMPZ CASING RUNL P Continue RIH with BHA#14, no correction at K1, lost push at 9,227-ft, PUW 32k,work to 9,261-ft, roll pump,work to 9,300-ft 01:21 01:30 0.15 9,300 8,038 COMPZ CASING RUNL P 9,300-ft, Release from liner, PUW 26k,good WOB change, reset depth to liner left in hole,top of liner at 8,038-ft. 01:30 03:24 1.90 8,038 44 COMPZ CASING TRIP P POOH pumping over the top, paint EOP flag's at 6,500-ft and 5,000-ft 03:24 03:54 0.50 44 44 COMPZ CASING OWFF P At surface, monitor well for flow, PJSM. 03:54 04:21 0.45 44 0 COMPZ CASING PULD P LD BHA#14 04:21 07:33 3.20 0 1,341 COMPZ CASING PUTB P PJSM-MU AL1 middle liner assembly, ported bull nose,44 jts slotted,3 pups 9.10-ft,9.42-ft,2.81-ft and shorty deployment sleeve. Page 9 of 14 11111 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:33 08:12 0.65 1,341 1,406 COMPZ CASING PULD P PJSM-MU AL1 middle liner assembly to BHA#15, MU to CoilTrak,surface test. 08:12 10:09 1.95 1,406 8,038 COMPZ CASING RUNL P RIH w/BHA#15,tie-in to K1 no correction, continue in hole,tag up on lower assembly @ PUW=31 K,set down 5K, release from liner, PUW=25K. Reset depth. 10:09 11:12 1.05 8,038 56 COMPZ CASING TRIP P POOH w/BHA#15 11:12 11:42 0.50 56 56 COMPZ CASING OWFF P Flow check, no flow. 11:42 12:06 0.40 56 0 COMPZ CASING PULD P PJSM. LD BHA#15 12:06 12:57 0.85 0 73 COMPZ CASING PULD P PJSM. MU OH anchored billet assembly, MU BHA#16,test tools. 12:57 14:51 1.90 73 6,675 COMPZ CASING TRIP P Open EDC. RIH w/BHA#16,tie-in K1 for+6'correction, continue in hole, PUW above window 27K,tag up on middle liner assembly @ 6,675', release from billet, PUW=27K. 14:51 16:00 1.15 6,675 66 COMPZ CASING TRIP P POOH for drilling assembly 16:00 16:30 0.50 66 66 COMPZ CASING OWFF P Flow check, no flow. 16:30 16:51 0.35 66 0 COMPZ CASING PULD P PJSM. LD BHA#16 16:51 18:15 1.40 0 0 COMPZ CASING PRTS P Pressure test new ODS PDL, crew change out 18:15 19:39 1.40 0 72 PROD3 STK PULD P PJSM-MU BHA#17 Drilling assembly, 1.9°AKO motor with HCC RB Bi-center bit, changed out float valves, MU to CoilTrak, surface test. 19:39 20:57 1.30 72 6,350 PROD3 STK TRIP P RIH with EDC open. 20:57 21:03 0.10 6,350 6,375 PROD3 STK DLOG P Tie in at K1 for plus 6-ft correction. 21:03 21:15 0.20 6,375 6,530 PROD3 STK TRIP P RIH, PUW above window 28k. 21:15 22:30 1.25 6,530 6,400 PROD3 STK DISP P Displace hole over to 9.4 ppg FloPro drilling fluid above window, close EDC. 22:30 22:45 0.25 6,400 6,662 PROD3 STK KOST P RIH dry tag top of liner at 6,662.5-ft, PUH 28k. 22:45 00:00 1.25 6,662 6,667 PROD3 STK KOST P 6,662-ft, Drill off billet 1.5 bpm at 3,577 psi, BHP 3,661 psi,aluminum across shaker at bottoms up, drilled off billet quickly J7/02/2015 Drill build section from 6,667-ft to 6,825-ft. POOH. PUD/LD BHA#17. MU/PD/RIH with BHA#18. Drill ahead AL2 lateral from 6,825-ft to 7,872-ft. Perform mud swap. Drilling in progress 00:00 00:15 0.25 6,667 6,672 PROD3 STK KOST P 6,667-ft, Drilling off billet 1.53 bpm at 3,611 psi, BHP 3,667 psi. 00:15 00:39 0.40 6,672 6,700 PROD3 DRILL DRLG P 6,672-ft, Drill ahead build section 1.53 bpm at 3687 psi, BHP 3,669 psi,WH 127, IA 243, OA 283 00:39 00:48 0.15 6,700 6,700 PROD3 DRILL TRIP P POOH to 6,635-ft, PUW 28k, RBIH, drift billet area clean. Page 10 of 14 111, Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:48 03:18 2.50 6,700 6,825 PROD3 DRILL DRLG P 6,700-ft, BOBD 1.54 bpm at 3,679 psi, BHP 3,685 psi,WH 129, IA 244, OA 290 03:18 05:00 1.70 6,825 72 PROD3 DRILL TRIP P 6,825-ft, Build TD called, POOH for drilling assembly 05:00 07:06 2.10 72 0 PROD3 DRILL PULD P PJSM-Undeploy and LD BHA#17. PT PDL. 07:06 08:24 1.30 0 72 PROD3 DRILL PULD P MU/PD BHA#18 08:24 10:24 2.00 72 6,825 PROD3 DRILL TRIP P RIH w/lateral drilling assembly, tie-in to K1 +9'correction, PUW=26K, continue in hole. 10:24 13:33 3.15 6,825 7,175 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,805 PSI, BHP=3,720 PSI, CTW=10.5K, WOB=1.8K, ROP=110. GEO wiper @ 7,046'. 13:33 14:18 0.75 7,175 7,150 PROD3 DRILL WPRT P Wiper to window, PUW=29K, RBIH. 14:18 17:06 2.80 7,150 7,525 PROD3 DRILL DRLG P Drill ahead: 1.51 BPM @ 3,820 PSI, BHP=3,765 PSI, CTW=9.3K, WOB=1.3K, ROP=135. 17:06 17:48 0.70 7,525 7,525 PROD3 DRILL WPRT P Wiper to 6,700', PUW=26K, RBIH. 17:48 19:42 1.90 7,525 7,665 PROD3 DRILL DRLG P 7,525-ft, BOBD 1.53 bpm at 3,861 psi, BHP 3,770 psi,WH 60, IA 480, OA 430 19:42 20:36 0.90 7,665 7,665 PROD3 DRILL WPRT P Geo.wiper to 7,425-ft, PUW 28k, RBIH. 20:36 00:00 3.40 7,665 7,872 PROD3 DRILL DRLG P 7,665-ft, BOBD 1.53 bpm at 3,798 psi, BHP 3,792 psi,WH 100, IA 535, OA 460, CTW 8.4k,WOB 1.4k, ROP 40 **Note: Begin mud swap, pump sweeps, new mud at bit at 7,763-ft. 07/03/2015 Drill ahead AL2 lateral from 7,872-ft to 9,344-ft. Drilling in progress. 00:00 00:06 0.10 7,872 7,875 PROD3 DRILL DRLG P Drill ahead 1.55 bpm at 3,603 psi, BHP 3,788 psi,WH 199, CTW 5.6k, WOB 2.1k, ROP 29 00:06 00:42 0.60 7,875 6,565 PROD3 DRILL WPRT P Wiper for tie in, PUW 29k. 00:42 00:51 0.15 6,565 6,590 PROD3 DRILL DLOG P Log RA for plus.5-ft correction. 00:51 01:24 0.55 6,590 7,875 PROD3 DRILL WPRT P Wiper in hole, RIW 10.9k 01:24 04:57 3.55 7,875 8,175 PROD3 DRILL DRLG P 7,875-ft, BOBD at 3,650 psi, BHP 3,805 psi, CTW 8.4k,WOB 1.8k, ROP 60. 04:57 05:42 0.75 8,175 8,175 PROD3 DRILL WPRT P Wiper trip to 7,175-ft, PUW 28k, RBIH 05:42 08:21 2.65 8,175 8,475 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,760 PSI, BHP=3,860 PSI, CTW=BK, WOB=1.7K, ROP=115. 08:21 09:09 0.80 8,475 8,475 PROD3 DRILL WPRT P Wiper to 7,475', PUW=26K, RBIH. 09:09 11:24 2.25 8,475 8,775 PROD3 DRILL DRLG P Drill ahead: 1.50 BPM @ 3,850 PSI, BHP=3,885 PSI, CTW=9K, WOB=1.9K, ROP=135. 11:24 13:15 1.85 8,775 8,775 PROD3 DRILL WPRT P Wiper for tie-in, PUW=26K, RA tie-in _ for+2.5'correction, RBIH. Page 11 of 14 1111 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/03/2015 24 hr Summary Drill ahead AL2 lateral from 7,872-ft to 9,344-ft. Drilling in progress. 13:15 16:27 3.20 8,775 9,075 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM ©3,890 PSI, BHP=3,882 PSI, CTW=4K, WOB=1.3K, ROP=95. 16:27 17:57 1.50 9,075 9,075 PROD3 DRILL WPRT P Wiper trip to 7,575', PUW=26K, RBIH. 17:57 22:24 4.45 9,075 9,319 PROD3 DRILL DRLG P 9,075-ft, BOBD 1.52 bpm at 3,879 psi, BHP 3,872 psi, CWT 7.0k,WOB 1.4k, ROP 90. 22:24 23:30 1.10 9,319 9,319 PROD3 DRILL WPRT P Wiper trip to 8,000-ft, RBIH 23:30 00:00 0.50 9,319 9,344 PROD3 DRILL DRLG P 9,319-ft, BOBD 1.50 bpm at 3,894 psi, BHP 3,940 psi, CWT 5.6k,WOB 1.1k, ROP 45 07/04/2015 Drill ahead AL2 lateral from 9,344-ft to extended TD at 9,867-ft. Pump sweeps,wiper to swab. Lay in 11.8 ppg K-Formate beaded liner running pill from confirmed TD 9,867-ft. M/U non-ported bull nose, 35 jts slotted and shorty to BHA#19. 00:00 05:48 5.80 9,344 9,620 PROD3 DRILL DRLG P 9,344-ft, BOBD 1.50 bpm at 3,894 psi, BHP 3,940 psi, CWT 5.6k,WOB 1.1k, ROP 45, hit ankerite 9,434'to 9,464'. 05:48 08:39 2.85 9,620 9,620 PROD3 DRILL WPRT P Wiper trip for tie-in, PUW=25K,tie-in for+4.5'correction, no issues through A4-5 shale zone, RBIH. Starting pumping new mud. 08:39 11:57 3.30 9,620 9,867 PROD3 DRILL DRLG P Drill ahead: 1.52 BPM @ 3,590 PSI, BHP=4,005 PSI, CTW=4K, WOB=1.3K, ROP=90. New mud at bit 9,627'. BHA wiper @ 9,737'& 9,784', PUW=25K. Continue drilling to TD @ 9,867'. Pump 10 X 10 sweeps. 11:57 14:27 2.50 9,867 73 PROD3 DRILL WPRT P Chase sweeps to swab, hole clean, no issues. 14:27 17:09 2.70 73 9,867 PROD3 DRILL TRIP P Tag up, reset depth, RBIH.Tie-in to K1 for+7.5'correction,continue in hole for corrected TD @ 9,867'. 17:09 19:48 2.65 9,867 72 PROD3 DRILL DISP P POOH laying in 11.8 ppg K-Formate beaded liner pill, completion fluid to surface, paint flags at 8,600-ft and 5,300-ft. 19:48 20:18 0.50 72 72 PROD3 DRILL OWFF P On surface, monitor well for flow, PJSM. 20:18 21:00 0.70 72 0 PROD3 DRILL PULD P LD BHA#18, bit condition 1-1-B U-G-X-I-PN-TD 21:00 21:30 0.50 0 0 COMPZ CASING PUTB P Prep floor for running liner,service top drive. 21:30 23:24 1.90 0 1,095 COMPZ CASING PUTB P PJSM-M/U bull nose, 35 jts slotted, shorty deployment sleeve. 23:24 00:00 0.60 1,095 1,139 COMPZ CASING PULD P PJSM-M/U lower liner assembly to BHA#19. 07/05/2015 Ran"AL2"liner in 3 segments to top of lower SBR at 6,531-ft. Begin bi-weekly BOPE test,witness waived by AOGCC rep,Jeff Jones at 15:00 on 7-5-15. 00:00 00:30 0.50 1,139 1,139 COMPZ CASING PUTB P M/U lower liner assembly and BHA #19 to CoilTrak,surface test _._.T Paga 12 of 14 Tirpe Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 03:30 3.00 1,139 9,867 COMPZ CASING RUNL P RIH w/BHA#19, tie-in to EOP flag for plus 4.9-ft correction, PUW 29k, continue in hole,sat down at 9,192-ft, PUW 34k,work past easily, sat down at 9,815-ft, roll pump to work liner down,tag up at 9,867-ft. PUW 35k,set down 5k, release from liner, PUW 25k. Reset depth. 03:30 05:45 2.25 9,867 44 COMPZ CASING TRIP P POOH with BHA#19, paint EOP flags. 05:45 06:15 0.50 44 44 COMPZ CASING OWFF P On surface, monitor well for flow. 06:15 07:00 0.75 44 0 COMPZ CASING PULD P PJSM. LD BHA#19 07:00 10:30 3.50 0 1,448 COMPZ CASING PUTB P PJSM. Prep floor. MU second liner assembly bull nose, 45 jts slotted, shorty. MU BHA#20, replace checks. 10:30 12:54 2.40 1,448 8,772 COMPZ CASING RUNL P RIH w/BHA#20,tie-in EOP flag for +4.5'correction,continue in hole,tag up @ 8,772', small weight bobbles last 25', PUW=29K, set down 3K, release from liner. PUH, PUW=26K, reset counter-1,404'. 12:54 14:21 1.45 8,772 56 COMPZ CASING TRIP P POOH w/BHA#20, paint EOP flags @ 6,400'&5,600'. 14:21 14:51 0.50 56 56 COMPZ CASING OWFF P On surface, monitor well for flow. 14:51 15:21 0.50 56 0 COMPZ CASING PULD P PJSM. LD BHA#20 15:21 17:30 2.15 0 881 COMPZ CASING PUTB P PJSM. Prep floor. MU third liner assembly bull nose, 25 jts slotted,3 jts solid, SBR deployment sleeve. MU BHA#21, 17:30 19:39 2.15 881 7,368 COMPZ CASING RUNL P RIH w/BHA#21, tie-in EOP flag for plus 4.6-ft correction,continue in hole,tag up @ 7,365-ft, PUW 31k, set down solid 8k, release from liner. PUW 27k, reset counters, PUH and log K1 for plus 2.5-ft correction, liner set at 7,368-ft 19:39 20:33 0.90 7,368 44 COMPZ CASING TRIP P POOH with BHA#21. 20:33 21:03 0.50 44 44 COMPZ CASING OWFF P On surface, monitor well for flow. PJSM 21:03 21:30 0.45 44 0 COMPZ CASING PULD P LD BHA#21 21:30 23:45 2.25 0 0 COMPZ CASING RURD P Prep for BOPE test,jet stack, grease tree and stack, load coil and stack. 23:45 00:00 0.25 0 0 COMPZ WHDBO PRTS P PJSM- PT inner reel iron and packoffs. 37/06/2015 Complete BOPE test. Ran Upper AL2 Sweel Packer assembly to 6,534-ft,top of upper SBR at 6,401-ft. Spot inhibited seawater around bcak side of swell packer from 6,630-ft to 6,401-ft. Displace well to inhibited seawater from 6,401-ft. Freeze protect from 2,500-ft. 00:00 12:00 12.00 0 0 COMPZ WHDBO BOPE P Test BOPE 250/3500, annular 2500. `*Note: Test waived by Jeff Jones at 15:00 pm on 7/5/15 Page 13 of 14 41° Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 0 0 COMPZ WHDBO CIRC P PJSM. LD BOP test equipment. PJSM. Circulate coil back to 11.8 ppg Formate. 13:30 14:00 0.50 0 0 COMPZ CASING OWFF P Monitor for flow, no flow. 14:00 16:00 2.00 0 174 COMPZ CASING PULD P PJSM. MU Final liner assembly: Seal assembly, 5'pup,XO, Halliburton swell packer assy,XO, 3 jts solid, SBR deployment sleeve. MU BHA#22. 16:00 17:45 1.75 174 6,534 COMPZ CASING RUNL P RIH w/BHA#22,tie-in for plus 6.5-ft correction, PUW 30k, RBIH, sting into SBR to 6,534.5-ft,top of upper SBR at 6,401-ft. 17:45 18:36 0.85 6,534 6,534 DEMOB WHDBO DISP P On line with corrosion inhibited seawater 1.18 bpm at 2,267 psi while sitting on SBR, returns from 6,630-ft up backside of swell packer for 15 bbls. 18:36 19:48 1.20 6,534 2,550 DEMOB WHDBO DISP P POOH loading well with corrosion inhibited seawater 19:48 21:45 1.95 2,550 44 DEMOB WHDBO FRZP P PJSM-RU LRS, P/T lines and equipment,freeze protect from 2,500-ft, RDMO LRS. 21:45 23:15 1.50 44 0 DEMOB WHDBO PULD P PJSM-Un-deploy/LD BHA#22 23:15 00:00 0.75 0 0 DEMOB WHDBO MPSP P PJSM-Bring in FMC equipment, Set BPV. 07/07/2015 Set BPV. Flush surface lines. Blow down Coil with N2. Swap out 2"reels. 00:00 01:00 1.00 0 0 DEMOB WHDBO MPSP P Set BPV. Off load FMC equipment. 01:00 05:00 4.00 0 0 DEMOB WHDBO RURD P PJSM-Flush coil and surface lines. SLB N@ caught behind move on Prudhoe side of river. remove counters,continue with rig down. 05:00 07:00 2.00 0 0 DEMOB WHDBO RURD P PJSM with SLB N2 crew, RU, cool down and P/T lines, blow down coil, RDMO SLB N2. 07:00 00:00 17.00 0 0 DEMOB WHDBO CTOP P Reel Swap Remove inner reel iron, unstab coil, remove counters, PJSM with Peak to remove and install reels,change out stripper brass 07/08/2015 Reel swap 00:00 06:15 6.25 0 0 DEMOB WHDBO CTOP P Finish changing out stripper brass, remove reel wrap and banding from reel, MU and pull test grapple,stap coil into injector and install inner reel iron and bulk head, install counters. 06:15 07:00 0.75 DEMOB Check tree bolts, all bolts loose on tree swab. 0 0 DEMOB PJSM-with Peak, complete rig move checklist, RDMO CDR2 to 2H-14 **Note: Rig release at 06:00 hours �r 'l=� OF Ty yw N 1//j�s THE STATE Alaska Oil and Gas ���\~,—s:'��,,.�►�� ofALA Conservation Commission S KA Witt ==- 333 West Seventh Avenue ixtriPkF GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 Op,ALASn' Fax. 907 276 7542 2_015www aogcc alaska.gov ANNE© .iUN q 1 Gary Eller Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3F-18 Sundry Number: 315-316 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, Cathy '. Foerster Chair DATED this da of May, 2015 Encl. STATE OF ALASKA • • A.__ ...,KA OIL AND GAS CONSERVATION COME- SION . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request' Abandon r Rug Perforations r✓ Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate I! Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well 1 Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc ' Exploratory p Development pr., 196-112 3.AddressStratigraphic r— Service r' 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22684-00 f 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No ri/ KRU 3F-18 r 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25643 • 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): 6868 ' 6236 • 6793' 6167' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 3440 7.625 3481' 3180' RECEIVED PRODUCTION 6821 5.5 6858' 6227' MAY 2 2 2015 ar5 5./z-7,/ 1 s AOGC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): - 6412-6428,6480-6490,6621-6641,6664-6684 5818-5832,5880-5889,6009-6027,6048-6067 3.5 L-80 6333 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO'DS'LANDINGNIPPLE MD=516 TVD=514 12.Attachments' Description Summary of R-oposal ri 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r" Development Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: w 5/29/2015 OIL r VVINJ r WDSPL r Suspended 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative' GINJ r Op Shutdown r Abandoned 17. I hereby c ify that the foregoing i true and correct to the best of my knowledge. Contact. Gary Eller @ 263-4172 Email. J.Gary.Eller@conocophillips corn Printed Name Gary Eller Title: Staff CTD Engineer Signature w Phone.263-4172 Date S 11 Commission Use Only ill Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 31S-3\(Q Plug Integrity r BOP Test VMechanical Integrity Test r Location Clearance r •Other:80 p f 5 t to .J 5-00E„, (/l, P 5 iD ):.5 2 43r s i t A-vinvIG(r"pre'vr•-, trc ttsf- fe7 2-5-4;c pS ) 41tcr.-safc pir�9 plaGrw,e-v,71 A/ pk-o ✓cd pc.," .2as.4c 25 ,/12 le, ) Spacing Exception Required? Yes ❑ No Ir Subsequent Form Required. /0— 40.7 O APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:�'Z7—/S� Approved application is valid for 12 mont s /rom the date of approval. submit Form and Form 10-403 Revised 5/2015 f12 _ S Attachments in Duplicate Vri /2G//5 O R I G I N A Ls7zs RBDMS3 MAY 2 8 2015 KRU 3F-18 CTD Summary for Plugging Perfs Sundry (10-403) Summary of Operations Background Well 3F-18 is a Kuparuk A/C-sand producer(development)well equipped with 31/2"tubing and 31/2"production liner. Three laterals from well 3F-18 will be drilled,two to the north(3F-18A& AL1)to recover reserves from rock producing mother bore and one to the south (3F-18AL2)to access A3 pay faulted out of 3F-09. CTD operations will target the Kuparuk A2 &A3 sands. Well 3F-18 was completed in the Kuparuk A-sand in 1996 with a single completion. The C-sand was perforated in 1999, but no change in rate was observed and it is assumed that the C-sand has been contributing throughout the life of the well. A RWO was completed in 2008 to replace the 3.5"tubing due to external corrosion. Well 3F-18 has been shut-in since 2011 due to rock production.Video logging of the production liner shows erosion of both the A-and C-sand perforations to be the cause of the rock production. Prior to CTD operations, an IBP will be set above the A-sand perfs and the C-sand perfs will be squeezed with cement. ConocoPhillips has submitted at 10-403 sundry application for a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A/C-sand perfs in this manner. After setting an IBP above the A-sands and squeezing cement into the C-sand perfs,the cement will be drilled out pre-rig. Nabors CDR2-AC drilling rig will set a whipstock in the 31/2"liner at the planned kickoff point. All three laterals will exit through the 3'/2" liner at 6540' MD and will target the A2 and A3 sands. All three laterals will be completed with 2%" slotted liner from TD with the final liner top located inside the 3'/2" liner at 6400. A 31/2"x 2%" liner-top packer will provide redundant isolation of the squeezed C-sand perfs. GG, . j'lie /ro�Dyro' LA, // L..,.,/ Pre-CTD Work Can fi'.i vc TO recoLvc iq'cerve.5 6 frtrn/ 7 1. Pump: Load hole with seawater. 4,e,nk /rsd°cvit Qnd v''•'11 jp go"d 'O'G'/ (.244e5, 2. E-line: Drift for 2-1/8" IBP and set an'IBP at 6,600'. Get a SBHP;test. r l ult/ir4t e 3. Pump: Perform infectivity test. ye Coy' 4'f4 `✓� f nut. fro/4' 4. Slickline: Drift tubing, tag top of fill. 4C'Oil . 5. Coil: Cement squeeze the C-sand perfs in the 3-1/2" liner,then clean out to 6450'. 6. Coil: Pressure test cement squeeze. Mill cement with Bi-center bit down to 6590' (40' past the base of the whipstock). Pressure test cement squeeze again. 7. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3F-18A Sidetrack(A3 sand- north) a. Set whipstock at 6540' MD b. Mill 2.80"window at 6540' MD c. Drill 3"bi-center lateral to TD of 9340' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7350' MD 3. 3F-18AL1 Lateral(A2 sand- north) a. Kick off of the aluminum billet at 7,350' MD Page 1 of 2 May 20, 2015 b. Drill 3"bi-center lateral to TD of 9,300' MD c. Run 2%"slotted liner from TD up to 6700' MD 4. 3F-18AL1 Lateral(A3 sand -south) a. Kick off of the aluminum billet at 6700' MD b. Drill 3"bi-center lateral to TD of 9650' MD c. Run 2%" slotted/blank liner from TD up to 6400' MD, inside the 31/2" liner(above C-sand perfs). Includes swell packer on 2%"blank liner below the squeezed C- sand perfs. 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Install 31/2" liner-top packer on 2%" liner at 6400' MD (above squeezed C-sand perfs). 