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188-043
RECEIVED STATE OF ALASKA MAY 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND ' CaCC la.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned Q • Suspended❑ lb.Well Class: 20MMC 25.105 20MMC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No.of Completions: Service 0 • Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 3/12/2015 ' 188-043/315-151 /315-038 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,Alaska 99510 4/24/1988 50-029-21796-01 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1106'FNL,2060'FWL,Sec.22,T13N, R9E, UM 4/26/1988 44241 30-16A Top of Productive Interval: 9. KB(ft above MSL): 58' 17. Field/Pool(s): 1887'FSL, 1053'FEL,Sec.21,T13N, R9E,UM GL(ft above MSL): 23' Kuparuk River Field/Kuparuk River Oil Pool Total Depth: 10.Plug Back Depth MD/TVD: 18. Property Designation: 1746'FSL, 1352'FEL,Sec.21,T13N, R9E, UM 8118'MD/6709'TVD- ADL 25513 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 525698 y- 6021714 Zone-4 8351'MD/6901'TVD , 2554 TPI: x- 522597 y- 6019417 Zone-4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 522299 y- 6019275 Zone-4 none 1636'MD/1612'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No Q 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) 7815'MD/6461'TVD 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 none SCANNED SEP 0 9 2015 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 175 sx AS I 9.625" 36# J-55 35' 2375' 35' 2215' 12.25" 900 sx AS III, 300 sx AS II 7" 26# J-55 1062' 8201' 1062' 6778' 8.5" 700 sx TLW,300 sx Class G 8,- 175 175 sx AS 4.5" 11.6# L-80 7688' 7947' 6358' 6569' 6" 15 bbls of 15.8#'G'Neat 24.Open to production or injection? Yes ❑ No Q 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): 4.5" 7695' 7688'MD/6357'TVD reperf 4.5":7838'-7859'MD 6480'-6488'TVD :4-,,,,,,;;k, ,• 26.ACID,FRACTURE,CEMENT SQUEEZE, ETC. ?j P�1� Was hydraulic fracturing used during completion? Yes❑ No EFIF_ ' Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): plugged off 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 v7L_ q Z /) CONTINUED ON SAGE 2 �11l� Submit ORIGINIAL only/ f��� ' ' 4�31is RBDMS`'[1 JUN 1 1 2015 ✓G 28.CORE DATA Conventional u..,a(s): Yes ❑ No E Sidewall Cores: 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑, Permafrost-Top surface surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1636' 1612' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Kuparuk C 7772' 16425' Base Kuparuk C 7801' 6449' Top Kuparuk A 7838' 6479' Base Kuparuk A 7969' 6586' NA Formation at total depth' Kuparuk 31. List of Attachments: Summary of daily operations,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. Contact' Jason Burke @ 265-6097 Email: Jason.Burke(a�conocophillips.com Printed Name. Dan Venhaus Title: CTD Supervising Engineer Signature. Phone: 26,3 -1/37Z Date. I Q - IS INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 INJ 30-16A ConocoPhillips ° n,pt Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl V) MD(ftKB) Act Btm(ftKB) cn,„,r,;rt. 500292179601 KUPARUK RIVER UNIT INJ 43.38 2,600.00 8,351.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 30-16A.3/1520159:3303 AM SSSV:NIPPLE Last WO: 12/11/2014 34.98 4/23/1988 • Vesical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _Last Tag'. Rev Reason:PERFORATE,SET PLUG AND hipshkf 3/15/2015 HANGER,330 Itj;(K;I WHIPSTOCK Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED 11 t 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread SURFACE 95/8 8.921 35.0 2,374.9 2,214.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread TIEBACK 7 6276 33.0 1,060.7 1,060.6 26.00 L-80 TC-II Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread '�PRODUCTION 7 6276 1,061.6 8,201.2 6,777.8 26.00 J-55 BTC Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)... WtlLen)L..Grade Top Thread CASING PATCH 6.089 5.488 1,011.4 1,121.0 1,120.7 FODC-OR CONDUCTOR;36.0-115.0-A A Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread LINER 41/2 4.000 7,687.5 7,947.3 6,568.9 11.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(ND)(ft)(B) Top Incl(") Item Des Corn (in) • 7,687.5 6,357.4 35.88'PACKER BAKER"2RH"ZXP LINER TOP PACKER 4.330 • I7,707.2 6,373.3 35.81 HANGER BAKER FLEX-LOCK HANGER 4.250 i Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(INft) Grade Top Connection TUBING-41/2x5@ 412 4.000 33.0 7,695.4 6,363.7 12.60 L-80 IBTM TIEBACK;33.0-1.050.7 7663'66 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) 33.0 33.0 0.03 HANGER CAMERON TUBING HANGER 3.833 CASING PATCH;1,011.4 7,635.8 6,315.5 36.12 NIPPLE DB NIPPLE,SR#T031038 3.813 1.121.0 7,684.5 6,354.9 35.90 LOCATOR BULLET SEAL LOCATOR 3.930 7,685.6 6,355.8 35.89 SEAL ASSY BULLET SEAL ASSEMBLY 4.250' "Miter In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;35.0-2,374.9 - Top(ND) Top Incl Top(ftK (ftKB) r) Des Com Run Date ID(in) • 7,815.0 6,460.9 35.5 WHIPSTOCK 3.625"STARBURST HOLLOW WHIPSTOCK 3/122015 ' (OAL=12.41',RA TAGS AT 2.2'FROM TOP OF NIPPLE;7,635.8 . - WHIPSTOCK) III 7,826.6 6,470.3 35.51 PLUG 3.568"WFT STARBURST PACKER(OAL=4.98', 3/11/2005 -,-7 " C III SET 52 DEG LOHS) 2. Perforations&Slots 4 Shot XO Enlarging(Tubing);7,683.7 Dens LOCATOR;7,684.5 Top(TVD) Btm(TVD) (shotsfl Top(ftKB) Btm(ftKB) (11KB) (MB) Zone Date t) Type Com 7,794.0 7,804.0 6,443.8 6,451.9 C-1,UNIT B, 3/16/1989 12.0 IPERF 60 deg.phasing;2 1/8" SEAL ASSY;7,685.6 30-16A EnerJet 7,838.0 7,859.0 6,479.6 6,496.7 A-1,30-16A 3/7/2015 6.0 APERF 60 deg phasing,33/8 Millennium DP 7,838.0 7,848.0 6,479.6 6,487.7 A-5,A-3,30- 3/16/1989 6.0 (PERF 30 deg.phasing;2 1/8" IA 16A EnerJet . 7,850.0 7,860.0 6,489.4 6,497.5 A-3,30-16A 3/16/1989 12.0 (PERF 60 deg.phasing;2 1/8" EnerJet "E. ,, 7,867.0 7,872.0 6,503.2 6,507.3 A-1,30-16A 3/10/2015 6.0 APERF 60 deg phasing,2.78" Millenium DP 7,869.0 7,889.0 6,504.9 6,521.2 A-2,30-16A 3/16/1989 12.0 (PERF 60 deg.phasing;21/8" EnerJet IPERF;7,799.0-7,901.0- - 7,908.0 7,928.0 6,536.7 6,553.1 A-1,30-16A 6/22/1988 8.0 APERF 45 deg.phasing;4 1/2" Ultrapak Csg L., • Cement Squeezes Top(ND) Btm(ND) WHIPSTOCK;7,815.0 Top(ftKB) Btm(ftKB) ((tKB) (ftKB) Des Start Date Corn 7,707.0 7,947.0 6,373.2 6,568.6 4 12"liner 1/10/2015 Cement 4 1/2"liner assembly for upcoming CTD from $r lees4seYe �.� 7947'-7707'.Pumped 5bbls fresh,mud flush 15 bbls. PLUG;7,825.6 4.9 pumped 15 bbls of 15.88 G neat cement,5 bbls fresh, dropped plug displaced with 60 bbls of 12.2#mud. Set packer and hanger assembly @ 4300 psi against I.. i?') cement plug. IPERF;7538.0-7548.0- kit .1 Notes:General&Safety APERF;7,838.0.7,859.0 d 3 J End Dale Annotation v.;/. NOTE IAIIPERF;7,850.0.7,560.0- J APERF;7,867.0-7.8720- >F' a IPERF;7,859.0-7,889.0-- \' \+ Y�`3$' 6 V'' l ti y APERF;7,908.67,9280- `jII LINER;7,687.57,997.3 1 PRODUCTION;1.058.0-8,201.2 1O-16A PRE-RIG WELL WORK DATE SUMMARY 2/21/2015 Late start due to extended safety meeting, construction equipment blocking access and waiting on hardline rig up. RIH w/venturi to 7,710' Work venturi for a while and POOH. Job in progress. 2/22/2015 RIH with a Venturi w/burn-over shoe and make hole. Returned to surface with just a few pieces of rubber, teflon, but a soild 6' of cement. RIH next with a 3.70 mill and used 9.4 PowerPro Mud from CDR2 and worked down to 7,780'from an initial tag of 7,708'. Job in progress. 2/24/2015 RIH w13.75" OD 5 Blade Inseted Mill to clean out cement. Mill from 7,752' CTMD down to 7,842' CTMD (7,862' RKB). Could not get past this depth and bit was giving indications we were milling on something other than cement. POOH to inspect bit and found a large chunk of aluminum stuck in center of the concave bit. Confer with town engineer and decision made to RDMO until procedures can be reviewed. Well is ready for E-Line to perform a Jewerly Log. Diesel from 7,842' to surface. 2/28/2015 LOCATED DB NIPPLE © 7607' SLM, 7636' RKB. DRIFT TBG W/3.45"x 20'1" DUMMY GUN TO 7846' SLM, EST. 7875' RKB. PHASE 3 WX MOVED IN RAPIDLY. R/D EQUIPMENT & SECURED WELL. WAITED OUT STORM @ RIG CDR2. 3/6/2015 (PRE-CTD)TREE VALVE TEST SV,SSV,MV ALL PASSED POSTIVE TESTS. AND DDT TO 0 PSI. TREE SHELL TEST TO 4900 PSI. - PASSED 3/6/2015 PERFORM MULITI FINGER CALIPER SURVEY FROM 7872 TO 7550. PERFORATE FROM 78387859. CCL TO TOP SHOT IS 7.5', CCL STOP AT 7830.5. ATTEMPTED TO PERFORATE THE TOP OF THE A2 SANDS FROM 78687872 BUT WAS UNABLE TO GET THAT DEEP WITH THE SECOND GUN STRING. 3/8/2015 MEASURED BHP © 7865' RKB ( 3892 PSI ), RAN 2.5" BAILER WORKED DOWN TO 7881' RKB OBTAINED SAMPLE, DRIFT TO 7830' RKB WITH 12'X 3.63" DUMMY WHIPSTOCK, JOB COMPLETE. 3/10/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND PERFORATE A2 SANDS FROM 7867'-7872'. WILL BE BACK TO SET WEATHERFORD PACKER TOMORROW. ***IN PROGRESS*** 3/11/2015 CORRELATE TO PERF RECORD DATED 6-MAR-2015 AND SET WEATHERFORD WS-R-BB PACKER MID ELEMENT @ 7829.1'. READY FOR SLICKLINE TO SET WHIPSTOCK TRAY. 3/12/2015 SET WEATHERFORD STARBURST HOLLOW WHIPSTOCK (12.41') (2 RA TAGS 2.2' FROM TOP OF WHIPSTOCK) @ 7815' RKB; RAN 3.5" LIB INDICATED WHIPSTOCK TRAY SET 180 DEGREES. SET BPV. ConocoPhillips Time Log & Summary 4Vellview Web Reporting Report Well Name: 30-16 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/14/2015 12:00:00 PM Rig Release: 4/20/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/12/2015 24 hr Summary Lay down gooseneck and install 2 3/8"rollers, reinstall gooseneck. Swap BOP rams. Swap coil tubing reels, install shim hubs, install reel drive motor, install pack-offs. 12:00 18:00 6.00 0 0 MIRU MOVE CTOP P PJSM-Lay down goose neck, change out rollers, install goose neck. change out gripper blocks, stripper,swap BOP rams. 18:00 22:00 4.00 0 0 MIRU MOVE CTOP P PJSM with Peak, lower reel onto Peak truck, swap reel drive motors out, install new reel, shim hubs, install reel drive and motor. 22:00 00:00 2.00 0 0 MIRU MOVE CTOP P PJSM. Secure coil reel. Install brass and pack-offs, clean-up, 03/13/2015 Stab 2 3/8"coil into injector head. Install new inner reel iron. ND BOP stack, secure wellhead on 30-12. Pull rig modules off well 12, cleanand inspect wellhead/work area. Spot modules over 30-16. Start rigging up CDR. 00:00 02:30 2.50 0 0 MIRU MOVE CTOP P PJSM. P/U stabbing cable, install grapple, pull test. Stab coil in injector, RD stabbing equipment. 02:30 05:00 2.50 0 0 MIRU MOVE CTOP P PJSM. Install new inner reel iron, pre-move checklist. 05:00 10:00 5.00 0 0 MIRU MOVE RURD P Complete RD from 30-12, ND BOP stack,secure stack for move, secure wellhead, load with methanol, check tree flange bolts,two bolts not snug, 40 minutes to complete. 10:00 13:00 3.00 0 0 MIRU MOVE PRLO P Working on pad prep, installing work platform after flow cross swap,work platform will not allow installation of MP valves, MU temp scafolding, install double swabs,double wings off companion, prep site for move. 13:00 18:00 5.00 0 0 MIRU MOVE MOB P Peak on location, PJSM-cold weather ppe, communication. Pull subs off of 30-12, clean and inspect wellhead/work area. Continue working on 30-16 tree configuration. 18:00 22:00 4.00 0 0 MIRU MOVE MOB P PJSM. Spot modules over 30-16. Release Peak crew. 22:00 00:00 2.00 0 0 MIRU MOVE RURD P PJSM. MIRU CDR2, berm cellar, RU PUTZ,steam. 03/14/2015 MIRU CDR2 on 30-16, complete rig up. Rig accept @ 12:00. NU BOP stack. Perform initial BOP test,test PDL's, in progress. 00:00 12:00 12.00 0 0 MIRU MOVE 'RURD P Continue RU operations, inter connect, TT hardline, pre spud checklist check,tree flange bolts, 11 Page 1 of 31 0 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:00 14:15 2.25 0 0 MIRU WHDBO RURD P Accept rig @ 12:00 on 03-14-15. NU BOP equipment, MP line,fill stack and shell test, good test. 14:15 23:00 8.75 0 0 MIRU WHDBO BOPE P Perform initial BOPE test,250/4900 psi,annular 2500 psi. Test witnessed by AOGCC(John Hill) 23:00 00:00 1.00 0 0 MIRU WHDBO RURD P PJSM. Lay down test joints and BOP test equipment, blow down. 33/15/2015 Rehead coil connector, Pull BPV. PT PDL's, inner reel iron,TT line. RIH w/BHA#1 to fish whipstock @ 7,815', got two up licks came free. POOH to check BHA, no fish,disconnect sheared. RIH w/BHA#2, in progress. 00:00 03:15 3.25 0 0 MIRU MOVE CTOP P PJSM. Install coil connector, pull test connector 41 K. MU E-line, meg test, MU blind sub. 03:15 04:45 1.50 0 0 MIRU MOVE MPSP P PJSM. Pull BPV, LD FMC equipment 04:45 08:45 4.00 0 0 MIRU MOVE PRTS T PJSM. Load coil, attempt to P/T TT line,froze up, hose and first stick of hardline at rig thawed, intake hose to TT thawed. 08:45 12:00 3.25 0 0 MIRU MOVE PRTS P PJSM. PT inner reel iron, stripper and TT and surface lines. Initial Tubing 1275 psi, IA 1657 psi, OA 0 psi, bleed TBG to 0 psi IA to 10 psi. 12:00 12:30 0.50 0 0 SLOT WELLPF OWFF T Monitor well 30 minutes,TBG 0 psi, IA 39 psi, OA 0 psi. Fish is set. 12:30 13:00 0.50 0 0 SLOT WELLPF CTOP T PJSM-Install checks, PT CTC and head 4k. 13:00 14:18 1.30 0 77 SLOT WELLPF FISH T PJSM-MU Weatherford fishing BHA #1, M to CoilTrak, Strip over well. 14:18 15:54 1.60 77 7,776 SLOT WELLPF FISH T TIH with fishing BHA#1, EDC open. Tie in to K1, plus 10-ft correction, continue in hole. 15:54 16:54 1.00 7,776 7,776 SLOT WELLPF FISH T 7,776-ft, Close EDC, swap well over to 11.7 ppg formate KWF 16:54 17:09 0.25 7,776 7,797 SLOT WELLPF FISH T Establish parameters 1 bpm at 530 psi, Diff 178, PUW 40k, RIH per Weatherford rep. RIW 14k, IA 180, OA 0.7796-ft, sat down 10k, PU clean,sat down 10k, hit down jar, PU 4k overpull, sat back down 11k, PU 70k, -21k WOB, Bi-Di jar hit and came free, 17:09 18:45 1.60 7,797 73 SLOT WELLPF FISH T TOOH per Weatherford rep, on surface. 18:45 19:15 0.50 73 73 SLOT WELLPF OWFF T PJSM. Flow check 30 minutes, no flow. 19:15 22:30 3.25 73 66 SLOT WELLPF PULD T PJSM. LD BHA#1.Weatherford disconnect sheared, no fish. Discuss with town,decide to run second fishing string. PJSM. MU BHA#2 with 2.5"Hyd. GS. 22:30 00:00 1.50 66 7,600 SLOT WELLPF TRIP T RIH w/BHA#2 to 7,600' Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/16/2015 24 hr Summary Made two unsuccessful runs to fish Weatherford whipstock @ 7,792', no fish. Stand by for new marching orders from town. Decide to make one under reamer run. MU BHA#4, RIH w/under remer assembly to 7,610'. 00:00 01:00 1.00 7,600 7,788 SLOT WELLPF FISH T Continue in hole to fish whipstock, tie-in to K1 for+7'correction, close EDC, PUW=42K. RIH @ min rate, engage fish @ 7,788'. Shut down pump,stack 2K down, straight pull 15K over. Hit five up jar licks @ 15K over, hit four more at 20K over, pull free, set back down 2K, pulled free, PUW=44K. 01:00 02:39 1.65 7,788 66 SLOT WELLPF TRIP T POOH to check BHA, open EDC. On surface. 02:39 03:09 0.50 66 66 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. 03:09 05:09 2.00 66 0 SLOT WELLPF PULD T PJSM. LD BHA#2, no fish, brought back lower section of disconnect and box trap. Does not appear that box trap fully engaged fish, pictures on "S"drive. PT above WS to 250 psi, monitor 30 mins. 05:09 09:45 4.60 0 0 SLOT WELLPF WAIT T Waiting on marching orders from town. 2nd PT above WS at 05:30 to 320 psi, 30 minutes 30 psi, at 07:30- 13 psi, at 09:30-8 psi. maintinence and cleaning on rig, choke B motor, DS counterhead ram. 09:45 10:15 0.50 0 0 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. Note: PJSM-Load out Weatherford equipment 10:15 11:39 1.40 0 57 SLOT WELLPF PULD T PJSM-MU BHA#3, Clean out assembly. 11:39 13:15 1.60 57 7,750 SLOT WELLPF TRIP T TIH with BHA#3, 0°straight motor, 3.80"bald nose crayola mill.Tie in to K1, plus 7-ft correction, close EDC, PUW 40k, continue in hole at min rate. 13:15 14:03 0.80 7,750 7,791 SLOT WELLPF WASH T On line 2.2 bpm, 1708 psi at 7,750-ft, wash down, stall at 7,792.8-ft, pumps off, PUW 40k,wash up/ down 7,760-ft to 7,791-ft while CBU, pump sweep. Note: lateral vibration 3 to 4 during passes after. 14:03 14:36 0.55 7,791 7,700 SLOT WELLPF WASH T PUH and wash up/down 7,700-ft to 7,730-ft per town, open EDC. 14:36 16:00 1.40 7,700 57 SLOT WELLPF TRIP T POOH chasing sweep out of hole. No signifficant cuttings or solids arcoss shaker. 16:00 16:30 0.50 57 57 SLOT WELLPF OWFF T Flow check 30 minutes, no flow. PJSM-laying down BHA 16:30 17:15 0.75 57 0 SLOT WELLPF PULD T LD BHA#3, Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 20:45 3.50 0 0 SLOT WELLPF WAIT T Waiting on under reamer from Prudhoe, Plan forward is to under ream 4 1/2"liner from 7,723-ft to 7,791-ft. 20:45 22:30 1.75 0 70 SLOT WELLPF PULD T PJSM. MU BHA#4, under reamer assembly 22:30 00:00 1.50 70 7,610 SLOT WELLPF TRIP T RIH w/BHA#4 under reamer 03/17/2015 Under ream from 7,724'to 7,791' 00:00 00:45 0.75 7,610 7,724 SLOT WELLPF DLOG T Log K1 for+7.5'correction. Continue in hole. 00:45 02:03 1.30 7,724 7,791 SLOT WELLPF UREM T Start under reaming at 7,724 @ 3 fpm. Pumping at 2 bpm @ 2450 psi, BHP=4025 psi,WOB=0. PUH to 7,724'with same parameters, PUW=40K, no real motor work observed. Open EDC, pump bottoms up. 02:03 03:18 1.25 7,791 71 SLOT WELLPF TRIP T POOH at 50 fpm to 7,600'. Continue OOH @ 100 fpm. 03:18 03:33 0.25 71 71 SLOT WELLPF OWFF T Flow check 03:33 05:51 2.30 71 83 INTRM1 RPEQP1PULD T PJSM. LD BHA#4. PJSM. MU BHA #5 05:51 07:45 1.90 83 7,610 INTRM1 RPEQP1TRIP T RIH w/BHA#5 whipstock assembly, EDC open. 07:45 08:06 0.35 7,610 7,791 INTRM1 RPEQP1 DLOG T Tie in to K1, plus 5-ft correction, PUW 42k,continue in hole pumps off. 08:06 08:15 0.15 7,791 7,775 INTRM1 RPEQP1WPST T 7,790.73-ft, Bit depth, positioned 0° HS, close EDC, released at 3400 psi,set down 5k, TOWS at 7,775-ft. 08:15 10:09 1.90 7,775 83 INTRM1 RPEQP1TRIP T 7,775-ft, TOOH for window milling assembly. 10:09 10:39 0.50 83 83 INTRM1 RPEQP1OWFF T Monitor well for flow. PJSM-lay down BHA. 10:39 11:21 0.70 83 0 INTRM1 RPEQP1 PULD T LD BHA#5 11:21 13:00 1.65 0 0 INTRM1 WHPST PULD P PJSM-Add riser for PD/PUD, open top doors to rig to allow gooseneck room to raise. 13:00 16:45 3.75 0 82 INTRM1 WHPST PULD P PJSM-MU BHA#6 window milling assembly, 1°AKO motor with string mill and 3.79"string mill and 3.80" DSM, unable to raise injector head high enough to MU to BHA, height of tree a lesson learned, drop 1-ft out of riser assembly. MU to CoilTrak, surface test, P/T riser 1500 psi. 16:45 18:21 1.60 82 7,620 INTRM1 WHPST TRIP P TIH with window milling BHA#6 EDC open. 18:21 18:36 0.25 7,620 7,620 INTRM1 WHPST DLOG P 7620ft,tie into the K1 marker correction of plus 4.5ft. PUW 42.5k 18:36 18:51 0.25 7,620 7,760 INTRM1 WHPST TRIP P 7620ft, continue RIH, RIW 14.3k 18:51 19:36 0.75 7,760 7,760 INTRM1 WHPST DISP P 7760ft, Swap well to 9.8ppg drilling mud. Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:36 19:51 0.25 7,760 7,775 INTRMI WHPST WPST P 7775ft, Dry tag TOWS, bring up pump 2.5bpm at 2300psi. IA 650, OA 0 19:51 00:00 4.15 7,775 7,779 INTRM1 WHPST WPST P Mill window as per recommended practice and Baker rep. 03/18/2015 Mill 3.80"Window 7775ft 00:00 04:30 4.50 7,779 7,787 INTRM1 WHPST WPST P Continue milling window as per Baker rep, ROP 1fph, 2.5bpm, 2500psi, 3.25k WOB ****Note: Bled down IA from 700psi to 150psi 04:30 10:35 6.09 7,787 7,787 INTRMI WHPST WPST P 7,786.6-ft Decrease in WOB,exited 4 1/2"liner, milling window as per schedule and Baker rep, ROP-.6 fph,2.5 bpm, 2500 psi, 3.90k WOB 10:35 12:05 1.50 7,787 7,788 INTRM1 WHPST WPST P Milling window as per Baker rep, ROP 1 fph,2.5 bpm, 2350 psi, 3.90k WOB 12:05 14:35 2.50 7,788 7,791 INTRM1 WHPST WPST P 7,788.2-ft, Decrease in WOB to.5k, milling as per schedule and Baker rep. 1 fph, 2.5 bpm at 2300 psi, some cement across shaker 14:35 16:59 2.41 7,791 7,795 INTRM1 WHPST WPST P 7,791-ft, Milling 2.5 bpm at 2350 psi, .5 WOB,WH 17, BHP 3596, EDC 10.9 ppg, call form town,work up to 11.7 EMW at window,2.5 bpm at 2,580 psi, BHP 3,880 psi, EDC 11.7 ppg,WHP 280 psi, ROP 1.7. 16:59 17:59 1.00 7,795 7,800 INTRM1 WHPST WPST P 7,795-ft, Milling rathole 2.5 bpm at 2,580 psi, BHP 3,855 psi,WHP 280, 11.7 ECD 17:59 20:44 2.75 7,800 7,800 INTRM1 WHPST REAM P 7800ft, TD rat hole, Back ream window area as per plan, 7770ft- 7798ft, highside, 30L, and 30R. 60fph, dry drift window area at 15 fph clean,tag TD at 7800ft. 20:44 22:29 1.75 7,800 82 INTRM1 WHPST TRIP P POOH,with Open EDC, pumping 3.0bpm at 2400psi. 22:29 22:59 0.50 82 82 INTRM1 WHPST SFTY P PJSM for undeploying BHA#6 22:59 23:59 1.00 82 82 INTRM1 WHPST PULD P Undeploy milling BHA 03/19/2015 RIH, drilled build section from 7800'to 8090'. POOH, undeployed build BHA, MU and deploy lateral drilling BHA, RIH,drill lateral. 00:00 02:00 2.00 82 0 INTRM1 WHPST PULD P Continue Undeploying milling BHA, ****Note:While undeploying found that we had to break the connection above the QTS breaking an o-ring connection that couldn't be tested when deploying build BHA, after discussing this rig team, recommendation from BHI was to remove wear sub from above the P&C to allow, proper break of QTS when deploying the next BHA's. Page 5 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:30 1.50 0 0 INTRM1 DRILL PULD P Swap tool around in pipeshed, remove wear sub from BHA, retest tools, ""Note: Mills gauged 3.790D no-go 03:30 04:00 0.50 0 0 INTRM1 DRILL PULD P M/U build BHA 04:00 04:15 0.25 0 0 INTRM1 DRILL PULD P PU, MU, QTS and retest riser connection to 4900psi. 04:15 06:30 2.25 0 82 INTRM1 DRILL PULD P Deploy BHA#7 build assembly,2.0° AKO motor and 3.75"X 4.25"HCC Bi-center bit, MU to CoilTrak, surface test. 06:30 07:54 1.40 82 7,600 INTRM1 DRILL TRIP P TIH with BHA#7, EDC open 07:54 08:12 0.30 7,600 7,800 INTRM1 DRILL DLOG P Tie in to K1, plus 5-ft correction, close EDC, PUW 37k. Continue in hole. 08:12 12:12 4.00 7,800 7,953 INTRM1 DRILL DRLG P 7,800-ft, OBD 2.52 bpm at 2,949 psi, BHP 3914,WHP 300, IA 300, OA 0,stall at 7,861-ft(6th), 10k overpull, BOBD 2.70 bpm at 3456, BHP 3,947 psi,WHP 243, IA 391, OA 0 12:12 12:33 0.35 7,953 7,600 INTRM1 DRILL WPRT P 7,953-ft, PUH for logging RA markers, PUW 40k, 12:33 13:15 0.70 7,600 7,953 INTRM1 DRILL DLOG P 7,600-ft, Tie in to K1, no correction, Log RA markers on both whipstocks, Top RA marker 7,787.5-ft, Btm RA marker(Weatherford WS)7,796-ft, BOW 7,790-ft. 13:15 15:45 2.50 7,953 8,090 INTRM1 DRILL DRLG P 7,953-ft, BOBD 2.70 bpm at 3,221 psi, BHP 3,990 psi,WHP 259, IA 376, OA 0, pump sweeps, 15:45 18:00 2.25 8,090 82 INTRM1 DRILL TRIP P 8,090-ft, TD build section land in projected Al pay, TOOH chasing sweeps to swab. 18:00 18:30 0.50 82 82 INTRM1 DRILL SFTY P PJSM for LD build section BHA#7 18:30 19:45 1.25 82 0 INTRM1 DRILL PULD P Undeploy build BHA 19:45 20:45 1.00 0 0 INTRM1 DRILL PULD P Reconfigure MWD tools in pipeshed, installing USMR below DGS. 20:45 22:15 1.50 0 82 INTRM1 DRILL PULD P Deploy BHA#8 22:15 23:51 1.60 82 7,615 INTRM1 DRILL TRIP P RIH with BHA#8,0.9 AKO motor with rebuilt 4.250D bi-center bit. 23:51 00:00 0.15 7,615 7,637 INTRM1 DRILL DLOG P 7615ft,tie into the K1 marker correction of plus 6ft, PUW 41k 03/20/2015 Drilled from 8090ft to 8737ft. 00:00 00:15 0.25 7,637 8,090 INTRM1 DRILL TRIP P Continue RIH thorugh window, clean. 00:15 02:33 2.30 8,090 8,290 INTRM1 DRILL DRLG P 8090ft, BOBD 2.8bpm at 3100psi, BHP 3949,WHP 235, IA 348, OA 0 02:33 03:00 0.45 8,290 7,836 INTRM1 DRILL WPRT P 8290ft,wiper up hole. PUW 38.5k 03:00 03:15 0.25 7,836 8,290 INTRM1 DRILL WPRT P 7,836-ft, Wiper back in hole. Page 6of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 03:33 0.30 8,290 8,358 INTRM1 DRILL DRLG P 8,290-ft, OBD 2.6bpm at 3010psi, BHP 3981,WHP 235, IA 328, OA 0, ROP 215 fpm, pushing on it for turn right, not working. 03:33 07:06 3.55 8,358 82 INTRM1 DRILL TRIP P 8,358-ft, PUH,discuss with town. TOOH for higher AKO motor. 07:06 08:33 1.45 82 0 INTRM1 DRILL PULD P PJSM-Un-deploy BHA#8, bit 1-1, looks good. 08:33 09:33 1.00 0 0 INTRM1 DRILL PULD P Adjust motor to 1.5°AKO. 09:33 11:09 1.60 0 82 INTRM1 DRILL PULD P PJSM-MU BHA#9, 1.5°AKO Motor and HYC 3 3/4"x 4.25"Bi-center bit, deploy, MU to CoilTrak, surface test. 11:09 12:30 1.35 82 7,610 INTRM1 DRILL TRIP P TIH with BHA#9 EDC open. 12:30 12:45 0.25 7,610 7,640 INTRM1 DRILL DLOG P Log K1, plus 5-ft correction, close EDC, PUW 39k. 12:45 13:15 0.50 7,640 8,358 INTRM1 DRILL TRIP P Continue in hole, clean thru window, 11.8k RIW. 13:15 14:54 1.65 8,358 8,560 INTRM1 DRILL DRLG P 8,358-ft, OBD 2.77 bpm at 3,124 psi, BHP 4,001 psi,WHP 268, IA 472, OA 0, averageing 11 degree DLS, last survey 14°DLS. 14:54 15:24 0.50 8,560 7,850 INTRM1 DRILL WPRT P 8,560-ft,Wiper up hole. PUW 42k 15:24 15:48 0.40 7,850 8,560 INTRM1 DRILL WPRT P 7,850-ft, Wiper back in hole, RIW 11k 15:48 17:48 2.00 8,560 8,684 INTRMI DRILL DRLG P 8,560-ft, OBD 2.77 bpm at 3,354 psi, BHP 3,987 psi,WHP 224, IA 777, OA 0,WOB 1.8k, ROP 90 from 8,486-ft Note: bleed down IA to 50 psi 17:48 18:03 0.25 8,684 8,684 INTRM1 DRILL WPRT P 8684ft, BHA wiper up to 8590ft, PUW 44k Looks like we transitioned into a different formation,WOB 2.7k, ROP 20 fph 18:03 21:03 3.00 8,684 8,717 INTRM1 DRILL DRLG P 8684ft, BOBD 2.79 bpm at 3354psi, BHP 4064,WHP 300, IA 406, OA 0 21:03 21:18 0.25 8,717 8,717 INTRM1 DRILL WPRT P 8717ft, BHA wiper up to 8600ft, PUW 42k 21:18 00:00 2.70 8,717 8,737 INTRM1 DRILL DRLG P 8717ft, BOBD 2.77 bpm at 3244psi, BHP 4079,WHP 325, IA 375, OA 0 03/21/2015 Drilled lateral from 8737ft to TD 8920ft. Performed a swab wiper, RBIH to confirm TD 8922ft, Lay in 11.75ppg liner pill without beads up to the window, and displace well to 11.85ppg to surface, check well for flow, LD drilling BHA, Function test BOPE. 00:00 02:45 2.75 8,737 8,760 INTRM1 DRILL DRLG P 8737ft, OBD 2.77 bpm at 3365psi, BHP 4050 psi,WHP 292, IA 409, OA 0 02:45 03:45 1.00 8,760 8,760 INTRM1 DRILL WPRT P 8760ft, Scheduled wiper up hole to 8200ft, PUW 42k ""Note: Pumping drilling rate 2.6bpm, set down at 8630ft, PU, lowered pump rate to 0.75 bpm, pass through without issue. Page 7 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 08:51 5.10 8,760 8,850 INTRM1 DRILL DRLG P 8760ft, BOBD 2.76 bpm at 3250 psi, BHP 3998,WHP 277, IA 408, OA 0, WOB 3k, ROP 11fph Looks like we transitioned into a different formation,WOB 1.4k, ROP 20 fph 08:51 09:45 0.90 8,850 8,850 INTRM1 DRILL WPRT P 8,850-ft, Geo wiper to discuss TD in town. 09:45 12:21 2.60 8,850 8,920 INTRMI DRILL DRLG P 8,850-ft, OBD 2.78 bpm at 3,315 psi, BHP 4,047 psi,WHP 302, IA 490, OA 0,WOB 1.6k, ROP 16. Note: Final ROP 55 fpm,WOB 1.6k. 13 degree DLS on last 70-ft drilled. 12:21 13:21 1.00 8,920 7,820 INTRM1 DRILL WPRT P 8,920-ft, TD called, PUW 41k, Chase sweeps to swabs, 5k overpull at 8,690-ft, 10k ovrepull at 8,650-ft, reduce pump rate to pull thru, call town. 13:21 14:03 0.70 7,820 8,800 INTRM1 DRILL WPRT P 7,820-ft, Wiper back in hole, PUH at 8,580-ft, choke plugging, BU from 8,650-ft, dime size clay balls, heavy shales across shaker, RBIH, reduce rate.5 bpm at 8,630-ft, RIW 9.0k to 8,760-ft with no problem. 14:03 16:30 2.45 8,800 82 INTRM1 DRILL WPRT P 8,800-ft, PUW 42k, TOOH 1.4 bpm at 1,774 psi, max overpull of 2k from 8,760-ft to 8,630-ft,TOOH, EDC open at 7,720-ft,Jog at 200-ft. 16:30 18:00 1.50 82 7,620 INTRM1 DRILL TRIP P At surface, reset depth, RBIH with BHA#9 18:00 18:15 0.25 7,620 7,620 INTRM1 DRILL DLOG P 7620ft-7645ft,Tie into K1 correction plus 4.0ft 18:15 18:45 0.50 7,620 7,650 INTRMI DRILL TRIP P Pressure Survey at window. PUW 40k 1.)0.25 bpm/WHP 425/CHP 340/ANN 3910/ECD 11.93 2.)0.5 bpm/WHP 400/CHP 320/ANN 3911/ECD 11.93 3.) 1.0 bpm/WHP 355/CHP 280/ANN 3911/ECD 11.93 4.)2.0 bpm/WHP 290/CHP 200/ANN 3911/ECD 11.93 Stactic BHP 3865 psi, 11.79 ppg ECD 18:45 20:00 1.25 7,650 8,922 INTRM1 DRILL TRIP P Close EDC, and continue through window to confirm TD. 20:00 20:45 0.75 8,922 7,682 INTRM1 DRILL TRIP P Confirm TD 8922ft, POOH, laying in 11.75 ppg liner running pill without beads up to the window, *'**Note: Paint EOP flags at 7600ft and 6400ft. Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 22:15 1.50 7,682 82 INTRM1 DRILL TRIP P POOH,with drilling BHA displacing well to 11.8 ppg complition fluid without beads. 22:15 22:45 0.50 82 82 INTRM1 DRILL SFTY P At surface, PJSM for LD drilling BHA#9, check well for flow. ****Note: Lost 10 bbls of Nabr to formation during displacement. 22:45 23:30 0.75 82 0 INTRM1 DRILL PULD P LD Drilling BHA 23:30 00:00 0.50 0 0 INTRM1 DRILL CTOP P PU test joint and function test BOPE. 03/22/2015 MU the B lateral 3.5"completion with composite shoe track. POOH and LD liner. MU and RIH with CO BHA. 00:00 00:30 0.50 0 0 INTRM1 CASING SFTY P PJSM, for MU B Lateral completion assembly with compostite shoe. 00:30 03:45 3.25 1,186 1,186 INTRM1 CASING PUTB P MU B lateral completion with 37jts of solid Hyd.511, 9.2#, L-80 with 7 cementrilizers, and shorty deployment sleeve. 03:45 05:00 1.25 1,186 1,230 INTRM1 CASING RUNL P MU BHI and BOT setting tools with GS. 05:00 07:27 2.45 1,230 8,222 INTRM1 CASING RUNL P RIH with 3.5"liner completion with BOT GS. Plus 0.5-ft correction at flag. PUW 45.5k. Continue in hole, RIW 12k. 07:27 08:21 0.90 8,222 7,927 INTRM1 CASING RUNL T 8,222-ft, Sat down 12k,work pipe 4 times,confer with town, pump 1 bpm in tension, PU to 67k to free liner, PUH slowly while discussing with town. 08:21 08:33 0.20 7,927 8,220 INTRM1 CASING RUNL T 7927-ft, RBIH pumping 1 bpm, slow down to 15 fph, start seeing weight swing at 8,145-ft, sat down 5k at 8,220-ft, not moving down,shut down pump, PUW 52k. 08:33 09:12 0.65 8,220 8,000 INTRM1 CASING RUNL T 8,220-ft, PUH slowly while discussing options with town. 09:12 11:30 2.30 8,000 1,230 INTRMI CASING RUNL T 8,000-ft, POOH for clean out assembly, pumping over the top. 11:30 12:00 0.50 1,230 1,230 INTRM1 CASING OWFF T Flow check. PJSM-laying down BHA. 12:00 12:45 0.75 1,230 1,183 INTRM1 CASING PULD T LD BHA#10 12:45 13:30 0.75 1,183 1,183 INTRMI CASING PUTB T PJSM-prep floors for laying down liner. 13:30 16:30 3.00 1,183 0 INTRM1 CASING PUTB T PJSM- LD B lateral completion with composite cement retainer, 37 jts of solid Hyd511, 9.2#, L-80 with 7 cementrilizers and deployment sleeve. Clean floors. 16:30 18:30 2.00 0 79 INTRM1 CASING PULD T PJSM-MU BHA#11, 1°AKO motor and 3.80"D331 mill(no back cutters) 18:30 20:00 1.50 79 7,620 INTRM1 CASING TRIP T RIH with clean out BHA#11. 20:00 20:15 0.25 0 7,600 INTRM1 CASING DLOG T 7620ft, Tie into the K1 marker correction of plus 5.0ft. 20:15 22:30 2.25 7,600 7,750 INTRM1 CASING DISP T 7750ft,displace well to 9.8ppg drilling fluid. Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 23:15 0.75 8,625 7,912 INTRM1 CASING WPRT T PUH to 7912ft 23:15 00:00 0.75 7,750 8,625 INTRM1 CASING TRIP T RIH,through window down to 8625ft, Pump 5x5 sweep,and chase up hole above window. 03/23/2015 RIH with clean out BHA#11. Set down at 8631'. Perform swab wiper trip. Set anchored aluminum billet at 8250'. _ 00:00 00:15 0.25 7,912 7,730 INTRM1 CASING WPRT T 7912ft, Continue PUH to 7730ft 00:15 00:39 0.40 7,730 8,636 INTRM1 CASING TRIP T 7730ft, RBIH to bottom sat down at 8631', PU heavy,try again and worked pipe down to 8636'. 00:39 01:57 1.30 8,636 7,700 INTRM1 CASING TRIP T PU, pump sweep and wiper to 7700'. 01:57 02:51 0.90 7,700 8,620 INTRM1 CASING TRIP T RBIH to 8620', pump 10 x 10 sweep. 02:51 05:12 2.35 8,620 79 INTRM1 CASING TRIP T Perform swab wiper. 05:12 08:12 3.00 79 8,480 INTRM1 CASING TRIP T At surface, reset counters, RBIH,tie in to K1 with plus 4.5-ft correction, continue in hole, clean thru window, no problem thru build or lateral section 08:12 10:42 2.50 8,480 79 INTRM1 CASING TRIP T 8,480-ft, Chase sweeps to surface, shale across shaker 10:42 13:00 2.30 79 0 INTRM1 CASING PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#11, blow down BHI tools, Bit 3.78"no-go(in 3.79"no-go) 13:00 14:54 1.90 0 78 INTRM1 STK PULD T PJSM-MU BHA#12, 3 5/8"OD OH anchored billet, deploy, make up to ColiTrak, surface test. 14:54 16:21 1.45 78 7,610 INTRM1 STK TRIP T TIH with BHA#12, EDC open pumping minimum rate. 16:21 16:33 0.20 7,610 7,630 INTRM1 STK DLOG T Tie in to K1, plus 5-ft correction, off on pump, PUW 41k. 16:33 17:03 0.50 7,630 8,262 INTRM1 STK TRIP T Continue in hole pumps off, close EDC at window, slacked off 2k at 7,790-ft, PU, reorientate slips 40 LOHS, RBIH through winndow with slight bobble, continue in hole. 17:03 17:15 0.20 8,262 8,250 INTRM1 STK WPST T 8,262.42-ft, Bit depth, PU neutral, release off Billet at 4,500 psi,set down 5k, OH anchored billet set with _ top at 8,250-ft. 17:15 19:00 1.75 8,250 78 INTRM1 STK TRIP T TOOH with billet setting BHA for drilling BHA. 19:00 20:42 1.70 78 0 INTRM1 STK PULD T PJSM-Undeploy, replace failed o-ring on PDL, LD BHA#12 Open hole anchored billet. 20:42 21:42 1.00 0 0 INTRM1 STK PULD T Reconfigure MWD tools in pipeshed, installed DGS below USMR. 21:42 23:06 1.40 0 0 INTRM1 STK PULD T PJSM-MU BHA#13, 0.9°AKO Motor and HCC 3 3/4"x 4.25" Bi-center bit and pressure deploy. Surface test. 23:06 00:00 0.90 0 4,290 INTRM1 STK TRIP T RIH with BHA#13. Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 33/24/2015 24 hr Summary RIH with drilling BHA#13 to sidetrack off anchored billet. Swap well to new 9.8 ppg mud.Tried to time milled off billet, but had several stalls. Displaced well to 11.8 ppg completion fluid and POOH for second anchored billet. RIH with BHA#14 and set second billet at 8183'. 00:00 00:36 0.60 4,290 7,600 INTRM1 STK TRIP T RIH with BHA#13. 00:36 01:24 0.80 7,600 7,600 INTRM1 STK DLOG T Tie in to K1, plus 4-ft correction, close EDC, PUW 37k. Continue in hole. 01:24 01:42 0.30 8,250 8,250 INTRM1 STK KOST T Tag up on anchored aluminum billet and start time drilling High Side, stalled PU, restart 01:42 02:42 1.00 8,250 8,255 INTRM1 STK KOST T 8250ft,time milling again,2.7 bpm at 3046psi, BHP 3984,WHP 204, IA 6, OA 0, Stall morning 8253ft 02:42 03:27 0.75 8,255 8,263 INTRM1 STK KOST T 8255ft, Push on it and stall at 8263ft. 03:27 03:42 0.25 8,263 8,263 INTRM1 STK KOST T 8263ft, PUW clean 40k 03:42 07:57 4.25 8,263 8,263 INTRM1 STK KOST T Work pipe down to 8256ft,stalled motor 7 times trying to get back to bottom. Try and RIH dry set down at 8257', PUH, bring up pump RBIH stalled again at 8256ft.PUH and restart pump, stall again at 8256.81'. PUW 44k, minus 4k BHIWOB 07:57 08:27 0.50 8,263 8,263 INTRM1 STK TRIP T 8256ft, PUH, prepair for mud swap, call town about plan forward. 08:27 09:12 0.75 8,263 8,263 INTRM1 STK DISP T 8250ft, swap hole over to new 9.8ppg drilling fluid. 09:12 09:57 0.75 8,263 8,263 INTRM1 STK DISP T RBIH to displace well to 11.8+ppg completion fluid from 8245ft. 09:57 10:57 1.00 8,263 82 INTRM1 STK TRIP T POOH,displacing well with 11.8+ ppg completion fluid. 10:57 12:42 1.75 82 82 INTRM1 STK SFTY T At surface,check well for flow, PJSM for LD tools. 12:42 13:42 1.00 82 0 INTRM1 STK PULD T LD tools 13:42 14:57 1.25 0 0 INTRM1 STK PULD T Reconfigure BHI tools in pipeshed. 14:57 15:27 0.50 0 0 INTRM1 STK SFTY T PJSM, for MU billet setting tools. 15:27 17:27 2.00 0 141 INTRM1 STK PULD T MU 3-5/8"Open Hole Anchored Billet with 2 joints of 2-7/8"ST-L. 17:27 19:21 1.90 141 7,594 INTRM1 STK TRIP T Trip in hole with BHA#14. 19:21 19:36 0.25 7,594 7,594 INTRM1 STK DLOG T Tie in at K1 marker at 7594'with a +4.5'correction. Close EDC. PU wt 41K. 19:36 20:21 0.75 7,564 8,258 INTRM1 STK TRIP T RIH at 20 fpm orientated HS sat down at 7857',try 40 L,try HS at 30 fpm,try 30 R and 40L at 30 fpm. Call town and discuss.Tried 20L at 15 fpm then 30R made it through the window. 20:21 20:51 0.50 8,258 8,258 INTRM1 STK WPST T Wt check 42K. Tag up on first aluminum billet at 8260'and picked up to nuetral wt 3 times.All three set downs at 8260'and nuetral wt 8258'. Pumped up to 3800 psi and sheared off billet.Set down on billet with 5K. Page 11 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:51 22:21 1.50 8,183 134 INTRM1 STK TRIP T POOH with BHA#14. 22:21 23:33 1.20 0 0 INTRM1 STK PULD T PJSM-LD BHA#14 Open hole anchored billet. No flow test. 23:33 00:00 0.45 0 82 INTRM1 STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 03/25/2015 Drilled off billet at 8186'and drilled to 9076'. 00:00 01:15 1.25 82 82 INTRM1 STK PULD T PJSM-MU BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 01:15 04:45 3.50 82 8,186 INTRM1 STK TRIP T RIH with drilling BHA#15 to sidetrack off anchored aluminum billet. Swap well back to drilling mud. Dry tag the billet at 8186'. 04:45 06:15 1.50 8,186 8,200 INTRM1 STK KOST T Start time drilling on billet. 