3. Obtain static BHP. Install GLV's. 4. Return to production Page 2 of 2 May 20, 2015 Loepp, Victoria T (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Tuesday, May 26, 2015 10:03 AM To: Loepp,Victoria T(DOA) Cc: Phillips, Ron L Subject: RE: KRU 3F-18(PTD 196-112, Sundry 315-316) Plug for Redrill) Attachments: 3F-18 proposed pre-rig schematic.pdf Victoria— Below is the MPSP write-up that was submitted with the PTD. Also, the proposed post-plugging (pre-CTD) schematic is attached. -Gary Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) A static bottom hole pressure of 3F-18 in July 2014 indicated a reservoir pressure of 2968 psi ©6045'ND or 9.4 ppg EMW. The highest pressure in an offset wells is at the 3F-04 well to the east with 3281 psi @ 5984'ND or 10.5 ppg EMW. Using the 3F-04 pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2683 psi. From: Loepp, Victoria T(DOA) [mailto:victoria.loepD )alaska.gov] Sent:Tuesday, May 26, 2015 9:53 AM To: Eller, J Gary Subject: [EXTERNAL]KRU 3F-18(PTD 196-112, Sundry 315-316) Plug for Redrill) Gary, Please provide the MPSP and a wellbore schematic post work for this sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska qov 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.Loeon@alaska.gov 1 tn 0 N N N —J J co ct - Q co CEs- N 2 4J - r= c0 N 4) -0 - co N O c v 2 0 v D o :4- to- a) 2 w ✓ CO M L CC • U O h �` CO .3 U r0 al 04 � V //��,� T O o N d N <V G a) -a C 45 N C C a) W �r ch a) E) O C 4) N Q O H Q N 0 .2- F = C N O @- cp N m — U m co =�Mj 4) U0 O 0 m C m O Zo O O o 0 0 0 N d N CI • J - lit c0.)CO O c0 co 45 c0 r N - V m U U CT; U U CO y C')ao ri a N N N N 4) 4) X O X m LO N LO E co c") CO CO m 2 O on O -f°a O co) a) U 0 to 2 C Co 2 O g O a' I 0 O N a Y U a n m m a. g _ as U a U = — o N 2 V A N i7. O RS gZ :uiiuiu:e _ illi II.I ✓ I T !!! CI b N 1— st U m "al co a 0 a) co 30 a) o g o co CL I aO , w x'00 �, 00 O J E 4) j.) O. #O J v a n^ a-0 0 CO co M co0 co co � N N - cOUN tN 0Oj COD CO O sr- O h. _ Co L N N O.... d0 CO C V' CO N N0 Co M .. 4) a @ CI CD00 N• �` O C V n co M Co0 0 O O— NNW Q co 0 CD O 4):=' 4) U CCD cco - o cfl L A y • 0 C Q 0 KUP PROD 3F-18 IV Cono[oPhillipsWill Attributes • &lex Angle&MD TDAlaska,Inc. ' - Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) • `Ca .T,drr„-. 500292268400 KUPARUK RIVER UNIT PROD 28.59 3,755.40 6868.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3F-113,8/3/20143:25:00 PM SSSV:NIPPLE 150 Last WO: 12/4/2008 7/11/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 6,630.0 7/31/2014 Rev Reason:TAG,H2S hipshkf 8/3/2014 HANGER;36.8 I} „l Casing Strings Casing Description OD(in) ID(In) Top(ftlt8) Set Depth(ftKB) Set Depth((Vol... Wt/Len(I...Grade Top Thread -y�r CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED JS]L9� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(N0)...WULen(I...Grade Top Thread 75 SURFACE /8 6.875 41.5 3,481.3 3,180.2 29.70 L-80 BTC-MOD 1 Casing Description PRODUCTION 5.5"x3.5" OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 51/2 4.950 36.8 6,858.0 6,227.0 15.50 L-80 LTC-MOD . { Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Iblft) Grade 'Top Connection CONDUCTOR;42.0-121.0 ,, TUBING 3 1/2 2.992 36.8 6,333.3 5,745.5 9.30 L-80 IBT I Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(^) Item Des Com (in) NIPPLE;516.1 . -. I 36.8 36.8 0.10 HANGER FMC 3 1/2"x 7 1/16"5M TBG Hanger wl 312"IBT Pup 3.500 516.1 513.7 13.33 NIPPLE CAMCO'DS'LANDING NIPPLE 2.875 6,277.4 5,694.3 23.45 NIPPLE Camco 2.812""DS"Nipple 2.812 6,320.4 5,733.8 23.57 SEAL ASSY Baker Seal Assembly 80-40 GBH22 w/locator(2.00' 3.000 spaceout) GAS LIFT;2739.9 11 Pe o &Slots r• Shot Dens Top[(Vol Btm(TVD) (shotslt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,412.0 6,419.0 5,817.6 5,824.0 C-4,3F-18 2/4/1999 4.0 APERF 21/2"HC-DP,180 deg pH,+/-90 deg 6,419.0 6,425.0 5,824.0 5,829.5 C-4,3F-18 12/26/1998 4.0 APERF 21/2"HC-DP,180 deg tpH,+/-90 deg SURFACE;4153,481.3--• 6,425.0 6,428.0 5,829.5 5,832.3 C-4,3F-18 2/4/1999 4.0 APERF 21/2"HC-DP,180 deg pH,+/-90 deg 6,480.0 6,490.0 5,879.8 5,888.9 C-1,3F-18 5/112002 6.0 APERF 2.5"HSD,PJ DP,60 deg GAS LIFT;3,947.7 1. pH 6,621.0 6,641.0 6,008.7 6,027.1 A-3,3F-18 727/1996 4.0 (PERF 21/2"HSD,180 deg pH - f 6,664.0 6,684.0 6,048.2 6,066.6 A-3,A-2,3F- 3/22/2009 6.0 APERF 2 1/8"PJ,45 deg phase 18 ( Mandrel Inserts GAS LIFT;4.960.8 1 St aS c On t 1 Nn Top(ND) Valve Latch Port Size TRO Run 0 Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type pn) (psi) Run Date m 1 2,739.9 2,516.0 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 7/11/2011 GAS UFT;5,606.6 II 2 3,947.7 3,594.7 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 7/11/2011 3 4,960.7 4,500.0 Camco KBG-2-9 1 Gas lift DMY INT 0.000 0.0 7/10/2011 4 5,696.8 5,163.7 Camco KBG-2-9 1 Gas Lift DMY INT 0.000' 0.0 8/102009 . 5 6,223.8 5,645.1 Camco . 'KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 12/6/2008 - GAS LIFT;6,223.8 End Date Annotation 10/10/2005 NOTE:Surface CSG patch @ bottom of mandrel hgr,39"L X 8"OD,X65 pipe ( 4/92008 NOTE:NIPPLE @ 517'w2.812"ID,BUT GAUGED TO 2.80" - NIPPLE;6277.4 12/6/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 ( 7/19/2011 NOTE:RAN VIDEO ON CASING DAMAGE IN 3.5 LINER FROM 6625-6632 SEAL ASSY;6,320.4 1 a 1 ✓ APERF;6,4120-,419.0 APERF;6,419.0-,425.0 ✓ APERF;6,425.66,428.0 APERF;6,480.0-6,490.0 IPERF;6,621.06,641.0 -•APERF;1664.06.684.0 PRODUCTION 5.57.3.5';36.8- J 6,858.0 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 sponsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the atrici or Steve 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 Vatricia r Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni 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 History tab Jenni 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 change Jenni 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 Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i C~.. j)' ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages' DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy~incent Nathan Lowell Date: ~)'~- Is~ ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Down Hole Video: 3F -18 Run Date: 7/19/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -18 Digital Video File (AVI) 1 DVD Rom 50- 029 - 22684 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: l' Signed: • WELL LO TRANSMITTAL PROACTIVE DIAgNOSlic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : " JUL 1 3 2U ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 21- May -11 3F -18 1 Report / CD 50- 029 - 22684-00 2) /01.-1 � 3,\\,- Signed : Dat e : ° ( I Print Name: sAr A"1.– , c- l 2 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E - MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips_Transmit.docx 1 III • I PI c-_,\I-ijos Memory Multi- Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 3F -18 Log Date: May 21, 2011 Field: Kuparuk Log No.: 10259115 ZX70 State: Alaska I Run No.: 2 API No.: 50 029- 22684 -00 Pipet Desc.: 3.5" 9.3 Ib. L-80 Top Log Intvll.: Surface Pipet Use: Tubing & Casing Bot. Log Intvll.: 6,667 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage COMMENTS : 1 The caliper data is correlated to Tubing Tally record (12- 4-2008). This log was run to assess the condition of the casing within the vicinity of the perforation interval. 1 Eroded perforations are recorded in joint 207 (6,628 ft) and joint 208 (6,632 ft). A 3 -D log plot for the eroded perforation interval is included in this report. I The caliper recordings indicate the 3.5" tubing and casing logged appears to be in good to fair condition. A maximum wall penetration of 47% recorded in lines of pits in joint 199 (6,403 ft). Additional wall penetrations ranging from 20% to 44% are recorded in 14 joints of 227 joints analyzed. Recorded damage appears in the I forms of lines of pits, line corrosion and isolated pitting. No significant areas of cross - sectional wall loss are recorded throughout the tubing and casing logged with the exception of eroded perforation interval. No significant I.D. restrictions are recorded throughout the tubing and casing logged. I This is the second time a caliper has been run in this well, and the first time for the 3.5" tubing and casing have been logged since the RWO (December 12, 2008). This summary report is an interpretation of data provided by Halliburton Well Services. 1 MAXIMUM RECORDED WALL PENETRATIONS: 1 Line of Pits ( 47%) Jt. 199 6,403 Ft. (MD) Line Corrosion ( 44%) Jt. 206 @ 6,594 Ft. (MD) Line of Pits (42 %) Jt. 181 @ 5,753 Ft. (MD) Line of Pits ( 38 %) Jt. 204 @ 6,537 Ft. (MD) 1 Line of Pits ( 38 %) Jt. 180 @ 5,730 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant cross - sectional wall loss ( > 7 %) are recorded outside the perforation interval. MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the tubing and casing logged. 1 Field Engineer: J. Conrad & P. Juday Analyst: C. Lucasan Witness: B. Boehme I 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 tai —III I • • F PDS Multifinger Caliper 3D Log Plot 1 Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3F -18 Dat : May 21, 2011 Description : Detail of Caliper Recordings Across The Erod Perforation Interval. C omments Depth Max. Penetration Maximum I.D. 3 -D Log Image Map 1 1ft:170ft 0 °,6 100 Inch 3.5 0° 0° 90° 180° 270° 0° I Minimum I.D. --I 2.5 Inch 3.5 Nominal I.D. - 2.5 Inch 3.5. ,_ ■ ■■ / �1 ■■■■ Marker Joint 205 ■ ■■■` E�■ ■■■ .._ ,i, 6560 ■ ■■ ■EEC ■ ■ ■■ _ . 1 �� ■ ■ ■ ■t F .... _- -- - ■ ■ ■■ . „. - ........ [III ■ ■ ■ ■... ■ ■ ■■ __ ___ 6570 ■ ■■■IPAfJ■■ ■■ II ■ ■ ■■'ili ■ ■■■ ■■■ ■1111 ■ ■ ■■ ■■■ ■lIL1■ ■■ 6580 ■■■ ■!E - Joint 206 ::::��� I ■■■ ■11117 ■ ■ ■■ ■■ ■ ■!FF!■ ■■ ■ ■■■IIIIM ■■ _ 6590 C ■ ■ ■ ■� @E' ■ ■ ■■ ■ ■ T= ■■ ■■fit■ ■ ■ ■CVF - -- - ssoo �— ■ ■ ■!E ■ ■ ■■ - ■ ■■■� ■ ■■■ - .�� ■ ■ ■ ■� ■ ■ ■■ ■■ ■�1 i MOM Joint 207 ss10 .� ■■■■� ■, - - a ■ ■ ■ ■rl.i■ -= Perforation �� ■■■EE's■ ' C ■ ■ ■C ■ri - ■■■ ■! ■` 6620 NI■ ■ ■ ■ ■_, m ■■■ ■� ■■r 1 I MU••f • ■ ■I - _ I ■ms -: �M■ ■ ■■ M=7 r �m� i mmosi I " L � = „a_ 6630 �� u■■■■■ ■� e — Joint 208 ■■■ ■ . 6640 - nll 1 Perforation ■ ■ ■ ■r FF = .. 1111111111M 1 rrrn 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 In Pipe 1 3.5 in (58.0' - 6660.6') Well: 3F -18 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: May 21, 2011 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 — 62 I • I 25 d 822 1 a J 50 1595 I 75 _ 2371 GLM 1 —1 _ 9 I ii5 1 00 3172 1 c GLM 2 .0 125 —.1 3972 II 1 150 = 4744 GLM 3 _41 A I 175 , 5533 GLM 4 I -I GLM 5 1 200 — 6408 209 6661 0 50 100 1 Damage Profile ((Yu wall) / Tool Deviation (degrees) Bottom of Survey = 209 1 1 1 1 • • 1 PDS Report Overview w Body Region Analysis I Well: 3F -18 Survey Date: May 21, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 250 Mil Penetration body Metal loss body 0 50 100 200 0 150 100 I 50 = 0 47 - A I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 227) 1 209 11 3 4 GLM 1 A 95 1 Damage Configuration ( body) 50 t GLM 2 40 143 30 1 GLM 3 20 I 10 GLM 4 -A -.. 0 Isolated General Line Other Hole / 189 I Pitting Corrosion Corrosion Damage Pos. Hole GLM 5 _ ' — TIM ■ I Number of joints damaged (total = 48) 47 0 1 0 0 Bottom of Survey = 209 1 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 21, 2011 I Joint Jt. Depth Pell. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % hset Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 58 0 0.02 6 4 2.92 Pup Lt. Deposits. I 1 62 0 0.03 10 2 2.97 1.1 92 0 0.01 5 1 3.00 Pup 2 96 0 0.03 13 3 2.94 Slight Ovality. Shallow Pitting. 3 126 0 0.03 11 3 2.95 I 4 157 0 0.03 10 3 2.94 5 187 0 0.03 10 2 2.96 6 218 0 0.02 8 1 2.97 7 250 0 0.03 10 3 2.94 I 8 280 0 0.03 11 1 2.97 9 312 0 0.02 9 2 2.96 10 342 0 0.02 7 2 2.95 11 372 0 0.03 11 3 2.97 I 12 403 0 0.03 10 3 2.97 13 435 0 0.02 9 2 2.98 14 465 0 0.02 7 2 2.97 15 497 0 0.02 8 2 2.98 15.1 528 0 0.03 10 3 2.94 Pup I 15.2 534 0 0 0 0 2.88 Camco DS Nipple 15.3 535 0 0.02 7 2 2.96 Pup 16 541 0 0.03 11 2 2.97 17 573 0 0.02 8 2 2.97 I 18 603 0 0.02 9 2 2.97 19 635 0 0.03 10 4 2.96 20 666 0 0.02 8 2 2.96 21 696 0 0.01 6 1 2.98 I 22 727 0 0.03 11 2 2.97 23 759 0 0.02 9 2 2.97 24 790 0 0.02 8 2 2.99 25 822 0 0.02 8 2 2.97 26 853 0 0.02 9 2 2.96 I 27 883 0 0.02 8 2 2.99 28 914 0 0.03 10 2 2.96 29 946 0 0.03 10 2 2.96 30 976 0 0.02 , 9 2 2.95 I 31 1007 0 0.02 9 2 2.95 32 1039 0 0.02 9 2 2.95 33 1070 0 0.02 9 2 2.96 34 1100 0 0.03 11 2 2.96 I 35 1132 0 0.02 8 2 2.94 36 1163 0 0.02 8 2 2.96 37 1194 0 0.02 8 2 2.95 38 1226 0 0.03 11 3 2.96 39 1257 0 0.03 11 3 2.95 I 40 1287 0 0.03 11 3 2.94 41 1318 0 0.03 11 4 2.96 42 1349 0 0.02 9 3 2.96 43 1380 0 0.03 13 3 2.95 Shallow Line of Pits. I 44 1411 0.03 0.03 10 4 2.95 45 1441 0 0.02 7 2 2.99 rat I I Penetration BoBody dy Page 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 21, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Lss I.D. D• Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 46 1471 0 0.02 9 3 2.98 I 47 1502 0 0.02 9 2 2.95 48 1534 0 0.02 8 2 2.96 49 1564 0 0.04 14 5 2.95 Shallow Line of Pits. ■ 50 1595 0 0.03 11 2 2.96 I 51 1626 0 0.02 9 1 2.97 52 1657 0 0.03 11 2 2.97 ■ 53 1688 0 0.03 11 3 2.95 ■ 54 1720 0 0.04 16 3 2.95 Shallow Line of Pits. ■ I 55 1750 0 0.03 11 5 2.93 t 56 1781 0 0.03 12 2 2.97 Shallow Pitting. ■ 57 1812 0 0.03 10 4 2.94 a 58 1843 0 0.02 7 2 2.95 I 59 1874 0 0.02 9 2 2.97 IN 1905 0 0.03 10 3 2.97 ■ 61 1937 0 0.03 12 2 2.97 Shallow Pitting. ■ 62 1968 0 0.02 9 3 2.95 ■ 63 1999 0 0.03. 13 2 2.97 Shallow Pitting. • I 64 2030 0 0.02 9 2 2.96 ■ 65 2060 0 0.03 10 3 2.95 ■ 66 2091 0 0.03 11 2 2.95 67 2122 0 0.02 9 2 2.96 I 68 2152 0 0.02 9 2 2.97 ■ 69 2184 0 0.03 11 4 2.93 70 2215 0 0.02 9 2 2.96 71 2246 0 0.02 7 2 2.94 I 72 2278 0 0.03 13 2 2.96 Shallow Pitting. ■ 73 2309 0 0.03 12 5 2.90 Lt. Deposits. II 2340 0 0.03 10 2 2.96 ■ 75 2371 0.03 0.03 12 4 2.93 Shallow Pitting. ■ 76 2403 0 0.03 10 3 2.95 ■ I 77 2434 0 0.03 11 3 2.95 • 78 2466 0 0.04 15 3 2.95 Shallow Line of Pits. • 79 2497 0 0.02 8 2 2.96 80 2528 0 0.03 10 2 2.96 is I 81 2560 0 0.03 10 5 2.94 ■ 82 2590 0 0.02 9 2 2.97 ■ 83 2622 0 0.03 10 2 2.97 ■ 84 2654 0.03 0.04 15 2 2.94 Shallow Line of Pits. • I 85 2684 0 0.03 11 3 2.95 86 2715 0 0.02 8 2 2.98 86.1 2746 0 0.02 7 2 2.97 Pup 86.2 2754 0 0 0 0 2.92 GLM 1 (Latch 0 4:30) I 86.3 2760 0 0.01 6 2 2.97 Pup 87 2768 0 0.02 7 2 2.97 88 2800 0 0.02 9 2 2.95 89 2830 0 0.02 9 2 2.96 ■ 90 2862 0 0.03 11 4 2.94 ■ I 91 2892 0 0.03 12 4 2.94 ■ 92 2923 0 0.03 11 2 2.95 Penetration Body I Metal Loss Body Page 2 1 I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 21, 2011 U Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 93 2955 0 0.02 9 2 2.96 94 2986 0 0.02 8 2 2.96 95 3017 0 0.03 10 2 2.95 ■ 96 3048 0 0.03 11 4 2.96 ■ 97 3080 0 0.03 13 2 2.96 Shallow Pitting. ■ I 98 3111 0.03 0.03 12 3 2.93 Shallow Line of Pits. Lt. Deposits. ■ 99 3141 0 0.03 10 4 2.94 ■ 100 3172 0 0.03 11 2 2.97 ■ 101 3202 0 0.03 11 3 2.96 ■ I 102 3234 0 0.02 9 3 2.95 Ill 3265 0 0.03 11 2 2.96 • ■ 104 3296 0 0.02 9 2 2.97 ■ 105 3327 0 0.03 10 3 2.95 IN 106 3358 0 0.02 9 2 2.96 ■ I 107 3389 0 0.03 10 2 2.96 108 3421 0 0.02 8 2 2.98 109 3452 0 0.02 9 2 2.96 110 3482 0 0.02 7 2 2.94 II I 111 3513 0 0.02 9 3 2.93 112 3544 0 0.02 8 2 2.98 113 3575 0.03 0.03 13 4 2.96 Shallow Line of Pits. 114 3606 0 0.02 7 2 2.96 3 I 115 3637 0 0.02 7 2 2.96 116 3669 0 0.03 10 2 2.96 117 3699 0 0.02 7 2 2.98 118 3730 0 0.02 9 , 2.96 119 3761 0 0.02 9 4 2.95 • I 120 3792 0 0.03 11 2 2.95 0 121 3823 0.02 8 2 2.97 122 3854 0 0.03 11 3 2.95 123 3885 0 0.01 6 1 2.96 I 124 3916 0 0.02 9 2 2.95 124.1 3947 0 0.01 6 2 2.99 Pup 124.2 3956 0 0 0 0 2.90 GLM 2 (Latch @ 11:00) i , 124.3 3963 , 0 0.02 8 2 2.97 Pup I 125 3972 0 0.03 10 2 2.95 126 4004 0 0.02 8 2 2.94 127 4034 0 0.03 12 2 2.98 Shallow Pitting. 1 128 4065 0 0.02 9 2 2.96 I 129 4096 0 0.03 10 3 2.93 130 412 7 0 0.02 7 2 2.96 il 131 4159 0 0.03 12 2 2.96 Shallow Pitting. ■ 132 4189 0 0.03 10 2 2.95 • 133 4221 0 0.03 13 2 2.96 Shallow Pitting. I 134 4251 0 0.02 8 2 2.97 135 4283 0 0.02 9 2 2.97 136 4314 0 0.03 10 2 2.97 137 4345 0 0.02 7 2 2.94 I 138 4376 0 0.02 7 3 2.95 139 4407 0 0.02 8 2 2.96 I 14 0 I 0.03 1 BoBody dy Page 3 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: May 21, 2011 I Joint Jt. Depth Purr. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 all) (Ins.) (Ins.) % (Ins.) 0 50 100 140 4438 0 0.02 9 2 2.97 I 141 4468 0 0.03 12 2 2.95 Shallow Line of Pits. 142 4500 0 0.03 10 4 2.94 143 4530 0 0.03 11 2 2.95 144 4561 0 0.02 7 2 2.96 I 145 4591 0 0.02 9 1 2.93 Lt. Deposits. 146 4621 0 0.02 9 2 2.95 147 4653 0 0.02 7 1 2.95 148 4684 0 0.02 9 2 2.94 I 149 4715 0 0.02 9 2 2.93 Lt. Deposits. 150 4744 0 0.02 7 2 2.93 Lt. Deposits. 151 4775 0 0.03 11 2 2.94 152 4805 0 0.02 8 2 2.95 I 153 4836 0 0.02 8 2 2.94 154 4867 0 0.03 10 2 2.93 Lt. Deposits. 155 4898 0 0.02 9 1 2.94 156 4928 0 0.02 7 2 2.94 156.1 4958 0 0.02 7 1 2.96 Pup I 156.2 4966 0 0 0 0 2.90 GLM 3 (Latch @ 6:00) 156.3 4972 0 0.02 8 2 2.93 Pup Lt. Deposits. 157 4981 0 0.03 10 2 2.92 Lt. Deposits. 158 5012 0 0.02 8 2 2.94 I 159 5042 0 0.02 9 1 2.94 160 5073 0 0.02 7 2 2.93 161 5103 0 0.02 9 2 2.93 Lt. Deposits. 162 5134 0 0.03 13 2 2.95 Shallow Pitting. I 163 5165 0 0.04 15 2 2.95 Shallow Pitting. 164 5196 0 0.03 12 2 2.94 165 5227 0 0.02 9 1 2.94 166 5257 0 0.03 11 2 2.94 167 5286 0 0.03 11 2 2.93 I 168 5315 169 5347 0 0.05 19 2 2.95 Shallow Line of Pits. 0 0.04 14 2 2.94 Shallow Pitting. 170 5379 0 0.03 11 2 2.93 171 5410 0 0.03 13 2 2.96 Shallow Pitting. 172 5441 0 0.03 10 2 2.96 173 5472 0 0.03 10 4 2.93 Lt. Deposits. 174 5502 0 0.02 9 3 2.94 175 5533 0 0.02 9 2 2.95 176 5564 0 0.03 1 1 3 2.93 Lt. Deposits. 177 5596 0 0.02 8 2 2.96 178 5628 0 0.02 9 2 2.94 179 5659 0 0.03 13 3 2.94 Shallow Line of Pits. I 179.1 5691 0 0.02 7 2 2.97 Pup 179.2 5700 0 0 0 0 2.89 GLM 4 (Latch @ 12:00) 179.3 5707 0 0.06 24 2 2.96 Pup Line of Pits. 180 5714 0.1 1 0.10 38 4 2.96 Line of Pits. 181 5745 0.04 0.11 42 6 2.92 Line of Pits. Lt. Deposits. I 182 5777 0.04 0.04 17 3 2.94 Shallow Pitting. 183 5807 0 0.06 22 2 2.94 Isolated Pitting. rat Body I Metal Loss ion Body Page 4 Penet 1 1 • • PDS REPORT JOINT TABULATION SHEET 1 Pipe: 3.5 in 9.3 ppf L -80 Well: 3F -18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. 1 Nominal I.D.: 2.992 in Country: USA Survey Date: May 21, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 184 5839 0 0.05 19 2 2.92 Shallow Pitting. Lt. Deposits. I 185 5869 0 0.02 9 3 2.92 Lt. Deposits. 186 5901 0 0.02 7 1 2.95 187 5932 0 0.02 8 2 2.94 188 5963 0 0.04 14 2 2.95 Shallow Pitting. I 189 5995 0 0.04 15 3 2.93 Shallow Pitting. 190 6027 0 0.04 17 2 2.93 Shallow Pitting. Lt. Deposits. 191 6059 0 0.04 15 2 2.95 Shallow Pitting. 192 6089 0 0.04 16 2 2.92 Shallow Pitting. Lt. Deposits. I 193 6121 0.03 0.06 22 2 2.95 Isolated Pitting. 194 6152 0 0.05 20 3 2.92 Line of Pits. Lt. Deposits. 195 6183 0 0.02 7 2 2.95 195.1 6214 0 0.02 8 3 2.95 Pup I 195.2 6224 0 0 0 0 2.88 GLM 5 (Latch @ 10:00) 195.3 6230 0 0.03 13 2 2.96 Pup Shallow Pitting. 196 6240 0.05 0.06 22 3 2.94 Line of Pits. 196.1 6272 0.06 0.06 23 7 2.93 Pup Line of Pits. 196.2 6277 0 0 0 0 2.81 Camco DS Nipple I 196.3 6278 0 0.02 9 2 2.90 , Pup Lt. Deposits. 197 6284 0 0.05 20 3 2.93 Line of Pits. Lt. Deposits. 197.1 6315 0 0.03 12 3 2.93 Pup 197.2 6320 0 0 0 0 3.00 Baker Seal Assembly I 197.3 6335 0 , 0.03 11 3 2.89 Pup Lt. Deposits. 198 6345 0.07 0.04 17 2 2.92 Shallow Line of Pits. Lt. Deposits. 199 6376 0 0.12 47 4 2.92 Line of Pits. Lt. Deposits. 