06:15 08:45 2.50 8,200 8,310 INTRM1 DRILL DRLG T Drill ahead at 30 fph,with 1K WOB, 2.75bpm at 2845psi, BHP 3982, WHP 282, IA 8, OA 0 08:45 09:00 0.25 8,310 8,310 INTRM1 DRILL WPRT T 8310ft,Wiper up hole to 8156ft, PUW 40k, Dry drift billet area clean. RBIH to drill ahead. 09:00 10:00 1.00 8,310 8,410 INTRM1 DRILL DRLG T 8310ft, BOBD 2.7 bpm at 2850psi, BHP 4044,WHP 301, IA 16, OA 0 10:00 10:45 0.75 8,410 8,410 INTRM1 DRILL WPRT T 8410ft,Wiper up hole to 7850ft, PUW 40k 10:45 12:45 2.00 8,410 8,600 INTRM1 DRILL DRLG T 8410ft, BOBD 2.75 bpm at 2850psi, BHP 4050,WHP 290, IA 26, OA 0 12:45 13:00 0.25 8,600 8,600 INTRM1 DRILL WPRT T 8600ft,wiper up hole to 8300ft, PUW 41k 13:00 13:30 0.50 8,600 8,666 INTRM1 DRILL DRLG T 8600ft, BOBD 2.79bpm at 3000psi, BHP 4024,WHP 254, IA 195, OA 0 13:30 14:30 1.00 8,666 8,666 INTRM1 DRILL WPRT T 8666ft,Wiper up hole to 7870ft, PUW 38k 14:30 16:30 2.00 8,666 8,804 INTRM1 DRILL DRLG T 8666ft, BOBD 2.8 bpm at 3000 psi, BHP 4019,WHP 273, IA 183, OA 0 16:30 16:39 0.15 8,804 8,804 INTRM1 DRILL WPRT T 200' BHA wiper, PUW 42K 16:39 17:09 0.50 8,804 8,825 INTRM1 DRILL DRLG T 8804 ft, BOBD 2.8 bpm at 3062 psi, BHP 4019,WHP 275, IA 239, OA 0 17:09 17:21 0.20 8,825 8,825 INTRM1 DRILL WPRT T 200' BHA wiper, PUW 41K 17:21 18:06 0.75 8,825 8,894 INTRM1 DRILL DRLG T 8825ft, BOBD 2.75 bpm at 3113 psi, BHP 4019,WHP 270, IA 392, OA 0 18:06 20:24 2.30 8,894 8,894 INTRM1 DRILL DLOG T Log tie-in wiper trip. Plus 7' correction. 20:24 21:09 0.75 8,894 8,922 INTRM1 DRILL DRLG T 8894 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398, OA 0 21:09 00:00 2.85 8,922 9,029 INTRM1 DRILL DRLG P 8922 ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 264, IA 398, OA 0 03/26/2015 Drilled lateral from 9029' to 9191'. POOH, changed out the motor and cleaned off the ballled up bit. 00:00 00:06 0.10 9,029 9,037 INTRM1 DRILL DRLG P 9029ft, BOBD 2.77 bpm at 3245 psi, BHP 4000,WHP 274, IA 398, OA 0 00:06 01:24 1.30 9,037 9,037 INTRM1 DRILL WPRT P 9037 ft,Wiper up hole to 8260 ft, PUW 44k Page 12 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:24 04:39 3.25 9,037 9,088 INTRMI DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 04:39 05:54 1.25 9,088 7,860 INTRM1 DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 05:54 06:54 1.00 7,860 9,088 INTRM1 DRILL WPRT P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 06:54 11:24 4.50 9,088 9,137 INTRMI DRILL DRLG P 9037 ft, BOBD 2.78 bpm at 3245 psi, BHP 4000,WHP 276, IA 401, OA 0 11:24 12:18 0.90 9,137 9,137 INTRM1 DRILL WPRT P 9137ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 12:18 18:36 6.30 9,137 9,178 INTRM1 DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 18:36 19:06 0.50 9,178 9,178 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbls pill of Drill Zone. 19:06 20:12 1.10 9,178 9,186 INTRM1 DRILL DRLG P 9137 ft, BOBD 2.80 bpm at 3245 psi, BHP 4000,WHP 276, IA 450, OA 0 20:12 20:36 0.40 9,186 9,186 INTRM1 DRILL WPRT P 9181 ft, BHA wiper, pumping 10 bbls pill of Drill Zone mixed with beads. 20:36 22:36 2.00 9,186 9,191 INTRM1 DRILL DRLG P 9186 ft, BOBD 2.80 bpm at 3250 psi. 22:36 00:00 1.40 9,191 9,191 INTRM1 DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 03/27/2015 LD drilling BHA#16, MU 37 jts liner and RIH and set it at 8900'. 00:00 00:12 0.20 9,191 82 INTRM1 DRILL TRIP P POOH with BHA#15 to check bit. PU wt 38K. 00:12 01:54 1.70 82 0 INTRM1 DRILL PULD P PJSM-LD BHA#15, 1.1°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. 01:54 03:00 1.10 0 82 INTRMI DRILL PULD P PJSM-MU BHA#16, 1.0°+AKO Motor and HYC 3 3/4"x 4.25" Bi-center bit. Surface test. 03:00 05:30 2.50 82 7,600 INTRMI DRILL TRIP P RIH with BHA#16. 05:30 05:45 0.25 7,600 7,600 INTRMI DRILL DLOG P 7600ft,Tie into the K1 marker correction of plus 14ft. 05:45 06:15 0.50 7,600 9,164 INTRM1 DRILL TRIP P Continue RIH to bottom 06:15 06:30 0.25 9,164 9,164 INTRM1 DRILL TRIP P 9164ft, Stack out, PUW 55k 06:30 07:00 0.50 9,164 9,089 INTRM1 DRILL TRIP P 9164ft, PUH, make call to town on plan forward, 07:00 09:30 2.50 9,089 82 INTRM1 DRILL TRIP P 9098ft, pump 10x10 sweep and perform swab wiper. 09:30 11:00 1.50 82 7,600 INTRM1 DRILL TRIP P At surface, reset counters, RBIH 11:00 11:15 0.25 7,600 7,600 INTRM1 DRILL DLOG P 7600ft, Tie into the K1 marker correction of plus 5.5ft. 11:15 12:36 1.35 7,600 9,120 INTRM1 DRILL TRIP P 7600ft, continue RIH `*""Note: Set down at the bottom of the window 8k, PUH, Run back through window at 18 fpm clean, continue RIH. 12:36 14:36 2.00 9,120 85 INTRM1 DRILL DISP P 9120ft, Lay in liner running pill with bead up to the window. Displacing well to 12.0 ppg completion fliud without beads to surface, Painting EOP flags at 6500ft,and 7600ft. Page 13 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:36 15:06 0.50 85 85 INTRM1 DRILL SFTY P At surface, check well for flow, PJSM for LD drilling BHA 15:06 16:06 1.00 85 0 INTRM1 DRILL PULD P LD drilling BHA#16 16:06 16:36 0.50 0 0 INTRMI CASING SFTY P PJSM for MU liner assembly 16:36 18:36 2.00 0 1,173 INTRM1 CASING PULD P MU 37 jts of 3-1/2"solid liner with a composite cement retainer/ shoetrack and aluminum bullnose. The top 3 jts have cementralizers installed. 18:36 20:06 1.50 1,173 1,221 INTRM1 CASING PULD P PJSM and MU BHA. Surface test. 20:06 21:48 1.70 1,221 6,500 INTRM1 CASING RUNL P RIH with BHA#17 21:48 22:00 0.20 6,500 6,500 INTRM1 CASING RUNL P 6500' EOP flag, zero correction. Up wt 46K. 22:00 00:00 2.00 8,494 8,560 INTRM1 CASING RUNL P Tag up at 8494 and start working pipe in hole at various speed, pumps on and off. 03/28/2015 Finish running liner in to hole. Perform a full BOPE test. 00:00 02:36 2.60 8,560 8,900 INTRM1 CASING RUNL P Working pipe in hole at various speed, pumps on and off from 8560' to 8900'. PU to neutral wt and pressure up to 3000 psi to release liner. 02:36 04:06 1.50 8,900 48 INTRM1 CASING RUNL P Pooh with liner setting BHA#17. 04:06 04:36 0.50 48 48 INTRM1 CASING PULD P At surface,check well for flow. 04:36 05:36 1.00 48 0 INTRM1 CASING PULD P LD liner setting BHA#17. 05:36 06:51 1.25 0 0 INTRM1 CASING PULD P MU nozzle and jet BOPE. 06:51 07:21 0.50 0 0 INTRM1 CASING PULD P Unstab INJH, RD nozzle and BHI checks. 07:21 09:36 2.25 0 0 INTRM1 CASING PULD P Flush surface lines, Grease BOP's and service tree. 09:36 21:36 12.00 0 0 INTRM1 WHDBO BOPE P BOPE test.Test waived by Matthew Herrera 9:25pm 3/26/15 21:36 22:36 1.00 0 0 INTRM1 CEMEN-CTOP P RD BOPE testing equipment, 22:36 00:00 1.40 0 INTRM1 CEMEN-PULD P Cut CTC off and boot end of a-line. 03/29/2015 M/U Cement BHA with stinger and RIH, Displace well to 8.6PPG fluid, Sting into retainer. Pump 10 BBIs 15.8PPG cement. Pump 8 BBIs then unsting from retainer, Pump remainder of cement. POOH filling coil voidage 00:00 00:18 0.30 0 0 INTRM1 CEMEN-PULD P PJSM about pumping slack forward. 00:18 02:33 2.25 0 0 INTRM1 CEMEN-PULD P Pumping slack forward. Cut 90'off. 02:33 03:33 1.00 0 0 INTRM1 CEMEN-PULD P Change of plan. Pump slack back into reel. Cut coil to find e-line. Rehead and pump slack forward. 03:33 06:33 3.00 0 0 INTRM1 CEMEN-PULD P PJSM, Install CTC, pull test to 35k, install UQC, PT 4300psi, 06:33 08:33 2.00 0 0 INTRM1 CEMEN-PULD P MU nozzle, stab on INJH and displace coil to 12.0 ppg NaBr. 08:33 10:03 1.50 0 11 INTRM1 CEMEN-PULD P MU cementing BHA#18, pump one coil volume forward Page 14of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:03 12:33 2.50 11 7,600 INTRM1 CEMEINI TRIP P RIH,with cementing BHA# 18 with Fixed bladed Centralizer,weight bar, and snap-latch cementing stinger, 100 fpm circulating 0.3 bpm. 12:33 14:33 2.00 7,600 8,840 INTRM1 CEMEN-TRIP P 7600ft,weight check 38k, slow down at the top of liner, 15 fpm, continue RIH to 8840ft 50'above CMT retainer. '""Note: Started stacking weight at 8823ft, stop coil, looks like we are in the high dog area of the hole, push on it,got weight back, continued in hole to 8400ft. 14:33 18:03 3.50 8,840 8,887 INTRM1 CEMEN'DISP P Displace liner to 9.8 ppg while POOH at 30 fpm, park at 7600ft and displace with 9.8". RBIH to 8886.57ft sting into the retainer, seen an pressure increase of 200 lbs. Set down 5k 8886.57ft.bring pump up to 1.0 bpm at 1259 psi, IA 0, OA 0 18:03 18:57 0.90 8,887 8,887 INTRM1 CEMEN-DISP P Crew change, run valave checklist, check SLB R/U to rig, PJSM with SLB cementers, Batch up cement @ weight 15.8 @ 18:55 18:57 19:27 0.50 8,887 8,887 INTRM1 CEMEN-DISP P Line up on pill pit and pump 4.3 BBIs 8.6 PPG mud to MM 19:27 19:51 0.40 8,887 8,887 INTRM1 CEMEN-DISP P S/D pump and line up to cement unit,WHP=579, IA=0, OA=0, Pump 5 BBIs Fresh water. S/D for cementers PT,4K, Line back up to coil 19:51 20:09 0.30 8,887 8,887 INTRMI CEMEN'CMNT P Cementers on line with 15.8PPG cement, 1 BPM, 2.34 BBIs between cemeters and rig MM, Pump 10 BBIs Cement, followed by 3 BBIs fresh, S/D and swap to rig pump 20:09 20:45 0.60 8,887 8,865 INTRM1 CEMEN'CMNT P Swap to rig pump and line up on 8.6PPG fluid,Vol in 12.9, 34.9 BBIs in goto 9.8PPG Power vis, 20:45 20:51 0.10 8,865 8,879 INTRM1 CEMEN-CMNT P 41.7BBIs in, reset out micro motion, 49.7 BBIs, all cement pumped at one for one. S/D pump and unsting from cement retainer, PUW=38K, Pump one more BBI 20:51 23:45 2.90 8,879 50 INTRM1 CEMEN-TRIP P POOH replace coil voidage, PUW=34K, Discuss WHP with Jason. Unable to get below—600 PSI, Continue out 23:45 00:00 0.25 50 0 INTRM1 CEMEN-TRIP P 50'from surface, Continue out following slimhole procedure 03/30/2015 Flush coil and pump inhibitor. Test wire-good. PT Cement-Fail. Blow down CT with N2. Remove coil from injector and secure to spool. Rig up to swap out Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 0 0 INTRM1 CEMEN'PULD P Master shut, bleed off WHP and remove tools, Shut swabs. Open master and monitir MP line.Trip sheets out at one to one.WHP @ 620. Bleed off 100 psi pressure came right back up 00:30 06:00 5.50 0 0 INTRM1 CEMEN-WOC P WOC 06:00 11:00 5.00 0 0 INTRM1 CEMEN-WOC P Line up, mix inhibitor, and flush surface lines, Stage 2 inch parts for reel swap. 11:00 14:30 3.50 0 0 INTRM1 CEMEN-WOC P Call out SLB N2 pumpers from Deadhorse, Remove CTS counter, stage new brass, and pac-offs. Unboot wire and test cable>2kMeg/38 Ohmes 14:30 17:00 2.50 0 0 INTRM1 CEMEN-WOC P PJSM with SLB N2 Pumpers, R/U and blow down coil to TT. Shut down Rig down N2 17:00 18:00 1.00 0 INTRM1 CEMEN-PRTS P Pressure test cement, Pump up 200 PSI pressure bled right back down 18:00 00:00 6.00 INTRM1 CEMEN-CTOP P R/D inner reel iron, Dress coil and install internal grapple connector. Unstab coil from injector and secure to storage reel. Rig up spool to lifting rams 03/31/2015 Reel swap from 2 3/8"to 2"coil. Change out BOP rams and gooseneck rollers. Stab coil in injector head, MU inner reel iron, test bulkhead. Rehead coil connector and UQC,test. Load coil and test inner reel iron and pack-offs. Prep for BOP test. 00:00 06:00 6.00 0 0 INTRM1 CEMEN'CTOP P PJSM with Peak-Load out 2 3/8" coil to truck, P/U 2"CT string. Swap out brass in stuffing box, C/O injector gripper blocks, C/O horsehead rollers,Torque reel saddle clamps 06:00 19:15 13.25 0 0 INTRM1 CEMEN-CTOP P PJSM, C/O BOP Rams and gooseneck rollers, Install stripper on injector and install packoff. Prep coil and install grapple, Stab coil in injector. M/U inner reel iron and pressure bulkhead. Meg test E-Line, good test. 19:15 23:30 4.25 0 0 INTRM1 CEMEN-CTOP P Rehead coil connector, and pull test. Rehead upper quick connect, meg test good. Load coil, pressure test inner reel iron, pack-offs. 23:30 00:00 0.50 0 0 PROD1 DRILL BOPE P Prep rig floor for BOP test. 04/01/2015 Finish prep for BOP test. Complete bi-weekly BOP test. PD BHA#19, RIH w/4.5"clean-out assembly to 7,590', in progress. 00:00 01:00 1.00 0 0 PROD1 DRILL BOPE P Continue prepping for BOP test, shell test to 4,900 psi. 01:00 13:00 12.00 0 0 PROD1 DRILL BOPE P Perform full BOP test 250/4900 psi, annular 2,500 psi. Test waived by AOGCC(Johnnie Hill)at 16:45 on 03-31-15. Page 16 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 18:00 5.00 0 0 PROD1 DRILL BOPE T Troubleshoot choke leaks. Change-out valves C5, C8, and C16. Retest. BOP test complete. Stab on wellhead,test inner iron and pack-offs. Start NAD NPT 5 Hrs 18:00 19:30 1.50 0 0 PROD1 DRILL RURD P PJSM. LD BOP test equipment, prep floor for pressure deployment. 19:30 22:00 2.50 0 0 PROD1 DRILL PULD P PJSM. MU/PU BHA#19 clean-out assembly. Pressure deployment BHA. 22:00 00:00 2.00 0 7,590 PROD1 DRILL TRIP P RIH w/4.5"clean-out assembly 04/02/2015 Make 4.5"liner clean-out run to 7,732'. Make 3.5"liner clean-out run to 8,700', milled continual cement from 8,500'to 8,700'. POOH for whipstock assembly. PUD BHA#20, PD BHA#21. RIH w/whipstock,whipstock became stuck 0 7,950',work pipe, in progress. 00:00 01:21 1.35 7,590 7,732 PROD1 DRILL TRIP P Continue in hole with clean-out assembly,tie-in K1 for+7' correction,close EDC. RIH watching for cement stringers, saw nothing. Shut down pump, dry tag TOL @ 7,732'. Open EDC, pump sweeps. 01:21 02:45 1.40 7,732 53 PROD1 DRILL TRIP P Chase sweeps to surface at max rate. 02:45 04:48 2.05 53 0 PROD1 DRILL PULD P PJSM. PUD BHA#19, LD BHA. 04:48 06:15 1.45 0 52 PROD1 DRILL PULD P PJSM. PD BHA#20 06:15 07:39 1.40 52 7,590 PROD1 DRILL TRIP P RIH w/3.5"clean-out assembly, EDC Open 07:39 07:45 0.10 7,590 7,618 PROD1 DRILL DLOG P Log K1 for+9' 07:45 07:57 0.20 7,618 7,700 PROD1 DRILL TRIP P Continue in 07:57 10:27 2.50 7,700 8,700 PROD1 DRILL MILL P Stop and shut EDC, PUW=34K, clean trip past liner top,first set down at 8024,stringers down to 8500 then constant milling to 8700' 10:27 11:03 0.60 8,700 8,700 PROD1 DRILL MILL P Recip across whipstock setting depth 8660 to 8700 while waiting for 10 X 10 sweeps 11:03 13:27 2.40 8,700 60 PROD1 DRILL TRIP P Chase sweeps to surface 13:27 14:57 1.50 60 0 PROD1 DRILL PULD P At surface, PJSM PUD BHA#20 3.5"liner clean out 14:57 16:15 1.30 0 0 PROD1 RPEQP1 PULD P M/U Whipstock BHA#21 16:15 17:30 1.25 0 73 PROD1 RPEQP1 PULD P PD BHA#21 Set Whipstock Page 17 of 31 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 00:00 6.50 73 7,950 PROD1 RPEQP1TRIP T RIH w/WS assembly, tie-in K1 for +8'correction,weight check above TOL @ 7,635'34K. Continue in hole, stack out @ 7,899'. PUW=37K. Make four more attempts,work WS to 7,926'. Call town,decide to POOH check BHA.Town change minds, decide to pump more lubes, RBIH. pump lubes around, start stacking and getting weight back @ 7,930', work down to 7,950', not getting weight back, stuck @ 7,950',work pipe, pump on/off and different orientation, no luck. Discuss with town. 04/03/2015 Pull free from stuck whipstock @ 7,950'. POOH LD BHA#21,whipstock left in hole. RIH w/nozzle,jet above fish @ 7,940'max rate. POOH, LD BHA. RIH w/dummy whipstock assembly, drift to top of fish @ 7,940', no issues. POOH, LD BHA. RIH w/new whipstock assembly, set whipstock @ 7,911', TOWS 7,900'40 ROHS. 00:00 00:15 0.25 7,950 7,950 PROD1 RPEQP1TRIP T Start pulling on stuck BHA with pump off, eight cycles to 65K, pump on at 1 bpm, pull 70K, pull free, HOT tool still working. 00:15 01:30 1.25 7,950 80 PROD1 RPEQP1TRIP T POOH to check BHA. 01:30 02:45 1.25 80 0 PROD1 RPEQP1PULD T PJSM. PUD BHA#21, Check BHA, no whipstock, hard cemment in collars of setting tool, pictures of setting tool in folder on"S"drive. LD BHA. 02:45 03:45 1.00 0 0 PROD1 RPEQP1PULD T Wait on Baker fishing tools. Town decided to run nozzle first. 03:45 05:00 1.25 0 26 PROD1 RPEQP1PULD T PJSM. PU/MU nozzle assembly. 05:00 06:48 1.80 26 7,941 PROD1 RPEQP1TRIP T RIH w/nozzle assembly 06:48 07:48 1.00 7,941 7,941 PROD1 RPEQP1TRIP T On top of fishpump 2.07 BPM @ 3780, Pump 10 X 10 sweep, recip on top of fish 07:48 09:24 1.60 7,941 25 PROD1 RPEQPI TRIP T Trip out 09:24 09:42 0.30 25 0 PROD1 RPEQP1PULD T On Surface, PJSM, Lay down FCO BHA 09:42 11:00 1.30 0 0 PROD1 RPEQP1 SVRG T Service/inspect injector&reel. Pull choke b apart 11:00 12:00 1.00 0 0 PROD1 RPEQP1 WAIT T Conference call with town-explore options decide to prep hole and run second whipstock 12:00 13:30 1.50 0 71 PROD1 RPEQPI PULD T Crew change, PJSM, Make up BHA #23 with Dummy whipstock and Deploy 13:30 15:12 1.70 71 7,939 PROD1 RPEQP1TRIP T Trip in hole with BHA#23 Dummy Whipstock tie into K1 @ 7610 to 7637 for+11 15:12 16:24 1.20 7,939 7,700 PROD1 RPEQP1 CIRC T Tag pinchpoint, Jet and recip to 7880 with sweeps, pumped second set of sweeps jetted 7939 to 7700'.2.1 BPM @ 4500 PSI 16:24 18:00 1.60 7,700 71 PROD1 RPEQP1TRIP T POOH at 2.09 BBIs/Min Page 18of31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:30 1.50 71 0 PROD1 RPEQP1PULD T PJSM. PUD BHA#23, LD BHA 19:30 21:00 1.50 0 74 PROD1 RPEQP1 PULD T PJSM. PD BHA#24 21:00 00:00 3.00 74 7,911 PROD1 RPEQP1 TRIP T RIH w/whipstock assembly,tie-in K1 for+7.5'correction, continue in hole to set septh @ 7,910'. PUW=34K. RBIH to set depth, close EDC, pressure up to release from WS @ 4,100 psi, stack 4K down. TOWS @ 7,900'40 ROHS. 04/04/2015 POOH, LD BHA#24. PD BHA#25. RIH w/window milling assembly. Mill window from 7,900'to 7,905', milling in progress. 00:00 01:30 1.50 7,911 74 PROD1 RPEQP1 TRIP P POOH for milling assembly. 01:30 04:00 2.50 74 72 PROD1 RPEQP1PULD P PJSM. PUD BHA#24, LD BHA. PJSM. PD BHA#25. 04:00 05:18 1.30 72 7,600 PROD1 WHPST TRIP P RIH w/window milling assembly, tie-in 05:18 05:36 0.30 7,600 7,643 PROD1 WHPST DLOG P Log K1 tie in for+5.5'correction 05:36 06:00 0.40 7,643 7,901 PROD1 WHPST TRIP P RIH to dry tag whipstock 06:00 15:00 9.00 7,901 7,904 PROD1 WHPST WPST P 7800, bring pumps on, 1.7 BPM @ 4000 PSI FS, BHP=3905, Call pinch point @ 7899.9 with motor work and DHWOB 15:00 16:48 1.80 7,904 7,905 PROD1 WHPST WPST P Confer with town,window going slowly,double check liner tally,way away from connection. Keep on, Pump up sample looking for dirt, Good supply of metal on magnets, 150 PSI motorwork 16:48 00:00 7.20 7,905 7,905 PROD1 WHPST WPST P P/U and restart, 1.52 BPM @ 3890 PSI FS, See DHWOB @ 7904.2. Only metal in sample. Slow going, several pick-ups, clean pick-ups, mainly metal across shakers. 34/05/2015 Continue milling window to 7,906'. POOH to check BHA. PUD BHA#25, PD BHA#26. Mill on window exit @ 7,906', no progress made. POOH.Wait on new orders from town, make clean-out run to 7,890'with dummy drift. Start out hole with BHA#27. 00:00 04:54 4.90 7,905 7,906 PROD1 WHPST WPST P Continue milling whiptock @ 7,905'. Cut pump rate to 1.53 BPM @ 3,650 PSI, BHP=3950 PSI, CTW=10K, WOB=4K. Restart several times, metal across shaker. 04:54 06:12 1.30 7,906 77 PROD1 WHPST TRIP T Forward progress stopped, Trip out to inspect BHA 06:12 08:12 2.00 77 0 PROD1 WHPST PULD T At surface, PUD BHA#25. Bit shows little evidence of crossing centerline. Motor tight and holding fluid. Check scribe down tool string good. Mill out @2.79NoGo 08:12 09:24 1.20 0 73 PROD1 WHPST PULD T M/U BHA#26 with 0°motor, new 2.80 window mill, new string reamer and pressure deploy 09:24 10:48 1.40 73 7,610 PROD1 WHPST TRIP T Trip in hole, EDC open Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:48 11:00 0.20 7,610 7,640 PROD1 WHPST DLOG T Log K1 for+4.5'correction, close EDC 11:00 11:18 0.30 7,640 7,905 PROD1 WHPST TRIP T Continue in well,dry tag @ 7905.81 11:18 15:18 4.00 7,905 7,906 PROD1 WHPST MILL T Bring pumps on 1.53 BPM @ 3450 PSI FS, BHP=3900, Getting DHWOB with no motorwork, Run at it to get motor work-150 PSI 15:18 16:36 1.30 7,906 80 PROD1 WHPST TRIP T Making no progress, no metal coming out, POOH 16:36 18:00 1.40 80 81 PROD1 WHPST PULD T At Surface, PJSM, PUD BHA#26, service injector and reel. 18:00 20:00 2.00 81 0 PROD1 WHPST PULD T Waiting new marching orders from town. 20:00 21:00 1.00 0 72 PROD1 WHPST PULD T PJSM. MU BHA#27, PD BHA. 21:00 23:30 2.50 72 7,890 PROD1 WHPST TRIP T RIH w/Dummy drift/nozzle,tie-in to K1 for+4.5'correction, continue in hole, no issues. Pump bottoms up at max rate 1.9 bpm @ 4,300 psi, clean 3.5" liner. 23:30 00:00 0.50 7,890 6,370 PROD1 WHPST TRIP T Start out of hole. 04/06/2015 POOH w/BHA#27, PUD BHA. PD BHA#28, Set 3.5"Monobore whipstock @ 7,875'. POOH and PUB BHA#28. PD BHA#29, RIH w/magnets and LIB,tag whipstock @ 7,877', POOH, PUD BHA#29. PD BHA #30, RIH w/milling assembly,dry tag whipstock 7,876', start milling window exit, in progress. 00:00 01:15 1.25 6,370 78 PROD1 WHPST TRIP T Continue out of hole with BHA#27. 01:15 02:30 1.25 78 0 PROD1 WHPST PULD T PJSM. PUD BHA#27 02:30 03:30 1.00 0 73 PROD1 RPEQP1 PULD T PJSM. MU BHA#28, PD BHA. 03:30 05:36 2.10 73 7,613 PROD1 RPEQP1TRIP T RIH w/Whipstock assembly,tie-in 05:36 05:42 0.10 7,613 7,641 PROD1 RPEQPI DLOG T Log K1 for+5'correction 05:42 06:24 0.70 7,641 7,886 PROD1 RPEQP1TRIP T Continue in to set depth ©7885.5, TOWS=7875 @ 20L,see tool shift @ 4200PS1, Set down 4K Looks good 06:24 07:42 1.30 7,886 78 PROD1 RPEQP1TRIP T Trip out after setting whipstock 07:42 08:30 0.80 78 0 PROD1 RPEQPI PULD T At surface, PJSM PUD BHA#29 Whipstock setting tools 08:30 10:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on Magnets from Deadhorse 10:00 11:06 1.10 0 67 PROD1 WHPST PULD T PJSM, P/U BHA#29, Magnets and 2.50 LIB 11:06 12:30 1.40 67 7,600 PROD1 WHPST TRIP T Trip in hole, EDC open 12:30 12:36 0.10 7,600 7,633 PROD1 WHPST DLOG T Tie into K1 for+5.5 12:36 12:48 0.20 7,633 7,878 PROD1 WHPST TRIP T Continue in with LIB,Tag @ 7877.87, see 2.6K DHWOB 12:48 14:00 1.20 7,878 75 PROD1 WHPST TRIP T Trip out of well 14:00 15:12 1.20 75 0 PROD1 WHPST TRIP T At surface,Tag up and space out, PJSM PUD BHA#29 15:12 16:00 0.80 0 0 PROD1 WHPST WAIT T Pics on LIB to S Drive, clean magnets, formulate plan forward 16:00 17:15 1.25 0 71 PROD1 WHPST PULD T PJSM, M/U and deploy BHA#30.6° motor and 2.80 window mill Page 20 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 19:21 2.10 71 7,877 PROD1 WHPST TRIP T RIH w/millinf assembly,tie-in to K1 for+5'correction, continue in hole. PUW=34K. Dry tag whipstock @ 7,876.7'. 19:21 00:00 4.65 7,877 7,879 PROD1 WHPST WPST T Start stick milling window: 1.50 bpm @ 3,775 psi, BHP=3,960 psi, CTW=12.4K,WOB=2.5K. 04/07/2015 Mill window exit from 7,876'to 7,880'. Progress not being made on window. POOH, PD BHA#30, LD BHA. Rig maintenance. PD BHA#31, RIH w/caliper assembly, log CCL from 7,600'to 7,865'. Log caliper survey from 7,880'to 6,980'. POOH and PUD BHA#31, LD BHA. Download caliper data, send for processing. Waiting on orders. 00:00 03:00 3.00 7,879 7,880 PROD1 WHPST WPST T Continue milling window exit. 1.52 bpm @ 3,740', BHP=3,924 psi, CTW=11 K,WOB=2.7K. have motor work, but progress is slowing down. 03:00 07:06 4.10 7,880 7,880 PROD1 WHPST WPST T Continue milling window: 1.53 bpm @ 3,725 psi, BHP=3,920 psi. CTW=11.5K,WOB=3K. Progress is slowing down, made about 4'total. 07:06 08:42 1.60 7,880 71 PROD1 WHPST WPST T 7880, Trip out for something else, PUW=33.5K 08:42 12:00 3.30 71 0 PROD1 WHPST PULD T PJSM-Un-deploy and LD 2.6BHA #30, P/T BHA and CTC,good, mill gauge 2.79"no-go,good shape, no damage or indication of wear to BHA, wait on PDS tools. 12:00 12:30 0.50 0 0 PROD1 WHPST SFTY T PDS tools on site, rig orientation for new to rig hand. 12:30 13:30 1.00 0 0 PROD1 WHPST PULD T Confirm plan forward caliper BHA set up, program tools, set timer for tool to open. 13:30 14:54 1.40 0 59 PROD1 WHPST PULD T PJSM-MU/Deploy BHA#31,tool set to open at 19:12. 14:54 16:00 1.10 59 7,595 PROD1 WHPST TRIP T RIH with caliper BHA#31. 16:00 16:45 0.75 7,595 7,865 PROD1 WHPST DLOG T Log K1 marker, plus 5-ft correction, PUW 32k, RBIH, CCL log from 7,600' to 7,865'@ 20 fpm..75 16:45 19:30 2.75 7,865 7,880 PROD1 WHPST TRIP T RBIH to 7,870'.Waiting on caliper to engage. RIH to 7,880'. 19:30 21:00 1.50 7,880 63 PROD1 WHPST DLOG T TOOH logging caliper survey @ 50 fpm to 6,980'. Caliper arms released, POOH at normal spped. 21:00 22:30 1.50 63 0 PROD1 WHPST PULD T PJSM. PUD BHA#31, LD Caliper BHA. 22:30 00:00 1.50 0 0 PROD1 WHPST WAIT T Waiting on orders. Download caliper data,send for processing, rig maintenance. 04/08/2015 Waiting on caliper survey.Waiting on orders, decide to run another whipstock,wait on whipstock assembly. RIH w/BHA#32 whipstock with OH anchor assembly, in progress. 00:00 06:30 6.50 0 0 PROD1 WHPST WAIT T Continue waiting on orders, process Caliper data, monitored MP. 06:30 07:00 0.50 0 0 PROD1 WHPST BOPE T PJSM-Function test BOPE 07:00 15:00 8.00 0 0 PROD1 WHPST WAIT T Continue waiting on orders, rig maintenance, monitor MP. Page 21 of 31 WELL LOG TRANSMITTAL DATA LOGGED 5i BEND$/201 ER To: Alaska Oil and Gas Conservation Comm. March 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED APR 0 3 2015 RE: Perforationand Packer Set Record: 30-16A AOGCC Run Date: 10-11 March 2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-16A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21796-01 SCANNED MAY 0 6 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: "dx•-•z44) 6-eocest ti OF ' �w�\�� Tye THE STATE Alaska Oil and Gas I��%Sly s ,;.-s�i � oALAsKA. Conservation Commission s '•114itt-= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS P. Fax: 907.276.7542 www.aogcc.alaska.gov Gary Eller k� CTD Engineer �"` \?f3 �� ConocoPhillips Alaska, Inc. 3 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16A Sundry Number: 315-151 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, 0641 P2ii-<-.-34L- Cathy . Foerster q Chair DATED this / day of March, 2015 Encl. STATE OF ALASKA A. .(A OIL AND GAS CONSERVATION COM ,ION • . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon Rug for Redrill F Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Ferf orate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate E Alter casing 1- Other: I- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 188-043 ' 3.Address: Stratigraphic r Service 6.API Number. P.0. Box 100360,Anchorage,Alaska 99510 50-029-21796-01 • 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 P KRU 30-16A• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 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): 8351 , 6901 . 8118' - 6709'• 7827' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 2340 9.625 2375' 2215' RECEIVED LINER 8168' 7 8201' 6778' LINER 238' 4.5 7945' 6571' MAK 1 8 ZU15 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7838-7859,7867-7872 6444-6452,6480-6498 4.5 L-80 7695 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 2RH ZXP LINER TOP PACKER MD=7688 TVD=6357 SAFETY VLV-BAKER FVLD SAFETY VALVE MD=1786 TVD=1745 12.Attachments: Description Surrrrkary of Proposal p' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/18/2015 Oil r Gas r WDSPL r Suspended F' 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to he best of my knowledge. Contact Gary Eller©265-6097 Email. J.Gary.Ellernconocophillips.com Printed Name Gary Eller Title: CTD Engineer Signature Phone:265-6097 Date .I`14i%l C mmission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness - 15-151 Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: (30P f e 5/ /c 49C /76 ; `-< <p5i-' , 4(05 / /75i ) /1 v2v7L> /c, t- pi6' i/ .-7flr- f51- to 25-cc' �f ,tt'r-ran /� plvy F /6i (-�1--1-) <<it0pp( v c /�r+' Zc �I.�C �5, /iT (� li 4l Spacing Exception Required? Yes ❑ No ✓/ Subsequent Form Required: /U —4O.7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date.3—f9—/S- 1/7-4 3/, /J --. Approved application is valid tor 12 ri pgth�/� rn�he date of approval b! 4„/_45 Form 10-403(Revised 10/2012) y146Ls Submit Form and Attachm in Duplicate / ) ORIGINAL � `3— RBDMS� APR - 2 2015 KRU 30-16A Abandonment Sundry for Redrill (10-403) Summary of Operations: Well 30-16A is a Kuparuk A sand injection well equipped with 4'/2"tubing and 4'/2" liner. Three laterals had been planned to be drilled from well 30-16A, but a mechanical failure of the whipstock has rendered the 30- 16A mother completion incapable of operation. ' ' 130-1. • nee.s to .e p ugged in a way that wi allow the redrill Z-70571-61—b3, ut spatial limitations make it impossible to plug it in a way that satisfies the requirements of 20 AAC 25.112(c)(1). ConocoPhillips proposes an abandonment method that will effectively satisfy the intent yet still allow the drilling of 30-16B. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to abandon the KTU 30-16A completion in preparation for red rill. 30-16A will be plugged when the 31/2" liner for 30-16B is cemented in place(see step 2e,below). The cement volume is adequate to cement the entire 31/2"liner in the open hole plus the—30' of liner lap inside the 4'/2" scab liner. After cement is in place,the liner lap will be pressure tested to ensure competence. If the pressure test fails,remedial options include another cement job on the 31/2"x 41/2" liner lap or placement of a 31/2" liner- top packer post-CTD. Rig Work 1. MIRU Nabors CDR2-AC rig using 2%"coil tubing. NU 7-1/16"BOPE,test. 2. 30-16B Lateral(A2 sand- Southwest) a. Set whipstock at 7775' MD inside the 4W' liner b. Mill 3.80"window at 7775' MD c. Drill 4.125"bi-center lateral to target depth of 8815' MD d. Run 31/2"blank liner with a 6' seal bore deployment sleeve back to 7750' MD e. Cement liner in place with 10 bbl of Class G cement f. Pressure test liner lap to ensure isolation of the KRU 30-16A perforations g. Swap 2%"CT back to 2"CT,retest BOPE h. Drill out the cement shoe and drill 3"bi-center lateral to TD of 10,650' MD i. Run 2%" slotted liner with an aluminum billet from TD up to 8925' MD 3. 30-16BL1 Lateral(A3 sand- Southwest) a. Kick off of the aluminum billet at 8925' MD b. Drill 3"bi-center lateral to TD of 10,650' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8885' MD 4. 30-16BL2 Lateral(Al sand- Southwest) a. Kick off of the aluminum billet at 8885' MD b. Drill 3"bi-center lateral to TD of 10,650' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8800' MD 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. MIRU CT and N2 lift well for flow back(less than 30 days) 4. Return to injection after performing MIT-IA Page 1 of 1 Tuesday,March 17,2015 0 ao2 g2 in O N Lf5 Q U) W ri co NO N m mr- m co w a moo IV >- m vv 0 co . o m o '^ O m � @j m ,- 0 om 0 OD eo N O O a U 0 C_ E.-- YO co E co m 0) Q�N` I m 2O M V a1 U - c0 N mY p C 0) \ is Q N in— O O] V a C QOa / u) co >'O V N'O \\ N \ / U co21 Y Q dX @ CO U a _ \ k CO _a ANY o O CD o ti \ (O O= U L a , W C CO CC O 21 CO co I.N ,// J X m N x n p o M O N N N co I-- a2 ` c r X N O 45 O 4 A V (O N to o.C U O 1 J O Z..1-1: a w U : ci a 2 v as A m� o a L CD IS V! 0 - - - hAM'Y,„;, 3}M, ..t lii.h31AVAiii:VreeY,••'�Cl) 'oma. A;pA. Ah,-... .'f.^'}...AAi . AL_ i PPPP)AA 'YAP h�}AAA..�SY77�Y�Y 14.6i,4^.�w�Y,,,�1, b (tlatM iit{[.''-f';i c.i'„c-t;t-14si.f+'.f f f f Mr Y�ill1C�filiiilifNagitM1A ti' tiff^ I 5 a 2 a o a c0 O 0 N 0- o-o O O = .- f7 00� N ~ Q� (6 O Na 0000 � N CO CN C`n ter` �� 8 � � �� � � � N N r M a (O a) �.nM N N V- O C 7sN NO)N D) o0 CV r--- (0 (OLS O) NN O N (nom Y -2 co co No0 m�� 6) V Cl)eC Q N UN a\ 2mN a N-N Nr� Uv CO O a I �'Fes- co co(O 1 0 0)Cf)m i CO c0 CO O) 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 - esponsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the PRatricia r 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 atrici or 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. 1,`L,c‘•o4 255,° WELL LOG TRANSMITTAL Dra. GGED 3 2SQzo1S M K.BENDER To: Alaska Oil and Gas Conservation Comm. March 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 2 4 2015 RE: Multi Finger Caliper(MFC) : 30-16A AOGCC Run Date: 3/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-16A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21796-01 NIiED [ SEWED `,4,4 fii : PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6..ekeigt STATE OF ALASKA AU \OIL AND GAS CONSERVATION COM. 310N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell ro Rug Perforations r Perforate r Other r Alter Casing p• Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc Development r Exploratory r 188-043 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21796-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 KRU 30-16A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): CBL,caliper Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8351 feet Plugs(measured) none true vertical 6901 feet Junk(measured) none Effective Depth measured 7945 feet Packer(measured) 7687 true vertical 6569 feet (true vertical) 6357 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 2340 9.625 2375 2115 LINER 260 4.5 7947 6569 PRODUCTION 8168 7 8201 6778 RECEIVED SCANNED FEC 2 ti L0 FEB 13 2015 Perforation depth: Measured depth: 7794-7804, 7838-7848, 7850-7860, 7869-7889, 7908-7928 True Vertical Depth: 6444-6452,6480-6488,6489-6498,6505-6521,6537-6553 AOGCC Tubing(size,grade,MD,and ND) 4.5, L-80, 7695 MD, 6385 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER ZXP PACKER @ 7687 MD and 6357 ND no SSSV 12 Stimulation or cement squeeze summary: Intervals treated(measured): 7707'-7947' Treatment descriptions including volumes used and final pressure: 15 bbls of 15.8#Class G cement 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP PI SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O Exempt: 314-489 Contact Theresa Lee (a,263-4837 Email Theresa.M.Leeconocophillips.com Printed Name / Theresa Lee Title Workover Engineer Signature i` `s ^„ Phone:263-4837 Date el / Z / ( 5 1/7-1,- 7/23//.5 RBDMS. FEB 2 3 1015 272 Form 10-404 Revised 10/2012 Submit Original Only KUP INJ & 3 r' ConocoPhillips 01 Well Attributes Max Angle MD TD0-16A A0i -cct Inc. Wellbore APl/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) tOssoml»enpc 500292179601 KUPARUK RIVER UNIT INJ 43.38 2,600.00 8.351.0 ••• Comment H2S(ppm) Date Annotation End Dale KB-Grd(k) Rig Release Date 30-16A,2/12/20152.49.18 PM SSSV:NIPPLE Last WO. 12/11/2014 34.98 4/23/1988 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..._.................................._..........._. Last Tag: Rev Reason.WORKOVER smsmith 2/6/2015 HANGER;33.0 i -.,(; J 1 Casing Strings nn,n,n,nnn„n,.,uv,nm,m Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grego Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED r, Casing Description 00(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread L. SURFACE 95/8 8.921 35.0 2,374.9 2,214.8 36.00(kJ-55 BTC --ir L Casing Description OD(In) ID(in) Top(ftKB) Set Depth KB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread TIEBACK 7 6.276 33.0 1,060.7 1,060.6 26.00 L-80 TC-II Casing Description OD(in) ID(In) Top(ftKB) Set Depth(k(B) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 1,061.6 8,201.2 6,777.8 26.00 J-55 BTC Mme''-_ _ '~Casing Description OD(in) 'ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CASING PATCH 6.089 5.488 1,011.4 1,121.0 1,120.7 FODC-OR Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)...1511/Len(I...Grade Top Thread i LINER 41/2 4.000 7,687.5 7,947.3 6,568.9 11.60 L-80 BTC CONDUCTOR:36.0-115.0 Liner Details Nominal ID Top(kKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) - 7,687.5 6,357.4 35.88 PACKER BAKER"2RH"ZXP LINER TOP PACKER 4.330 7,707.2 6,373.3 35.81 HANGER BAKER FLEX-LOCK HANGER 4.250 Tubing Strings Tubing DescriptionI String Ma...ID(in)4Top(kKB) I Set Depth(k..J Set Depth(TVD)(...I Wt(Ib/ft) Grade Top Connection @ TUBING-4 1/2 x 5 4 1/2 .000 33 0 7.695,4 6,363 7 12.60 L-80 IBTM 7683 66 Completion Details Nominal ID TIEBACK;33.0-1,060.7 Top(N(B) Top(TVD)(kKB) Top Incl(°) Item Des Com (in) 33.0 33.0 0.03 HANGER CAMERON TUBING HANGER 3.833 7,635.8 6,315.5 36.12 NIPPLE DB NIPPLE,SR#T031038 3.813 7,684.5 6,354.9 35.90 LOCATOR BULLET SEAL LOCATOR 3.930 CASING PATCH:1,011.4- I I 7,685.6 6,355.8 35.89 SEAL ASSY BULLET SEAL ASSEMBLY 4.250 1,121.0 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (kKB) Zone Dale t) Type Com SURFACE;35.0-2,374.9 '117,794.0 7,604.0 6,443.8 6,451.9 C-1,UNIT B, 3/16/1989 12.0 IPERF 60 deg.phasing;2 1/8" 30-16A EnerJet -- 7,838.0 7,848.0 6,479.6 6,487.7 A-5,A-3,30- 3/16/1989 6.0 IPERF 30 deg.phasing;2 1/8" 16A EnerJet NIPPLE;7,635.8IIE 7,850.0 7,860.0 6,489.4 6,497.5 A-3,30-16A 3/16/1989 12.0 (PERF 60 deg.phasing;2 1/8" EnerJet 7,869.0 7,889.0 6,504.9 6,521.2 A-2,30-16A 3/16/1989 12.0 (PERF 60 deg.phasing;2 1/8" EnerJet 7,908.0 7,928.0 6,536.7 6,553.1 A-1,30-16A 6/22/1988 8.0 APERF 45 deg.phasing;41/2" X0 Enlarging(Tubing);7,683.7 U)trapak CSg LOCATOR:7,684.5 • Cement Squeezes . Top(TVD) Btm(TVD) Top(ftKB) Bim(kKB) (ftKB) (kKB) Des Start Date Com SEAL ASSY;7,885.6 7,707.0 7,947.0 6,373.2 6,568.6 41/2"liner 1/10/2015 Cement 41/2"liner assembly for upcoming CTO from 7947'-7707'.Pumped 5bbls fresh,mud flush 15 bbls. pumped 15 bbls of 15.8#G neat cement,5 bbls fresh, dropped plug displaced with 60 bbls of 12.28 mud. y Set packer and hanger assembly @ 4300 psi against � � cement plug. 3 iffi Notes:General&Safety :, End Date Annotation sk-V N(JTE. s,....