200 6408 0 0.82 100 57 2.82 Perforation. Lt Deposits. "mew I 201 6439 0 0.04 17 3 2.92 Shallow Pitting. Lt. Deposits. 202 6471 0.07 0.64 100 68 2.83 Perforation. Lt. Deposits. 203 6503 0.04 0.09 36 4 2.91 Line of Pits. Lt. Deposits. 204 6535 0.08 0.10 38 4 2.91 Marker Joint Line of Pits. Lt. Deposits. OIMMON 205 6550 0.05 0.09 35 3 2.92 Marker Ioint Line of Pits. Lt. Deposits. -"MI I 206 6566 0.07 0.11 44 6 2.90 Line Corrosion. Lt. Deposits. 207 6597 0.51 1.01 100 95 2.85 Perforations. Lt. Deposits. 208 6630 0.50 1.17 100 100 2.89 Perforations. Lt. Deposits. 209 6661 0 0.02 7 1 2.80 Deposits. i t Penetration Body Metal Loss Body I 1 1 1 1 Page 5 1 1 1 • • 1 PDS Report Cross Sections I Well: 3F -18 Survey Date: May 21, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan 1 1 Cross Section for Joint 199 at depth 6403.090 ft Tool speed = 28 Nominal ID = 2.992 I Nominal OD = 3.5 _ Remaining wall area = 96% Tool deviation = 23° / 1 1 1 1 1 \ , , / 1 \ \ N I Finger = 17 Penetration = 0.119 ins Line of Pits 0.12 ins. = 47% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 3F -18 Survey Date: Tool Type: May 21, 2011 Field: Kuparuk UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf L -80 Analyst: C. Lucasan 1 1 Cross Section for Joint 206 at depth 6593.657 ft Tool speed = 49 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 97% I Tool deviation = 24° 1 I i / __, 1 1 1 \ ---,.„, 1 N. / 1 __ I Finger = 9 Penetration = 0.112 ins Line Corrosion 0.11 ins. = 44% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 KUP I ConocoPhillips = I Attributes gle & MD TD 3F -18 : . Wdibore APWWI Field Name Well Status Ind 1 °) MD (WS) Act Btm (MB) .11. . Ire: 500292268400 KUPARUK RIVER UNIT PROD 28.59 3,755.40 6,868.0 coataitratiar " Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date I weu Conk, - 3F - la 10/4/2010 9 1 4 AM SSSV: NIPPLE 150 12/6/2009 Last WO: 12/4/2008 7/11/1996 Schematic - Actual Annotation Depth (m(B) End Date Annotation Last T SLM 6,737.0 8/10/2009 Rev Reason: GLV C/O Imosbor 10/4/2010 .. Casing Strings Last Mod ... End Dale Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd HANGER, 37 CONDUCTOR 16 15062 37.0 121.0 121.0 62.50 H - 40 WELDED i Casing Description String 0... String ID ... Top (MB) Set Depth R... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 7 6.750 41.5 3,481.3 3,180.2 29.70 L BTC - MOD Casing Description String 0... String ID _. Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 36.8 6,858.0 6,227.0 15.50 L-80 LTC -MOD 5.5 "x3.5" Tubing Strings I Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, TUBING 3 1/2 2.910 36.8 6,333.3 5,747.1 9.30 L -80 IBT 37 -121 Completion Details Top Depth (TVD) Top Ind Noml... NPPLE, 516 1E1 Top (TIKB) (� (1 item Description Comment FMC 3 1/2" x 7 1/16" 5M TBG H ID pro I I 36.8 36.7 0.10 HANGER Hanger w/ 3 1/2" IBT Pup 3.500 516.1 513.6 13.76 NIPPLE CAMCO'DS' LANDING NIPPLE 2.875 6,277.4 5,697.1 25.35 NIPPLE Camco 2.812" "DS" Nipple 2.812 6,320.4 5,735.6 25.12 SEAL ASSY Baker Seal Assembly 80-40 GBH22 w/locator (2.00' spaceout) 3.000 GAS Z 0 Perforations & Slots Top (TVD) etm (TVD) Dens Shot Top (m(e) etm (Itl®) MKS) (ma) Zone Date Oh- Type Comment 6,412.0 6,419.0 5,818.1 5,824.5 C-4, 3F -18 2/4/1999 4.0 APERF 2 1/2" HC -DP, 180 deg pH, +/- 90 deg 6,419.0 6,425.0 5,824.5 5,829.9 C-4, 3F -18 12/26/1998 4.0 APERF 2 1/2" HC -DP, 180 deg pH, +1- 90 deg 6,425.0 6,428.0 5,829.9 5,832.6 C -0, 3F -18 2/4/1999 4.0 APERF 2 1/2" HC -DP, 180 deg pH, +/- 90 deg I SURFACE. "J l 6,480.0 6,490.0 5,879.8 5,889.0 C -1, 3F -18 5/11/2002 6.0 APERF 2.5" HSD, PJ DP, 60 deg pH ata,ael 6,621.0 6,641.0 6,009.0 6,027.4 A -3, 3F -18 7/27/1996 4.0 IPERF 2 1/2" HSD, 180 deg pH 6,664.0 6,684.0 6,048.4 6,066.7 A -3, A -2, 3F -18 3/22/2009 6.0 APERF 2 1/8" PJ, 45 deg phase GAS LET, Notes: General & Safety 3,946 End Date Annotation 10/10/2005 NOT Surface CSG patch @ bottom of mandrel hgr, 39" L X 8" OD, X65 pipe 4 /9/2008 NOTE: NIPPLE @ 517' w/2.812" ID, BUT GAUGED TO 2.80" 12/6/2008 NOTE: VIEW SCHEMATIC w /Alaska Schemalic9.0 GAS LIFT, 4,961 GAS LIF I 5.697 I IrT I 1 I 1 NIPPLE6277 Inn I SEAL ASSY 6,320 1 APERF, 6,412 -6,419 6,41 APERF. 8 ERF. I PPE425 6,4256428 AF 6,4686490 Mandrel Details Top Depth Top Port I (TVD) Ind OD valve Latch Size 7R0 Rrn Stn Top MKS) MKS) ( °) Make Model M1 Sery Type Type ( Mai Run Date Can... 1 2 739 9 2,515.0 24.77 Camco KBG -2 -9 1 Gas Lift GLV INT 0.156 1282.0 8/11/2009 2 3947.7 3,594.9 26.97 Camco KBG-2 -9 1 Gas Lift GLV INT 0.188 1,317.0 8/11/2009 IMF 6.621 3 4,960.8 4,499.8 26.41 Camco KBG -2 -9 1 Gas Lift OV INT 0.250 0.0 9/9/2010 I . 4 5,696.8 5,164.5 24.75 Camco KBG-2 -9 1 Gas Lift DMY INT 0.000 0.0 &10/2009 5 APERF, 6.6646 684 6,223.8 5,645.1 23.35 Camco KBG 1 Gas Lift DMY INT 0 000 0.0 12/6/2008 I PRODIN 5 35". 37-6,858 TD, 6,668 Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] ~~~~ ~l7 j~ Sent: Sunday, September 05, 2010 1:41 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv 1~~ !.~ (~-~((Z~ Subject: 3F-18 (PTD 196-112) Report of failed TIFL Attachments: 3F-18 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 3F-18 (PTD 196-112) failed a diagnostic TIFL. The TIO prior to the test was 140/1310/70. A leaking GLV is sus ected. Slickline will troubleshoot and repair if possible. Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 9/7/2010 KRU 3F-18 PTD 1961120 9/5/2010 Ti0 Pressures Plot sno. 3000. 200. 3000. 3000. 3000. • 0. 0. D- 0. 0. 0. 0. lsoo lzoo 900 600 300 0 PLOT SIART TIME 04-JUN-10 10:54 MINOR TIME MAJOR TIME WEER PICK TINE ?777 7?7?????T?77?? SC TAG MANE DESCRIPTION 1' 4`;aLt1P; i.§TEST WL3F-18-CHOKE FLOW TUBING CHOKE ????"?'' SCRATCH 67 FLOW TUBING PRESSURE ?77?7?;' SCRATCH_67 FLOW TUBING TEMP ??????> AI-P3F5002-18 GL CASING PRESSURE ??????? ~ ?????7? SCRATCH_67 INNER ANN[JLUS PRF.S ???? ' SCRATCH_67 OUTER ANNULUS PRES ??????? +p2160:Op:Op gRS 02-SEP-10 1ps54 PREV WELL DRILLSITE WELL 3 f 18 , NEXT WELL ENTRY ZYPE OPERATOR OPERATOR VERIFIED ~ SYSTEM AUTO ENTRY ~ BOTH • ANNULUS PRESSURE TRENDS WELL NAME WLKRU3F-18 __ ,~~ ~ ~_~. ~ KUP .. ~ _ 3F-18 ~ ~ 1 COt1Q~0i I ii~t1~?S ~ Well Attributes _ ax Anyle & MD ITI D ', ~ I Wellbore APl/UWI Fieltl Name Well Status Intl (`I ~.fL (Ithl) rAc(Bfm{ttKB) ~~ - _ 500292268400 KUPARUK RIVER UNIT PROD 28.59 3,755.40 6,868.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 175 12/22/2008 Last WO: 12/4/2008 7/11/1996 ___ well Gonfa.-aF-te ~i22o09538.37 kM 5 nem lic-Aauai ,,,:tatlon ~~~ De th RKB P ( ) End Date Annotation Last Mod By End Date „i Tag. SLM 6 ,737.0 8/10/2009 Rev Reason: TAG -79' RATHOLE, GLV C/O Imosbor 8/12YL009 ~-_ _ - Ca51n~Strings _ -_ _-J s ~. ~ rannrg Descripton 'Siring 0... Siring ID ... Top (RKB) Set Depth fit... ~ Set Dep[h (ND) ... String Wt_. String ... String Top Thrd CONDUCTOR 1fi 15.062 37.0 121.0 121.0 62.50 H-40 / Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... S et Depth (ND) ... String Wt... String ... String Top Thrd j SURFACE 75/8 6.750 41.5 3,481.3 3,180.2 29.70 L-80 HANGER, 37 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... S et Depfh (ND) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.653 37.5 6,340.0 5,753.2 15.50 L-80 Casing Description String 0... String ID ... Top (ftK8) Set Depth (f... S et Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 31/2 2.867 6.340.0 6.858.0 6,227.0 9.30 L-80 t ^- Tubing Strings ~ - i - ~`- Tubing Description -- - St g 0... String ID ... Top (ttKB) Set D pth (/ ISet Depth (ND) .. Stnng Wt.. St Ing ... String Top Thrd ', I TUBING 2.910 I 36 8 ~ 3 1/2 I , 6,333 3 _ 5,747.1 9 30 L 80 _ IBT _ Completion Details _ __ __ _- CONDUGTOR, 7~p (.ep[h 37-121 (ND) Top Inel Top RKB) (RKB) (°) It em Description Comment ID (in ' , 36.8 36.7 0.10 H ANGER FMC 3 1/2" x 71/16" 5M TBG Hanger w/ 3 1Y1"IBT Pup 3.500 , +, I. 516.1 513.6 13.76 N IPPLE CAMCO'DS' LANDING NIPPLE 2.875 NIPPLE, 516 !!!,,,,,,ddd' - 6,277.4 5,697.1 25.35 N IPPLE Camco 2.8 12" "DS"Nipple 2.812 I '~ 320.4 6 5 735.6 25.12 S EAL ASSY Baker Seal Assembly 80-40 GBH22 wAocator (2.00' spaceout) 3.000 , , ~ Perforations & Slots - l ~ _ - - _ -' Shot _ _ ~ Top (NO) Btm (ND) Dens _ ~ To (ttKB) Btm (RKB) (ftK8) (RKB) Zone Date (sh~~~ T pe Comment Gns ul'r, ~_ ~ 6,412 6,419 5,818.1 5,824.5 C-4, 3F-18 2/4/1999 4.0 APERF 2 1/2" HC-DP, 180 deg pH, +/- 90 deg 2,740 -~ 6,419 6,425 5,824.5 5,829.9 C-4, 3F-18 12/26/1998 4.0 APERF 2 1/2" HC-DP, 180 deg pH, +/- 90 deg SURFACE, 41-3,481 -• -S GAS LIFT, 3,948 ~- ~ GAS LIFT, r _ 4,%1 1 , k { GAS LIFT, ~ 5,697 ~I J Notes: General 8 pipe GAS LIFT, 6,224 1 NIPPLE, 6,277 i 1~ I 1 SEAL ASSY, 6,320 PRODUCTION, 376,340 APERF, 6,412-6,419 -_ --_ APERF. 6 bs6 azs Mandrel Details _ __ -~ , , __-- ~ Top iieplh Top _- _ _ _ Por [ APERF, (ND) Incl OD Valve Latch Size TRO Run 8,4256,428 Btn Tap (RKB) (RKB) (°I Make Model IiN Serv TYPe Type lin) (psi) Run Date Com... 1 2,739.9 2,515.0 24.77 Camco KBG-2-9 1 Gas Lifl GLV INT 0.156 1,282.0 8/11/2009 APERF, 2 3,947.7 3,594.9 26.97 Camco KBG-2-9 1 Gas lift GLV INT 0.188 1,317.0 8/11/2009 6,4806,490 3 4,960.8 4,499.8 26.41 Camco KBG-2-9 1 Gas Lift OV INT 0.250 0.0 8/10/2009 4 5,696.8 5,164.5 24.75 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 0.0 8/10/2009 IPERF. 6 fi216 641 5 6,223.8 5,645.1 23.35 Camco KBG-2-9 1 Gas Lift DMV INT 0.000 0.0 12/62008 , , APERF, , 6,664-6,684 PRODUCTION. 6,340-6.656 TD, 6,868 ~r~~~~~~~G1- NO. 5203 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Company: Alaska Oil & Gas Cons Comm ATTN: Beth ~~ ~, -~ ,~ i ! ~ ~~ Attn: Christine Mahnker~ ~ , ~~;~y~~, ~ j~ t „~ . F~ 333 West 7th Ave, Suite 100 6 ~ Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-03 ~2D-03 ANHY-00070 INJECTION PROFILE ' _ - j '~ 04/04/09 1 1 ANHY-00075 PRODUCTION PROFILE - ' 04/10/09 1 1 1 E-29 B04C-00030 PRODUCTION PROFILE ! 9 04/14/09 1 1 3G-13 ANHY-00079 INJECTION PROFILE _ t/ 04/15/09 1 1 3F-18 B04C-00031 PRODUCTION PROFILE / 04/15/09 1 1D-117 8148-00027 INJECTION PROFILE '~-- 04/16/09 1 1 1 1D-128 AYS4-00057 INJECTION PROFILE 04/16/09 1 1 iH-21 B14B-00028 PRODUCTION PROFILE G 04/17/09 1 1 1 D-120 AYS4-00058 INJECTION PROFILE 04/17/09 1 1 2K-22 AYS4-00059 IBP/SBHP - 04/18/09 1 1 1 E-15 AYS4-00061 INJECTION PROFILE Z,,. 04/20/09 1 1 9Y-04 AYS4-00071 INJECTION PROFILE 04/28/09 1 1 3F-02 AYS4-00063 PRODUCTION PROFILE <'~- 04/22/09 i 1 G-04 6148-00036 SBHP SURVEY `S. L° G( 04/23/09 1 1 1 iR-03A AYS4-00063 SBHP SURVEY , y -i_ ~+ ~O~j, _(~~~ ~ 9~/(~ 04/23/09 1 1 iG-06 B14B-00035 SBHP SURVEY ~~ j ~~ - ~~~ ~ ~~l ~ 04/23/09 1 1 iR-i0 B14B-00031 SBHP SURVEY + j~ c 04/20/09 i 1 2F-02 AYS4-00060 INJECTION PROFILE v (,+ - l~ I I 04/19/09 1 1 1R-15 B14B-00032 SBHP SURVEY, - ~ '- '~} L 04/20/09. 1 1 04/30/09 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 56i-8317, Thank you. Page 1 of 2 Maunder, Thomas E (DOA) From: Peirce, John W [John.W.Peirce@conocophillips.comJ 1 Sent: Wednesday, Apnl 29, 2009 8:51 AM (; ~ „ ~`' To: Maunder, Thomas E (DOA) `~ \~ Subject: FW: 3F-18 Perforating Tom, Below are all the post-pert well tests on 3F-18 (pert job was 3-22-09) and s ome addition al comments regarding the 3F-18 issues that you inquired about. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office Well Test History 3F-18: 500292268400:4/29/2009 Test SEP SEP Total Date Length CHK PRES Temp FTP WHT Oil Water Gas GLG WC FGOR TGLR Sai 04/15/200916:14 6.30 176 164 76 175 119 295 95 290 290 24.40 0 48 At 04/11/2009 20:12 18 176 175 118 185 120 54 1367 1009 790 96.20 4049 710 At 04/0912009 09:28 4.10 176 117 122 133 124 115 1569 1168 807 93.20 3140 693 At 04107/200917:03 42 176 169 119 184 121 82 1397 1208 943 94.50 3252 817 At 04/03/200919:08 42 176 156 120 168 121 90 1427 1174 894 94.10 3111 773 At 03/24/2009 01:45 15.80 178 175 122 188 123 327 1455 1340 1004 81.70 1029 752 At From: Poletrky, Isabel C Sent: Tuesday, Apri128, 2009 3:38 PM To: Peirce, John W Subject: RE: 3F-18 Perforating Hi John, ~, Yes, you are right. Cross flow is expected blc of the pressure difference and the PPROF confirms that we still have A sand contribution, but nothing is done to address the crossflow. About the well tests, the last one in the report is flagged as bad quality (4/15/09), but immediately after we had a well test (3/24109) and it looked like we were getting about 20 bopd more. Thanks, Isabel From: Peirce, John W Sent: Tuesday, April 28, 2009 10:11 AM To: Poletrky, Isabei C Subject: Re: 3F-18 Perforating Isabel, 4/29/2009 Page 2 of 2 We recently sent in a Report Sundry (form 10-404} to AOGCC to report the 3F-18 perforating job that was done on 3-22-09. Tom Maunder at AOGCC has some questions regarding what we reported (see below). The Report Sundry is attached for reference. My guess is that C to A sand crossflow while the well is shut-in is to be expected due to different zonal pressures, and that we have no intention of doing anything to address crossflow since the PPROF showed we get a decent A sand inflow contribution when the well is flowing. Regarding the post pert production rate reported, it is probably true that the last well test that we provided on the form is not representative of the well. The PPROF job comments indicated the we!! is slugging badly, so we may just be having a hard time getting a good well test? Please let me know if these are appropriate responses to Tom's questions. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office From, Maunder, Thomas E (DOA} [mailtoaom.maunder@alaska.gov] Sent: Tuesday, April 28, 2009 9:20 AM To: Peirce, John W Subject: 3F-18 (196-112} John, I have reviewed the 404 for the recent perforating and logging work on this well. Is there further work planned to address the cross-flow? Also, on the production date, it is indicated that there is no gas production and the water significantly reduced. Can you provide some comments about that? Call or message with any questions. Tom Maunder, PE AOGCC 4/29/2009 • ~~:r~ • STATE OF ALASKA ~~~ ~ ~ ~(~(~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS'~~'S~`a ~'~ ~` has ~~~~• ~9-rxn~~Y<- 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhIIIIpS Alaska, InC. Development ~ Exploratory ^ 196-112 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22684-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 55' ~ 3F-18 " 8. Property Designation: 10. Field/Pool(s): ADL 25643 Kuparuk River Field /Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6868' feet true vertical 6236' feet Plugs (measured) Effective Depth measured 6793' feet Junk (measured) true vertical 6167' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 3491' 7-5/8" 3481' 3180' PRODUCTION 6340' 5-1/2" x 6340' 5752' PRODUCTION 518' 3-1/2" 6858' 6227' Perforation depth: Measured depth: 6412'-6428', 6480'-6490', 6621'-6641', 6664'-6684' true vertical depth: 5818'-5833', 5880'-5889', 6009'-6027', 6048'-6067' Tubing (size, grade, and measured depth) 3.5", L-80 @ 6333' MD Packers & SSSV (type & measured depth} SBE @ s32o' Camco'DS' nipple @ 516' 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 Casin Pressure Tubin Pressure Prior to well operation 308 1144 1427 -- 185 Subsequent to operation 295 0 95 -- 175 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature / ~J, }°~ ._ ~ Phone: 265-6471 Date 4 -+Z2,^O~ /~ W '~ Pr ared b Sharon AlI u -Drake 263-4612 Form 10-404 Revised 04/2006 ~= Surbm'_ riginalOnly y'~~~ Y~ ACC C011000PI11~~iPS '' Well Attribute s Max Angl ° A„r:.:., r_ Wellbore APVU WI Prodnn/Type Field Name Well Stat tncl ( I MD . O KUPARUK RIVER U N IT RO 28.59 ) p _Dat Comment H2S ~ n End Date ~K81 ... SSSV NIPPLE 7 1/i/2009 Last WQ 12!4/2008 __ WaIIC fig:3F18, 42G 1( _ _ Schematic A u u: .,i Annotation Depth (ftKB) '~. End Data Annotation I Last Tag' SLM 6,762.0 I, 1/30/2009 (Rev Reason: PERFORATIONS Casing String s Casing Description ( String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String W .CONDUCTOR 16 15.062 0.0 121.0 121.0 62.5( PATCH. 10 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... '~ String W SURFACE 75/8 6.750 4t5 3,481.3 3,780.2 ~ 29.7C Casing Description String 0... String ID ... Top (ftKB) Set Depth (f_. Set Depth (ND) ... String W PRODUCTION 51/2 4.653 37.5 6,340.0 5,753.2 15.5( Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Dapih (ND) ... Skiing W PRODUCTION 31/2 2.867 6,340.0 6,858.0 6,2270 9.30 HANGER, 37- _ Tubing_String Tubing Description s _ String 0.-String ID ... Top (ftKB) TSet Depth (f... Set Oepth (ND) ... String W TUBING 31/2 2.910 ~i Completion Details Top Depth (ND). Top Inc! Top (ftKB) ~ (ftKB) ~ (°) Item Dascriptic CONDUCTOR. 36.8 36.7 0.10 HANGER 0121 516.1 513.6 13.76 NIPPLE 6,277.4 '. 5,697.1 25.351 NIPPLE 6,320.4 5,735.61 25.12~SEAL ASSY NIPPLE. 516- i~.i __._ rr_r_ nv-__•-__ __.. _.._r_ GAS LIFT, _ 2,]60 SURFACE, - _ 413,481 GAS LIFT. _ 3,948 GAS LIFT, _ 6.961 GAS LIFT, 5,697 GAS LIFT, 6.220 NIPPLE, 6,2]]- SEAL ASSV, 6,320 PRODUCTION, 37-6,340 APERF, 6,612-6,619 APERF, fiats-s,42s APERF. 6,4256.426 APERF. s.4ao-s.49a IPERF, - 6,621fi,64'I - APERF, 6,664-6,684 PRODUCTION, ~ e 6,340-6,858 TD. 6,868 10 6,412 Comment IAL CASING PATCH INSTALLED AT BOTT :E CASING MANDREL HANGER. SLEEVE 39" LONG x 8" OD, X65 PIPE 3F-18 w/Alaska Schematic9.0 Ma ndrel Details Top Da pth Top ~- I Port (TVDI Inc! OD Valve Latch Size TRO .Stn Top (ftKB) (ftKB) (°) ~' Make Model (in) Serv Type Typo ON I (p 1 2,739 9', 2,515.0 24.77 Camco KBG-2-9 1 Gas Lift GLV INT 0.156 , 1,2 ~~ 2 3,947.7 3,594.9 26.97I Camco KBG-2-9 1 Gas Lift GLV INT 0.156 1,2 - 3 4,960.8 4,499.8 26.41 Camco KBG-2-9 1 Gas Lift GLV INT 0.188 1,3~ 4 5,696.8 5,164.5 24.75i Camco KBG-2-9 1 Gas Lift OV INT 0.188 5 6,223.8 5,645.1 23.35 Camco KBG-2-9 1 Gas Lift DMY INT 0.000 3F-18 rD \ct Btm (ftKB) 6,868.0 gig Release Date 7/11/1996 rata 4/20/2009 ID Run deg PH, +l- 90 Run Date Comm 12/6/2008 3F-18 Well Work Summary DATE SUMMARY 3/22/09 PERFORATED WITH 2 1/8" P ER ENERJET 45 DEGREE OFFSET 6 S CHARGES FROM 6664'-6684' 4/15/09 RAN PRODUCTION PROFILE WITH DEFT AND GAS LIFT SURVEY. RESULTS: GAS LIFT FROM GLV #3 AT 4961'. DIFFICULT TO GET ACCURATE PRODUCTION SPLITS DUE TO SLUGGING. SMALL AMOUNT OF PRODUCTION FROM A-2 SAND AT 6664'-6684'. APPROXIMATELY 35% OF PRODUCTION FROM A-3 SAND AT 6621'-6641', APPROXIMATELY 55% OF PRODUCTION FROM C-1 SAND, APPROXIMATELY 10% OF PRODUCTION FROM C-4 SAND. SHUT IN WELL AND CROSSFLOW SEEN FROM C SANDS TO A-3 SAND. Page 1 of Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Monday, January 26, 2009 5:10 PM To: Maunder, Thomas E (DOA) Subject: RE: 3F-18 (196-112) Attachments: 3F-18 Schematic (12-25-08).pdf; 3F-18 Well Service Reports.doc Tom, My apologies for the outdated drawing. I corrected the removal of the plug on the 10-404 before Sharon sent it to you, but forgot to tell her to include an updated schematic. Attached is the most current schematic and the pre/post rig work summary. Unfortunately, due to our wonderful electronic schematic builder, we cannot change the fact that it refers to the lower portion of a tapered casing string as a liner; our schematics used to be so much better when they were manually built and updated. The program Sharon uses to create the 10-404 automatically pulls the data from the schematics, hence, the reason it called it a liner also. I'll make note of this and let everybody in our group know to be aware of how the 10-404's are reported on this type of completions. Ong ~ `Wells ~~`` tt~~ `Worl~yverEreg:neer 3~ 4~ ~~;-.. 