--b r g IPERF;7,794.0-7,804.0- . g g IPERF;7,836.0-7,848.0 IPERF;7.850.0-7,880.0- X` IPERF;7,889.0-7,689.0- zg J' J J APERF;7,908.0-7.828.0 J J LINER;7,887.5-7,947.3 '' `v; PRODUCTION;1,058.0-8,201.2 li 30-16A POST RIG WELL WORK DATE SUMMARY 2/7/2015 SLB CTU #4: PERFORM WEEKLY BOP TEST ON BACK DECK. WILL RETURN IN THE MORNING FOR FCO AND FLUID SWAP WITH VENTURI. 2/8/2015 SLB CTU#4: CIRCULATE OUT DRILLING MUD WITH JET SWIRL NOZZLE ASSEMBLY TO HARD TAG AT 7710' CTMD (7723' RKB). UNABLE TO MAKE HOLE- ESTIMATING 189' OF FILL. RIH WITH WEATHERFORD VENTURI BASKET AND GET A LOT OF METAL DEBRIS AND SOME CEMENT-LIKE CHUNKS. WELL LEFT CIRCULATED TO SEA WATER AND FREEZE PROTECTED TO 2500'. RIG BACK AND DISCUSS OPTIONS. ConocoPhiIIips Time Log & Summary We/'view Web Reporting Report Well Name: 30-16 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 12/11/2014 1:00:00 PM Rig Release: 1/16/2015 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/11/2014 24hrSummary MIRU. Set auxiliary equipment. Berm up rig. R/U lubricator and pull BPV. Rig up hardline. Load KWF and blend. R/U lines to kill well. Pre-spud meeting. PT hardline. Bleed gas cap from well. Tubing pressure/IA pressure 0 psi. 09:30 13:00 3.50 MIRU MOVE MOB P Move rig from 30-13 to 30-16. Shuffling rig mats. Hang tree in cellar. Rig accepted @ 13:00 hrs 13:00 15:30 2.50 MIRU MOVE RURD P Set auxiliary equipment. Berm up rig. 15:30 17:30 2.00 MIRU WELCTL RURD P R/U Lubricator and pull BPV. Tubing-0 psi IA-100 psi OA-50 psi. 17:30 22:30 5.00 MIRU WELCTL RURD P Rig up hardline. Take on KWF and blend. R/U to kill well. 22:30 23:00 0.50 MIRU WELCTL SFTY P Pre-Spud meeting-Jake's crew 23:00 00:00 1.00 MIRU WELCTL KLWL P PJSM. PT hard line. Bleed gas cap from tubing and IA. Tubing pressue 0, IA 0. 12/12/2014 Displace well with 12.2 ppg KWF while holding 150 psi back pressure. Monitor well,static. Install BPV and test. N/D tree, N/U BOPE. Test BOPE 250/4000 psi. M/U landing joint, BOLDS, observe tubing in compression. Attempt to pull tubing free, unable to. Circulate hole volume. Continue working pipe up to 118K, observe 10K drop in weight, Pick up on decompletion, observe 15K drop in weight. Pick up to 118K over,weight dropped to 45K. Pull hanger to the floor with 45K;tubing parted. No pressure on SSSV capillary tubing. R/U Camco spooler, monitor well. L/D hanger and pull decompletion out of the hole. One AL-5 packer recovered;string sheared at safety joints between the two AL-5 Packers. 00:00 03:00 3.00 MIRU WELCTL KLWL P Displace well with 12.2 ppg KWF at 3 bpm, hold 150 psi back pressure. ICP 960 psi, FCP 1000 psi. 305 bbls pumped, 294 bbls returned. 12.1 ppg returned. S/D and take back into pit. Pump additional 30 bbls _until 12.2 ppg returned. BD hardline. 03:00 03:30 0.50 MIRU WELCTL OWFF P Monitor well,static. 03:30 04:30 1.00 MIRU WHDBO MPSP P PJSM Set BPV and test from below. 04:30 06:30 2.00 MIRU WHDBO NUND P ND tree and adaptor. 06:30 07:30 1.00 MIRU WHDBOOTHR P install blanking plug and pressure up &secure SSSV in the open position 07:30 10:30 3.00 MIRU WHDBO NUND P NU BOPE&install lines Page 1 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 17:00 6.50 MIRU WHDBO BOPE P Shell test stack to 4K. Test BOPE 250/4000 psi 1) BR, Kill#13,TD HCR, 3.5 IF dart, choke 4,11,12 pass. 2) Kill HCR, Man TD, 3.5 IF FOSV, choke 3,7,9,10 pass. 3) LPR w/2 7/8 TJ, choke 2,5,8 pass 4)Ann, 2 7/8 TJ, man kill,choke HCR Pass 5) LRP W/3.5 TJ, choke#6 pass 6)Ann/w 3.5 TJ choke#1 pass 7)uprs w/7"TJ man choke pass 8)Annular w/7"TJ pass Draw down: initial pressure 3050 after closing 1950 psi. 200 psi recovery 23 sec. full recovery 98 sec. Nitrogen 4 x 1900 17:00 17:30 0.50 MIRU WHDBO MPSP P Blow down stack. Pull BPV&test dart. 17:30 18:15 0.75 COMPZ RPCOM PULL P Installed work jt. BOLDS, Observe 4K loss in weight. Work pipe up to 125K; no indication of AL-5 packers shearing. 18:15 20:30 2.25 COMPZ RPCOM CIRC P Establish circulation. Circulate 2 x hole volume at 5 bpm 1500 psi. 20:30 21:00 0.50 COMPZ RPCOM PULL P Continue to work pipe from 35K to 118K.; hold tension. Observe 10K drop in weight(AL-5 packer). Pick up, observed 15K drop in weight. Pick back up to 118K,weight fell to 45K. Pull hanger to the floor; PUW 45K. 21:00 22:00 1.00 COMPZ RPCOM CIRC P Circulate hole while rigging up Camco spooler. Capillary tubing no longer has pressure on it. 22:00 22:30 0.50 COMPZ RPCOM OWFF P Monitor hole, static. 22:30 00:00 1.50 COMPZ RPCOM PULL P POOH with decompletion. Recovered 1 AL-5 dual packer. Tubing and control line housing both sheared at safety joints. 12/13/2014 Inspect AL-5 packer and LID. Kick out pipe. Load, drift and strap D while waiting on tools from Baker. M/U BHA#1 spear assembly. RIH and attempt to engage fish, unsuccessful. POOH with BHA 1. M/U BHA#2 overshot. R/U E-Line and RIH with string shot. Fire string shot at 7,150', POOH. RIH with RCT cutter to 7,171 to correlate. E-Line stuck, no up or down movement. Attempt to Jar free. Jar up 32 times before free. Correlate RCT on depth and cut tubing at 7,148.5'. POOH with E-Line to 1,777'. E-line unable to pass through SSSV. Attempt to pump open SSSV and strip E-line through. Stage pumps up to 11.5 bpm, 1580 psi. Unable to get E-Line tool through SSSV. 00:00 02:30 2.50 COMPZ RPCOM PULD P Inspect and L/D AL-5 packer. Strap and kick out pipe. Page 2 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 05:30 3.00 COMPZ RPCOM OTHR T Load, drift and strap DC while waiting on tools from baker 05:30 08:00 2.50 COMPZ RPCOM PULD P load fishing tools and strap. Make up BHA#1 spear assembly. 08:00 09:30 1.50 0 1,025 COMPZ RPCOM TRIP P RIH with Dp to top of fish @ 1025 ft. unable to engage fish. 09:30 10:30 1.00 1,025 0 COMPZ RPCOM TRIP T POOH with BHA#1 10:30 12:30 2.00 0 1,025 COMPZ RPCOM FISH T RIH with BHA#2 over shot.Space out drill pipe for wireline engage fish with 20 K over. set slips. 12:30 21:00 8.50 0 7,171 COMPZ RPCOM ELNE P PJSM. RU Eline to cut tbg. RIH with string shot. Sat down in GLM @ 7161'. Shot string shot @ 7150 ft. POOH. load RTC RIH to coorelate to 7171'. 21:00 21:45 0.75 7,171 7,138 COMPZ RPCOM ELNE T E-Line stuck at 7,171, no up or down movement. Attempt to pull out of it. Begin firing E-Line Jars Jar x—15 times prior to coming free. 21:45 22:30 0.75 7,138 7,149 COMPZ RPCOM ELNE P Coorelate E-Line on depth and cut tubing with RCT at 7148.5'. POOH with E-Line 22:30 00:00 1.50 7,149 1,777 COMPZ RPCOM ELNE T E-Line stuck at SSSV. Attempt to pump SSSV open. Stage pumps up to 11.5 bpm, 1580 psi to attempt and open SSSV. 12/14/2014 Continue to attempt and pump open SSSV to allow E-line tools out. Attempt to pump heavy slugs, unable to get E-Line out. Part E-Line tools at 3800#. POOH and RID E-Line. Attempt to pull decompletion. P/U to 85K and observe AL-5 packer shear with 10K drop in weight. Pick up to 150K, no movement. Circulate hole clean. R/U Digital Slickline. RIH with Jet Cutter and cut tubing at 1,810'. POOH, R/D slickline. POOH with DP PUW 55K. L/D AL-5 Packer, rig up Camco. POOH with decompletion to 320'. 00:00 02:15 2.25 1,777 1,776 COMPZ RPCOM ELNE T Continue to attempt and pump open SSSV while E-Line strips through packoff. Pumping 11.5 bpm, 1580 psi. Able to get 10'of 43'tool length through SSSV. Build 13.5 ppg sweep and attempt to pull E-line through with sweep at SSSV x 2. Pump 13.8 ppg sweep and attempt to pull through. E-Line parted at tool head with 3800#PUW. 02:15 04:00 1.75 1,776 0 COMPZ RPCOM ELNE P POOH with E-Llne and R/D. 04:00 05:00 1.00 0 0 COMPZ RPCOM CIRC P R/U and circulate hole volume. 05:00 08:00 3.00 0 0 COMPZ RPCOM PULL T PJSM. Pick up on tubing, observe 10K drop in weight at 85K. Continue to work pipe up to 150 K with out movement. Broke circulation @ 10 BPM @ 1100 psi while working pipe. No success. probable non cut @ 7148 ft. 08:00 11:00 3.00 0 0 COMPZ RPCOM OTHR T Discussed with town next plan of action. called out Digital slick line. continue to work tbg.while waiting on them. Page 3 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 20:00 9.00 0 1,810 COMPZ RPCOM SLKL T RU Schlumberger DS unit. RIH with Jet cutter. Cut tubing at 1,810'. POOH. R/D Schlumberger. 20:00 21:30 1.50 1,810 785 COMPZ RPCOM TRIP P Pick up on tubing, PUW 55K. POOH standing back drill pipe. 21:30 22:30 1.00 785 785 COMPZ RPCOM RURD P Load and rig up Camco spooler. 22:30 00:00 1.50 785 320 COMPZ RPCOM PULL P POOH with decompletion. L/D AL-5 packer. Continue POOH with decompletion to 320'. 12/15/2014 Continue to POOH with decompletion. SSSV,control line and 29 SS bands(total)recovered. M/U Baker Overshot and RIH to 1763'; PUW/SOW 60K,establish parameters. Continue to RIH and tag fish at 1,804'. Dress off stub and engage fish. R/U E-Line and RIH with jet cutter,tag up at 2,530'and 2,831'. POOH. M/U drift run with CCL to 7,150'. POOH, M/U Jet Cutter and RIH. Attempt to cut tubing,Jet cutter would not fire. POOH. E-Line timed out. R/D E-Line. Circulate HV x 2. Work string 140K max. 00:00 00:45 0.75 320 0 COMPZ RPCOM PULL P Continue to POOH with decompletion. SSSV and control line recovered. 29 SS bands(total recovered) 00:45 02:30 1.75 0 0 COMPZ RPCOM RURD P Strap and kick out decompletion. C/O floor equipment. 02:30 03:00 0.50 0 0 COMPZ RPCOM PULD T M/U Baker Overshot 03:00 04:00 1.00 0 1,763 COMPZ RPCOM TRIP T RIH with BHA#3 overshot assy to 1763 04:00 06:00 2.00 1,763 1,805 COMPZ RPCOM FISH T Establish parameters. PUW/SOW 60K. Free torque @ 30 rpms 650 ft-lbs;210 psi at 20 spm. RIH and tag up at 1,804', Dressed offf tbg stump and engaged fish.set grapple. landed slips with 20 K tension. 06:00 19:00 13.00 1,805 1,805 COMPZ RPCOM ELNE T PJSM: RU Eline to run jet cutter. RIH tagged @ 2530 ft with 125 lbs down weight pick up and continue to RIH with cutter.Tagged again @ 2831 (top GLM)String is sticking. kicked on pumps @ 4 BPM @ 550 psi. POOH removed cutter and made up 2.5"CCL for drift run. RIH with drift run to 7150 ft. POOH with drift run. RIH with 2.25"jet cutter. Continue to pump every few 1000 ft as line kept setting down on something Unable to get the cutter to fire. Short in system POOH. Lay down lubicator in shed 19:00 21:30 2.50 1,805 1,805 COMPZ RPCOM ELNE T E-Line timed out. While waiting on E-Line. Circulate hole volume x 2 at 5 bpm 585 psi. 21:30 00:00 2.50 1,805 1,805 COMPZ RPCOM ELNE T E-Line timed out,While waiting on E-Line work pipe max pull 140K. Pre spud meeting with Mike's crew. Continue working pipe. 12/16/2014 Continue circulating HV and working string while waiting on Eline(timed out), R/U Eline&RIH set down on tubing punch @ 6985', P/U&make tubing cut @ 6950'good indication of cut at surface. POOH w/Eline work tools through tight spot @ 2660', R/D Eline equipment, P/U on string cut free 88k PUW,stand back 1800'of DP, L/D fishing BHA, L/D decompletion tubing 157 jts. Change out floor equipment Page 4 of 38 Time Logs Date From To Dur S. Depth E Depth Phase Code Subcode T Comment 00:00 04:00 4.00 1,805 1,805 COMPZ RPCOM ELNE T Continue working pipe while waiting on E-Line-timed out. 04:00 05:30 1.50 1,805 1,805 COMPZ RPCOM ELNE T Circulate 1.5 x hole volume at 4 bpm 450 psi while waiting on E-Line- timed out. 05:30 12:00 6.50 1,805 1,805 COMPZ RPCOM ELNE T R/U E-Line. RIH with 2.25"jet cutter. RTC cutter was setting down on top of tubing punch. Made clean cut @ 6950',good indication at surface. While POOH had to work string to get through tight spot @ 2660'. Max pull to pull through tight spot after numerous pumping attempts. Tool came free. POOH. 12:00 14:00 2.00 1,805 6,947 COMPZ RPCOM ELNE T PJSM-RD E-line tools and surface equipment. P/U on tubing string-cut free with 88K upweight. 14:00 16:00 2.00 6,947 5,100 COMPZ RPCOM TRIP P Stand back DP to 1800'. C/O rig floor equipment to 2 7/8"and pump dry job. 16:00 17:30 1.50 5,100 3,300 COMPZ RPCOM PULL P Begin pulling 2 7/8"decompletion. 17:30 19:00 1.50 3,300 3,300 COMPZ RPCOM OTHR P Strap 2 7/8"tubing, unload shed. 19:00 23:30 4.50 3,300 0 COMPZ RPCOM PULL P Continue pulling decompletion f/ 3300' 157 jts 1 cut jt 23:30 00:00 0.50 0 0 COMPZ RPCOM RURD P Clean and clear floor, change out floor equipment. 12/17/2014 M/U BHA#4 Overshot&RIH t/6780', Slip and Cut Drilling Line, Latch fish @ 6938',Jar free on 10th hit 80k over, Circ Bottoms up, Observe well for flow static, POOH Standing Back Dp, L/D BHA Fish&Eline tools, Change out floor equip, M/U BHA#5 RIH w/Clean out Assy.t/7590'Wash down Tag top of PBR w/NoGo @ 7626'CBU, OWFF Well Static. 00:00 01:30 1.50 0 308 COMPZ RPCOM PULD P M/U Overshot BHA#4 as per Baker RIH 01:30 04:00 2.50 308 6,780 COMPZ RPCOM TRIP P RIH w/BHA#4 Overshot on 3.5" DP f/308't/6780' 04:00 05:30 1.50 6,780 6,780 COMPZ RPCOM SLPC P Slip and Cut Drilling Line 05:30 06:30 1.00 6,780 6,938 COMPZ RPCOM JAR P P/U weight above fish 125K, 98K down. Latch fish @ 6938' RKB, P/U to 150K,good latch. Begin jarring 80K over-straight pull 80K over, seals pulled free on 10th hit. 06:30 08:00 1.50 6,938 6,900 COMPZ RPCOM CIRC P P/U one joint, circulate B/U @ 5 bpm, 1100 psi. 08:00 08:30 0.50 6,900 6,900 COMPZ RPCOM OWFF P No-flow 08:30 12:00 3.50 6,900 700 COMPZ RPCOM TRIP P TOOH with seal assembly, standing back DP. Page 5 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 700 0 COMPZ RPCOM PULL P Lay down overshot&jars,single out remaining decompletion from TOF- total of 696' Pulled 6 joints, pup, GLM,pup. E-line tool found in 3rd joint below GLM roughly 7260'. Lay down E-line tool by breaking out joints in mousehole. Continue to lay down decompletion. Remaining joints from 7260 to 7634' were full of cement/slight trapped pressure between the breaks,slowly bleed off pressure. Seal assembly full of cement on inside but clean on outside-lenght 12.40', OD is 3.25" 17:00 18:15 1.25 0 49 COMPZ WELLPF RURD P Clean up rig floor,swap out handling equipment. P/U 7"scraper run BHA with 2 7/8"stinger that will no-go out @ 11.40'ft. 18:15 21:15 3.00 49 7,626 COMPZ WELLPF TRIP P RIH w/clean out BHA#5 t/7590' Wash down Tag top of PBR NoGo @ 7626'Observe pressure Increase 300 psi. 21:15 23:30 2.25 7,626 7,626 COMPZ WELLPF CIRC P Circulate bottoms up @ 6 bpm 1630 psi, Observe gas cut mud @ 2200 stks, Circ 330 bbls. 23:30 00:00 0.50 7,626 7,626 COMPZ WELLPF OWFF P Observe well f/Flow Static 12/18/2014 POOH w/clean out BHA, L/D BHA, M/U Dutch Riser, R/U Digital Slickline, Pressure test Lubricator t/1000 psi, RIH w/CBL Logging tool, Log well f/7423'TOC 1100' POOH, RIH w/#1 RBP set @ 4990'WLM, POOH, Rehead running tool, slickline crews change out, M/U RBP#2 RIH&set© 1607'WLM 00:00 03:30 3.50 7,626 0 COMPZ WELLPF TRIP P POOH Standing back DP 4"f/7626' 03:30 04:30 1.00 0 COMPZ WELLPF PULD P LD BHA 04:30 05:30 1.00 0 0 COMPZ WELLPF SLKL P R/U Dutch riser, clean up rig floor. 05:30 10:30 5.00 0 0 COMPZ WELLPF SLKL P PJSM-R/U Digital Slickline.Test lubricator to 1000 psi. 10:30 16:30 6.00 0 0 COMPZ WELLPF QEVL P RIH for CBL. Begin logging @ 7423'. Logs indicate TOC 1040'and possible deformation or damage of 7" @ 1045' 16:30 18:30 2.00 0 0 COMPZ WELLPF SLKL P Run first RBP to a setting depth of 4990'WLM, POOH rehead running tool. 18:30 19:00 0.50 0 0 COMPZ WELLPF PRTS P Pressure test RBP#1 t/1000 psi f/ 10 min good test. 19:00 23:00 4.00 0 0 COMPZ WELLPF SLKL P Rehead DSL running tools for#2 RBP, Change out Eline crews. 23:00 00:00 1.00 0 0 COMPZ WELLPF SLKL P M/U RBP#2 RIH set @ 1607'WLM. Test 1000psi/10 min. Page 6 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/19/2014 24 hr summary POOH w/Running tool, L/D Running tool, M/U dump bailer BHA fill dump bailer w/sand,Attempt to dump bailer on top of RBP, POOH Bailer full, Reload bailer w/dry sand, RIH atempt second dump run attempt t/ dump on RBP, POOH didn't dump, mix slurry sand, RIH Attempt third bailer dump POOH, Failed, R/D Bailer Assy. M/U Jet Cutter Assy. RIH cut 7"Casing @ 1050' POOH, R/U&Test BOP's 250/4000 psi w/3.5",4.5" &7"test jts, R/D Test equipment RIH w/DP t/1587' displace well over V heated water, R/U and dump 16 sacks 40'of sand on top of RBP. 00:00 02:30 2.50 0 0 COMPZ WELLPF SLKL P POOH w/RBP running tool. L/D Running tool M/U Dump bailer Assy. Load w/sand, _ 02:30 07:00 4.50 0 0 COMPZ WELLPF SLKL T RIH w/Dump Bailer attempt to dump sand POOH unable to dump sand, packed off in bailer, Reload Bailer, RIH make second attempt to dump sand POOH Bailer packed off wouldn't dump. Mix slurry with soap/detergent to try and attempt third time. No-luck 07:00 10:00 3.00 0 0 COMPZ WELLPF SLKL P R/U jet cutter-RIH make 3 passes. Tie in correction, +5 ft. Set at cutting depth of 1050'-1052'. CCL depth 1032'. Fire and good indication of cut casing. Monitor OA. No change. Pump down 7"at 2 bpm,230 psi no pressure build,good indication of cut/communication. Stop pump. 10:00 11:30 1.50 0 0 COMPZ WELLPF SLKL P POOH with DSL&RD equipment for release. 11:30 12:30 1.00 0 0 COMPZ WELLPF SLKL P RD Dutch riser, install test plug. 12:30 13:00 0.50 0 0 COMPZ WHDBO BOPE P Fill stack begin testing BOPE 250/4000 psi. State test waived witness by Matthew Herrera 13:00 16:30 3.50 0 0 COMPZ WHDBO BOPE P 1) Blind, Kill#13, Choke#11,12,4, 3 1/2"dart, Hyd TD. 2) Blind, Kill HCR, Choke#3,7,9,10, 3 1/2"floor valve, Man TD. (floor valve test stump leaked)Re-test. 3)3 1/2"LPR, 3 1/2"FOSV, Choke #2,5,8. 4)3 1/2"annular, 3 1/2"FOSV, Choke#2,5,6, Man Kill. 5)7" UPR, Man kill, Choke HCR, Choke#1. 6)7"annular, Man Kill, Choke Man, Choke#1. 16:30 17:00 0.50 0 0 COMPZ WHDBO BOPE P Draw down test. Initial 3050 psi , closure 2050 psi. 200 psi/16 secs,full system 77 secs. 17:00 18:00 1.00 0 0 COMPZ WHDBO RURD P Lay down test joint, drain stack, pull test plug&K/O test joints. 18:00 19:30 1.50 0 1,590 COMPZ WELLPF TRIP P RIH w/3.5" DP U 1590' DP tag up on RBP,work through thight spots f/ 1515'down U 1585'take 5-10k 19:30 20:00 0.50 1,590 1,590 COMPZ WELLPF SVRG P Service rig and top drive. Page 7 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:00 2.00 1,590 1,590 COMPZ WELLPF CIRC P Reverse circulate heated water down IA taking returns t/pits, Losses observed while circ. no visible pressure increase on OA while pumping, Shut down circulate long _ way until returns clear up. 22:00 00:00 2.00 1,590 1,590 COMPZ WELLPF CIRC P Dump sand 16 sacks 40'of sand on RBP 12/20/2014 Dump sand 40'on RBP,wait on sand, Pull up t/990'Displace arctic pac @ 6 BPM 400 psi,wait on heated sea water,displace 150 bbls heated water 6 bpm 400 psi, POOH standing back DP,drain stack N/D BOPE, grow stack 8 3/8"w/hydra tight, N/D tubing spool, pull pack off, N/U DSA and spacer spool, N/U BOP Stack, Attempt t/pull 7"slips hanging up in stack,split stack remove slips, M/U stack, Pull 7"to rig floor, L/D spear, UD 7"Casing to shed. 00:00 01:45 1.75 1,590 1,590 COMPZ WELLPF CIRC P Dump sand on RBP down DP 16 total sacks 40'of sand on RBP 01:45 02:45 1.00 1,590 990 COMPZ WELLPF TRIP P Work and reciprocate pipe spot sand in place POOH t/990'. 02:45 03:30 0.75 990 990 COMPZ WELLPF CIRC P R/U&Dispace Arctic pac to tiger tank 6 bpm 400 psi 03:30 06:00 2.50 990 990 COMPZ WELLPF CIRC P Blow down lines let OA sit with hot water for 40,minutes, circ additional 150 bbls out to kill tank. 06:00 06:30 0.50 990 0 COMPZ WELLPF TRIP P TOOH standing back DP. 06:30 07:30 1.00 0 0 COMPZ WELLPF OWFF P Suck out stack and monintor OA- no flow. Crew change. 07:30 09:30 2.00 0 0 COMPZ WELLPF NUND P PJSM-ND BOPE 09:30 12:30 3.00 0 0 COMPZ WELLPF NUND P ND tubing hanger, R/U hydrotight equipment for casing growth.Total of 8-3/8"of growth. Pull casing pack-off 12:30 18:30 6.00 0 0 COMPZ WELLPF NUND P Begin NU casing spool, DSA, Cement Cross and BOPE 18:30 21:00 2.50 0 0 COMPZ WELLPF NUND T Attepmt to pull 7"casing, M/U Spear engage casing stub, P/U 68k free pipe, P/U 20'Slips grabbing in stack work pipe unable to get through stack with slips. Split&rqaise stack remove slips, set down and tighten flange. 21:00 23:30 2.50 0 0 COMPZ WELLPF PULL P Pull 7"casing t/floor break out spear L/D casing stub, L/D 7"Casing to pipe shed. 24 full jts 1 pup and 2 cut jts. Total Length 1005.38'of casing pulled, 1034' RKB.Total casing versus original tally is complete tie back pulled,cut on 1st joint of lower casing completion. No centrilizers ran according to original tally. 23:30 00:00 0.50 0 0 COMPZ WELLPF RURD P Clean and clear rig floor, Break down spear assy. 12/21/2014 Set test plug&test BOP Breaks t/250/3000 psi, R/D test equip. M/U Clean Out BHA, RIH t/7"Casing stub no hole issues encountered, POOH, L/D Clean Out BHA, M/U Rigid milling Assy, RIH t/7"Casing Stub @ 1032'Circ 2 bottoms ups, Light sand returns, no losses, POOH, L/D BHA M/U 7" Dress off BHA, RIH , Mill& Dress off 7"casing f/1034't/1041', Pump Hi Vis Sweeps, POOH Inspect Milling BHA, shaving of 7"casing around inner mill, M/U Dress off BHA RIH t/1034'Wash over 7"casing&mill f/1041't/1043'Pump Hi Vis sweep, POOH Page 8 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 COMPZ WELLPF RURD P P/U BHA Components, R/U Test equipment, M/U test Jt&Test plug, test breaks t/250/3000 psi . R/D Test equipment, Set wear ring. 03:00 04:00 1.00 0 328 COMPZ WELLPF PULD P M/U Clean Out BHA#7 04:00 04:45 0.75 328 1,032 COMPZ WELLPF TRIP P RIH w/BHA#7&clean out surface casing U 1032' DP No Obstructions encountered. 04:45 06:45 2.00 1,032 0 COMPZ WELLPF TRIP P POOH Change out BHA as pre BOT rep. 06:45 07:45 1.00 0 330 COMPZ WELLPF PULD P P/U BHA#8 Ridgid mill assembly. 07:45 09:15 1.50 330 1,034 COMPZ WELLPF TRIP P TIH to top of 7 @ 1034', circ two B/U @ 6 bpm, no losses, light sand/fill to surface. TOOH 09:15 10:15 1.00 330 317 COMPZ WELLPF PULD P Lay down BHA#8, P/U BHA#9-7"dress off milling assembly. 10:15 11:00 0.75 317 1,034 COMPZ WELLPFTRIP P TIH-P/U weight off bottom 62K 11:00 17:00 6.00 1,034 1,042 COMPZ WELLPF MILL P Free torque-700#, 50 RPM, 8 bpm @ 350 psi. Begin milling @ 1034'- set down 5K,torque 1600-2600#, continue milling.Average 1 fph milling, light metal shaving mixed with cement sheath. Pump sweeps 1 per hour. Milled 5ft of swallow with 2-3 ft of dressing on casing lip. Just prior to final depth, mill torqued up to 6000#and stalled, P/U off bottom-clean,drift down clean, attempt to rotate but torqued up again. Pump final sweep prior to POOH. 17:00 18:00 1.00 1,042 42 COMPZ WELLPF TRIP T TOOH 18:00 20:00 2.00 42 316 COMPZ WELLPF PULD T Break and inspect milling BHA. Found junk around inner mill assy. M/U same milling assy. RIH 20:00 20:30 0.50 316 1,032 COMPZ WELLPFTRIP T RIH w/BHA#9 Milling Assy.U 1032' 20:30 22:30 2.00 1,032 1,043 COMPZ WELLPF MILL T Wash down tag top of stub @ 1034' wash over stub U 1041'Mill down U 1043'5-7k WOB 107 spm 2500-3500 torque, Pump hi vis sweep, Dress stub f/1035'U 1037'Average 1.5 fph 22:30 23:30 1.00 1,043 42 COMPZ WELLPFTRIP T POOH w/BHA#10 Milling Assy. 23:30 00:00 0.50 42 0 COMPZ WELLPF PULD T Break&Inspect BHA, Found junk around inner milling Assy. L/D BHA. 12/22/2014 RIH w/Multi String Cutter tag top of stub @ 1037'unable to get down, POOH, M/U Taper Mill and string Mill Assy, RIH work through 7"stub U 1060', POOH, M/U Multi String Cutter RIH Locate collar below stub, P/U 8' Make cut @1047', POOH inspect cutter knives slight wear on leading edge, RIH w/spear attempt U engage fish, multiple attempts, NoGo POOH, Inspect spear slips not engaged, RIH attempt to latch fish setting down @ 1037', POOH No, Fish, RIH w/Taper/String Mill work through stub, POOH, M/U Spear RIH,Attempt U engage fish 15k over pull came free 5k drag f/7', POOH, Grapple in release position, RIH w/Spear w/ String/Taper Mill NoGo on stop sub unable to latch fish. POOH inspect BHA, Grapple missing. L/D Spear BHA Page 9 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 1,037 COMPZ WELLPF PULD T M/U Multi string cutter BHA RIH t/7" Casing Stub @ 1037' Unable to get into 7"work string NoGo 02:00 02:30 0.50 1,037 0 COMPZ WELLPF TRIP T POOH w/Multi String Cutter BHA #11 02:30 04:00 1.50 0 1,057 COMPZ WELLPF PULD T M/U Taper/String Mill BHA RIH t/ 1057'work throught stub w/rotary and pumps. 04:00 05:00 1.00 1,057 0 COMPZ WELLPF TRIP T POOH w/BHA#12 L/D BHA 05:00 06:00 1.00 0 0 COMPZ WELLPF PULD T P/U BHA#13-multi string cutter. 06:00 08:30 2.50 0 1,047 COMPZ WELLPF CPBO T TIH and slide through top of 7"@ 1036', located next collar @ 1054'by pumping 1 bpm.Work string two more times to ensure correct depth/collar. P/U 8 ft and begin making cut on 7"casing. Made cut @ 1047' RKB 08:30 10:00 1.50 1,047 0 COMPZ WELLPF PULD T TOOH, lay down BHA#13. Inspect cutter blades, light wear on cutters showing a possible indication of cut. Lay down Cutter&P/U BHA#14- _ 7"spearing assembly. 10:00 12:00 2.00 0 1,036 COMPZ WELLPF FISH T TIH with spear-attempt to latch into fish @ 1036'. No luck. Made multiple attempts, pumping and dry with no indication of making any progress. Tapered mill @ 1043'slips tagging up @ 1036' 12:00 13:30 1.50 0 1,036 COMPZ WELLPF TRIP T TOOH, inspect tool-slips were not in engaging position. Change out slips and TIH to attempt to fish 6' casing stub. 13:30 14:00 0.50 1,036 1,036 COMPZ WELLPF FISH T Make single attempt to latch into fish,tag/no go in same spot as first run. Pull out of hole to inspect to see if any physical evidence of stacking on spear. 14:00 14:30 0.50 1,036 0 COMPZ WELLPF TRIP T TOOH-no luck,single mark/goove around bottom of slip. 14:30 15:00 0.50 0 240 COMPZ WELLPF PULD T Lay down Spear BHA#15, P/U BHA #16-6 1/8"tapered and watermellon mill. 15:00 16:30 1.50 240 1,072 COMPZ WELLPF TRIP T RIH w/Taper mill BHA,dress off into 7"casing stub t/1072'dress stub. 16:30 17:30 1.00 1,072 0 COMPZ WELLPF PULD T POOH w/BHA#16 Taper Mill Assy. M/U BHA#17 Spear Assy w/taper Mill 17:30 18:30 1.00 0 1,037 COMPZ WELLPF TRIP T RIH w/spear Assy. Engage fish @ 1037'Over pull 15k straight pull, came loose 5k drag f/7' 18:30 19:30 1.00 1,037 0 COMPZ WELLPF TRIP T POOH w/spear Assy BHA#17 19:30 20:00 0.50 0 0 COMPZ WELLPF PULD T Inspect BHA, No Fish, Grapple in release position. Reset grapple. Page 10 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:30 2.50 0 1,037 COMPZ WELLPF TRIP T RIH w/spear Assy.w/Taper Mill, Engage fish @ 1037'work spear 25k over pull, pulling off, atttempt t/ swallow 6'only getting 4'of travel, attempt t/dress off 7"w/string/ tapered mill, attempt t/re-engage 7" w/spear, Unable to grab. 22:30 23:00 0.50 1,037 0 COMPZ WELLPF TRIP T POOH 23:00 00:00 1.00 0 42 COMPZ WELLPF PULD T Inspect BHA Grapple missing off spear, L/D Spear BHA, M/U BHA# 18 Tandem Mill Assy. RIH 12/23/2014 RIH with Tandem Mill Assembly and clean up the top of the 7"casing. RIH with 7"casing spear assembly, engage the 7"casing with spear at 1041.5', and begin jarring. After two jar hit something broke free, POOH, and no fish recovered. RIH with multi string cutter, located the first cut at 1047',and cut the 7"casing for the second time at 1047'. RIH with spear,engage the 7"casing at 1037', begin jarring,and after two jar hits at 50K over spear pulled free. POOH and no fish recovered. RIH with Wavy Mill Shoe,tagged at 1040', and started to attempt to work over 7"stub. Town Engineer decided to make a camera run. RIH with 2-7/8"mule shoe but unable to make it past 1042'. RIH with tapered mill/string mill assembly and still unable to make it past 1037'. 00:00 01:30 1.50 42 1,036 COMPZ WELLPF TRIP T RIH w/Tandem Mill Assy.Attempt V Mill on 7"Casing stub 01:30 03:30 2.00 1,036 1,052 COMPZ WELLPF MILL T Mill on 7"Casing stub stalling out, Work Through make 3 passes, Clean stub up running in and reaming up. 03:30 04:30 1.00 1,052 0 COMPZ WELLPF TRIP T POOH w/String Mill BHA LID BHA 04:30 05:00 0.50 0 1,051 COMPZ WELLPF PULD T M/U Spear BHA RIH t/1051'. 05:00 06:00 1.00 1,051 1,053 COMPZ WELLPF FISH T Engage fishing neck,Tapered mill @ 1053'-grapple on spear @ 1041.5'. Almost 1 ft deeper than last spearing run. P/U 30K-begin working spear on fish. Jars warming up and fired 30K over,straight pull 60K over. Second time something broke free. 06:00 06:30 0.50 1,053 0 COMPZ WELLPF TRIP T POOH to inspect. No fish on spear. 06:30 08:00 1.50 0 0 COMPZ WELLPF PULD T Lay down BHA#20, P/U BHA#21 - casing cutter. 08:00 09:00 1.00 0 1,047 COMPZ WELLPF TRIP T TIH and locate previous cut @ 1047' 09:00 10:30 1.50 1,047 1,047 COMPZ WELLPF CPBO T Pump 3 bpm, blades located old cut A@ 1047.40',stop pumping drift area X2. Clean,engage pumps again, locate cut at same mark. Begin cutting pipe to ensure clean cut on 7" 10:30 11:00 0.50 1,047 0 COMPZ WELLPF TRIP T TOOH with cutter 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD T Cutting surface on blades indicate good cut. P/U Spear assembly. BHA #22 12:00 13:00 1.00 0 0 COMPZ WELLPF TRIP T TIH, latch top of 7"@ 1037'with spear, pulled 30K over,jar X 2 @ 50K over spear pulled free. POOH. 13:00 13:30 0.50 0 0 COMPZ WELLPF PULD T Lay down Spear assembly. 13:30 14:30 1.00 0 0 COMPZ WELLPF SLPC T Slip and cut drilling line. Page 11 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 16:30 2.00 0 1,040 COMPZ WELLPF TRIP T TIH with BHA#23-Wavy Mill Shoe to tag at 1040', PU=57K and SO= 62K. 16:30 17:30 1.00 1,040 1,040 COMPZ WELLPF MILL T PU,start circulating at 6 BPM= 150, SO,and tag at 1040'. PU and attempt to rotate past obstruction at 30 RPM,free torque=300 ft-lbs with 3K-5K down. Town Engineer decided to make a camera run. 17:30 18:45 1.25 1,040 0 COMPZ WELLPF TRIP T TOOH with BHA#23. 18:45 19:45 1.00 0 0 COMPZ WELLPF PULD T Lay down BHA#23. PU and MU BHA#24-2-7/8"Mule shoe assembly 19:45 21:00 1.25 0 1,042 COMPZ WELLPF TRIP T TIH with BHA#24. Tagged at 1037', work down to 1042'with 5K down but unable to make it any deeper 21:00 21:30 0.50 1,042 0 COMPZ WELLPF TRIP T TOOH with BHA#24 and lay down. 21:30 22:00 0.50 0 405 COMPZ WELLPF TRIP T PU, MU, and TIH with BHA#25- Tapered Mill/String Mill assembly 22:00 23:00 1.00 405 405 COMPZ WELLPF RGRP T Hydraulic hose on the top drive grabber box failed and spilling approximately 3 cups into containment. Cleaned up hydraulic fluid and replaced failed hydraulic hose. 23:00 00:00 1.00 405 1,037 COMPZ WELLPF TRIP T Continue to TIH with BHA#25 and tag at 1037'. Attempt to work into 7" without success. 12/24/2014 Circulate the well over to clean fresh water with 276 bbls. RU E-Line and RIH with EV camera log. Images show top of 7"has a rough section of pipe from 1036-1038'. RD E-Line and TOOH with E-Line guide shoe. RIH with tandem string mills with 3-1/2"mule shoe joint to top of the stub at 1037'. Work into stub with and SO down to 1090'with the mule shoe. Work string mills across stub several times, shut down rotary/pumps, PU above stub,and attempt to slide into stub but tagged at 1042'. Try to work down past 1042'varying parameters without success. RIH string mill assembly with 5'mule shoe pup joint,tag stub at 1037', attempt to work into stub with 1/4, 1/3, and 1/2 turns, rotate at 10 RPM and got the mule shoe into the stub. RIH to 1077', back ream up to stub with mills and work past stub with both mills several times with 10 BPM=500 psi and rotating from 10 RPM up to 70 RPM with 300-1100 ft-lbs of torque. 00:00 00:45 0.75 1,037 1,037 COMPZ WELLPF CIRC T Circulate the well over to clean fresh water at 8 bbls min=440 psi with 276 bbls. 00:45 02:00 1.25 1,037 0 COMPZ WELLPF TRIP T TOOH with BHA#25 and lay down. 02:00 02:30 0.50 0 6 COMPZ WELLPF PULD T PU and MU BHA#26-E-line guide shoe 02:30 03:30 1.00 6 1,029 COMPZ WELLPF TRIP T TIH with BHA#26 and space out for good working height for E-line(shoe depth= 1029'). 03:30 08:00 4.50 1,029 1,029 COMPZ WELLPF ELOG T Wait for E-line to arrive. 08:00 10:00 2.00 1,029 1,029 COMPZ WELLPF ELOG T PJSM-rig up E-line. Page 12 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 15:00 5.00 1,029 1,029 COMPZ WELLPF ELOG T RIH with E-line for DHV log.Images show top of 7"has a rough section of pipe from 1036-1038'. Fluid was too murky below 1040'to identify any other images. Circulate @ 2bpm, cleaner images around 1036'- Attempt to inject clean water @ 1 bpm 290 psi. Images did not clean up below 1038'. Clear images in DP &E-line entry guide but not in cased hole. 15:00 16:00 1.00 1,029 1,029 COMPZ WELLPF ELOG T RD E-line-crew left location @ 16:00 hrs left equipment R/U. 16:00 17:00 1.00 1,029 0 COMPZ WELLPF TRIP T TOOH with E-line shoe guide 17:00 18:30 1.50 0 0 COMPZ WELLPF PULD T Lay down BHA#26. PU and MU BHA#27-String Mill assembly with 3-1/2"mule shoe joint. 18:30 19:00 0.50 0 1,010 COMPZ WELLPF TRIP T TIH with BHA#27 to 1010', PU= 57K, and SO=60K. 19:00 21:00 2.00 1,010 1,042 COMPZ WELLPF REAM T RIH,tag stub at 1037',work into stub with 1/4 turn, and SO down to 1090' with the mule shoe(upper string mill below MSC cut). Break circulation at 10 BPM=600 psi and back ream out to 1067'; lower mill at 1036 and work to 1044'with lower mill four time. Shut down rotary and pumps, PU above stub and attempt to slide into stub but tagged at 1042'. Try to work down past 1042'varying parameters without success. 21:00 21:45 0.75 1,042 0 COMPZ WELLPF TRIP T TOOH with BHA#27 21:45 22:00 0.25 0 0 COMPZ WELLPF PULD T Lay down BHA#27. PU and MU BHA#28-String Mill assembly with 5'mule shoe pup joint. 22:00 22:30 0.50 0 1,010 COMPZ WELLPF TRIP T TIH with BHA#28 to 1010', PU= 57K, SO=60K, and Rotating=60K. 22:30 00:00 1.50 1,010 1,077 COMPZ WELLPF REAM T RIH,tag stub at 1037', attempt to work into stub with 1/4, 1/3, and 1/2 turns, rotate at 10 RPM and got the mule shoe into the stub. RIH to 1077', back ream up to stub with mills and work past stub with both mills several times with 10 BPM= 500 psi and rotating from 10 RPM up to 70 RPM with 300-1100 ft-lbs of torque. 12/25/2014 Continue to work string mills across stub and attempt to slide into casing stub without rotation with any success. Entered casing stub several time with rotation. RIH with 7"casing spear,worked into casing stub by rotating at 10 RPM, shut down the rotary, and SO to put grapple at 1044'. PU with 40K overpull and saw movement up with slight drag. TOOH with fish and lay down 7"casing fish. RIH with 8-1/2"string mill and work 9-5/8"casing to just above the casing stub. RIH with 8-3/4"string mill and work 9-5/8"casing to just above the casing stub. RIH with 6-1/8" RCJB,cleanout down to top of casing stub at 1047', and recovered nothing in the RCJB. RIH with 8-1/2" RCJB, cleanout down to top of casing stub at 1047',and recovered nothing in the RCJB. RIH with 8-1/2"wavy bottom shoe,attempt to slide over casing stub at 1047.5'without success; attempt several times varying parameters still without success. Page 13 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:30 1.50 1,077 1,037 COMPZ WELLPF MILL T PU above 7"casing stub, attempted to slide into stub without success. Rotated at 10 RPM and were able to enter stub. Reamed stub with mill with the same parameters multiple times. PU above stub but still had to rotate to get into the stub. Repeated several times. 01:30 02:00 0.50 1,037 0 COMPZ WELLPF TRIP T TOOH with BHA#28 02:00 03:15 1.25 0 0 COMPZ WELLPF PULD T Lay down BHA#28. PU and MU BHA#29-7"casing spear. 03:15 03:45 0.50 0 989 COMPZ WELLPF TRIP T TIH with BHA#29 to 989', PU =57K, SO=60K, and rotating=60K. 03:45 04:00 0.25 989 1,052 COMPZ WELLPF FISH T RIH and tag stub at 1037'. Work into stub with mule shoe after several attempts rotating at 10 RPM. Shut down rotary and SO to put grapple at 1044'. PU with 20K overpull, set down 5K, PU with 40K overpull and saw movement up with slight drag. 04:00 05:30 1.50 1,052 0 COMPZ WELLPF TRIP T Slowly TOOH with BHA#29. 