1 y ~ ~Ut~ `Work# (907)265-6845 a;~~sJ'~*~d~~.i~ `~~~~ Celf# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 26, 2009 10:14 AM To: Packer, Brett B Subject: 3F-18 (196-112) Brett, I am reviewing the 404 submitted for the workover performed in late November. 1. On the 404 it is indicated that there is production casing with a liner while such is not the case. The well is equipped with a tapered casing with a seal bore at the XO. 2. It is also stated that there is no packer which is technically correct however there is a seal bore which functions as the equivalent of the packer. In the future, when wells are so equipped please note this in the "packer line". 3. No pre-/post rig work summary was included. 4. On the drawing, the WRP and junk catcher are still shown. Since the well is reported to be producing, it appears these items have been removed from the well. I have made hand corrections to the 404, but please send a new drawing and the pre-/post rig work summary. Call or message with any questions. Tom Maunder, PE AOGCC 1 /27/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION. REPORT OF SUNDRY WELL OPERAT,~~~VS JgNa2~ - 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ f ~t~, ^ °~ t~~•. Alter Casing ^ Pull Tubing Q ~ Perforate New Pool ^ Waiver ^ Time+S~n ^ + sr , :.. , Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well" ~^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 196-112 / ' 3. Address: Stratigraphic ^ .Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22684-00 ` 7. KB Elevation (ft}c 9. Well Name and Number. RKB 41', pad 55' 3F-18 ` 8. Property Designation: 10. Field/Pool(s): ADL 25643 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6868' feet true vertical 6236' feet Plugs (measured) Effective Depth measured 6793' feet Junk (measured) true vertical 6167 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 3491' 7-5/8" 3491' 3189' PRODUCTION 6340' 5-1/2" 6340' 5752' LINER 518' 3-1/2" 6858' 6227' th P fo ti d th M d d " ~ 6412' 1' / 6 2 6 21' ' ' ' : er ra on ep : easure ep Q - 4 , 6480 490 -664 8 - , 66 true vertical depth: 5818'-5833', 5880'-5889', 6009'-6027' Tubing (size, grade, and measured depth) 3.5", L-80, 6333.27' MD. // ~ j Packers & SSSV (type & measured depth) no packer `a~\ ~S`~ ~ ~ ~O ~ ~ v -~ tl ~ ~ Camco'DS' nipple @ 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable ~ - i~~l~„ ~~~u` ~ r~jQ~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 400 958 1897 -- 186 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ' Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none contact Brett Packer @265-6845 Printed Name Brett P Title Wells Group Engineer ~L~~ 1 /~~- a cke ~~ ~ !/ "' Phone: 265-6845 Date ~ ~ Signature !~~~ ~ P ared b haron Allsu Drake 263-46 2 Form 10-404 Revised 04/2006 JR161NAL ~~, Submit Original Only ~!` -~ `y • .- ConocoPhillips ~` ' PATCH. TuGeg N~np CONDUCTC o-1 NIPPLE S GAS LI I 2.7 SURFAC 63. GAS LI F 3.9 GAS Llf d.9 GAS LII s.e GAS u I 8,2 NIPPLE. fi 2 SEAL ASS 8.3 PBR. 8.7 PRODUCTIC D4.] APEP 8,0124. ~ APEF 8,4184. APEF B.d254. ~ APEF B.dBDB, a IPEF e.ez14, e LINE B.Sd0.8. B TD. 8.8 KUP • SLM 6,390.0 1220/2008 Rev Reason: PULL PLUG, TAG 3F-18 I Bti11,RKB, 6,868.0 I Rekeee Det 7/11/1996 ~ ueee 12/25/2008 ~, ~^ KUP • 3F-18 ~tJt1C3CC71P~"11~~1~35 WeILAttnbu ` tes I MaxA ggle&MD .Tl) 11;ha i+'+ ~ Wellbore APW WI { Fieltl Name Well StdtpS (Prod/ln/Type Inc!() IMD (ftK8) 'Act Bfm (ftK8) I . _ 500292268400 KUPARUK RIVER UNIT ( PROD 28.59 3,755.40 i 6,868.0 _ H2S (ppm) Date Annotation End Data KB-Grd (ft) Rig Release Dat _- ..- PPLE -- S 120 I 7/1/2008 (Last WO: I 1214/2008 7/11/1996 wal_c I -6Fi6: us 9 Sch r~,al A ~, otation J ~ A De [h ftK8 End Data P ( 1 I Annotation ' End Dale NIPPLE. 516 - - ___..,~ __..-...r.._., CONDUCTOR 16 15.062 0 0 r 121.0 ~~~ i__...o .-.... 121.0 62.50 r __...a ... H-00 ICasing Description iStrin 0... g Strin ID ... g To ftK61 p( Set Depth i... ( Set De th ND p ( )... ~'~String Wt... String... String Top Thrd ~ 7 /8 6. 50 0 3,4910 3 7890 m ~ L-80 ' Casin Description 9 iStrin 0... 9 Strin ID ... pi ) To ftK8 Set Depth t... P ) yyt ~ g rString ... IString TOp Thrd Set Da th ND Sh' s O D O (t S 1/2 4.653 0.0 6,340.0 5,753.2 15.50 I L-80 C I n Descr ip ion g IString O... String lD ... Top (ftK8) Set Deplh (t... Set Depth(ND)... IString Wl... String ...'String Top Thrd LINER _ 31/2 2.867 6,340.0 6,858.0 6227.0 9.30 L-80 '~ ___ Tubing Strin~s _ _ Tubing Description (String 0... String ID ... Top (ftKel~ Set Depth (f... Set Depth (NDI ... String Wt... IString ... 'String Top Thrd (l V DI I Top Inc! I, '..Top (ftK8) (flK8) ~~ (°) Description I Comment Run Date '1 ID_(in) OAS uFi. ___ 10 0 10.0 0.02 PATCH EXTERNAL CASING PATCH INSTALLED AT BOTTOM OF 10/10/2005 ' 7 825 _ 2.7w (SURFACE CASING MANDREL HANGER. SLEEVE PATCH: 39" LONG x 8" OD, X65 PIPE i 327.0 5,741.5' 25.08 PBR Baker Locator 7/11/1996 3.000 suRFACE, _ 8-3 691 6, .0 5,797.31 24J5 CATCHER SET CATCHER SUB @ 6381 SLM 11/21/2008 0.000 , _. ____ 6,390. 5,798.2! 24.75 WRP SET WEATHERFORD 3-1/2"SPECIALCLEARANCE WRP 11/14/2008 0.000 AT 6390' MD (MID-ELEMENT) OAS UFT, 3.948 PerForatio _ ___.., _. _- Shot Top (TVD) Btm (TVD) Dans _ Top (ftK8) i Btm (flK8 (ftK8) (ftK61 Zone Date lsh... TYPe Comment _ - 6,412.O 6 419.0 5,818.1 5,824.5 C-0, 3F-18 2/4/1999 4.0 APERF 2 1/2" HC-DP, 180 deg pH, +/_ g0 deg - 6,419.Oi 6,425.0 24.5 5,829.9 C-0, 3F-18 ,12/26!1998 4.0 APERF 2 1/2" HC-DP, 180 deg pH +/- 9p tleg 6,425.0 6 428.0 5,8 9 5 832.6 C-0, 3F-18 ~ 2/4/1999 4.0 APERF 2 1/2" HC-DP, 180 deg pH +/- g0 deg OASb yfit' I 6,480.01, 6 490.01 5,879. 5,889.0 C-1, 3F-18 5/11!2002 6.0 APERF 2.5" HSD, PJ DP, 60 deg pH .4 ~I 6,621.0, 6,641.0! 6,009.0 6,027.4 A-3, 3F-18 7/27/1996 4.0 IERF 2 1/2" HSD, 180 deg pH Notes: General 8 Safet _ End Date Annotation '',4/9/2008 NOTE: NIPPLE @ 51 /2.812" ID, BUT GAUGED TO 2.80" OAS LIFT. 5,697 r 112/6/2008 NOTE: VIEW SCHEMATI w/Alaska Schematic9.0 - ____. - ~~~~~~~~.~1~6 NIPPLE, 6.2]] / ~ ~~ 1 _ ~.yFl ~~~~'llll ~II ~~u.~4.~•~.~~~si-...r.~.ss. SEAL ASSV..- 6.320 - PBR,6,327 PRODUCTION, 0-6.340 CATCHER,_ 6.389 WRP, 6, - APERF, 6,412-6,419 APERF,__ 6,419-6 625 APERF, _ 6,426-6.428 APERF, 6 480-6.490 IPERF,. 6,621-6,641 - -- LINER, 6,34G-6.856 TD. 6.868 OD Valve Latch Sae TRO Run 1 ,739,91 2,515.0 24.77 Camco KBG-2-9 1Gas Lift 3,947.711 3,594.9 26.97 Camco KBG-2-9 1 Gas Lift 3 4,960 8 4,499.8 26 41 Camco KBG-2-9 1 ~ Gas Lift 4 5,696.8 5,164.5 24.76,Camco '.KBG-2-9 1 Gas Lih • • 3F-18 Well Service Reports Pre/Post RWO Date Event Description 1/15/09 PERFORM FILL CLEAN OUT TO PBTD C~ 6757 CTMD, HEAVY SOLIDS & ROCKS IN RTNS. WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. 12/20/08 PULLED WRP @ 6390' RKB. TAGGED @ 6606' SLM, JOB COMPLETE. 12/19/08 WASHED DOWN TO TOP OF WRP @ 6375' CTMD. REVERSING OUT WITH SD AND DG, LEFT WELL FREEZE PROTECTED AND SHUT IN. READY FOR SLICK LINE. 12/9/08 - 12/17/08 BAILED FILL ON WRP. DELAYS DUE TO PHASE 2 & 3 WEATHER. 12/8/08 RECOVER_F,D STiJCK TOOLSTR_TNG. BAILED FILL OFF CATCHER SUB na, 6389' RKB & PULLED SAME. IN PROGRESS. 12/7/08 BAILED FILL OFF CATCHER SUB. STUCK TOOLSTRING; DROPPED CUTTER BAR. RECOVERED ALL WIRE. PULLED CUTTER BAR. TOP OF FISH @ 6350' SLM. 12/6/08 PULLED SOV @ 6223' RKB & REPLACED WITH DV. MIT IA 3000 PSI, PASS. PULLED DVs @ 5697', 4961', 3948' & 2740' RKB. SET 3/16" OV @ 5697' RKB. SET GLVs @ 4961', 3948' & 2470' RKB. IN PROGRESS. 11/30/08 - 12/4/08 Rig Workover 11/20/08 CMIT TO 2500 PSI (PASSED), BLEED TBG.,IA TO 20 PSI (DHD TO RETURN TO PERFORM REMAINDER OF DRAWDOWN TEST), SET 2.71" CATCHER @ 6381' SLM- 6390' RKB. 11/14/08 SET WEATHF.RF(~RD 3-1/2" SPECIAL. CLEARANCE WRP AT 6390' MD (MID, ELEMENT). DID NOT TAG TD. WELL LEFT SHUT IN. 11/12/08 DRIFTED TBG WITH 2.70 CENT, 3' STEM, 2.73 SWAGE TO 6611' SLM. PULLED DV @ 5947' RKB. WELL READY FOR WRP. 10/16/08 T & IC POT/PPPOT -PASSED, FUNCTION TESTED T LDS (PRE-RWO ) 5/21!08 PULLED 3.5" WRP @ 6331' SLM. MEASURED BHP @ 6526': 2863 PSI. COMPLETE. 5/16/08 CMIT T x IA -PASSED 5/15/08 SET WEATHERFORD 2.69" OD WRP WITH MID ELEMENT AT 6356'. READY FOR DHD TO TROUBLESHOOT. 4/29/08 PULLED 3.5 CAT STANDING VALVE FULL OF SCALE @ 6318' RKB. RAN CALIPER SURVEY FROM 6360' TO SURFACE. RECOVERED GOOD DATA. JOB COMPLETE. 4/23/08 RAN A LEAK DETECTION LOG. PUMPED DIESEL DOWN THE TUBING AT 0.5 BPM WHILE TAKING RETURNS FROM THE IA TO THE FLOWLINE VIA A JUMPER HOSE ** FOUND A TUBING X IA LEAK AT 6170' ** 4/18/08 DETERMINED LEAK IN TBG. TO BE BETWEEN 5986' RKB AND 5976' RKB (BELOW STA #4 @ 5947 RKB) (( LEFT CAT STANDING VALVE IN TBG (43 1/4" OAL - 20 1/2" DEEP FISH NECK) FOR E-LINE TO DO LEAK DETECT )). 4/17/08 LEAK DETECTED W/ HOLEFINDER AND DETERMINED LEAK TO BE BETWEEN 5924' RKB AND 5993' RKB (SUSPECTING STA # 4 @ 5947' RKB ). SET CAT STANDING VALVE @ 6318' RKB. PULLED OV @ 5947 RKB (GROOVE CUT THROUGH BOTH PACKING STACKS) AND SET NEW OV (STILL HAVE TBG. X IA COMMUNICATION }. PULLED OV, RAN POCKET BRUSH, AND SET DGLV ( EXTENDED PACKING W/ 9 AVA SEALS) @ 5947' RKB . ATTEMPT TO PRESSURE UP TBG. AND STILL HAVE TBG. X IA COMMUNICATION. ((IN PROGRESS )). 4/14/08 RE-TIFL (FAILED) Cono~QPhillips Time Log & Summary 1NelNiew Web ReAOR'Fng ~ \epo Well Name: 3F-18 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 11/30/2008 4:00:00 PM Rig Release: 12/4/2008 6:00:00 PM Time Logs Date From 7o Dur S. Depth E Depth Phase Code Subcode T Comment _ __ 11/30/2008 _ _ 2a hr Summary Road rig from 1 R-09 to 3F-18. MIRU and circulate well -dead. 01:30 05:00 3.50 COMPZ MOVE MOB P Move Nordic Rig 3 from 1 R-09 to S ine road and 1 R access. 05:00 07:30 2.50 COMPZ MOVE OTHR P Set down and Standby for CPAI feild crew chan e 07:30 16:00 8.50 COMPZ MOVE MOB P Continue to move Nordic Rig 3 to 3F pad. Nordic Ri 3 ac ted on 3F-18 16:00 on 11 /30/2008. 16:00 18:00 2.00 COMPZ MOVE PSIT P Spot tanks, RU Equipment, and RU hardline to kill tank. Load pits w/ 9.6 brine. 18:00 20:30 2.50 COMPZ WELCTL OTHR P Open up well. 0 psi SITP -BPV installled. 60 psi SIIA, 0 psi SIOA. Lubricate out BPV and and SITP was 2 si. 20:30 23:30 3.00 COMPZ WELCTL CIRC P PT hardline to kill tank @ 2,500 psi. Circulate 190 bbls of 9.6 ppg brine @ 3 bpm @ 150 psi taking returns to Kill tank till returning fluid wt was 9.6 ppg. Circulate 1 hole vole of 190 bbls back to ri its. Well Dead. 23:30 00:00 0.50 COMPZ WELCTL OWFF P Monitor well -well dead. 12/01 /2008 Set BPV, ND Tree. NU BOP. Test BOPE -Blind rams failed. 00:00 02:30 2.50 COMPZ WELCTL NUND P Set BPV. ND Tree 02:30 05:30 3.00 COMPZ WELCTL NUND P NU BOPE 05:30 07:00 1.50 COMPZ WELCTL BOPS T Attempt to test. Blanking plug leakin ull lu and set new lu . 07:00 00:00 17.00 COMPZ WELCTL BOPE P Continue testin BOPE. Test LPR's, UPR's and annular. along w/ choke manifold and passed @ 250/2,500 psi. 24 hr notice given to AOGCC @ 18:00 hrs @ 11-29-08. Witness of test waived by Bob Noble @ 07:25 hrs on 11-30-08. Blind rams failed, re-dressed -failed. Swap out Blind rams w/ new carriers, ackers and to seals. Failed. 12/02/2008 ND 11" BOPE, NU tree, tested and freeze protected well, backed rig off well, CO BOP stacks to 13 5/8", ulled ri over well, circulated out diesel to kill tank, ND tree, started NU 13 5/8" stack. >~ a Tirne Logs _ _- - _ - _! Date From To Dur S. De_ th E. De th Phase Code Subcode T Comment __ r 00:00 04:00 4.00 0 0 COMPZ WELCTI NUND ___ T Drain Stack and Remove Blind rams from 11" BOP stack. ND ROPE service break same. Set back BOP Stack. 04:00 08:30 4.50 0 0 COMPZ WELCTI NUND T NU Tree and test void to 5000 psi / 15 min. Pull BPV set TTP plug and test tree to 5000 si. Pull TTP. 08:30 10:30 2.00 0 0 COMPZ RPCOM FRZP T Freeze protect well w/ 50 bbl of diesel. U-tube tubin and IA. 10:30 15:30 5.00 0 0 COMPZ RPCOM OTHR T Jack and move back rig to change out BOPE (remove 11"stack and install 13-5/8" stack), spot rig over we . 15:30 18:30 3.00 0 0 COMPZ WELCTL CIRC T R/U to kill well. PJSM, pressure test hard line. Circ hole volume at 3 bpm, 580 si. 18:30 19:00 0.50 0 0 COMPZ RPCOM OTHR T Blow down and rig down circ lines. 19:00 21:00 2.00 0 0 COMPZ WELCTL NUND T Install bpv, ND tree. 21:00 00:00 3.00 0 0 COMPZ WELCTI NUND T Install blanking plug and start NU 13 5/8" BOP. 12/03/2008 Test 13 5/8" BOP, pulled hanger to floor, CBU, POOH LD 3 1/2" completion, racked and tallied new 3 1/2" com letion, PU and RIH with new 3 1/2" IBT com letion and 'ewel 00:00 02:30 2.50 0 0 COMPZ WELCTI NUND T Install VBR's in upper gate, 3 1/2" rams in lower ate. 02:30 04:30 2.00 0 0 COMPZ WELCTI BOPE T RU and test 13 5/8" BOP stack at 250 low - 2,500 high, perform draw down test. Notified AOGCC of up-coming 13 5/8" BOP test at 18:00 hrs on 12-2-08. Witness of up-coming test was waived by AOGCC Rep John Cris . 04:30 05:00 0.50 0 6,327 COMPZ RPCOM OTHR P Pull blanking plug and BPV, install landing jnt, RU circ hose, BOLD's, ulled to 150K and seals came free, u wt 85K, ulled han er to ri floor. 05:00 06:00 1.00 6,300 6,300 COMPZ RPCOM CIRC P CBU at 5 bpm - 1,450 psi taking clean returns to its. 06:00 15:00 9.00 6,300 0 COMPZ RPCOM TRIP P LD hanger and landing joint. POOH with 3-1/2" tubing and seal assembly. Up wt = 83 K#, down wt = 72 K#. Sever external corrosion observed on the the bottom 5 joints of 3-1/2" tubing (joints # 189 to 193). Photos taken and NSK Corr. Dept. was notified. Majority of holes and corrosion was found at mid-joint in all 5 'oints. 15:00 19:00 4.00 0 0 COMPZ RPCOM RURD P Un-oad pipeshed, load new jewelry, prep handling equipment for IBT, clean rig floor, prep pipeshed to PU and RIH. 19:00 00:00 5.00 0 4,642 COMPZ RPCOM RCST P PU and RIH with 3 1!2" IBT com letion strin to 4,642'. ~- ~- ~'g ~ P 6RL ~ 43&`' ~ i, r~ Time Logs ~ Date _ From To Dur S_ .Depth E -Depth Phase- --Code __Subcode T Comment ____ _ ___ 12/04!2008 24 hr summary Cont PU and RIH with completion, locate and space out, spot corrosion inhibited brine in lA, land string, RU and test tubing and IA, set BPV and ND BOP's, NU tree and test, freeze protect well, set BPV and RDMO, move ri from 3F ad to 30 ad. 00:00 01:30 1.50 4,642 6,336 COMPZ RPCOM RCST P Cont PU and RIH with 3 1/2" IBT completion from 4,642'. Tag no-go at 6,323' md, mule shoe at 6,336', up wt 85K, down wt 70K. 01:30 02:00 0.50 6,334 6,334 COMPZ RPCOM HOSO P Space out with 4' pup, MU FMC Gen IV hanger, landing joint and circ hose. 02:00 03:00 1.00 6,334 6,334 COMPZ RPCOM CIRC P Reverse circ 75 bbls corrosion inhibited brine with 1% CRW-132 at 3 b m - 520 si. 03:00 03:30 0.50 6,334 0 COMPZ RPCOM OTHR P Drain BOP stack, land hanger, RILD's. Mule shoe at 6,334'. 03:30 04:00 0.50 0 0 COMPZ RPCOM DHEQ P RU and test 3 1/2" tubin at 2,500_ psi for 15 minutes on chart, good test. 04:00 05:00 1.00 0 0 COMPZ RPCOM DHEQ P Bleed tubing to 1,750 psi, pressure up on IA to 3,000 psi, pressure bleedin off checked a crrc mes, re-torqued lock downs, pressured up on IA to 3 000 si and held for 30 minutes on chart, good test. Bled IA then tubing to 0 psi, pressured up on IA and sheared SOV in lower GLM at 1,700 si. 05:00 09:30 4.50 0 0 COMPZ RPCOM NUND P RD circ lines, LD landing joint, install BPV, ND 13 5/8" BOP. 09:30 12:00 2.50 0 0 COMPZ RPCOM NUND P NU Tree. Test packoff to 5000 psi / 15 min. Pull BPV, set TTP, test tree to 5000 si. 12:00 14:30 2.50 0 0 COMPZ RPCOM FRZP P RU and pump freeze protect. Pump 60 bbl of diesel down the IA taking returns up the tubing. Allow tubing and IA to a-tube. Tubin /IA/OA ressure = 0/0!0 14:30 18:00 3.50 0 0 COMPZ RPCOM RURD P Set BPV. Secure well, dress tree. Nordic Rig 3 released from 3F-18 at 18:00 on 12-04-2008. ~~ ~'~ca~ 3 ~f ~ ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4678 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04!30/08 3K-102 NA PRODUCTION PROFILE _ 04!08/08 1 1 1 E-04 11996622 LDL ~~ -t p - G( 04/16!08 1 1 2U-13 11996617 PRODUCTION PROFILE - ay 04/10/08 1 1 2W-17 11996618 SFRT - 04/12/08 1 1 2L-330 11970662 PERF/SBHP U - l 04/19/08 1 1 3F-18 11970666 LDL Q 04/23/08 1 1 1 D-130 11964595 LDL C~ ~_ 04/23/08 1 1 1Y-07 11964596 INJECTION PROFILE -~~; / ~ 04/24/08 1 1 2T-217A 11970667 INJECTION PROFILE --p ~ 6to /~ 04/24/08 1 1 1F-05 11964597 INJECTION PROFILE / /Cj 04/25/08 1 1 3K-102 12021157 MEM PROD PROFILE _ ~ 04/26108 1 1 iL-09 11970669 PRODUCTION PROFILE _ c( 04/26/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~ o . AA ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/open Hole/Mechanical Lags and /or Tubing inspection(Caliper J MTT} The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActnre Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 } Caliper Report 29 Aprv08 3F-18 1 Report / EDE 50-029-2268400 2) 1Qi~e-lea ~ MAY 1 ~ 2DD8 Signed Print Name: -~~t~r~ Oate : v PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RO SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL: ~:~~~83a'.~tD~3w~~3s3es'?G~*!3^4~,ii+C'a's WEBSRE:;.~'+y`,~.73'3Sa~'43Ykf?C .:~v>§a? C:\Documen~ and Settings\Owner\Desktop\Transmit_Conoco.doc • • Memory Mult"r~inger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3F-18 Log Date: Apri129, 2008 Field: Kuparuk Log No.: 9544 State: Alaska Run No.: 1 API No.: 50-029-22684-00 Pipet Desc-: 3.5" 9.3 Ib. L-80 EUE 8RD MOD Top Log Intel; Surface Pipet Use: Tubing and Liner Bot. Log Intel: 6,380 Pt. (MD) tnspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : ' This caliper data is tied Into the D-Nipple ~ 6,318' (Dialler`s Depth). This log was run to assess the condition of the tubing and liner logged with respect to corrosive and ' mechanical damage. This is the first time a POS caliper has been run in this well. The caliper recordings indicate the 3.5" tubing logged is in good to poor condition with respect to corrosive damage. Holes are recorded in joints 186 (6,055') and 190 (6,170'). Recorded damage appears in the forms t of general corrosion with intermittent line corrosion and deeper isolated pitting. Cross-sectional wall loss of 26% is recorded at the hole in joint 190 (6,170'). No significant LD. restrictions are recorded throughout the tubing and finer logged. ~,~~, MAY 7 200& MAXIMUM RECORDED WALL PENETRAl10NS ~' Holes! (100°~) Jt. 190 @ 6,170 Ft. (MD) Hole! (100%) Jt. 186 ~ 6,055 Ft. (MD) Line Corrosion (50%) Jt. 165 @ 5,334 Ft. (MD) ~,' Isolated Pitting (41%) Jt. 195 ~ 6,380 Ft. (MD) Isolated Pitting (38%) Jt. 177 @ 5,741 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No significant areas of cross-sectional wall loss (> 11 %) are recorded throughout the tubing and liner i logged. MAXIMUM RECORDED ID RESTRICTIONS ~ No significant LD. restrictions are recorded throughout the tubing and liner logged. Field Engineer: S. Carpenter Analyst: A9. Lawrence & C. Waldrop Witness: C. Fitzpatrick ~ ProActive Diagnostic Servicev, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (281) 565-1369 E-mail: PDS,a~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 655-2314 ' 1~1Co-l(~ ~ 1(0!~ • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (27.4' - 6379.2') Well: 3F-18 Field: Kuparuk Company: ConocoPhi~ips Alaska, Inc. Country: USA Survey Date: April 29, 2008 ^ A pprox. Tool De viation . A pprox. Borehd e Profil e 34 793 1584 2372 GLM 1 p 3201 ~ c t 3992 GLM 2 4819 GLM 3 5647 GLM 4 GLM 5 195 6379 0 5 0 1 00 Da mage Pr ofile (% wall) / Tod D eviatio n (degr ees) Bottom of Survey = 195 1 25 50 75 ~ 100 E Z .0 125 ~_ 150 3 175 ~. • • PDS Report Overview ~ S, Body Region Analysis Well: 3F-18 Survey Date: April 29, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro & M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. l 3 5 ins 9 3 ppf L-80 EUE 8RD MOD 2 992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body =~ metal loss body 150 100 50 0 0 to 1 to 10 to 20 ro 40 to over 1% 10% ZO% 40% 85% 85% Number of ~oints anal sed rotal = 209 pene. 0 55 134 16 2 2 loss 113 94 1 1 0 0 Damage Configuration (body ) 80 60 40 20 0 iwlated general line ring hole~poss pitting corrosion corrosion corrosion ible hole Number of ~oints dams ed total = 117 78 29 8 0 2 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 100 0 49 GLM 1 GLM 2 145 GLM 3 GLM 4 191 _---- GLM 5 - Bottorn of Survey= 195 Analysis Overview page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3F-18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 29, 2008 Joint No. Jt. Depth (Ft.) I'~vi. l II „c•t (Ins.) Pen. Body (Ins.) Pen. % Me~il I uti~ •~ Min. LD• (Ins.) Comments Darnage Profile (°I° wall) 0 50 100 .1 27 U 0.02 7 I .95 PUP .2 30 U 0.01 4 2.90 PUP 1 34 0 0.03 13 2.94 Sh Ilow ittin . 2 66 0 0.0 9 i 2.95 3 98 U 0.03 1 3 _' 2.93 Shallow itbn . 4 130 (1 0.02 ~) 1 2.93 5 161 ~ ~ 0.03 10 ~? 2.93 6 193 11 0.03 11 I 2.93 7 2 4 (? 0.03 1 1 2.94 8 255 0 0.03 12 1 2.93 9 2 7 0 0.03 13 2.94 Shallow i do . 10 318 (~ 0.03 12 1 2.94 11 350 0 0.03 13 ~ 2.92 Shallow it6n . 12 382 ~ ( 0.02 9 1 2.93 13 413 0 0.04 14 2 2.93 Shallo ittin . 14 445 U 0. 2 9 (~ 2.92 15 47 0 0.03 10 2.93 5.1 508 (~ 0 0 u 2.81 Camco DS Ni No Go 16 510 (? 0.03 12 I 2.94 Shallow corrosion. 17 541 l ~ 0.03 11 2.94 18 573 t~ 0.03 13 1 2.94 Shallow itU 19 605 0 0.03 11 _' 2.93 20 637 U 0.03 10 ~' 2.93 21 667 0 0.02 9 1 2.92 2 6 8 u 0.03 11 (, 2.93 23 730 t~ 0.03 11 _' 2.94 4 762 a .02 ~~ 1 2.93 25 793 0 0.02 ~> _' 2.95 26 825 0 0.03 12 ~' 2.94 Shallow itUn . 27 857 0 0.04 14 ~' 2.94 Shallow itpn . 28 888 0 0.03 I1 1 2.93 29 920 0 0.03 13 4 2.93 Shallow ittin . 30 952 0 0.03 1 1 1 2.94 Shallow itUn . 31 984 0 0.02 ~~ I 2.93 32 1015 U 0.04 14 I 2.93 Shallow corrosion. 33 1046 ~) 0.03 1 ~' 2.94 34 1078 ~ ~ 0.01 t~ I 2.93 35 1110 (~ 0.04 1-1 I 2.95 Shallow itUn . 36 1142 U .03 1 > I 2.93 Shallow corrosion. 37 1173 U 0.04 1 ~ _' 2.94 Shallow corrosion. 38 1 05 0 0.03 1 ~ b 2.93 Sh Ilow it'n . 39 1236 0 0.01 4 1 2.94 40 1268 t ~ 0.03 12 _' 2.95 41 1300 (~ 0.02 8 1 2.94 42 1332 0 0.03 13 I 2.93 Sallow ittin . 43 1363 ~ ~ 0.02 ~~ ~' 2.93 44 1395 (i 0.01 4 1 2.94 45 1427 0 0.03 11 ? 2.94 46 1459 U 0.03 13 _' 2.92 Shallow itUn . 47 1491 0 0.03 13 7 2.94 Shallow corrosion. Penetration Body Metal Loss Body Page 1 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3F-18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 29, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ulxc•~ (lns.) Pen. Body (Ins.) I'en. °/> Mc~l,~l lu~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1522 t? 0.03 1 t 1 2.94 49 1554 U 0.01 b 2.93 50 1584 l i 0.03 l U 2.94 51 1615 t ~ 0.03 I I 2.93 52 1647 U 0.02 rs I 2.93 53 1679 ~ ~ 0.01 ~ I 2.93 54 1711 t ~ 0.03 I I -1 2. 3 5 1742 U 0.02 ~) I 2.94 56 1774 U 0.04 14 I 2.93 Shallow itUn . 57 1806 r_) 0.03 11 2.92 58 1838 U 0.03 10 r) 2.93 59 1869 a 0.02 9 1 .93 0 1900 t 7 0.02 ~~ 1 2.92 61 1932 i! 0.04 15 2.94 Sallow itti 62 1963 U 0.02 ~> 4 2.94 63 19 3 0 0.03 1 1 -1 2.93 Shallow itUn . 64 2025 U 0. 3 11 I 2.91 t De sits. 65 2055 t) 0.01 5 I 2.92 66 2087 U 0.03 1 "~ 1 2.93 Shallow corrosion. 67 2119 i1 0. 2 ') -} 2.93 68 2151 t~ 0.04 15 I 2.93 Shall w cor osion. 69 2182 t I 0.02 ~> 2.93 70 2 14 U 0.04 14 1 2.93 Shallow 'tUn . 71 2245 t ~ 0.03 1 t ~ - 2.93 72 7 U 0.03 l i - 2 94 Shallo ittin . 73 2309 U 0.04 15 ~ 2.94 Shallow corrosion. Lt. De sits. 74 2341 U 0.03 Ill 1 2.93 75 2372 0 0.04 I -1 I 2.93 Shallow corrosion. 76 405 0 0.02 ~~ I 2.93 77 2436 tl 0.02 ~~ I 2.94 78 2468 ~? 0.03 l l 1 2.93 Sh Ilow corrosion. 79 2500 ~ ~ 0.02 is 2 2.93 80 532 t I 0.01 5 1 2.93 81 2563 U 0.03 12 5 2.93 82 2595 U 0.04 1-1 ~ 2.94 Shallow i 6n . 83 2627 n 0.03 I U -~ 2.94 84 2659 a 0.02 t3 t3 2.93 85 2690 ~ ~ 0.03 12 1 2.93 86 2722 U 0.02 9 1 2.93 87 2754 0 D.O1 5 U 2.93 88 2785 U 0.03 11 1 2.94 89 2817 U 0.04 14 I 2.93 Shallow ittin . 90 848 U 0.03 10 I 2.94 91 2880 U 0.03 l3 I 2.93 Shallow itU 92 2912 i1 0.03 11 4 .94 93 2943 it 0.02 ~> 1 2.94 94 2975 ~~ 0.03 la ~ 2.9 Shallow it'n . 94.1 3006 0 0.01 (, ~' 2.91 PUP 94.2 3(121 U 0 11 t~ N A GLM 1 Latch ~ 5~0 94.3 302£3 t~ 0.01 4 I 2.96 PUP Penetration Body Metal Loss Body Page 2 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3F-18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 29, 2008 Joint No. Jt. Depth (Ft.) I'cn. l tl„ ~~t (Ins.) Pen. Body (Ins.) Pc•n. °/~ ~~1~~tal I uti~ °.4. Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 95 3043 ~? 0.04 1-l I 2.94 Shallow itUn . 96 3074 U .03 I 1 2.92 Shallow it'n . 97 3106 tt 0.03 1 s u 2.91 Shallow itti 98 3137 t? 0.02 ~) I 2.93 99 3169 (t 0.01 4 I 2.92 100 3201 t t 0.04 1 '"i -1 2.92 Shallow corrosion. Lt. a sits. 101 3233 a 0.0 '~ 2.93 102 3265 t t 0.04 I -1 ~, 2.93 Shallow corrosion. 103 3 96 (? 0.01 t> i 2.91 104 3328 i t 0.0 1 1 t t 2.93 105 3359 i t 0.03 1 1 i t 2.91 106 3391 tt 0.03 11 it 2.9 107 3422 a 0.02 9 I 2.91 108 345 tt 0.03 1 9 _' 2.92 Shallow itUn Lt. De sits. 109 3486 tt 0.04 I5 1 2.91 Shallow itUn . 110 3517 U 0.03 I ll 2.89 Shallow it§n . 111 3549 U 0.02 t3 ~ 2.93 112 3 81 U 0.02 '~ 1 .91 113 3613 (t 0.02 9 1 2.93 114 3644 tt 0.04 15 I 2.91 Shallow it6n . 115 3676 U 0.03 1 3 I 2.92 Shallow it6n . 116 370 U .03 12 ~ 2.93 Pittin . 117 3740 tt .04 14 I 2.90 Shallow itfi 118 3772 (? 0.04 15 I 2.91 Shallow ittin . 1 380 t t 0.04 I -1 I 1 I w it ~ t. e sit 120 3835 tt 0.04 I' ~ 2.91 Shallow ittin Lt. De its. 121 3867 a 0.03 I1 ~ 2.91 122 3899 ll 0.04 15 I 2.92 Shallow ittin . 123 3930 U 0.03 13 t 2.91 Shallow itUn . 124 3962 t1 0.03 II r 2.93 125 992 tt 0.03 I1 2.91 Lt. sits. 126 4024 (t 0.03 I tl I 2.92 127 4055 ~~ 0.05 lt3 _' 2.88 Shallow corrosion. t. De sits. 128 4087 tt 0.03 12 _' 2.88 l.t. De sits. 129 4119 U 0.03 11 5 2.94 130 4150 tt 0.04 1~1 _' 2.87 Shallow itUn Lt. De its. 131 418 u.u5 0.03 I I I 2.91 Pittin in u set. 132 4213 tt 0.04 I ; I 2.89 Shallow corrosion. Lt. De sits. 133 4245 (t 0.03 I ~' I 2.89 t. De sits. 134 4276 tt 0.03 Ll I 2.87 Shallow corrosion. Lt. De sits. 134.1 4308 (? 0.04 15 2.89 P P Shal ow ittin . 134.2 4324 U 0 It tt N A GLM 2 Latch 11:30 134.3 4330 t r 0.03 1 1 2.89 PUP Lt. a sits. 135 4345 n 0.03 13 ,' 2.91 Shallow it6n . 136 4376 U 0.04 I b _' 2.88 Shallow corrosion. 137 4408 tt 0.04 15 I 2.89 Shallow ittin Lt. De sits. 138 4-040 t1 0.04 14 U 2. 8 Shallow it6n Lt. De its. 139 4471 ~~ 0.05 ~(t I 2.88 Shallow corrosion. Lt. De sits. 140 4503 (~ 0.04 I S 2.88 Shallow corrosion. Lt De x>sits. 141 4535 r) 0.04 I - 2.88 Shallow Pittin ~. Lt De osits. Penetration Body Metal Loss Body Page 3 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L$0 EUE 8RD MOD Well: 3F-18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 29, 2008 Joint No. Jt. Depth (R.) I'~•u. t 11,><~t (InS.) Pen. Body (Ins.) I'c~n. °/, 'uh~t,il I „~ ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 142 4567 tl 0.04 1 5 I 2.89 Shall w corrosion. 143 4598 U 0.04 I ~ 1 2.88 Shallow ittin . Lt. De sits. 144 4630 U 0.05 I ti 2.89 Shallow ittin Lt. De 'ts. 145 4661 It 0.04 17 ? 2.89 Shallow corrosion. Lt. De sits. 14b 4692 U .06 Za ? 2.90 Corrosion. Lt. D sits. 147 4723 U 0.04 1 ti ? 2.89 Shallow corrosion. Lt. De sits. 148 4755 a 0.04 1 ; I 2.88 Shallow ittin Lt. a sits. 149 4787 U 0.04 17 I .87 Shallo corrosion 150 4819 U 0.04 1 ti 2.89 Shallow i ~n Lt. De si 151 4850 t I .04 17 2. 8 Line shal ow corrosion. Lt. De i s. 152 4881 U 0.05 _' I 2.87 C rrosion. Lt De it . 153 4913 a 0.05 ~'t1 ~' .90 Shal ow corrosion. Lt. De sits. 154 444 t~ 0.07 8 I 2.89 Line corrosion. Lt. De sit . 155 4977 tt 0.06 ~'S 3 2.88 Li e corrosi n. t De sits. 156 5008 t I 0.05 _' u I 2.88 L'ne hallow corrosion. t. De 'ts. 157 5039 a 0.06 <~' 2.86 Corrosion. Lt. De sits. 158 5072 U 0.06 _' ' _' 2.88 Line corr ion. Lt. De sits. 1 9 5103 (1 0.05 1U I .88 Line rrosion. Lt. De sits. 160 5135 U 0. 6 ' t I 2.87 Corrosion. Lt. De sits. 161 5167 tl .05 ~'l) 2.88 Line shallow corrosion. Lt. De i s. 162 5199 U 0.05 21 I 2.88 Corrosion. 163 230 tt 0.05 1 ~' 2.8 Isolated ittin Lt De sits. 163.1 5262 t~ 0.04 1 7 I 2.87 PUP Shallow ittin . 163.2 5277 tt 0 t1 a N A GLM 3 Latch~8:30 16 .3 2 3 U 0.0 t I 0 P P hall i' 164 5299 ! t 0.04 I ; I 2.88 Shallow ittin Lt. De its. 165 5332 tt 0.13 iU _' 2 88 Line corrosion. 166 5363 tl 0.08 ~ 1 I 2.89 Isolated ittin 167 5394 U 0.04 17 I 2.89 Shallow ittin . 168 5425 tl 0.04 17 U 2.88 Shallow ittin . 169 5458 a 0.03 1 3 ~ 2.91 Shallow ittin . 170 5489 U 0.04 15 t) 2.88 Shallow ittn . 171 5520 tt 0.04 1 _:> 1 2.88 Shallow itti 172 5553 U 0.03 l t _' 2.90 Shallow ittin . 173 5584 tl 0.04 lt~ I 2. 0 Shallow ittin . 174 5616 U 0.03 I i _' 2.93 Shallow ittin . 175 5647 t) 0.0 l a 1 2.92 Shallow ittin . 176 5678 tt 0.03 12 I 2.89 Shallow ittin . 177 5710 U 0.10 38 2.89 Isolated ittin 178 5742 n 0.03 11 1 2.90 179 5773 a 0.04 I6 1 2.87 hallow it'n . 180 5805 tl 0.03 13 I 2.92 Shallow ittin . 18 5836 i t 0.03 1 1 I 2.91 182 5868 tt 0.05 2O I 2.91 Shallow ittin Lt. De sits. 183 5899 a 0.03 I2 1 2.91 183.1 5931 t~ 0.03 12 2 2.92 PUP 1 3. 5947 ~ I 0 l) t ~ N A GLM 4 Latch ~ 9:00 183.3 5952 tl 0.05 18 2.94 PUP Shallow ittin . 184 5968 ~' 0.0 ~ I 2.92 Isolated ittin 185 5999 0.06 -i 2.93 Isolated ittin Penetration Body Metal Loss Body Page 4 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD MOD Well: 3F-18 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiAips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 29, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ul,~c~t Iln>.) Pen. Body (Ins.) I'c~n. % ~tc~!,il lu,s ",~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 6031 ~! 0.33 1 t)u I I 2.88 Hole ! 187 6063 t! 0.04 15 ~ ~ 2.89 Shallow it§n . 188 6095 ~! 0.05 'U 2.89 Isola ed i tin 189 6126 a 0.05 1 ~) I 2.88 Shallow ittin . 90 6158 t! 0.50 li)O ?t~ 2.90 H e ! 191 6188 t) 0.06 ~'~ I 2.90 Isolated ittn 192 6218 (! 0.05 1 f3 1 2.90 Shallow itfin 192.1 6250 ~! 0.03 12 I 2.91 PUP 192.2 6265 U 0 U (! N A GLM 5 Latch ~ 1 :30 192.3 6271 U.t)t, 0.08 3 ; 2.93 PUP Isolated itfi 93 6287 U 0.10 ;t3 ~~ 2.87 Corrosion. t. a sits. 193.1 6318 i! 0 l) i! 2.75 Ca ico D N~ e o Go 193.2 6320 ~! 0.04 14 (! 2.91 PUP Shallow ittin . 193.3 6326 U 0.03 1 U ~! 2.73 PUP De its. 193. 6338 u 0 ll U 3.00 P R 194 634 U.1O 0.04 I7 I 2.88 Shallow itUn . 195 6379 ~! 0.10 41 2.86 Isolated ittin Lt. De sits. _ Penetration Body Metal Loss Body Page 5 ~~ s PDS Report Cross Sections Well: 3F-18 Survey Date: April 29, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ,Vo. of Fingers: 24 .Tubing: 3.5 ins 9.3 f L-80 EUE 8RD MOD Anal st: C. Waldro & M. Lawrence Cross Section for Joint 190 at depth 6169.74 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 74 Tool deviation = 2 7 ° Finger 11 Radius = 1.878 ins • Cross Sections page 1 Holes! 26% Metal Loss HIGH SIDE = UP ~~ PDS Report Cross Sections ti Well: 3F-18 Survey Date: April 29, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8RD MOD Anal st: C. Waldro & M. Lawrence Cross Section for Joint 186 at depth 6055.217 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 89 Tool deviation = 24 ° Finger Z4 Penetration = 0.333 ins Hole! 0.33 ins. = 100% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 ~ ConocoPhillips Alaska, Inc. KRU 3F-18 3F-18 API: 500292268400 Well T e: PROD An le TS: 24 de 6411 SSSV Type: Nipple Orig Com letion: 7/11/1996 Angle @ TD: 23 deg @ 6868 NiP (5i7~ie, oD:3.5o0) Annular Ftuid: Last W/O: Rev Reason: FORMAT CHANGE TuBmG (0-6327 Reference L Ref L Date: Last U ate: 11/15/2005 , oD:3.5o0, Last Ta : 6633 TD: 6868 fiK6 iD:2.s92) Last Ta Date: 8/20/2005 Max Hole An le: 29 de 3755 Casin Strin -ALL STRI NGS Deacri 'on Size T Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 Gas Lin MarxlreWalve ~ SUR. CASING 7.625 0 3491 3189 29.70 L-80 ~ © PROD. CASING 5.500 0 6340 5752 15.50 L-80 (3o2s-3oz7, PROD LINER 3.500 6340 6858 6227 9.30 L-80 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 6327 5740 9.30 L-80 EUE 8RD MOD Perforations Summa Gas girt Interval TVD Zone Status Ft 3PF Date T Comment MandreWahe 2 (4326-4327 6412 - 6419 5817 - 5824 C-4 7 4 2/4/1999 APERF 180 deg phasing, +/- 90 de , 2 1/2" HC-DP , 6419 - 6425 5824 - 5829 C-4 6 4 12/26/1998 APERF 180 deg phasing, +(- 90 de 2 1/2" HC-DP 6425 -6428 5829 - 5832 C-4 3 4 2/4/1999 APERF 180 deg phasing, +/- 90 d 2 1 /2" HC-DP Gas Lift .. 6480 -6490 5880 - 5889 C-1 10 6 5/11/2002 APERF 2.5" HSD, PJ DP Chgs, 60 d h Mar,drewane 3 (5279-5280, © I J 6621 - 6641 6009 - 6027 A-3 20 4 7/27/1996 IPERF 180 deg phasing, 2 1!2" HSD Ga s Lift M andr els/Valves St MD TVD Men Man Type Mfr V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3026 2773 BST AXT GLV 1.0 Ti 0.156 1293 9/3/2004 2 4326 3933 BST AXT GLV 1.0 Tl 0.188 1326 9/3/2004 Gas Lit[ MarttlrelNahe 3 5279 4785 BST AXT GLV 1.0 T7 0.250 1427 9/3/2004 a 4 5947 5392 BST AXT OV 1.0 T1 0.250 0 9/10!2005 (5947-5948, 5 6265 5683 BST AXT DMY 1.0 T1 0.000 0 9/3/2004 Oth er I s ui .etc. -JEWELRY De th TVD T Descri lion ID 517 514 NIP Camco 'DS' Landin Ni le NO GO 2.812 6318 5731 NIP Camco'D' Landin Ni le NO GO 2.750 Gas lib 6327 5740 PBR Baker Locator 3.000 "~'~D'"""'y ~ G®neral Notes VaNeS (6zs5-szsfi ~ - Date Note , oD:a.75o) 12/4/1997 Camco'DS' Ni le 517' w/2.812" ID, but 2.795" wouldn't PASS throw h 12/4/97 . 0/10!200 EXTERNAL CASING PATCH INSTALLED AT BOTTOM OF SURFACE CASING MANDREL HANGER. SLEEVE PATCH: 39" LONG x 8" OD X65 PIPE NIP (6318-6319, OD:3.500) PBR (6327-6328, OD:3.500) Pert (6419-6425) Pert (64ao-6a9o) Perf (6627-6641) 3F-18 (PTD 1961120) Report Of Failed TIFL Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] ~ Sent: Sunday,. March 30, 2008 8:28 AM ~~ ~~ ~ I~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: 3F-18 (PTD 1961120) Report Of Failed TIFL Attachments: 3F-18 TIO Plot.jpg; 3F-18 Wetlbore Schematic.pdf '1-U.yC ~'~-~.~s Tom & Jim, Kuparuk gas lifted producer 3F-18 (PTD 1961120) failed a diagnostic TIFL on 3/28/08 and has been added to the weekly SCP report. The TIO prior to shut in for the TIFL was 180/1150/400. A leaking GLV is suspected so slickline will trouble shoot the suspected tubing leak and repair if possible. The well will be fixe ors ut in by 4/25/08. Attached is a 90 day TIO plot and a wellbore schematic. Please let me know if you have any questions. «3F-18 TIO Plot.jpg» «3F-18 Wellbore Schematic.pdf» Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1720 Pager (907) 659-7000 pgr. 909 4/24/2008 KRU 3F-18 PTD 196-112 TIII~ Plat - 3F-18 X200 ~ OOC~ 800 ~- 600 400 200 0 30-Dec-07 12-Ja~r~-0$ 25-J~r~-08 07-Feb-O$ 20-Feb-08 04-Mir-08 17-Mar-08 Gate 200 150 u. E n~ 100 0 50 0 KR U 3F-18 Conocophillips Alaska, tn~. - 3F-i8 - - - -- - - -- - _ - __ APt: 500292268400 _ Weil T e: -_ PROD -- ran ie u. TJ: 24 de m b41 i j SSSV T e: Ni le Ori Com letion : 7!11/1996 An le TD: 23 de 6868 Annular Fluid: Last W/O: Rev Reason: TAG NIP (517518, - Reference Lo Ref Lo Date: Last U date: 3/28/2008 OD:3.500) Last Ta : 6633' RKB TD: 6868 ftK6 TUBING rest Taq ^ate: 3/20/2008 Max Hole Angle: 29 deq (a7 3755 (05327, Casing String -ALL STRIN GS OD:3.500, ID:2.992) Descri lion Size To Bottom TVD Wt Grade Thread t` PRnr) LINER ? Snn Fzen e>zssz x227 Q zn L-Rn Gasue ~ Tubing String -TUBING MandrelNalve 1 -Y __.. _ - ~ -~ Size Top ~ = Eo _. ttom T . ~~~ 'lC~ Wi ~ Grade - Thread (3026-3027. n - _ ~n .p L ~ _ E~JC f C h.1 ~G s Perforations Summary _. I Interval ~ TVD i Zone i Status i Ft i SPF i Date i Tvoe i C:nm ment I Gas lift MandrelNalve 2 (4326-4327, Gas Lift MandrelNalve 3 (5279-5280, Gas Lift MandrelNalve a (5sa7-ssas. Gas Lift 3ndrel/Dummy Valee 5 (6265-6266, OD:4.750) NIP (6318$319, OD:3.500) PBR (6327Fi328, OD:3.500) Perf (64195425) Pert (64806490) Pert (6621-6641} CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 7.625 0 3491 3189 29.70 L-80 PROD. CASING 5.500 0 6340 5752 15.50 L-80 6412 - 6419 5817 - 5824 C-4 7 4 2/4/1999 APERF 180 deg phasing, +/- 90 deg, 2 1!2" HC-DP 6419 -6425 5824 - 5829 C-4 6 4 12/26/1998 APERF 180 deg phasing, +/- 90 deg, 2 1/2" HC-DP 6425 - 6428 5829 - 5832 C-4 3 4 2/4/1999 APERF 180 deg phasing, +/_ 90 deg, 2 1/2" HC-DP 6480 - 6490 5880 - 5889 C-1 10 6 5/11/2002 APERF 2.5" HSD, PJ DP Chgs, 60 deg h .6621 - 8641 I ftnnq _ nn27 I A-~ I I 2n I a I ~i27i144R I IPERE 11Rn dPr, phasinrl 2 1i?~ Hcp ~ i ~ ~> Gas Lift Mandrels/Valves i W St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Pori TRO Date Run Vlv Cmnt 1 3026 2773 BST AXT GLV 1.0 T1 0.156 1293 9!3/2004 2 4326 3933 BST AXT GLV 1.0 T1 0.188 1326 9/3/2004 3 5279 4785 BST AXT GLV 1.0 T1 0.250 1427 9/3/2004 4 5947 5392 BST AXT OV 1.0 T1 0.250 0 9!10/2005 5 g?F~ Sgst2 BST 4YT DMV 1.0 Tt n nnn 0 9/3/2004 I Other (plugs., equip., etc.) -COMPLETION De th TVD T s' ~' -. ti ~ _ 3 6327 5740 PBR Raker Lncatnr General Notes Date Note I 12/4/1997 NOTE: Ni le 51 T w/2.812" ID but 2.795" r I 1 1 PATCH EXTERNAL CASING PATCH INSTALLED AT BOTTOM OF SURFACE CASING MANDREL HANGER. SLEEVE PATCH: 39" LONG x 8" OD X65 PIPE 10/10/2005 7.525 517 514 NIP Camco'DS' Landin Ni le NO GO 2.812 6318 5731 NIP Camco'D' Landin Ni le NO GO 2.750___ i 3 npU i . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 SCANNED SEP 0 8 2006 \\<}-- \ o..l9' Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907 -659- 704~,'ì(you have any questions. ",/ / Sincerely, d /7 ///' ¿/ /' / ?' ~¿;zX:~~ / I M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date " 3¡::.,P:t .... " .-'. 18Q,~~~5 . :. . J\JA , . . . . .~C..·· .' 812't¡2~Ö~ . 3F-02 1 85-226 24' 7.0 8/1 4/2006 7. 5 8/2 1 /2006 3F,;.Ø3 '. . . ..., ' i8~f~21' . . J~'4" . . ..' <2.3 ' . .:... '8/14f2QÐQ ':, r '. 8~~1f2:QQ~< '-N 3F-04 1 85-228 80' 22. 7 1 0' 8" 8/1 4/2006 38.2 8/2 1 /2006 ~ ·~',··'f.ß~. '. 5:1· . I'c. ·;ß'f't'4'/2:Ø.Ø'6 . .' ~. . 1:5. ..: 8~1'ÞZOØ6 . ,.: ~ 0 -,-:- '-.- _, ; ~ _ - ,_, "'___. _0: -_-~_;: .-- _.y^ 3F-06 1 85-244 Did not modify 3F,;07 ' '1Øi*2'{î5. . .. Ie- . .."', . 6;6· . . . 8/Hf/ZQQ6 f' ': 7.5. '.. .8/21JeQQ6. i~_ . .. '-~,~'. 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6 .6 8/2 1 /2006 "3F~oø .. '. ·1$~~1(}·, Did not modify 3F- 1 0 1 85-271 SF NA NA 6. 6 8/2 1 /2006 .,35-11: . I"" '185:.'21-2"; .,:. '. :$F '... 'NA . , :N~\>' ..... 1.7 a'f~3i4M:~ ., . ~12 1 85-273 7'4" 1 .8 8/1 4/2006 6.2 8/23/2006 ., '. ;;'f9~Æ't:~~~ ..... .. '. . NA .. '11I.M' ;"..:. ·'j}'ì~ÎîQ:Q~' .~. .'.. 3F-14 1 85-292 Did not I'~ ¡;-: "1a-i>;~~r .2~4· ,', . . .ß111!2~:OO:fj': .è..., ' '. ¡"8'f2~Z20:()$ :!~:.:\,~~::'" ,',t..'~' ' ,- _~1~J~;:~ '.; .. " . ~,-" 3F-16 1 96-1 5 1 6" NA NA 2. 7 8/23/2006 '3£41 ~11" < 3.1,. 8/1412€Jfl6; ;' . ' .8 8f2~1~ÕCQ::' y 3F-1 8 1 96-1 1 2 4' NA NA 28 8/23/2006 ·317~l9; '.' . , " 2Ø'41::01a-, ':';;c;;, k,' . $" ..... . . NA : . . 8" '!\lA'; . .;,. .. '~" . 2 . · . 'cg/~W2QÐ:$. 3F-20 1 99-079 36" NA NA 1 7.7 8/23/2006 3F-2.1 . . . ..' . 2ÖÖ1203 . . '45" NA NA 31 . ..8/21J2006 RECEIVED AUL; () 1') 2006 08/01/06 Schlumberger ..aJæXa Oil & Gas Cons. Corr~ Anchorage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¡c,rc -! l:d- Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 :SÇ/\NNED l\UG ~~ /', I.)~ Kuparuk Field: Well Log Description BL Color CD Job# Date 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1 R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 96' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD LINER Perforation depth: e e RECEIVED OCT 1 9 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TION~a$ka Oil & Gas Cons. Commission Repair Well 0 Pull Tubing D Operat. ShutdownD Stimulate D Waiver D Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development _ 0 Stratigraphic D Other Time Extension D D Re-enter Suspended Well 5. Permit to Drill Number: Exploratory D Service D 6. API 'umber: 50-029-22684-00 9. Well Name and Number: 3F-18 10. Field/Pool(s): Kuparuk Oil Pool measured 6868' feet true vertical 6236' feet measured 6868 feet true vertical 6276' feet Length Size MD 121' 16" 121' 3395' 7-5/8" 3491' 6244' 5-1/2" 6340' 518' 3-1/2" 6858' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3189' 5752' 6227' Measured depth: 6412-6428,6480-6490,6621-6641' true vertical depth: 5817-5832,5880-5889,6009-6027' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6327' MD. ~JìNNE~: fJQV 032005 Packers & sssv (type & measured depth) Baker seal assembly Seal=6327' SSSV= NIP SSSV= 517' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 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: 305-122 Contact Printed Name Signature Marie McConnell / MJ Loveland @ 659-7224 Marie McConnell" .. A / /, Title t.I ~.~~ Phone Problem Wells Supervisor 907 -659-7224 Date 10/15/2005 Form 10-404 Revised 04/2004 Submit Original Only e 3F-18 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/25/2005 Cut top 34" off conductor. Removed cement and exposed 7-5/8" casing. Found externally corroded casing with a pin hole leak 14" below bottom of csg mandrel hanger as shown in Photo #1. AOGCC inspector Chuck Scheve waived witness of casing damage. 10/1/2005 Cut and removed an additional section of conductor for a total of 50" of conductor removed. Removed cement to same depth and inspected 7-5/8" casing to determine the required patch lenQth. 10/10/2005 Seal welded top casing threads to casing hanger mandrel bottom. Installed external surface casing sleeve patch over corroded casing from seal weld to 39" below mandrel hanger. Patch was a 39" long section of 8", X65 pipe, split and welded to surface casing across the corroded casing as shown in Photo #2. Patch design drawing also attached. 10/11/2005 MITOA to 1800 psi passed. See attached MITOA test report. Installed denso corrosion resistant coatin on the atch and ex osed surface casin . 10/13/2005 Patched conductor to original height. Topped off conductor with corrosion inhibitor/waterproofing sealant: -28 gals of ROYFILL 404-8 corrosion inhibitor filler at 125 deQ F. ~c:- e (. \ Subject !i te r t:t ~e File f}53r-1B 5/~eve. By .¡fA-. ¡'J, . rrftd-//4KiJP/.cÞt Date · ße ~;Ie~ I t he t1/.c;~dr; / I èCl$.i""2 iD i-Ae $4~ reg /prt.$, Cl6 La :5/~/J.' I/eod {;r Se4 / úÆJC£~ . ... " $eo/ we lei the I:/¡rei!ld$ ot fhe.. .lÞfol1dr¡/..' (4 ~Id {?Ct$~e$). ,I . r/i:. .~ lee ve..b -/:;;e Into' £he. Gë ðf /:::ÞJ 'e . 'Sea f ¿,ve. I d ,~ . I . f ( · 62dMV~' weJcI-~i...· I! qS/rlJ' U(j¿¿Adi-¡ I /.'. ¥P »'14 tc  S j¢>eve.,., t;;lu'c,..Æne.$.£.. .. '" ., .... ~); ~ . . ;".; ..;. C . , ; 7%",,·¡ 'j . i , :;...... ·u ~ SLfJ ;f: j) '.' ~ _IXf?:D{ ": ) , . ,pe_·. v.:z'lf L..$k :::J(.~... :! II ! ! ~ . é),·3 '15 t)æ' {)_;~ ". off}: . - / . r: . ;;-:"-'! . i·w.i;i/ plJ?.e..- mr '. ;:";-,¡., ·i~t;e sle~//~ -. .. .t...( ~. ~)' ; ;. f -,jl-- - - ..~ .~ .,.~: Q.L PRINTING (907) 563-4743 .. Calculations Chàr .tOI.1 :jð/ð~/Z.ðéJ.s- Sheet number J fll'!ð. ð kt?æ-~¿[leiL 7ú~¡(l 1 Ct:¡~/',,~ )11ÒtI14"¡ / . , j : .' t, ". \ . .-. . ¡ ~ . -" ~ -" \ ; . . . , . ¡ .. ¡ 1/ ~3r .. :, j , ! ; .~;;..: '... ,... .:..8-:4... ~..'. -:",. J ---t.. L....i..-_.i ). t . j' ! Î. . ./._. -+_.._~_.. L.+.._~ , ! í ¡ ¡ ì ' ; ~L''"~'~f' l--,.{···i ¡ ;, ¡ .,.. 1b¡:r ~f '~. ! ";', _ . . S/.ee.Je. ßcmd ; .._.t ,'4 ',-~- j '" ... i' ... . " -.., , .- 4·· .. -[-.- t· -. . 3;'. ,; , ','- ." .A ",...~_ 8ð't-6tJ;/"l it,.pi $I-es.ve. - ße¡.",J; ~ ~ , : i .",... ~ 1 , ~- ¡. 4 ¡ i ~.l ~ .. i. ~_ t. : .~ ~ >.! ; I ¡ ,~ ~i _i. . ..' . f . '¥" .. i . :"l I ¡ ! I i ! f t '-' ... i' J... ¡ ¡ \ í t ...? , I I .1 I' f I " -.... ~ ¥ ¡ i ; . : : i i : ~ : ~ ::~~rr.·.... .,1. .,' ·..,f.¡~-.:.¡.i::._·.-,;:,I". ï J-r:- ,.....; '--r"'- ¥,,¡,.--..; .¡. - , . f' ¥··'t" ..:.-. ; i ; "' " ~ . ¥ ~ .' . -, :... ~ ~ . r ..., . - ·©(Q)~W , t "" MECHANICALeTEGRITY TEST (MIT) FORMe WELL NO.: 3F-18 DATE: 110-11-05 WELL TYPE: I Prod I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA 1 i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel bf dd' T Record all Wellhead Pressures e ore an urine est. START TIME: 111 00 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T 1 PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)- (PSI)* (PSI)** FAIL S TUBING 0 0 0 0 T IA 0 0 0 0 Pass OA 0 1800 1720 1690 1 COMMENTS: START TIME:I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)- (PSI)* (PSI)- FAIL S TUBING T IA I 9-5IS" OA 113-3IS" 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME: I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA I 9-5IS" OA 113-3IS" 3 COMMENTS: rSC COMMENTS, * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION m -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: 10. Sauvageau / J. Arend cc: PWS 6/3/00 ,j} --''"'11 elF [-t\ ",I: ," iF I ' ;,. !~ " i '1 ¡ ì\ ~ : : " I I ' \ \ :,: " '" '"\ I:i i I \, r, : :, '''''1 '¡, ,I . \' ,I lQi tuu J It ') rf\\ n ! ! \\ \\ ~!I .:ü,\ il L: " ~ \1 L..:.=:J i¡"~\ t? I [U!I d, ¡ ¡ ! :~ f ~ :I ! : , l Ij \.:::J J ) '-'II :( i¡1.j "'1\"\ riD ,r::"i\', 11 i;~ ", II f.i i' I '~ " , I' \\ I U \I ,1!n\\ ~U ~A FRANK H. MURKOWSKI, GOVERNOR A"fA~1iA. OIL AND GAS CONSERVATION COMMISSION Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk 3F -18 Sundry Number: 305-122 Dear Mr. Dethlefs: 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 . (\ \0/ . ,G:t',.',, "",~, \" SCANNED MAY 2 6 2005 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 d, ay falls 01!5a Uday or weekend. A person may not appeal a Commission decision to Superior Urj unless rehearing has been requested. ~, _ ,¡ ( ìJA ' o DATED this/~OfMay, 2005 Ene!. 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 96' 8. Property Designation: Kuparuk River Unit / vlJ Srf2,"OS ) STATE OF ALASKA) ED 1__ ALASKA OIL AND GAS CONSERVATION COMMISSION RE CE IV ~ APPLICATION FOR SUNDRY APPROVAL MAY 11 2005 11 ( 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 o o o Suspend 0 o o Repair well Pull Tubing 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 6868' 6236' 6868 Casing Length Size CONDUCTOR 121' 16" SUR. CASING 3395' 7-5/8" PROD. CASING 6244' 5-1/2" PROD LINER 518' 3-1/2" Perforation Depth MD (ft): 6412-6428, 6480-6490, 6621-6641' Packers and SSSV Type: Baker seal assembly SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Perforate o Alaska m,^,,~$ C~$. ~m~~i~~'D o Time Ext_~e Other 0 Stimulate Re-enter Suspended Well o 4. Current Well Class: Development _ 0 Stratigraphic 0 Exploratory 0 Service 0 5. Permit to Drill NUJX1ber: 1961120 V 6. API Number: /' 50-029-22684-00 9. Well Name and Number: 3F-18 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6236 MD TVD Burst 121' 121 3491' 3189 6340' 5752 6858' 6227 Perforation Depth TVD (ft): 5817-5832, 5880-5889, 6009-6027' Packers and SSSV MD (ft) Seal=6327' SSSV= 517' Tubing Size: 3-1/2" 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Commencing Operations: Immediately 16. Verbal Approval: Date: 08/22/04 Commission Representative: Tom Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlefs ~ Signature ý~ C-r ommission Use Only Contact: Title: Phone 659-7043 Conditions of approval: Notify Commission so that a representative may witness Collapse Tubing Grade: L-80 Tubing MD (ft): 6327' Plug Integrity 0 BOP Test 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Loveland/McConnell 659-7224 Problem Well Supervisor Date 0/~ Sundry Number: 30S:- /~ Mechanical Integrity Test 0 Location Clearance 0 ~, v..J "-.<è -. \<ZCI.. ~ \-..0.- ":> 'ö~ C'\ "E:."( ~~ " , \ ~'-\}thlfR~tiM ~r-~ MU'\"~\CI~ O~~P:0'~ BY ORDER OF ~ ~ COMMISSIONER THE COMMISSION Date: I 0 RBOMS RF'. f\"I~',' ~ ~ 7005 INSTRUCTIONS ON REVERSE Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. Kuparuk We1l3F-18 (PTD 1961120) SUNDRY NOTICE 10-403 APPROVAL REQUEST May 7, 2005 This application for Sundry approval for Kuparuk well 3F-18 is for the repair of a surface easing leak. The well is an oil produeer, completed in July 1996. On August 22, 2004, liquids in the eonduetor were observed by the Operator. The AOGCC was notified on August 23. On August 23, 2004, a eement shoe was pumped into the outer annulus (OA) to isolate formation pressure at the surfaee casing shoe from pressurizing the OA and supporting the leak mechanism. Recent diagnostics were performed to loeate the leak, but the exact leak depth has not been determined. The tight tolerance between the 5-1/2" production casing and 7-5/8" surface casing does not provide enough room to locate the exact depth. However, the response from pumping and purging with nitrogen suggests the leak is less than 7-feet below the OA annular valve. With approval, repair of the surface easing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the OA and conduetor so that hot work may be conducted in a safe manner. 5. Cut away the eonductor casing and remove eement around surface casing for inspection. Approximately the top 8-feet of conductor will be removed to provide aeeess to the surface casIng. 6. CP AI Meehanical Engineers will determine appropriate pateh andlor repair to return the casing to operational integrity. 7. QA/QC the repair and MIT-OA for a final integrity eheek. 8. Install anti-eorrosion eoating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 ~""" ) . ..- .... . .~. ; . ConocoPhillips Ala" ',S""',',.,.'""",,,k,.,,', ·a,."",.., "",',.'" "I,"",....c. .. ... "3F"18. API: 500292268400 SSSV Type: Nipple NIP (517-518, OD:3,500) TUBING (0-6327, OD:3,500, ID:2.992) Gas Lift Mandrel/Valve 1 (3026-3027, Gas Lift Mandrel/Valve 2 (4326-4327. Gas Lift Mandrel/Valve 3 (5279-5280, Gas Lift Mandrel/Valve 4 (5947-5948. Gas Lift 3ndrel/Dummy Valve 5 (6265-6266, OD:4,750) NIP (6318-6319, OD:3.500) ~ i~ '.! I I I r 1~ JI,""---' !~i¡\1J' ~ ;;¡ ~-i.. , ' II I ¡'.' t.....8:· -.--)ì , ~ ~I"~,:uuJ. ~ L_~I" f.. ' ~ i¡ 11 , , r!~--~ ti!~!- -.. i! .'. I ¡i I' i f j «;--l ¡, .----~ j, s· ~ r I I ._- "':r " j I ~ 5 III I I· PBR i (6327-6328, OD:3,500) Perf (6419-6425) =t Perf (6480-6490) J Perf (6621-6641 ) =i ) KRU 3F-18 Well Type: PROD Orig 7/11/1996 Completion: Last W/O: Ref Log Date: TO: 6868 ftKB Max Hole Angle: 29 deg (â) 3755 Angle @ TS: 24 deg @ 6411 Angle @ TO: 23 deg @ 6868 Annular Fluid: Reference Log: Last Tag: 6631 Last Tag Date: 3/27/2005 Gasihg.,.SffiJ'lg>µÄIlL···SmRINGS Description Size CONDUCTOR 16.000 SUR. CASING 7.625 PROD. CASING 5.500 PROD LINER 3.500 IÚbiÎ"lg..·Sffi¡ig .'f".mOBING Size I Top 3.500 0 peffóriãtiØÎ"ls·SLJl'r1måry Interval TVD 6412 - 6419 5817 - 5824 Rev Reason: TAG FILL Last Update: 4/2/2005 Bottom 121 3491 6340 Thread Zone C-4 Status Ft SPF 7 4 6 4 3 4 10 6 20 4 Date Type Comment 2/4/1999 APERF 180 deg phasing, +/- 90 deg, 2 1/2" HC-DP 12/26/1998 APERF 180 deg phasing, +/- 90 deg, 2 1/2" HC-DP 2/4/1999 APERF 180 deg phasing, +/- 90 deg, 2 1/2" HC-DP 5/11/2002 APERF 2.5" HSD, PJ DP Chgs, 60 deg ph 7/27/1996 IPERF 180 deg phasing, 21/2" HSD 6419 - 6425 5824 - 5829 C-4 6425 - 6428 5829 - 5832 C-4 6480 - 6490 5880 - 5889 C-1 6621 - 6641 6009 - 6027 A-3 Gås·.·.Lift···Mål"ldfelslMalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 3026 2773 BST AXT 2 4326 3933 BST AXT 3 5279 4785 BST AXT 4 5947 5392 BST AXT 5 6265 5683 BST AXT Othel'pILJgS,åqüiP.,ètc.)'" JEWELRY Depth TVD Type 517 514 NIP 6318 5731 NIP 6327 5740 PBR GenerârNótés Date I Note 12/4/1997 Cameo 'OS' Nipple (â) 517' w/2.812" 10, but 2.795" wouldn't PASS through (12/4/97). GLV GLV GLV OV DMY 0.156 1293 0.188 1326 0.250 1427 0.250 0 0.000 0 Date Run 9/3/2004 9/3/2004 9/3/2004 9/3/2004 9/3/2004 Vlv Cmnt 1.0 1.0 1.0 1.0 1.0 T1 T1 T1 T1 T1 Description Cameo 'OS' Landing Nipple NO GO Cameo '0' Landing Nipple NO GO Baker Locator ID 2.812 2.750 3.000 '~t::¡;" .'-' {'U ! í' JI; '¡ ,\ ¡l/lJ\ æ; u Lrd, FRANK H. MURKOWSKI, GOVERNOR A. I 1 A. S IiA 0 IL AND GAS CONSERVATI ON COMMISSION 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 1, 2004 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99519-6612 ~.~ , 1;2- Re: Kuparuk 3F-18 Sundry: 304-329 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure Conoc;p., ill i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 24, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AI< 99501 Dear Mr. Maunder: Enclosed please find both a 10-403 Application for Sundry Approvals and a 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we1l3F-18. The reports regard a cement shoe that was pumped into the Outer Annulus. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, H~ Jerry Dethlefs Problem Well Supervisor Attachments OR'G'~JAL RECEIVED AUG 2 62004 Alaska Oil & Gas Cons. Commission Anchorage RECEIVE~ APPLICATION FOR SUNDRY APPROVAL AUG 2 62004 ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION 20 MC 25.280 K' 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Perforate aska Oil ~..;;: (;°'t!3 (;OOOOMUWDp.' 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time ~~ Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory 0 1961120 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22684-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 3F-18 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6868' 6236' 6868 6236 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SUR. CASING 3395' 7-5/8" 3491' 3189 PROD. CASING 6244' 5-1/2" 6340' 5752 PROD LINER 518' 3-1/2" 6858' 6227 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6412-6428,6480-6490,6621-6641' 5817-5832,5880-5889,6009-6027' 3-1/2" L-BO 6327' Packers and SSSV Type: Packers and SSSV MD (ft) Baker seal assembly Seal=6327' SSSV= NIP SSSV= 517' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Immediately Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: 08/22/04 ,L:M..J WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: TomMa~r'~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: DethefslMcConnell659-7224 Printed Name ~ry Dethlefs D ..LO Title: Problem Well Supervisor Signature ~C~ ./ ') Phone 659-7224 Date if k3/t; ~ / ~ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 30 V- 3d4 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMs 8Fl ~ 0 2 ?OO\ S"",eque"',m D ~ ~~o~ J-~\~'J~\\V~~\Q~' .. \e..c.k Approved by. r-n ~ ORIGINAL BY ORDER OF ~f/# J COMMISSIONER THE COMMISSION Date: V- --- I Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ConocoPhillips Alaska, Inc. Kuparuk We1l3F-18 (PTD 1961120) SUNDRY NOTICE 10-403 REQUEST 8/23/04 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Kuparuk producing well 3F-18. The cement shoe is required to stop a fluid leak to surface through an apparent hole in the surface casing into the conductor casing. 3F-18 was drilled in 1996 and has been in production since that time. A surface casing cement shoe was not pumped at the time of original completion. On August 22, 2004, Operations personnel reported "wet gravel" around the wellhead and diesel dripping from the conductor top. Bleeding pressure from the Outer Annulus (OA) stopped the leak. When the bleeding was shutdown the OA slowly recharged above 200 psi and the leak started again. It is apparent that some pressure support is originating from the open-ended surface casing. Isolating the surface casing from formation pressure with cement will allow the OA to be kept at zero pressure eliminating the leak to surface. The proposed plan includes pumping a cement shoe to shut-off the pressure support and leak to the surface. Subsequent diagnostics will verify the existence, depth and severity of the leak in the surface casing. Should a leak be confirmed, the AOGCC will be contacted about a proposed repair plan. u 1( . \. \ ~- \ \ ~ tl' - - lb.» ?~~~~ C",- Q'Y'- öf\. '\ <> '"'0\ ~ n Ú~\)CA. CN ~ 'ö ær---~\-\l (J~~ JDO~~\ \<:> e\~\-.JQ\<Cu-...~ \-0 ~ ~O'JI o ~\~~(è\ '\ ~ ~,,«.:. ~ 5;/ ~ .., SlIt) \\ c.,.." ".'-.} \ ~~ (.':!> ,~ 1.> - <O.'ð '\ (., t>S;) '\ 0 ~~\~~\ct \" \0 ~":Iê. \ " . O~ ~ .;,'/r;.\ ~ t::I:) /, O~ -:: JS Ot:J<t c... ~.od(. ~ ~~'" ~.. ~~.\'~ 0/ c.:.~¡:;;I .\,Q", .+, \. "i:.F\\.' NSK Problem Well Supervisor 08/23/04 CO~øPh iIIipsAlaska, Inc. KRU 3F-18 3F-18 API: 500292268400 Well TvDe: PROD AnQle lID. TS: 24 dea lID. 6411 NIP (517-518, SSSV Type: Nipple Orig 7/11/1996 Angle @ TD: 23 deg @ 6868 ComDletion: OD:3.500) Annular Fluid: Last W/O: Rev Reason: Taafill Reference Loa: Ref Loa Date: Last UDdate: 5/23/2003 Last Taa: 6674 TD: 6868 ItKB Last Tag Date: 5/11/2003 Max Hole Anale: 29 d~ 3755 ...... ,',.,,"i .. ...... Description Size TOD Bottom TVD Wt Grade Thread GasUl! CONDUCTOR 16.000 0 121 121 62.50 H-40 l,,1andrelNalvE SUR. CASING 7.625 0 3491 3189 29.70 L-80 1 (æ26-3027, PROD. CASING 5.500 0 6340 5752 15.50 L-80 OD:4.75O) PROD LINER 3.500 6340 6858 6227 9.30 L-80 "'!>.""""'. ."""","""'",,'.""""""',"""',,, ..> ..,.. i." i~ .. .'. ...,..... ~i. Size I Top I Bottom TVD I Wt I Grade I Thread 3.500 I 0 I 6327 5740 I 9.30 I L-80 I EUE 8RD MOD ........,.... ..... i........... ".""""".' .' ..... .'" GasLifl .,...., Interval TVD Zone Status Ft SPF Date TYDe Comment 'vIandrelNalvE \ 6412 - 6419 5817 - 5824 C-4 7 4 2/4/1999 APERF 180 deg phasing, +/- 90 2 (43264327, >; dea, 2 1/2" HC-DP OD:4.75O) 6419-6425 5824 - 5829 C-4 6 4 12/26/199f APERF 180 deg phasing, +/- 90 dea, 2 1/2" HC-DP 6425 - 6428 5829 - 5832 C-4 3 4 2/4/1999 APERF 180 deg phasing, +/- 90 dea. 2 1/2" HC-DP 6480 - 6490 5880 - 5889 C-1 10 6 5/11/2002 APERF 2.5" HSD, PJ DP Chgs, 60 GasLifl dea Dh l,,1andreWalvE 6621-6641 6009 - 6027 A-3 20 4 7/27/1996 IPERF 180 deg phasing, 21/2" 3 (527%200, HSD OD:4.750) .' .< ,.",.. < i'" .'..,..,.. ~ "'."'.""'" '..",.. St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vly Mfr Type Run Cmnt 1 3026 2773 BST AX!" GLV 1.0 T1 0.156 1337 8/25/1996 GasLifl 2 4326 3933 BST AX!" GLV 1.0 T1 0.156 1325 8/25/1996 I1drel/Dummy 3 5279 4785 BST AX!" GLV 1.0 T1 0.188 1347 8/25/1996 Valve 4 4 5947 5392 BST AX!" DMY 1.0 T1 0.000 0 7/12/1996 (5947-5948, 5 6265 5683 BST AX!" OV 1.0 T1 0.250 0 8/25/1996 Otbêr luïîj;",.ïîUIi:í¡itöi ~JEWELRY .. "',,'" "'. OD:4.75O) DeDth TVD Type Description ID 517 514 NIP Cameo 'DS' LandinQ NiDDle NO GO 2.812 6318 5731 NIP Cameo 'D' Landina NiDDle NO GO 2.750 GasLifl 6327 5740 PBR Baker Locator 3.000 'vIandrelNalvE ........,.. """," ",'...,'" <'"""" . """',,',' ""'" '.,... ." 5 (6~266, Date INote 00:4.750) 12/4/19971 Cameo 'DS' NiDDle lID. 517' w/2.812" ID, but 2.795" wouldn't PASS throuah (12/4/97). NIP ~ (631~19, OD:3.500) TUBING II (0-ô327, OD:3.500, ID:2.992) PBR (6327-6328, OD:3.500) Perf - - (641%425) - - - - - - - - Perf - - (648().M9()) - - - - - - - - Perf - - (6621-6641) - - - - - - [Fwd: Kuparuk we1l3F-18 (PTD 1961120) Surface Casing Leak] Subject: [Fwd: Kuparuk we113F-18 (P From: Thomas Maunder <tom maunder Date: Mon, 23 Aug 200416:04:16 -0800 To: Jim Regg <jimJegg@admin.state.ak.us> Sorry about that, I thought you were in the distribution on this message. I guess I need to put my glasses on. Having a low pressure on the OA due to the hydrostatic difference is not unusual. According to Jerry, the pressure bleeds off easily, but will build up. In our conversation he did say that they were NOT bleeding off gas. I quizzed him hard on this regarding the integrity of the 5-1/2" production casing. The preliminary diagnostics did not show the IA communicating with the GA. Tom Subject: Date: From: To: CC: Well -------- Original Message -------- Kuparuk well 3F-18 (PTD 1961120) Surface Casing Leak Mon, 23 Aug 2004 06:00:55 -0800 Dethlefs, Jerry C <Jerry.C.Dethlefs@conocophillips.com> Tom Maunder AOGCC (E-mail) <tom maunder@admin.state.ak.us> Chuck Scheve AOGCC (E-mail) <chuck scheve@admin.state.ak.us>, Supv <n16..:!: 7@con9_cophi~_!j2..