05:30 06:30 1.00 0 0 COMPZ WELLPF PULD T Lay down BHA#29 and 7"casing fish. 06:30 09:30 3.00 0 0 COMPZ WELLPF RURD T Break down BOT fishing spear, had to use cutting torch in pipe shed area to cut off 7"fish in order to break down the rest of the BHA. Bring in mills and 9 5/8"assembly for drift/ dressing runs. 09:30 12:30 3.00 0 1,052 COMPZ WELLPF TRIP T TIH with BHA#30 with 8.5"string mill. First tag © 1044', rotate 1/2 turn and drifted down to 1053'. P/U establish pump/torque parameters. Slowly ream down seeing work @ 1047', made it down to 1052' (1 ft above top of 7"with string mill. Light cement returns, very light metal shavings on magnets. Stop rotating, P/U and drift. Tagged as drifting down© 1047', (mule shoe depth). Work string twice pumping © 6 bpm, had to make 1/2 turn to slip into 7"casing. drift through twice to 1052'.TOOH 12:30 14:00 1.50 0 0 COMPZ WELLPF PULD T Lay down BHA#30, P/U BHA#31 with 8.75"string mill, and put additional extension below to see if tag up points are different from previous run. (7"casing stub vs 9 5/8") 14:00 15:00 1.00 0 1,077 COMPZ WELLPF TRIP T TIH with BHA#31. Tag @ 1047', P/U and roll into 7"drift down to 1077' pumping 6 bpm. Blow down, TOOH. 15:00 16:30 1.50 1,077 0 COMPZ WELLPF PULD T Lay down BHA#31, P/U BHA#32- 6-1/8"RCJB&string magnets. Page 14 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 0 1,048 COMPZ WELLPF TRIP T TIH to 1030',break circulation at 8 BPM= 1050 psi and wash down to tag at 1047.5'. PU and wash from 1030'to 1047.5' 17:30 18:00 0.50 1,048 0 COMPZ WELLPF TRIP T TOOH with BHA#32 18:00 19:30 1.50 0 0 COMPZ WELLPF PULD T Lay down BHA#32. Nothing in the RCJB and magnets full of metal debris. Clean off magnets. PJSM. PU and MU BHA#33-8-1/2"RCJB. 19:30 20:30 1.00 0 1,048 COMPZ WELLPFTRIP T TIH with BHA#33 20:30 21:00 0.50 1,048 1,048 COMPZ WELLPF WASH T TIH to 1030', break circulation at 8 BPM= 1050 psi and wash down to tag at 1047.5'. PU and wash from 1030'to 1047.5' 21:00 21:30 0.50 1,048 0 COMPZ WELLPF TRIP T TOOH with BHA#33. 21:30 22:15 0.75 0 0 COMPZ WELLPF PULD T Lay down BHA#33. Nothing in the RCJB. PU and MU BHA#34-8-1/2" Wavy Bottom Shoe. 22:15 23:30 1.25 0 1,048 COMPZ WELLPF TRIP T TIH with BHA#34 to 1010'. Attempt to slide over casing stub at 1047.5' without success. Attempt several times varying parameters still without success. 23:30 00:00 0.50 1,048 0 COMPZ WELLPF TRIP T TOOH with BHA#34. 12/26/2014 - RIH with tandem string mill, ream the casing from 1005'to 1045'and attempt to slide into stub without rotation with no success but able to get in with slight rotation. RIH with guided wavy shoe;able to get guide into stub unable to get shoe over stub. RIH with cut lip guide shoe and attempt to work over stub without success. RIH with cut lip guide shoe with carbide on leading edge,to work over stub, made about 8"then were not able to make any more hole. RIH with guided drag tooth shoe and attempt to work over stub without success. TOOH and wait for E-Line. 00:00 01:00 1.00 0 0 COMPZ WELLPF PULD T Lay down BHA#34-8-1/2"Wavy Bottom Shoe. PU and MU BHA#35 -tandem string mill assembly. 01:00 01:30 0.50 0 933 COMPZ WELLPFTRIP T TIH with BHA#35 993', PU =60K, SO=60K, Rotating=62K with 600 ft-lbs torque 01:30 03:30 2.00 933 1,047 COMPZ WELLPF REAM T Break circulation at 8 BPM and wash down to stub set 3K down. PU 3' rotate at 20 RPM, got into stub, SO, and no-go with 5K down. Ream with string mills from 1045'to 1005',60-70 RPM, 600-1000 ft-lbs torque. Pump 23 bbls hi vis sweep at 10 BPM. Attempt to slide into stub without rotation with no success but able to get in with slight rotation. 03:30 04:00 0.50 1,047 0 COMPZ WELLPF TRIP T TOOH with BHA#35 04:00 05:00 1.00 0 0 COMPZ WELLPF PULD T Lay down BHA#35. PU and MU BHA#36-Guided Wavy Shoe. 05:00 06:00 1.00 0 1,047 COMPZ WELLPF TRIP T TIH with BHA#36. Tag and attempt to work cut lip guide over top of 7". Dry tag-no luck,slowly rotate 30 rpm pumping 6 bpm, no luck. Did not want to mill on 7" Page 15 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 06:45 0.75 1,047 0 COMPZ WELLPF TRIP T TOOH 06:45 08:15 1.50 0 0 COMPZ WELLPF PULD T Lay down B HA#36, P/U BHA#37 -cut lip guide"overshot". 08:15 11:15 3.00 0 1,047 COMPZ WELLPF TRIP T Tag @ 1047'-P/U and attempt to roll slowly ove the stub, made about 4-5". Torqued up, hard tag, P/U 3K over. Attempt to drift again, no luck. Torqued up again while trying to roll while going over 7". TOOH 11:15 12:45 1.50 0 0 COMPZ WELLPF PULD T Inspect BHA-inside marks looks like got over the casing stub by 2". Discuss with town and P/U new cut lip guide with carbide on partial bottom of taper. Ground down a thinner lip for BHA#38. 12:45 13:30 0.75 0 1,047 COMPZ WELLPF TRIP T TIH with BHA#38-tag 1047'. 13:30 16:30 3.00 1,047 1,048 COMPZ WELLPF MILL T Begin milling/rotating over casing with cut lip guide.6 bpm @ 133 psi, 20 RPM @ 400-1600 torque. Pump sweeps @ 8 bpm, light small cement chunk returns, no signs of metal. Continue milling/washing over stub. Could not make any more hole after 8" 16:30 17:00 0.50 1,048 0 COMPZ WELLPF TRIP T TOOH to inspect BHA 17:00 17:30 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#38 17:30 19:00 1.50 0 0 COMPZ WELLPF OTHR T Call town eningeer and discuss results of last run, options, and plan forward. 19:00 19:30 0.50 0 0 COMPZ WELLPF PULD T PU and MU BHA#39-Guided Drag Tooth Shoe. 19:30 20:00 0.50 0 989 COMPZ WELLPF TRIP T TIH with BHA#39 to 989', PU =58K, SO=62K, rotating=61K, 50 RPM, free torque=500 ft-lbs, 8 BPM =250 psi. 20:00 21:00 1.00 989 1,056 COMPZ WELLPF MILL T SO and slide into stub without issue and tag with 5K down at 1047.5'with the shoe. PU and rotate at 20 RPM, SO, and tag at same spot. Rotate at 50 RPM, tag with 5K, and not making any hole. PU, rotate at 20 RPM,tag with 10K, and same result. PU, rotate at 50 RPM, tag with 10K, and still no making any hole. 21:00 21:30 0.50 1,056 0 COMPZ WELLPF TRIP T Call town engineer and discuss options. Decision is to run caliper and gryo with E-line. TOOH with BHA#39 21:30 22:00 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#39. 22:00 00:00 2.00 0 0 COMPZ WELLPF ELOG T Wait for E-line(ETA 06:00 hours) Page 16 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12/27/2014 24 hr Summary Wait for E-Line(E-Line arrived at 07:00 hours). Test BOPE to 250/3000 psi(BOPE test pressure max. of 3000 psi due to casing head rating)with 3-1/2"and 7"test joint;witness of BOPE test waived by AOGCC inspector John Crisp on 12/27/14 at 05:28 hours. RU E-Line, RIH with CBL and caliper logging tools and log from 1250-750'. Data shows cut @ 1047'and light deformation in 9 5/8"@ 1030'-1040'. Cement is present behind pipe. RIH with gyro and log from 1250'to surface. RIH with 5'string shot#1 but unable to get into stub at 1047', made several attempts without success. RD E-Line in order to run DP to provide guide for E-Line. E-Line timed out. PU and MU 6-1/8"String Mill Drift assembly. 00:00 05:30 5.50 0 0 COMPZ WELLPF ELOG T Wait for E-line(ETA 06:00 hours) 05:30 08:30 3.00 0 0 COMPZ WELLPF RURD T Spoke with John Crisp-waived witness of BOPE test. BOPS test pressure max. of 3000 psi due to casing head rating. Pull wear ring,flush stack, install test plug with Cameron rep.(install blanking plug in test plug). E-line arrived on location @ 07:00 hrs,spot, re-head,test line while waiting on BOPE test. 08:30 12:00 3.50 0 0 COMPZ WHDBO BOPE T 1)Blind, Kill#13, Choke#11,12,4, 3 1/2"dart, Hyd TD. 2)Blind, Kill HCR, Choke#3,7,9,10, 3 1/2"floor valve, Man TD. 3)3 1/2"LPR, 3 1/2"FOSV, Choke #2,5,8. 4)3 1/2"annular, 3 1/2"FOSV, Choke#2,5,6, Man Kill. 5)7"UPR, Man kill, Choke HCR, Choke#1. 6)7"annular, Man Kill, Choke Man, Choke#1. 12:00 12:30 0.50 0 0 COMPZ WHDBO BOPS T Draw down test. initial 3050 psi, after closure 2000psi, 200 psi-14 seconds, full system-79 seconds. Bottles 1900 psi. 12:30 13:00 0.50 0 0 COMPZ WHDBO RURD T Pull 7"test joint, pull test plug. 13:00 14:30 1.50 0 0 COMPZ WELLPF FLOG T PJSM-R/U E-line on rig floor. 14:30 18:00 3.50 0 0 COMPZ WELLPF FLOG T RIH with CBL&caliper logging tool from 1250'-750'. Data shows cut @ 1047'and light deformation in 9 5/8" @ 1030'-1040'. Cement is present behind pipe. 18:00 20:30 2.50 0 0 COMPZ WELLPF FLOG T Run GYRO from 1250'-surface. 20:30 23:30 3.00 0 0 COMPZ WELLPF ELNE T PU, MU, and RIH with 5'string shot #1. Unable to get into stub at 1047', made several attempts without success. POOH,disarm firing head, and RD E-Line in order to run DP to provide guide for E-Line. E-Line timed out. 23:30 00:00 0.50 0 0 COMPZ WELLPF PULD T PU and MU BHA#40-6-1/8"String Mill Drift assembly. Page 17 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/28/2014 24 hr Summary TIH with 6-1/8"String Mill Drift work into top of 7"with 1/2 turn, RIH to 1069'and set down 5K on obstruction. PU,start slowly rotating/pumping,weight fell off, and obstruction moved down. Continue to RIH with 1-2K drag to 1452'and set down 5K. PU 15', SO,and continue to RIH to 1512'. At 1512'set 10K down three times. Attempted to drift thru 7"stub with tapered mill without success. RIH with E-Line guide shoe and wait for E-Line to arrive. RU E-Line,fire string shot#1 centered at 1056'and string shot#2 at 1051'. RIH with back-off tool assembly filling every stand with diesel and attempt to back-off 7"casing without success. 00:00 02:45 2.75 0 1,512 COMPZ WELLPF TRIP T TIH with BHA#40,work into top of 7" with 1/2 turn, RIH to 1069'and set down 5K on obstruction. PU 3', rotate at 10 RPM, pump at 8 BPM= 250 psi, SO,set down 2K, and torque stalled out at 6500 ft-lbs. Let torque out, PU, SO with 1-2K, bouncing on obstruction torque 350-1200 ft-lbs,weight fell off, and obstruction moved down. Continue to RIH with 1-2K drag to 1452'and set down 5K. PU 15, SO, and continue to RIH to 1512'. At 1512' set 10K down three times(top of sand/debris pile). 02:45 03:30 0.75 1,512 0 COMPZ WELLPF TRIP T TOOH with BHA#40-6-1/8"String Mill Drift. 03:30 04:00 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#40. PU and MU BHA#41 -Tapered Mill Drift 04:00 04:30 0.50 0 1,047 COMPZ WELLPF TRIP T TIH with BHA#41 to 1047'but unable to drift into stub with tapered mill. 04:30 05:00 0.50 1,047 0 COMPZ WELLPF TRIP T TOOH with BHA#41 05:00 05:30 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#41. PU and MU BHA#42-E-Line guide shoe. 05:30 06:15 0.75 0 1,050 COMPZ WELLPF TRIP T TIH with BHA#42 to 1050'. 06:15 10:30 4.25 0 0 COMPZ WELLPF ELNE T Wait for E-Line to arrive(ETA 09:00 hours). 10:30 13:00 2.50 0 0 COMPZ WELLPF ELNE T Eline arrived on location 10:30. PJSM @ 11:30-R/U equipment for string shot runs. 13:00 17:00 4.00 0 0 COMPZ WELLPF ELNE T RIH-log and perform string shot#1 @ 1056'. POOH,good indication of shot, rebuild second run and fire second string shot @ 1051'. POOH with E-line. 17:00 18:00 1.00 0 0 COMPZ WELLPF ELNE T RD E-Line 18:00 19:00 1.00 1,050 0 COMPZ WELLPF TRIP T TOOH with BHA#42 and lay down mule shoe and DP pup. 19:00 20:00 1.00 0 0 COMPZ WELLPF PULD T PU and MU BHA#43-Back-off tool assembly. 20:00 22:00 2.00 0 1,266 COMPZ WELLPF TRIP T TIH with BHA#43 filling every stand with diesel. Tagged top of stub at 1047', PU 6", rotate at 3-4 RPM, and SO into stub with slight bobble. Continue to RIH to 1266'with top anchor at 1049'. PU=60K and SO =63K. Page 18 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 1,266 1,266 COMPZ WELLPF CPBO T RU head pin and test pump hose. Set bottom anchor at 1070',saw shear at 700 psi. Shut down pump, bleed of pressure and SO 8K. Pressure up and set top anchor, saw shear at 1700 psi continue to pressure up to 3800 psi. SO additional 2K. Bleed pressure off and begin to attempt to back-off 7" casing per Baker rep. Pressure up to 3800 psi multiple time with no movement. Pressure up to 3900 psi (max pressure)multiple time with no movement. 12/29/2014 Continue to attempt to back-off 7"casing per Baker rep but unable to achieve back-off. Drop pump out sub dart, circulate out the diesel, and TOOH with back-off tool. RIH with guided wavy shoe, mill over 7"stub about 8", hard tag at 1048.5'and TOOH. RIH with pilot mill assembly and mill 7"casing to 1053'at midnight. 00:00 01:00 1.00 1,266 1,266 COMPZ WELLPF CPBO T Continue to attempt to back-off 7" casing per Baker rep, pressuring up to max pressure 3900 psi but unable to achieve back-off. Released upper anchor, pressured up, confirmed that the back-off tool is operating correctly, and released the lower anchor. 01:00 01:45 0.75 1,266 1,266 COMPZ WELLPF CIRC T RU circulating hose. Drop pump out sub dart and pump out sub sheared at 2200 psi. Circulate out the diesel at 4 BPM =220 psi. Blow down lines and RD circulation equipment 01:45 02:30 0.75 1,266 0 COMPZ WELLPF TRIP T TOOH with BHA#43-Back-off tool assembly. 02:30 03:30 1.00 0 0 COMPZ WELLPF PULD T Lay down BHA#43. 03:30 05:00 1.50 0 0 COMPZ WELLPF PULD T PU and MU BHA#44-Guided Wavy Shoe. 05:00 05:30 0.50 0 1,056 COMPZ WELLPF TRIP T TIH with BHA#44 05:30 07:30 2.00 1,056 1,057 COMPZ WELLPF MILL T Set up milling parameters, RPM 10-20,torque 300-2200#. See initial tag @ 1047.5',work string 5-6 times indications look like we slid over 7", P/U weight 2K overpull. Begin lightly milling with wave shoe down 8", milling off relatively easy. Hard tag/milling @ 1048.5'. Stop milling, P/U weight had 5 K overpull. 07:30 08:30 1.00 1,057 0 COMPZ WELLPF TRIP T TOOH to inspect BHA.Wear on show indicates metal milling on bottom of shoe. 08:30 09:30 1.00 0 0 COMPZ WELLPF OTHR T Conference call with town for next multiple runs. 09:30 15:30 6.00 0 0 COMPZ WELLPF OTHR T Wait on Mills to arrive from BOT. Gel up pits for milling, 36 LSYP, PV 8. LPage 19 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:00 1.50 0 0 COMPZ WELLPF PULD T P/U BHA#45-7-7/8"X 6-1/8"Pilot mill(14")with 6-1/8"DC.TIH-seen a little weight bobble @ 1043.3',tag top of 7"@ 1047.5. P/U and set paremeters. 17:00 00:00 7.00 0 1,053 COMPZ WELLPF MILL T 10 bpm @ 210 psi, RPM 80- 600-800 FTQ, P/U weight 60K,down 64.Work string down-tag @ 1047.5',slowly roll gain additional 8". P/U and begin milling. 2K down-1048',80 RPM, 1500-2250#TQ, 10 bpm @ 212psi. Increase to 3-6K weight on bit at 1049'and continue to mill 7" pumping 10 bbl sweeps as needed down to 1053'at midnight getting metal shaving and cement over the shakers. 12/30/2014 Continue to mill the 7"casing with same parameters from 1053'to 1055'pumping sweeps as needed.Top drive shut down, restart top drive but unable to rotate above 53 RPM in low gear. TOOH to fix top drive. Inspect Mill, all metal muncher buttons gone and stinger worn down from 6-1/8"to 5-7/8". Top drive was fixed at 04:00 hours. RIH with flexible tandem 8-3/4"string mills down to 1055', 1 -2k down drag. Pick up to 1030'and wash/ream down to 1055'. Work through tight spot at 1041'multiple times. RIH with 8-1/4"pilot mill and mill 7"casing down to 1058'. RIH wit stiff tandem 8-3/4"string mills down to 1058'with no tight spots or drag encountered. Wait for 8-3/4"wavy shoe to be delivered to location during phase 2 weather conditions. 00:00 01:00 1.00 1,053 1,055 COMPZ WELLPF MILL T Continue to mill the 7"casing with same parameters from 1053'to 1055' pumping sweeps as needed. 01:00 03:00 2.00 1,055 1,055 COMPZ WELLPF RGRP T Top drive shut down, restart top drive but unable to rotate above 53 RPM in low gear. Attempt to rotate at 80 RPM in high gear and top drive stalled out with no weight on bit. Shut down and try to trouble shoot. Still unable to rotate above 53 RPM in low gear and top drive stalls out when in high gear at 80 RPM with no weight on bit. Mill at 50 RPM, made about 2"and top drive making noises with erratic torque. Pump a sweep, slowly PU out of 7"casing, SO, and tag top of 7"at 1055'. 03:00 03:30 0.50 1,055 0 COMPZ WELLPF TRIP T TOOH to fix top drive and inspect BHA#45. 03:30 04:00 0.50 0 0 COMPZ WELLPF PULD T Inspect Mill, all metal muncher buttons gone and stinger worn down from 6-1/8"to 5-7/8". Lay down BHA #45. *Top drive was fixed at 04:00 hours* 04:00 06:00 2.00 0 0 COMPZ WELLPF PULD T Bring tools into the pipe shed. PU and MU BHA#46-Tandem 8-3/4" String Mills with flex joint and 6-1/8" DC 06:00 07:00 1.00 0 1,009 COMPZ WELLPF TRIP T TIH with BHA#46 to 1009'. Page 20 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 08:30 1.50 1,009 1,055 COMPZ WELLPF REAM T Obtain parameters: 10 BPM @ 240 psi. 650-700 Free torque, 63k PU, 65k SO. Wash down from 1009'to 1055', 1 -2k down drag. Pick up to 1030'and wash/ream down to 1055'. 10 BPM @ 200-250 psi, 650-850 torque,60 RPM.Work through tight spot at 1041'multiple times, varying working depths between 1030'to 1055'total of 10x. Observed fair amount of metal shavings at shakers. Rotary torque dropped to 500-600k torque with no down drag. Pull up to 1007'. 08:30 09:00 0.50 1,055 306 COMPZ WELLPF TRIP T TOOH with BHA#46 306'. 09:00 10:00 1.00 346 0 COMPZ WELLPF PULD T Lay down BHA#46. No signs of wear on string mills. 10:00 10:30 0.50 0 201 COMPZ WELLPF PULD T PJSM. MU BHA#47, 6 1/8"X 8 1/4"Pilot mill with 6 1/4"drill collars. 10:30 11:15 0.75 201 975 COMPZ WELLPF TRIP T TIH with BHA#47 to 975'. 11:15 16:30 5.25 975 1,058 COMPZ WELLPF MILL T Obtain parameters: 10 BPM @ 200 psi. 150-300 Free torque,60k PU, 63k SO.Wash down from 975'to 1055', 1 -2k down drag. Engage rotary @ 80 rpm, 700-1200#torque. Mill from 1055'to 1058' ROP @ 8" Per hr. pumping 10 bbl sweeps per hr. 16:30 17:30 1.00 1,058 0 COMPZ WELLPF TRIP T Trip out of hole with BHA#47. Good wear pattern on mill indicating 7"mill off. 17:30 18:15 0.75 0 0 COMPZ WELLPF PULD T Make up BHA#48. Tandem string mill assembly 18:15 18:45 0.50 0 992 COMPZ WELLPF TRIP T TIH with BHA#48. 18:45 19:30 0.75 992 1,058 COMPZ WELLPF REAM T Establish parameters, PU=62K, SO =64K, rotating=62K,60 RPM, Free torque=300-400 ft-lbs, and 10 BPM =190 psi. Wash down to 1058'with no tight spots or drag encountered. Pump a sweep while reciprocating pipe 60'. Blow down TD. 19:30 20:00 0.50 1,058 218 COMPZ WELLPF TRIP T TOOH with BHA#48 20:00 21:15 1.25 218 0 COMPZ WELLPF PULP T Lay down six 6-1/4" DC's and lay down BHA#48 21:15 21:45 0.50 0 0 COMPZ WELLPF PULD T PU and MU BHA#49-Guided Wavy Shoe assembly without the wavy shoe that has not arrived on location yet. 21:45 23:00 1.25 0 0 COMPZ WELLPF RURD T Kick out 6-1/4"DC's, 6-1/4"jar, 6-1/4"bumper sub, and the 8-3/4" string mills from the pipe shed. Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 COMPZ WELLPF OTHR T Wait for shoe to arrive during phase 2 weather conditions. SIMOPS: Kick miscellaneous fishing tools. 12/31/2014 Wait for shoe to arrive during phase 2 weather conditions. RIH with guided wavy shoe assembly to 401'. Phase 3 weather conditions, operations shut down until extreme weather passes. 