§_. com..::: NSK Problem Tom: As per my discussion yesterday with you, we found what appears to be a surface casing leak on Kuparuk well 3F-18. The well was SVS tested on Saturday (witnessed by Scheve) and did not have a problem then, but on Sunday the DSO noticed diesel slowly leaking over the top of the conductor into the gravel in the cellar. The well does not have an OA cement top job previously pumped, and the OA appears to recharge from the open shoe to over 200 psi. The OA will not remain bled off so there is not a way to stop the leak. The approach we are taking is to pump an OA cement shoe, which we will attempt today (8/23/04). Once we get the leak stopped we can continue diagnostics to determine the depth and severity of the leak and figure out repair options. A tubing plug has been set for now to minimize any complications from the well. As per the reporting requirements matrix and the need for a 10-403, I will use our conversation yesterday as the verbal approval. The 10-403/404 will follow in a few days. Thanks for calling me back on this issue. Jerry Dethlefs ConocoPhillips Alaska 659-7224 1 of 1 8/26/2004 11 :32 AM KRU 3F-18 Subject: KRU 3F-18 From: James Regg <jim_regg@admin.state.ak.us> Date: Mon, 23 Aug 200415:45:39 -0800 To: Tom Maunder <tom_maunder@admin.state.ak.us> \<;Ç,-\\;1 Received a spill report for KRU 3F-18 (8/22/04) advising of diesel bubbling out of conductor; cause listed as "corrosion/erosion"; removed gravel from well to begin diagnostic work 1 of 1 8/26/2004 11 :32 AM STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate D Other 0 Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 1961120/ ~tk-~~ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360 50-029-22684-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 96' 3F-18 8. Property Designation: 10. FieldlPool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6868' feet true vertical 6236' feet Plugs (measured) Effective Depth measured 6868 feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 3395' 7-5/8" 3491' 3189' PROD. CASING 6244' 5-1/2" 6340' 5752' PROD LINER 518' 3-1/2" 6858' 6227' Perforation depth: Measured depth: 6412-6428,6480-6490,6621-6641' RECEIVED true vertical depth: 5817-5832,5880-5889,6009-6027' SEP - I 2004 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6327' MD. Alaska Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) Baker seal assembly Seal=6327' SSSV= NIP SSSV= 517' 12. Stimulation or cement squeeze summary: R8DfAS Sf L SB' \I" LV" Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 291 243 923 1264 196 Subsequent to operation 291 243 923 1264 196 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry 3ÕQ N/~{ ~¿xempt: Contact Dethefs/McConnell 659-7224 Printed Name ~ry Dethlefs D~ Title Problem Well Supervisor ~ Signature ~ C A: ~-:::;I Phone 659-7224 Date ~ ~3- ëJ t/ ~ 7' ,. ......., Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ConocoPhillips Alaska, Inco Kuparuk We1l3F-18 (PTD 1961120) REPORT OF SUNDRY OPERATIONS 8/23/04 On August 23,2004, a cement shoe was pumped into the Outer Annulus (5-1/2" x 7-5/8" annulus) of Kuparuk well 3F-18. The cement shoe was pumped to isolate the annulus from the natural formation pressure that was supporting a small surface casing leak to the surface. The following are field notes that describe the operation: PUMP OA CEMENT SHOE. PUMPED 40 BBLS ARCTIC SET I 15.8 PPG CEMENT W /CELLOPHANE FLAKES, DISPLACE WITH 35 BBLS DIESEL. ESTIMATED CEMENT TOP 2100' MD. SHUT-IN WITH 400 PSI OA PRESSURE. ConocoPhillips intends to diagnose the suspected leak in the surface casing as to severity and depth and determine potential repair options. The AOGCC will be contacted prior to repairs being attempted. CQhOCoPb iIIipsì\'.kii, '...c. KRU 3F-18 3F-18 API: 500292268400 Well Tvoe: PROD Anale /â) TS: 24 dea /â) 6411 NIP (517-518, SSSV Type: Nipple Orig 7/11/1996 Angle @ TD: 23 deg @ 6868 Camoletian: 00:3.500) Annular Fluid: Last W/O: Rev Reasan: Taafill Reterenee Laa: Ret Loa Date: Last Update: 5/23/2003 Last Taa: 6674 TD: 6868 ftKB Last Taa Date: 5/11/2003 Max Hale Anale: 29 dea (1i1 3755 ~~ cc ~ Descriotion Size Too Bottom TVD Wt Grade Thread Gaslifl CONDUCTOR 16.000 0 121 121 62.50 H-40 'v1andrelNalve SUR. CASING 7.625 0 3491 3189 29.70 L-80 1 (3026-3027, PROD. CASING 5.500 0 6340 5752 15.50 L-80 00:4.750) PROD LINER 3.500 6340 6858 6227 9.30 L-80 1'ûblnâ.'Slftnâ~1'USING ",'",., ,',""'" . ' ,"", Size I Too I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 6327 I 5740 I 9.30 I L-80 I EUE 8RD MOD """""""'.' ""',''"',...,,,, . .. ..'",,' Gaslifl Interval TVD Zone Status Ft SPF Date TvDe Comment lAandrelNalve 6412 - 6419 5817 - 5824 C-4 7 4 2/4/1999 APERF 180 deg phasing, +/- 90 2 (43264327, < dea. 2 1/2" HC-DP 00:4.750) 6419 - 6425 5824 - 5829 C-4 6 4 2/26/199f APERF 180 deg phasing, +/- 90 dee, 2 1/2" HC-DP 6425 - 6428 5829 - 5832 C-4 3 4 2/4/1999 APERF 180 deg phasing, +/- 90 dea. 2 1/2" HC-DP GasLifi 6480 - 6490 5880 - 5889 C-1 10 6 5/11/2002 APERF 2.5" HSD, PJ DP Chgs, 60 dea ph 'v1andrelNalve 6621-6641 6009 - 6027 A-3 20 4 7/27/1996 IPERF 180 deg phasing, 2 1/2" 3 (5279-5280. " HSD 00:4750) '" ., ~~ '..'.'........"...'...... ,.. .' . ...... St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv Mfr Tvoe Run Cmnt 1 3026 2773 BST I'ìXf GLV 1.0 T1 0.156 1337 8/25/1996 GasLifi 8. 2 4326 3933 BST I'ìXf GLV 1.0 T1 0.156 1325 8/25/1996 IldrellDummy 3 5279 4785 BST I'ìXf GLV 1.0 T1 0.188 1347 8/25/1996 Valve 4 4 5947 5392 BST I'ìXf DMY 1.0 T1 0.000 0 7/12/1996 5 6265 5683 BST I'ìXf OV 1.0 T1 0.250 0 8/25/1996 (5947-5948. Otbir. ¡¡luCii mul """ ,,' '"." "..'.",~""'..'. "",."."....,.."...., ..'. 004.750) Deoth TVD TvDe Descriotion ID 517 514 NIP Cameo 'DS' Landina Nipple NO GO 2.812 6318 5731 NIP Cameo 'D' Landina Nipple NO GO 2.750 Gas Lift It. 6327 5740 PBR Baker Locator 3.000 lAandrelNalve General Notes 5 (6265-6266. Date INote 00:4.750) "~ 12/4/19971 Cameo 'DS' Nipple@517'w/2.812" ID, but 2.795" wouldn't PASS throuah 112/4/97). ... NIP rI (631ß.Q319, 00:3.500) I TUBING (W!27, J] 00:3.500, 10:2.992) PBR (6327-6328, 00:3.500) Perf - - (641%425) - - - - - - - - Perf - - (648().M9()) - - - - - - - - Perf - - (6621-6641) - - - - - - Kuparuk we1l3F-18 (PTD 1961120) Surface Casing Leak ...-._-~.) Subject: Kuparuk we1l3F-18 PTD 1961120) Surf: Casing Leak From: "Dethlefs, Jerry C" <Je conocophillips.com> Date: Mon, 23 Aug 2004 06:00:55 -0800 To: "Tom Maunder AOGCC (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Chuck Scheve AOGCC (E-mail)" <chuck_scheve@admin.state.ak.us>, NSK Problem Well Supv <nI617@conocophillips.com> Tom: As per my discussion yesterday with you, we found what appears to be a surface casing leak on Kuparuk well 3F-18. The well was SVS tested on Saturday (witnessed by Scheve) and did not have a problem then, but on Sunday the DSO noticed diesel slowly leaking over the top of the conductor into the gravel in the cellar. The well does not have an OA cement top job previously pumped, and the OA appears to recharge from the open shoe to over 200 psi. The OA will not remain bled off so there is not a way to stop the leak. The approach we are taking is to pump an OA cement shoe, which we will attempt today (8/23/04). Once we get the leak stopped we can continue diagnostics to determine the depth and severity of the leak and figure out repair options. A tubing plug has been set for now to minimize any complications from the well. As per the reporting requirements matrix and the need for a 10-403, I will use our conversation yesterday as the verbal approval. The 10-403/404 will follow in a few days. Thanks for calling me back on this issue. Jerry Dethlefs ConocoPhillips Alaska 659-7224 1 of 1 8/23/2004 4:04 PM 1. Operations performed: 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 !e, AK 99510-0360 4. Location of well at surface 18' FNL, 5267' FEL, Sec. 29, T12N, R9E, UM At top of productive interval 2592' FNL, 332' FEL, Sec. 30, T12N, R9E, UM At effective depth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation shutdown_ Plugging_ Perforate _XX Pull tubing _ Repair well _ Other _ 6. Datum elevation (DF or KB feet) RKB 96 feet 7. unit or Property name ' At total depth 2767' FNL, 350' FEL, Sec. 30, T12N, R9E, UM 12. Present well condition summary Total depth: measured true vertical Stimulate _ Alter casing _ 5. Type of Well' Development __X Exploratory __ Stratigraphic __ Service (asp's 50851 O, 5985802) (asp's 508161, 5983053) Kuparuk Unit 8. Well number 3F-18 9. Permit number/appr:oval number 196-1 12 / 10. APl number 50-029-22684 11. Field / Pool Kuparuk Oil Pool 6868 feet 6236 feet Plugs (measured) Effective depth' measured 6673 feet true vertical 6057 feet Junk (measured) Casing Length Size CONDUCTOR 80' 16" SUR. CASING 3440' 7-5/8" PROD. CASING 6299' 5-1/2" PROD LINER 518' 3-1/2" PROD LINER Cemented 262 sx AS 1 800 sx AS I!1,290 sx Class G 200 sx Class G included above Measured Depth 80' 3491' 6340' 6858' True vertical Depth 80' 3189' 5752' 6227' Perforation depth: measured 6412' - 6428', 6480' - 6490', 6621' - 6641' true vertical 5817'- 5832', 5880'- 5889', 6009' - 6027' (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 6327' MD. Packers & SSSV (type & measured depth) None CAMCO 'DS' LANDING @ 517' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Oil-Bbl 120 230 Prior to well operation Subsequent to operation 780 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations X Oil__ X Gas__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED Anchorage R. epresentative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 600 260 Casing Pressure . Tubing Pressure 154 Signed Michael Mooney Title: Wells Team Leader Form 10-404 Rev 06/15/88 · Suspended __ Service Questions? ~aii Mike Mooney 263-4574 Date Prepared by Sharon Altsup-Drake 263-4612 SUBMIT IN DUPLICATE 6OO - 160 ,, Date Comment 3F-18 Event History 05/10/02 05/11/O2 DRIFT TBG W/10'X 2.63" HCDG, TAGGED FILL @ 6773' WLM, NO PROBLEMS, COMPLETE [TAG] PERFORATED C1 SAND INTERVAL @ 6480'- 6490', W/10' OF 2-1/2" HSD, 6 SPF, POWER JET DP CHGS, 60 DEG PHASING. NO WHTP CHANGE AFTER GUN FIRED. [PERF] Page I of I 5/30/2002 SCANNEC) JUN 2~ (~ ;~002 PHILLIPS 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 June 4, 2002 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 3F-18 (196-112) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations fbr 'the recent perforation operations on the KRU well 3F-18. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney~ Wells Team Leader Phillips Drilling MM/skad RECEtVED $C;ANNE~ JUN 2 ~ 2i~t]2 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON OR BEFORE JANUARY 03 2001 PL E W M ATE IA L U_N D ER TH IS M ARK ER C:LORI~VIFILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate_ Plugging _ Perforate X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKB, Pad 55 3. Address: Exploratory ~ 7. Unit or Property: P,O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 23' FNL, 14' FWL, Sec 29, T12N, R9E, UM 3F-18 At top of productive interval: 9. Permit number/approval number: 2592' FNL, 332' FEL, Sec 30, T12N, RgE, UM 96-112 At effective depth: 10. APl number: 2743' FNL, 347' FEL, Sec 30, T12N, R9E, UM 50-029-22684-00 At total depth: 11. Field/Pool: 2772' FNL, 349' FEL, Sec 30, T12N, R9E, UM Kuparuk River Field / 0il Pool 12. Present well condition summary Total Depth: measured 6868 feet Plugs (measured) None true vertical 6236 feet Effective Deptl measured 6793 feet Junk (measured) None true vedical 6167 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 262 Sx AS I 121' 121' Surface 3440' 7,625" 800 Sx AS III & 3481' 3180' 290 Sx Class G Production 6817' 5,5" X 3.5" 200 Sx Class G 6858' 6227' Liner Perforation Depth measured 6412'-6419'; 6419'-6425'; 6425'-6428'; 6621'-6641' ~ECEiV~o_ true vertical 5817'-5824'; 5824'-5829'; 5829'-5832'; 6009'-6027' Tubing (size, grade, and measured depth) t~i~ Oil~ ~15 C005, 3.5", 9.3 Ib/ft, L-B0 @ 6327' AnChorage Cor~r~ission Packers and SSSV (type and measured depth) Pkr: PBR - Baker Iocator @ 6327'; None, Nipple @ 517' 13. Stimulation or cement squeeze summary ORIGINAL Perforate 'C' sands on 2/4/99, Intervals treated (measured) 6412'-6419'; 6425'-6428' Treatment description including volumes used and final pressure Perforated using 2.5" HC guns w/DP charges @ 4spt, final pressure was 1400 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 178 124 418 1251 212 Subsequent to operation 269 543 629 1112 212 15. Attachments MiT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil _X Gas Suspended Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /IA,~..,,' Signed ~ Title: Production Engineering Supervisor Date I1~1~ ~ ... Form 10-404 Rei 06/15/88 SUBMIT IN DUPLICATE J Alaska, Inc. ~ ..... ;(UPARUK RIVER UNIT /ELL SERVICE REPORT K1(3F-18(W4-6)) WELL JOB SCOPE JOB NUMBER 3F-1 8 PERFORATIONS-E-LINE 0120991520.16 DATE DAILY WORK UNIT NUMBER 02/04/99 PERFORATE C SAND 8345 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes (~) NoI ~ Yes (~ No SWS-VETROMILE LIGENZA Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann . Initial Outer Ann I Final~Ou~Ann DALLY SUMMARY I PERFORAT C SAND FROM 6412' - 6419' AND FROM 6425' - 6428'. TIME 11:30 12:30 13:15 14:00 15:00 16:00 LOG ENTRY MIRU SWS. TGSM WIND CHILL NEAR -70. MINIMIZE TIME OUTSIDE. TAKE FREQUENT BREAKS. CONTACT SECURITY, SET OUT SIGNS FOR RADIO SILENCE. MAKE UP TOOLS. HEAD, GRADIO, CCL, MPD, SAFE, 20' 2-1/2"HC, DP, 4 SPF, TOTAL LENGTH 33.8'. LENGTH FROM CCL TO TOP SHOT = 11.5. 24.5' TO SECOND ZONE TOP SHOT. PRESSURE TEST LUBE/BOPS TO 3,000 PSI. SHUT IN WELL & LIFT GAS. RIH. TIE IN W/GAMMA RAY AT 6500'. PRODUCTION ENGINEER ON SIGHT FOR TIE IN PASSES. LOCATE AT 6400.5 TO PLACE TOP SHOT AT 6412' FIRED GUN THREE TIMES WITH NO SIGNIFICANT INDICATION ON SURFACE THAT GUNS FIRED. LOG UP, POH PRESSURE INCREASE IN TUBING GOOD INDICATION SHOTS FIRED. ON SURFACE, ALL SHOTS FIRED. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $18o.oo HALLIBURTON $0.00 $1,041.00 LITTLE RED $0.00 $600.00 SCHLUMBERGER $7,344.00 $7,344.00 TOTAL FIELD ESTIMATE $7,344.00 $9,165.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate_ Plugging _ Perforate X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X~_~. 41' RKB, Pad 55 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 23' FNL, 14' FWL, Sec 29, T12N, R9E, UM 3F-18 At top of productive interval: 9. Permit number/approval number: 2592' FNL, 332' FEL, Sec 30, T12N, R9E, UM 96-112 At effective depth: 10. APl number: 2743' FNL, 347' FEL, Sec 30, T12N, R9E, UM 50-029-22684-00 At total depth: ! 1. Field/Pool: 2772' FNL, 349' FEL, Sec 30, T12N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 6868 feet Plugs (measured) None true vertical 6236 feet Effective Deptl measured 6793 feet Junk (measured) None true vertical 6167 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 262 Sx AS I 121' 121' Surface 3440' 7.625" 800 Sx AS III & 3481' 3180' 290 Sx Class G Production 6817' 5.5" X 3.5" 200 Sx Class G 6858' 6227' Liner Perforation Depth measured 6419'-6425'; 6621'-6641' truevertical 5824'-5829'; 6009'-6027' ~EC Tubing (size, grade, and measured depth) Og-~' 3.5", 9.3 lb/fi, L-80 @ 6327' ~ ~,SL,~ ~0IlS' ~0~t~$~'101't'"" Packers and SSSV (type and measured depth) Pkr: PBR - Baker Iocator @ 6327'; None, Nipple @ 517' 13. Stimulation or cement squeeze summary Perforate 'C' sand on 12/26/98. 6419'-6425' Intervals treated (measured) OR Treatment description including volumes used and final pressure Perforated using 2.5" HC guns @ 4spt, final pressure was 400 psi. 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 215 264 473 1155 171 Subsequent to operation 230 335 559 11 64 193 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ~X 0il X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date Form 10-404 Rev q ~ SUBMIT IN DUPLICATE Alaska, Inc. - ..... KUPARUK RIVER UNIT ~[ ,,'ELL SERVICE REPORT '~ K1(3F-18(W4-6)) WELL JOB SCOPE JOB NUMBER 3F-18 PERFORATE, PERF SUPPORT 1213981615.4 DATE DAILY WORK UNIT NUMBER 12/26/98 ADD PERFS TO C-4 SANDS DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR I (~ Yes O NoI (~ Yes O No ALLDREDGE JOHNS ESTIMATE KAWWRK 230DS36FL $7,572 $8,981 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer/~n I Final O~'Ann 200 PSI 400 PSI 1400PSI 1400PSII 400 PSII "" 0PSI DALLY SUMMARY PERFORATED 6419' RKB TO 6425' RKB WITH 2.50 GUN, 4 SPF [Perf] TIME LOG ENTRY 10:00 MIRU SCHLUMBERGER E-LINE. SAFETY MEETING. HAVING PROBLEM WITH ELECTRONICS ON TOOLS. 12:55 RIH W/GAMMA, CCL, 6' 2.50" HALLOW CARRIER 4 SPF WITH SAFE SYSTEM , TO 6700', LOG UP WITH GAMMA, CCL. TIE-IN REF. BACK TO OPEN HOLE LOG. 15:00 TOP SHOT AT 6419' RKB TO BTM AT 6425', FIRE GUN, LOOKED GOOD. LOG UP, OBTAINED JEWRLY LOG WHILE POOH. 16:20 AT SURFACE, ALL SHOTS FIRED, RDMO, TURNED WELL OVER TO DSO FOR PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $80.00 APC $300.00 $300.00 HALLIBURTON $0.00 $669.00 LITTLE RED $0.00 $660.00 SCHLUMBERGER $7,272.00 $7,272.00 TOTAL FIELD ESTIMATE $7,572.00 $8,981.00 PERMIT 96-112 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS CBL ~10-407 ~000-6770 '~/~OMPLETION DATE DAILY WELL OPS Page: 1 Date: 07/07/98 RUN RECVD FINAL 09/25/96 IOl/? yes ~_~And received? Are dry ditch samples required? Was the well cored? yes ~__, Analysis & description received? Are well tests required? yes ~o~ Received? Im~s~-P~-~l Initial Well is in compliance COMMENTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-18 (Permit No. 96-112) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3F-18. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad STATE OF ALASKA ,~L~SKA OIL AND GAS CONSERVATION C .... ;MISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1 Statu~ of Well Classification of Service Well OIL E~] GAS [--~ SUSPENDED E~] ABANDONED [] SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, In¢ 96-112 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22684 4 Location of well at surface -~ ~ 9 Unit or Lease Name ! - ,~;¢~,~;, '~ Kuparuk River Unit 23' FNL, 14' FWL, Sec. 29, T12N, R9E, UM :' 10 Well Number At Top Producing Interval ': '-_'-, ~.. ._ 2592' FNL, 332' FEL, Sec. 30, T12N, R9E, UM ;~ 3F-18 At Total Depth i.~.~~ ~'~" 11 Field and Pool 2772' FNL, 349' FEL, Sec. 30, T12N, R9E, UM - ' ............ : .... KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Ri~l RKB 41' PAD 55'I ADL 25643 ALK 2574 12 Date Spudded02_Jul_96 13 Date T.D. Reached09_Jul_96 14 Date Comp. , Susp. or Aband.27_Jul_96 (peri'd) I15 Water Depth' if O~shOrONA fOOt MSL I~ 6 NO' Of cOmpletiOnsl 17 lotal Depth (MD+IVD) 18 Plug Back Depth (MD+IVD) 1 ~ Directional Survey 120 Depth where SSSV set 21 lhickness of permafrost 6868' MD & 6236' TVD 6793' MD & 6167' TVD YES xL~ NO [~I NA feet MD = 1380' SS APPROX 22 Type Electric or Other Logs Run ARC5/GR, G PJCCL/SLT-J 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 121' 24" 262 sx AS I 7.625" 29.7# L-80 SURF. 3481' 9.875" 800 sx AS III Lead, 290 sx Class G Tail 5.5" x 3.5" 15.5#/9.3# L-80 SURF. 6858' 6.75" 200 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6327' 6621' - 6641' MD 4 spf 6009' - 6027' TVD !26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6621 '-6641' total of 144974# proppant placed in perfs, left 18600# in wellbore. 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/25/96I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10/7/96 12.20 TEST PERIOD ¢ 525 347 147 136 662 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 194 934 24-HOUR RATE I~ 1033 683 290 --24" 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 0C l Submit in duplicate Rev. 7-1-80 CONTII',,MED ON REVERSE SIDE , 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 6411' 5817' Bottom Kuparuk C 6490' 5889' Top Kuparuk A 6601' 5990' Bottom Kuparuk A 6752' 6129' FREEZE PRQTECT ANNULUS WITH DIESEL 31. LIST OF A-FFACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~ Title 'i~ ~;~L ~--i, ~"~ · DATE INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 7/12/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:3F-18 RIG:PARKER WELL ID: AK8565 AFC: AK8565 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST TYPE' FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI' 55% SECURITY:0 AFC EST/UL'$ OM/ OM API NUMBER: 50-029-22684-00 7/2/96 (1) PBTD: 852'(731) SUPV:RLM DAILY: MW: 9.3 PV/YP: 22/32 APIWL: 6.2 DRILLING Move rig 150' from 3F-19 to 3F-18. Accept rig at 1200 hrs. 7/2/96. Function test diverter. Spud at 1600 hrs. 7/2/96. Directional drill from 121' to 188'. Could not make con- nection due to 5-15' fill each time pumps were shut down. Increase vis. to 120 from 60 then to 225. Circulate out gravel and pea gravel. Directional drill from 188 to 852'. $90,297 CUM: $90,297 ETD: $0 EFC:$90,297 7/3/96 (2) MW: 9.8 PV/YP: 34/29 APIWL: 5.4 PBTD: 3491' (2639) CEMENT CASING SUPV:RLM Directional drill from 852' to 1007'. Flowline and bell nipple packed off with clay. Work pipe and jet flow line. Directional drill from 1007' to 3491'. DAILY: $86,382 CUM: $176,679 ETD: $0 EFC:$176,679 7/4/96 (3) PBTD: 3491'(0) SUPV:RLM DAILY: MW: 8.5 PV/YP: 4/0 APIWL: 20 CIRCULATE AT 3501' Held pre-job safety meeting. Run 7-5/8" casing to 3481' Cement casing. CIP at 0900 hrs. 7/4/96. Tested choke and manifold to 300/3000 psi. Test all lines, valves, rams and hydril to 300/3000. $190,973 CUM: $367,652 ETD: $0 EFC:$367,652 7/5/96 (4) PBTD: 4546'(1055) SUPV:RLM DAILY' MW: 8.8 PV/YP: 9/9 APIWL: 14 DRILLING Test casing to 2000 psi for 30 minutes. Clean out cement, float collar at 3393', cement shoe at 3481. Drill new hole from 3491' to 3501' Perform LOT. EMW=12.2 ppg. Directional drill from 3982' to 4546' $73,449 CUM: $441,101, ETD: $0 EFC:$441,101 7/6/96 (5) MW: 8.9 PV/YP: 20/16 APIWL: 5.5 PBTD: 5815' (1269) RIH SUPV:RLM Directional drill 6.75" hole from 4546' to 5815'. Perform open hole FIT. 12.68 EMW at the 7-5/8" shoe. POOH. DAILY: $84,608 CUM: $525,709 ETD: $0 EFC:$525,709 7/7/96 (6) PBTD: 6331'(516) SUPV:RLM DAILY: MW: 11.4 PV/YP: 27/18 APIWL: 4.7 REPAIR RIG Directional drill 6.75" hole from 5815' to 6075'. Anadrill pulser locked up after 3800 strokes had been pumped. Repair pulser. Directional drill 6.75" hole from 6075' to 6331' Observe well on connection, slight flow. CBU, no gas or oil CUt mud. Well static. $90,434 CUM: $616,143 ETD: $0 EFC:$616,143 -7/8/96 (7) PBTD: 6635'(304) SUPV:RLM DAILY: MW: 12.4 PV/YP: 31/18 APIWL: 4.5 DRILLING AT 6712' Directional drill 6.75" hole from 6331' to 6635'. Check flow, well flowing. Shut in well. Increase mud weight to 11.9 ppg. Circulate out kick per kill schedule. Open well gas breaking out, no flow. Continue circulating and raise weight. $95,087 CUM: $711,230 ETD: $0 EFC:$711,230 7/9/96 (8) PBTD: 6868'(233) SUPV:DCL DAILY: MW: 12.5 PV/YP: 21/23 APIWL: 4.5 RIH W/5.5" CSG Pump out from 6635' to 6336' Drilling from 6635' to 6868' Circ and condition mud. Check flow. Suspect light spot in mud in hole. Gas and oil cut returns at bottoms up. Circ and condition mud. Check flow. OK. RIH. No fill. CBU. Had small amount of gas and oil cut mud at bottoms up. Increase mud weight. Monitor well. OK. Pump slug. Continue POH LD BHA. $86,721 CUM: $797,951 ETD: $0 EFC:$797,951 7/10/96 (9) PBTD: 6868' (0) SUPV:DCL DAILY: MW: PV/YP: APIWL: RIH W/3.5" TBG Held pre-job safety meeting. RIH w/3.5" x 5.5" casing to 6858' Pump cement. Bumped plug. Floats did not hold. Reseat plug. Shut in casing. ND BOPE. Install packoff and tbg head. Test to 3000 psi. NU BOPE. Test BOPE. $175,111 CUM: $973,062 ETD: $0 EFC:$973,062 7/11/96 (10) PBTD: 6868' (0) SUPV:DCL DAILY: MW: PV/YP: APIWL: RIG RELEASED Held pre-job safety meeting. RIH w/3.5" completion. Locate into PBR. Test casing to 3500 psi f/30 minutes. Test tbg to 3500 psi/10 minutes. Test annulus to 3500 psi for 10 min. ND BOPE NU tree. Freeze protect annulus. Release rig @ 1600 hrs. 7/11/96. $107,234 CUM: $1080,296 ETD: $0 EFC:$1080,296 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(3F-18(W4-6)) 3F-18 DATE 07/27/96 DAY 1 DAILY SUM JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0725961959.4 DAILY WORK UNIT NUMBER PERF 'A' SANDS OPERATION COMPLETE Tbg , Tbg ]SUCCESSFUL. i[ KEY PERSON SUPERVISOR Y, S sL I:, Initial Pr-~s '1 Final Press '1 Initial Inner Inner Ann Initial Outer Ann 0 PSI! 600 PSI[ 0 PS 0 PSI 0 PSI 0 PSI VlARY PERFORATED 'A' SAND FROM 6621' TO 6641' WITH 2.5" HSD GUN (BIG HOLE CHARGES, 4 SPF, 180 DEG PHASING, 5 DEG CW FROM HIGH SIDE). TIME 08:00 08:45 09:45 10:00 LOG ENTRY MIRU AND HOLD TAILGATE SAFETY MEETING. CALL IN RADIO SILENCE ALERT TO SECURITY. INFORM PEOPLE ON PAD OF PERFORATING ACTIVITIES AND RADIO SILENCE. SIGNS ON BOTH SIDES OF ROAD ENTERING PAD. ORIENT GUNS 5 DEG CW FROM HIGH SIDE OF HOLE. ARM AND PU GUN #1. GUN#1 IS 2.5" HSD HOLLOW CARRIER WITH BIG HOLE CHARGES, 4 SPF, 180 DEG PHASING. PT LUB TO 2500 PSI. PdH WITH FN/CCL/MPD/GUN#1 . CCLTOTS = 3.5'. TIE INTO CBL (7/26/96) WHICH IS TIED INTO ANADRILL ARC 5 (7/4-9/96). NO CORRECTION BETWEEN LOGS IN DEPTH OF INTEREST. POSITION CCL@ 6617.5 TO SHOOT 6621'-41'. iNCREASE WHPTO 1600 PSI (- 200 PSI OVERBALANCE). FIRE GUNS. WHP DECREASED TO 1200 PSI. GOOD INDICATION ON SURFACE THAT GUNS FIRED. PULLED AN EXTRA 400 LBS THEN BROKE FREE. POOH WITHOUT ANY FURTHER COMPLICATIONS 11:00 ON SURFACE. ALL SHOTS FIRED. RD AND MOVE TO 3F-19. ARCO Alaska, Inc. Date: September 11, 1996 RETURN TO: ARCO Alaska, inc. Attn. · Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 9735 3G-25 q6~ lq2,, 3F-19 ¢/f~. 112... 3F-18 ~'6,~1,~ 3F-17 ~' o°~O 2M-35 ~'(,, O-/~ 2M-34 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log 07-25-96 07-27-96 07-26-96 07-27-96 O7-28-96 07-31-96 Receipt Ack n o wi e d g e(~__b,,,~=.4 ~::~4~--~_ Date: DISTRIBUTION: Sharon Allsup-Drake DS Development ATO- 1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 2700-3520 7460-7876 6p00-6770 6460-7045 14000-14775 16240-16560 Chapman/Zuspan NSK Wells Group NSK69 Memo: To: ARCO' DaVid Johnston Tuckerman Babcock Jack Hartz Well KRU 3F-18 Kick: 8July96 8July96 Fm' Blair Wondzell c:\aogccgen\kru3f-18.kic) 10:15 am 7/8/96. Chuck Scheve called about 10:1 5 am and reported that Parker 245 was on the choke. They had been drilling at 6635 md, 6021 tvd (in the "A2" sand ?) with 11.4 ppg mud. Well started flowing, shut it in. SIDPP 130 PSI, SICP 360 psi. Now weighting up to 11.9 ppg mud. Item TD 7-5/8" 5-1/2" 3-1/2" PTD Proposal: 6926 md, 6283 tvd 3449 md, 3176 tvd. 6317 md, 5738 tvd. 6926 md, 6283 tvd. Actual 3481 md 7'.10 am 7/9/96. Chuck reported that they had raised the mud weight to 1 2.4 ppg, killed the well, and were back drilling. Final report on the 7/8/96 kick, KRU well 3F-18. TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 18, 1996 Michael Zanghi, Drill Site Develop Supv '~,CO 'Alaska. Inc. P O Box 100360 Kupamk River Unit 3F-!8 ARCO ''~ Pe,,~mit No' 96-1 ! 2 Sur. Loc. 23'FNL i4'r vVL. Sec. 29. T12N, R9E. UM Btmhote Loc. 2491'FSL. 279'FEL, Sec. 30, T12N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundu, Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and anv diagnostic logs that were mn. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice max,' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Jol~ston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CCi Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill r"l lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry r"l Deepen r'l Service [--I Development Gas D Single Zone X MulfipleZone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 55' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25643, ALK 2574 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 23' FNL, 14' FWL, Sec. 29, T12N, RgE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2732' FSL, 253' FEL, Sec. 30, T12N, R9E, UM 3F-18 #U-630610 At total depth 9. Approximate spud date Amount 2491' FSL, 279' FEL, Sec. 30, T12N, RgE, UM 6/1 8/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3F-07 6926' MD 2491 @ TD feet 11.4' @ 100' feet 2459 6283' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 26.7° Maximum surface 1 880 psig At total depth ('T'VD) 3200 psig 18. Casing program Settinc~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TV• MD TVD (include stage data) 24' 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 9.875' 7.625" 29.7# L-80 LTC 3408' 41' 41' 3449' 3176' 580 Sx Arcticset III & HF-ERW 290 Sx Class G 6.75' 5.5" 15.5# L-80 LTCMOD 6276' 41' 41' 631 7' 5738' 250 SxClassG HF-ERW Top 500' above Kuparuk 6.75' 3.5" 9.3# L-80 EUE8rdlV 609' 6317' 5738' 6926' 6283' 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: trumeeaS~/r;rl~cal ff::: Plugs(measured) ORIGINAL Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Ueasl~'h l~ I Vrrm Rrtical depth Structural Conductor Surface Intermediate MAY ;5 1 1996 Production Liner Alaska 011 & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis ~ Seabed report D 20 AAC 25.050 requirements X r 21. I hereby certify that:hlfor~ng iVrue~/(~. ' -~'~ and correct to the best of my knowledge Signed , Title Drill Site Develop. Supv. Date Commission Use Only See cover letter for Pe~,~.u.._m,~,/~,~, __ ~.. ~, ~,, ~ Approval date ~ ~, other requirements Conditions of approval Samples required ~ Yes ~ No Mud logl~quirc~l r~ Yes ,~ No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~ Yes D No nequired working pressure for BOPE r~ 2M [] 3M [~ 5M g] 1OM [-~ 15M David W. Johnston by order of ..... . /~,/.,, Approved by Commissioner the commission Date ~_~//0-~ Form 10-401 Rev. 7-24-89 i tri[~licate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3F-18 · 0 . . . . . . . 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,449')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (6,926') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. RECEIVED Alaska 0tt & Ge~ Cot;~,. Commission DRILLING FLUID PROGRAM Well KRU 3F-18 Spud to 9-5/8" surface casin~l Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General 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 and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,880 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3F-18 is 3F-07. As designed, the minimum distance between the two wells would be 11.4' @ 100'. Drilling Area Risks: Risks in the 3F-18 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. 'Spud mud should be adjusted to a FV between 50-80 sec/qt to ~r~ ~r~,~(~. MAY 3 1 ~996 ANNULAR PUMPING OPERATIONS WELL KRU 3F-18 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rin~eate will not be injected dgwn the dedicated disposal well but will be recycled or held for an open ~.nnulus.! The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3F-18 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3F-18 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3F surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3482 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 58 57 5.500 15.5 L-80 3 LTC-M 4990 4 2 4 2 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling w~l~t[~-s~'s~~ with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). MAY Alaska 01! & P~r~ t~,~r~ O,.~rflrni~Rion ARCO ALASKA, Inc. Ped 3F 18 slot #18 Ku~ruk River Unit North Slope, Alaska CLEARANCE REPORT Baker Hughes I NTEQ Your ref : 18 Version Our ref : proplS07 License : Date printed : 16-#ay-96 Date created : 11-Jan-96 Last revised : 16-May-96 FieLd is centred on nlq) 16 18.576,w150 5 56.536 Structure is centred on nlq) 22. 20.~56,w1&9 55 51.2~9 SLot location is n70 22 20.730,w149 55 50.84)9 SLot Grid coordinates are N 5985800.280, E 508513.939 SLot local coordinates are 23.00 S 14.00 E Reference North is True North ( WARNING= DATA BELC&I IS A SUMMARY, DETAIL PROXI#ITIES NOT TABULATED ) Object we[ [path CLosest approach with 3-D Last revised Distance #.D. Divergi~ fr~nM.D. PGNS <O-8600'>,,16,Pad 3F 21-Nov-91 262.4 300.0 300.0 POI$ <O-8108'>,,13,Pad 3F 21-Nov-91 187.7 0.0 0.0 P~l$ <O-8730'>,,1,Ped 3F 21-#ov-91 159.7 450.0 450.0 PGNS <0-7455'>,,15,Ped 3F 21-Nov-91 ?.37.0 325.0 325.0 PGI~ <O-(~)75'>,,14,Pad 3F 21-Nov-91 211.8 350.0 350.0 PGHS <0-7570'>,,12,Pad 3F 21-Nov-91 16~.6 100.0 200.0 PGM$ <O-8600">,,11,Pad 3F 21-Nov-91 137.2 200.0 200.0 P~I$ <O-6650">,,10,Pad 3F 21-Nov-91 112.0 100.0 200.0 PIllS <O-7050">,,8,Pad 3F 21-Nov-g1 13.5 325.0 325.0 PGH$ <O'8070'>,,7, Ped 3F 21'Nov'91 11.4 100.0 400.0 PGM$ <O-7717">,,6,ped 3F 21-Nov-91 36.8 500.0 PGMS <O-88'/'5'>,,5oPad 3F 21-Nov-91 61.6 200.0 200.0 PGNS <O-6913'>,,4,Ped 3F 21-Nov-91 82.2 625.0 625.0 PGMS <O-7~O~m>,,3,Pad 3F 21-Nov-91 106.1 675.0 2100.0 PI;NS <O-7864'>,,2,Pad 3F 21-Nov-91 130.7 700.0 700.0 P~I$ <O-7785'>,,9,Pad 3F 21-Nov-91 88.0 300.0 3060.0 19 Version ~G,,19,Ped 3F 16-#ay-96 150.5 300.0 300.0 3F-C Version ~5,,3F-C,Pad 3F 16-Nay-96 277.2 300.0 300.0 minimun distance method RECEIVED Al~;kjl 011 & (~aa Cons. Commission Anchorage Created by : jones For: D PETRASH Dote plotted : 16-May-96 Pict Reference is 18 Vers~ ~6. Coordinates ere in feet reference slot j~18. True VerUcal Depths ore reference RK8 (Parker ~245). 0 o o o cq .. 400 _ 800 _ O 2800_ ~_ - Q) 32oo_ -- (j,) 3600_ ~ - 4000 _ I I V 'ARCO ALASKA Structure Pad 3F 1 1 Inc. Field : Kuparuk River Unit Well : 18 j Location : North Slope, Alaska S 6.04 DEG W 2539' (TO TARGET) <-- West .... 400 200 0 200 6O00 _ 6400_ 400 I I I I I ~ _ 200 SURFACE LOCATION: 23' FNL. 14' FWL " SEC. 29, T12N, RgE / 0 1 ~'O°KOP,O~ TVD=500 TMD=500 DEP=O . 8as. Permofro,t l/ 400 ~ 112,.~.~OO BUILD , DEG /100' JTop Ugnu Sands ',~ T/ UGNU SNDS TVD=1896 TMD=2016 DEP=575 III . . 1200 ~ a/~75/6 cas,no Pt - ~- ~ / _ ~ 400 ~ 12732' FSL, 253' FEL/ TARGET ~ - '~ I SEC_ 3O. T12N. RgE/ 'r'vD=s801 ~ _2200 SOUTH 2525 - AVERAGE ANGLE X w~T 267 /' / '%, _~oo ~ _28o0 ~ T/ ~ INTERg~ WD=Sg~ TMD=6~4 DEP=2636 B/ KUP SNDS ~D=8104 TMD=6726 ~69~ 1 InnP · ~ ~ ~=~ga8 ~=oggo ~gP=gTa/v~MI o , /~o I TD L~ON: Al8~kB 011 & 6a~ COns. Gommi~8~ :o, T~2N, 0 400 800 1200 1600 2000 2400 2800 Anchorage Scale 1 : 200.00 Vertical Section1 on 186.04 azimuth wlth ~efemnce 0.00 N, 0.00 E from slot J~18 ARCO ALASKA, Inc. by :ione. For: ]Dote plott~l : Plot Refere~e is 18 Ve~ ~6. , ~ Field : Kuporuk River Unit Location : North Slope, Alaska ~Co~tes are in feet ref~ ~ot ~18. ~p~s ar~ r~f~e RKB (Pa~ ~245)., <-- West Scale 1 · 10.00 2~ 180 160 140 120 1 O0 80 60 40 20 0 20 ~ 60 80 1 O0 120 I I I I I I I I I I I I I I I I I I I I I I I I I [ I I I I I I - ~ 40 _ O_ 20_ I _ 0 2~_ 220_ 2~ 180 160 140 120 1 O0 80 60 40 20 0 20 ~ 60 80 1 O0 120 < - - We sf MAY3sao~99~ ~o.oo 80 o o o _40 Alaska Oil & Gas Cons. Commission Anchorage o 20 _40 _120 I - I _140 V -- _160 _180 _220 -- _240 -- _260 -- _280 _2O0 UPARUK RIVER UNI' 20" DIVERTER SCHEMATIC 3 2 O ' DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. 4. 20' - 2000 PSI DRILLING SPOOL WITH ONE 16' OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE, THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. RECEIVED MAY ~ 11996 (~tl ~ 9a~ ~. Commission DKP 11/9~J4 7 5 4 II 13 5/8" 5000 PS! dOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT ACCUMULATOR PRESSURE IS 30(X) PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. & OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. P- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. & CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3(XX) PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 6. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(XX) PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 30(X) PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. l& RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL AC~ATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" -2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPCXDt. 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPOOLW/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED · WELL PERMITCHECKLIST COMPANY/¢7/' .-O_ WELL NAME,/'~,~/ ,~,,~- ///,~ PROGRAM: exp [] dev~.redd, El serv [] wellbore seg [] ann. disposal para req ~ FIELD & 'POOL ~ ~:~O//,~ INIT CLASS. ~"'~,~/ /'~ -<:~ ~ ~'/ GEoi. AREA ~--~ ~ UNIT# ///~'~ ON/OFF SHORE~ , , , ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................. 4. Well located in a defined pool .................. 5. Well located proper distance from dflg unit boundary .... 6. Well located proper distance from other wells ......... 7. Sufficient acreage available in drilling unit ........... 8. If deviated, is wellbore plat included .............. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............ 11. Permit can be issued without conservation order ...... 12. Permit can be issued without administrative approval .... 13. Can permit be approved before 15-day wait ......... N ,N 'N N N N N N N N N N N ENGINEERING APPR DATE 14. Conductor string provided ................... (~¢/N 15. Surface casing protects all known USDWs .......... (~ N 16. CMT vol adequate to circulate on conductor & surf csg . . . 17. CMT vol adequate to fie-in long sffing to surf csg ....... Y 18. CMT will cover all known productive horizons ......... ~ N 19. Casing designs adequate for C, T, B & permafrost ...... (_~ N 20. Adequate tankage or reserve pit ................ (~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved .... 22. Adequate wellbore separation proposed ............ 23. If diverter required, is it adequate ................ (~ N 24. Ddlling fluid program schematic & equip list adequate .... .(¢~) N 25. BOPEs adequate ........................ ~ N 26. BOPE press rafing adequate; test to 3'c.x~45 psig. _(~ N 27. Choke manifold complies w/APl RP-53 (May 84) ....... ,~ N 28. Work will occur without operation shutdown .......... ~ N 29. Is presence of H2S gas probable ............... L~ N 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............ ./'Y N 33. Seabed condition survey (if off-shore) .......... .//.. Y N 34. Contact name/phone for weekJy progress reports .... /... Y N Jexlaloratory only] GEOLOGY APPR DATE REMARKS GEOLOGY: ENGINEERING: JDH ----"-- JDN COMMISSION: Comments/instructions: TAB ~,---'~;~ HOW/lib- A:~FORMS'cheklist rev 4/96