00:00 02:00 2.00 0 0 COMPZ WELLPF OTHR T Wait for shoe to arrive during phase 2 weather conditions. 02:00 02:45 0.75 0 0 COMPZ WELLPF PULD T Wavy shoe on location. Load into pipe shed and strap. Shoe has different size thread than was expected. Break out 8-3/8"drive sub and replace with 8-1/8"drive sub. MU wavy bottom shoe. 02:45 03:00 0.25 0 401 COMPZ WELLPF TRIP T TIH with BHA#49 to 401'Phase 3 weather conditions shut down operations. 03:00 00:00 21.00 401 401 COMPZ WELLPF OTHR T Phase 3 weather conditions, operations shut down until extreme weather passes. 01/01/2015 After Phase 3 weather conditions lifted, RIH with guided wavy shoe, and mill cement from around the 7" casing down to 1061'. RIH with cut lip guide assembly, dropped over 7"without any issue, attempt to rotate down but the TD stalled out. RIH with guided wavy shoe and mill cement from 1061'to 1063'. RIH with 8-3/4" tandem mill assembly. Wash out the BOPE stack. RIH with 7"casing patch, ES cementer, and 7"26#L-80 TC-II casing to casing stub at 1058'. 00:00 03:30 3.50 401 401 COMPZ WELLPF OTHR T Phase 3 weather conditions, operations shut down until extreme weather passes. 03:30 03:45 0.25 401 991 COMPZ WELLPF TRIP T TIH with BHA#49-Guided Wavy Shoe assembly 03:45 06:30 2.75 991 1,061 COMPZ WELLPF MILL T Establish parameters PU=58K, SO =60K, rotating=60K,60 RPM, free torque=400 ft-lbs, 10 BPM=310 psi. Rotate half a turn to get bullnose inside, SO,and tag stub at 1058'. PU, rotate at 60 RPM, and begin milling cement from 1058'with 4-5K down,torque 1.5-2K ft-lbs down to 1061'.Wash over torque @ 1300 to 2200. Pump pressure @ 375 psi. Cement returns. Sat down @ 1058' with 5K with drive sub. Pick up off stump&circulated clean. 06:30 07:30 1.00 1,061 0 COMPZ WELLPF TRIP T TOOH with BHA#49.Wavy bottom mill assembly. 07:30 08:30 1.00 0 311 COMPZ WELLPF PULD T Pick up BHA#50-cut lip assembly 08:30 10:00 1.50 311 1,061 COMPZ WELLPF TRIP T TIH with BHA#50. Dropped over top of 7"stump @ 1058 ft no issues. Attempted to rotate down 1 more ft stalled out TD. 10:00 11:00 1.00 1,061 0 COMPZ WELLPF TRIP T TOOH with BHA#50 11:00 11:30 0.50 0 311 COMPZ WELLPF PULD T Make up BHA#51 -Wavy bottom mill assembly with 6 ft swallow Page 22 of 38 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 311 1,058 COMPZ WELLPF TRIP T TIH with BHA#51 12:00 13:30 1.50 1,058 1,063 COMPZ WELLPF MILL T Wash over 7"stump @ 1058'slight rotation to drop bull nose into 7" stub. Engaging cement at 1061' wash down to 1063"@ 10 BPM @ 330 psi. Free torque @ 65 RPM = 986 Ft. lbs.. engagement torque 1600 to 3000 FT lbs. 13:30 14:30 1.00 1,063 0 COMPZ WELLPF TRIP P TOOH with BHA#50 14:30 16:00 1.50 0 1,058 COMPZ WELLPF TRIP P TIH with BHA#51. 8 3/4"Tandem string mill assembly to 1055' Pumped 20 BBL hi-vis sweep. 16:00 17:30 1.50 1,058 0 COMPZ WELLPF TRIP P TOOH with BHA#51. 17:30 18:45 1.25 0 0 COMPZ WELLPF RURD P Pull wear ring and set test plug to prevent metal from going down hole. 18:45 20:00 1.25 0 0 COMPZ WELLPF WWWH P MU magnet with BOPE wash tool and wash out BOPE cleaning magnet as needed. Lay down magnet and BOPE wash tool 20:00 21:00 1.00 0 0 COMPZ WELLPF RURD P Pull test plug and kick out Baker fishing tools. 21:00 21:30 0.50 0 0 COMPZ WELLPF RURD P RD DP running equipment and RU Doyon Casing running equipment. 21:30 22:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM to run casing. 22:00 00:00 2.00 0 1,058 COMPZ WELLPF PUTB P RIH with 7"casing patch, ES cementer, and 7"26#L-80 TC-II casing to casing stub at 1058'(PU= 63K, SO=64K). 01/02/2015 Engage casing patch onto 7"casing stub and PU to 110K to ensure patch is engaged. RU SLB cementers, pump 7"tie back cement job, and RD SLB cementers. WOC for 4 hours and ND BOPE stack. Wait on Schlumberger to bring cement to location for top job that they did not leave after cementing in tie back. Mix up and pour cement for top job from 9'to surface. Install emergency slips on 7"casing, land in 50 K tension and install Wachs cutter;cut off casing stump=32.64'(9.54'in hole). ND cement cross/valves,spacer spool, and DSA. Open lower ram cavity and inspect(clean, no cement or metal). Change upper rams to 4-1/2"solid body rams. Set BOPE back on stump. Install new pack-off. 00:00 00:15 0.25 1,058 1,061 COMPZ WELLPF FISH P SO and engage 7"casing. SO 30K and PU to 110K over. 00:15 03:00 2.75 0 0 COMPZ WELLPF RURD P RD Doyon Casing running equipment. Change short bails out for long bails. Load plug into cement head and RU cement head. RU lines to cement head. 03:00 03:45 0.75 0 0 COMPZ WELLPF RURD P PJSM. PU SLB cementer and PT lines to 4500 psi 03:45 04:00 0.25 0 0 COMPZ WELLPF PRTS P PT the 7"casing to 2500 psi for 5 minutes(good test). Bring the pressure up to open the ES cementer(sheared at 3100 psi). PU to 115K(50K over). Page 23 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 06:00 2.00 0 0 COMPZ WELLPF CMNT P Circulate 100 bbls of fresh water, followed by 10 bbls of ASI neat cement, 50 bbls of pressure net, 7 bbls of ASI neat cement, drop ES cementer closing dart, followed by 5 bbls of ASI neat cement, and displace with a total of 41.5 bbls of fresh water. Shut-in 13.5 bbls into the displacement and started squeezing cement away at max pressure of 350 psi, squeezing away a total of 27.5 bbls of cement. Close the ES cementer at 1590 psi. Shut down pumps. Cement in place at 05:30 hours. Leave pressure on OA for 30 minutes. Pressure on OA 10 psi. 06:00 07:00 1.00 0 0 COMPZ WELLPF RURD P RD SLB cementers and RD cement head. 07:00 11:00 4.00 0 0 COMPZ WELLPF WOC P Wait on cement. 11:00 13:30 2.50 0 0 COMPZ WHDBO NUND P ND BOPE stack. 13:30 15:30 2.00 0 0 COMPZ WHDBO CMNT T Wait on Schlumberger to bring cement to location for top job that they did not leave after cementing in tie back. 15:30 16:30 1.00 0 0 COMPZ WHDBO CMNT T Mix up and pour cement for top job from 9 ft to surface. 16:30 18:30 2.00 0 0 COMPZ WHDBO NUND P Install E-slips on 7"casing and land in 50 K tension install Wachs cutter cut off csg stump=32.64'(9.54'in hole). 18:30 00:00 5.50 0 0 COMPZ WHDBO NUND P PJSM. ND cement cross and valves. ND spacer spool and ND DSA. Open lower ram cavity and inspect (clean, no cement or metal). Change upper rams from 7"solid body rams to 4-1/2"solid body rams. Set BOPE back on stump. Install new pack-off. 01/03/2015 Continue to install pack-off. NU new tubing head,test pack-off to 250/3000 psi(good test), NU DSA, and NU BOPE. Test BOPE to 250/4000 psi with 3-1/2"and 4-1/2"test joint;test witnessed by AOGCC inspector Chuck Sheve. Had to change out the TD double ball valve(Hydraulic/Manual TD)then tested it and the 3-1/2" EUE 8rd FOSV to 250/4000 psi. The 4-1/2" EUE 8rd FOSV failed, it was removed from service, and will be sent out to be rebuilt. TIH with 6-1/8"mill tooth bit to drill out cement,plug, and ES cementer. Tagged top of cement at 883'. 00:00 05:30 5.50 0 0 COMPZ WHDBO,NUND P Continue to install pack-off. NU new tubing head,test pack-off to 250/3000 psi(good test), NU DSA, and NU BOPE. 05:30 07:30 2.00 0 0 COMPZ WHDBO RURD P Set test plug,fill the stack with water,grease the chokes/TD/BOPE stack, and RU BOPE test hoses. Shell test the BOPE against the upper 4-1/2"rams with a 4-1/2"test joint to 250/4000 psi. Good test. Page 24 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 0 0 COMPZ WHDBO BOPE T Continue to prep for test while waiting on state to arrive. 09:00 18:15 9.25 0 0 COMPZ WHDBO BOPE P BOPE test 250/4000 psi.:Test wittiness by Chuck Sheve AOGCC Inspector. 1)Test gas alarms Pass 2) UPR PR w/4.5 TJ , Kill line, Choke 4,11,12, 3.5 IF dart. Pass 3)Man Choke, man kill,3.5 IF FOSV pass 4)HCR choke, HCR kill pass. 5)Choke 1,3,7,9,10 Pass. 6)Lwr PR Choke 2,5,8,4.5 EUE 8rd FOSV. Failed 4.5 EUE 8rd FOSV needs to be rebuilt(out of service). 7)Lwr PR w/4.5 TJ passed 8)Annular w/4.5 TJ 250/3500 psi. Pass 9)BR, choke 5,8,2, TD HCR failed 10)BR, choke 5,8, TD HCR fail 11)BR Choke TD man Fail. Begin single isolation. 12)3.5 TJ Lwr PRs, pass 13)3.5 TJ annular 250/3500 psi, pass 14) Hydraulic TD, Choke 2, 5, 8, lower pipe rams with 3-1/2"test joint. Failed 18:15 18:30 0.25 0 0 COMPZ WHDBO BOPE T 15) Hydraulic TD only,failed 18:30 19:15 0.75 0 0 COMPZ WHDBO BOPE P 16) Blind rams, Choke#2, 5, 8- Passed SIMOPS: Changing out the TD double ball valve(Hydraulic/Manual TD) 19:15 19:45 0.50 0 0 COMPZ WHDBO BOPE P 17) Blind rams, Choke#2, 5, 6- Failed low test(grease choke#6 and function). Retest-Passed SIMOPS: Changing out the TD double ball valve(Hydraulic/Manual TD) 19:45 20:00 0.25 0 0 COMPZ WHDBO BOPE P Draw down test. initial 3000 psi, after closure 1950psi, 200 psi-17 seconds, full system-86 seconds. Four N2 bottles at 1900 psi. Pull test plug. 20:00 22:00 2.00 0 0 COMPZ WHDBO BOPE T Continue to change out the TD double ball valve(Hydraulic/Manual TD) 18)Hydraulic TD and 3-1/2" EUE 8rd FOSV-Passed 19)Manual TD and 3-1/2"EUE 8rd FOSV-Passed Page 25 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 22:30 0.50 0 0 COMPZ WHDBO RURD P RD BOPE test equipment, blown down TD ,and install wear ring. 22:30 23:15 0.75 0 0 COMPZ WELLPF PULD P PU and MU BHA#53-6-1/8"Mill Tooth Bit. 23:15 23:45 0.50 0 883 COMPZ WELLPF TRIP P TIH with BHA#53 and tag cement at 883' 23:45 00:00 0.25 883 883 COMPZ WELLPF DRLG P Obtain milling parameters: PU= 57K, SO=60K, Rotating=57K,free torque=600 ft-lbs,6 BPM=220 psi. 01/04/2015 Mill cement 883'to top of plug at 1040';drilled through plug and ES cementer down to 1042'. Encountered cement/debris at 1505', milled down to 1514', and TOOH. PT casing to 3200 psi for 15 minutes(good test). RIH with RCJB and cleanout from 1514'to 1515'. TOOH and recovered debris on the magnet and in the RCJB. Again RIH with RCJB,top drive shut down,shut down operations, and repair top drive cable. Continue to clean out debris but unable to get past 1515'. TOOH and recovered more debris on the magnet and in the RCJB. RIH with bladed junk mill,tagged at 1516.5, attempt to break up obstruction, and push down hole. Top drive shut down again, shut down operations, and repair top drive cable. Continue to mill obstruction and push down to 1517.5'. RIH with fishing magnet,TOOH, and recovered large chunk of the lost grapple. 00:00 05:30 5.50 883 1,514 COMPZ WELLPF DRLG P Mill cement with 4-6K down,torque= 600 ft-lbs,6 BPM=300 psi to top of plug at 1040'. Increase to 100 RPM and Drilled through plug/ES cementer with 600-1200 ft-lbs down to 1042'. Encountered cement/debris at 1505'and began drilling at 60 RPM with torque= 800-1000 ft-lbs and 6-10K down. Mill down to 1514'. Pump a 15 bbl hi-vis sweep and blow down top drive. 05:30 06:30 1.00 1,514 0 COMPZ WELLPF TRIP P TOOH with BHA#53-6-1/8"mill tooth bit 06:30 07:00 0.50 0 0 COMPZ WELLPF PRTS P PT casing and ES port to 3200 psi for 15 minutes Good test 07:00 10:30 3.50 1,514 1,515 COMPZ WELLPF TRIP T RIH with BHA#54 RCJB Clean out from 1514 to 1515'not making any hole. Pumped Hi-vis sweep 10:30 12:00 1.50 1,515 0 COMPZ WELLPF TRIP T POOH with BHA#54. lots of shavings on magnet.& ES junk in RCJB cleaned out Boot baskets 12:00 13:00 1.00 0 1,501 COMPZ WELLPF TRIP T RIH with BHA#55 RCJB assembly 13:00 14:00 1.00 1,501 1,501 COMPZ WELLPF RGRP T Repair Top drive cable 14:00 16:00 2.00 1,501 1,515 COMPZ WELLPF CIRC T Continue to clean out Junk from ES shoe and casing milling operation with RCJB. Circulating @ 8 BPM @ 2000 psi. FT @ 350 FT lbs @ 60 RPMs Not getting beyond 1515 ft taking wt but going up junk basket. 16:00 17:30 1.50 1,515 0 COMPZ WELLPF TRIP T POOH with BHA#55. recovered more junk in RCJB from ES cementer. and metal shavings on magnets&Boot baskets 17:30 17:45 0.25 0 0 COMPZ WELLPF OTHR T Clean up work floor. 17:45 18:15 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#55. PU and MU BHA#56-Bladed Junk Mill, 18:15 19:00 0.75 0 1,515 COMPZ WELLPF TRIP T TIH with BHA#56 to 1515', PU= 65K, and SO=65K Page 26 of 38 Time Logs I Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment J 19:00 19:30 0.50 1,515 1,517 COMPZ WELLPF MILL T Set 5K down at 1516',set down 20K, and obstruction moved down to 1516.5'. Attempt to break up obstruction and push down hole. Made about 2"after several hit. PU and rotate at 30 RPM=400 ft-lbs SO,set 2K down, and top drive shut down. 19:30 21:00 1.50 1,517 1,517 COMPZ WELLPF RGRP T Shut down operations to fix top drive. 21:00 21:30 0.50 1,517 1,518 COMPZ WELLPF MILL T Rotate down at 30 RPM,torque= 400-700 ft-lbs, 2K down,and dry drill. Vary RPM 10-30 RPM, hit down a couple time with no rotation, and obstruction moved down hole to 1517.5'set 5K down. 21:30 22:00 0.50 1,518 0 COMPZ WELLPF TRIP T TOOH with BHA#56 22:00 22:30 0.50 0 0 COMPZ WELLPF PULD T Lay down BHA#56. PU and MU BHA#57-6" Fishing Magnet. 22:30 23:15 0.75 0 1,518 COMPZ WELLPF TRIP T TIH with BHA#57 to 1517.5'and set down three times. 23:15 23:45 0.50 1,518 0 COMPZ WELLPF TRIP T TOOH with BHA#57 23:45 00:00 0.25 0 0 COMPZ WELLPF PULD T Lay down BHA#57. Recovered large chunk of the lost grapple. 01/05/2015 TIH with drag tooth shoe,tagged at 1517.5', and dry drill/washed down to 1522'. TIH with RCJB,tagged at 1522', and dry drill/washed down to 1537'. RCJB was packed full of metal debris and chunks of grapple. TIH with RCJB tagged at 1537'and cleaned out to 1563'getting sand over the shakers(recovered nothing in the RCJB). Slip and cut drilling line. TIH with RCJB tagged at 1564'and cleaned out to hard tag 1568.5' (recovered nothing in the RCJB). TIH with RCJB,wash over the top of the RBP, and swap the well over to 12.2 ppg mud. TIH with RBP retrieving head and attempted to retrieve RBP but were unable to engage RBP. 00:00 00:30 0.50 0 0 COMPZ WELLPF PULD P PU and MU BHA#58-6"Drag Tooth Shoe(smooth OD/ID) 00:30 01:30 1.00 0 1,480 COMPZ WELLPF TRIP P TIH with BHA#58 to 1480' 01:30 02:00 0.50 1,480 1,522 COMPZ WELLPF MILL P Obtain parameters: PU=65K, SO= 65K, Rotating=65K,free torque= 600 ft-lbs. RIH and tag at 1517.5'. PU 3', rotate at 30 RPM, an dry mill to 1518'with 1-2K down. Break circulation at 4 BPM=300 psi and mill down steady to 1519'with 5K down. PU 6'and CBU. Shut down pumps, SO, and tag at 1521'. PU, rotate at 30 RPM, SO, and dry mill to 1522'. Shut down rotary at tag twice at 1522'with 5K down. 02:00 02:45 0.75 1,522 0 COMPZ WELLPF TRIP P TOOH with BHA#58 02:45 03:30 0.75 0 0 COMPZ WELLPF PULD P Lay down BHA#58. PU and MU BHA#59-RCJB. 03:30 04:00 0.50 0 1,484 COMPZ WELLPF TRIP P TIH with BHA#59 Page 27 of 38 j Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 1,484 1,537 COMPZ WELLPF WASH P Obtain parameters: PU=65K, SO= 65K, Rotating=67K,free torque= 400 ft-lbs. RIH and tag at 1522'with 5K down. PU, rotate at 60 RPM, and dry mill to 1523'. Break circulation at 8 BPM= 1600 psi and chase debris down to 1528'. Shut down rotary and pumps. SO,tag at 1529',dry mill 1',turn on the pump to 8 BPM and chase debris down to 1535'. PU,tag at 1535', and dry mill 1', turn on the pump to 8 BPM and chase debris down to 1537'. PU, turn off rotary and pumps,SO,tag at 1537'with 5K down 05:00 05:30 0.50 1,537 0 COMPZ WELLPF TRIP P TOOH with BHA#59 05:30 06:30 1.00 0 0 COMPZ WELLPF PULD P Lay down BHA#59. Recovered more of the grapple and shavings. 06:30 07:30 1.00 0 1,537 COMPZ WELLPF TRIP P RIH with BHA#60. RCJB assembly 07:30 08:30 1.00 1,537 1,547 COMPZ WELLPF WASH P Engaged pumps @ 10 BPM @ 2000 psi C/O to 1547 ft sand back over the shakers. circulated clean 08:30 09:30 1.00 1,547 0 COMPZ WELLPF TRIP P POOH with BHA 60. recovered ES junk and metal shavings 09:30 10:30 1.00 0 495 COMPZ WELLPF TRIP P RIH with BHA#61 to 415 ft 10:30 11:30 1.00 495 495 COMPZ WELLPF SLPC P Slip&cut Drilling line 11:30 12:30 1.00 495 1,563 COMPZ WELLPF WASH P Continue to RIH with BHA#61 tagged @ 1550 C/o to 1563' circulated clean. 12:30 14:00 1.50 1,563 0 COMPZ WELLPF TRIP P POOH with BHA#61. Basket clean 14:00 14:30 0.50 0 1,564 COMPZ WELLPF TRIP P RIH with BHA#62.same assembly. 14:30 16:00 1.50 1,564 1,569 COMPZ WELLPF WASH P Tagged fill @ 1564'worked down to 1567 tagged solid with 10 K down dry drilled to 1568.5 16:00 17:00 1.00 1,569 0 COMPZ WELLPF TRIP P POOH with BHA#62. Empty. 17:00 17:45 0.75 0 1,519 COMPZ WELLPF TRIP P RIH with BHA#63. RCJB assembly 17:45 19:00 1.25 1,519 1,587 COMPZ WELLPF CIRC P Circulate at 8 BPM= 1600 psi,wash down to top of the RBP#2 at 1586.5' and set 5K down. PU 2', pump 30 bbls fresh water hi-vis sweep,then displace well to 12.2 ppg mud. Blow _ down TD. 19:00 20:00 1.00 1,587 0 COMPZ WELLPF TRIP P TOOH with BHA#63 20:00 20:45 0.75 0 0 COMPZ WELLPF PULD P Lay down BHA#63. Magnets full but RCJB empty. PU and MU BHA#64 -RBP Retrieving Head. 20:45 21:45 1.00 0 1,565 COMPZ WELLPF TRIP P TIH with BHA#64 Page 28 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 23:00 1.25 1,565 1,588 COMPZ WELLPF MPSP T PU=57K, SO=57K. Tag at 1588', set 5K down, PU,and no overpull. Break circulation at 2 BPM=200 psi, SO, and tag at the same spot with no pressure increase. Set down 10K and still no pressure increase. Start rotating at 20 RPM, SO, and tag at 1588'(no torque increase). Shut down pumps/rotary and attempt to engage RBP with no success. 23:00 23:45 0.75 1,588 0 COMPZ WELLPF TRIP T TOOH with BHA#64 23:45 00:00 0.25 0 0 COMPZ WELLPF PULD T Lay down BHA#64 01/06/2015 M/U BHA#65 fishing magnet. RIH and tag at 1588'. POOH-no recovery. M/U BHA#66 RCJB. RIH and establish parameters. Attempt to mill over junk on top of RBP, no footage gained. POOH, recovered parts of ES Cementer and RBP. M/U and RIH with BHA#67 RCJB to 1588.5'. POOH, recovered parts of ES Cementer. M/U BHA 68 Overshot with 2-1/8"Grapple, RIH and engage fish to 1589.5. POOH with RBP#2. M/U BHA#69 RBP retrieval head and RIH. Tag RBP#1 at 4975'and attempt to engage. Unable to get over RBP. POOH. M/U BHA#70 Overshot with 2-7/8"grapple. 00:00 00:30 0.50 0 0 COMPZ WELLPF PULD T PU and MU BHA#65-6"Fishing Magnet 00:30 01:15 0.75 0 1,588 COMPZ WELLPF TRIP T TIH with BHA#65 tagged at 1588' twice with 5K down. 01:15 02:15 1.00 1,588 0 COMPZ WELLPF TRIP T TOOH with BHA#65. 02:15 03:00 0.75 0 0 COMPZ WELLPF PULD T Lay down BHA#65. PU and MU BHA#66-6-1/8"RCJB with extended head. 03:00 04:15 1.25 0 1,576 COMPZ WELLPF TRIP T TIH with BHA#66 to 1576'. 04:15 06:30 2.25 1,576 1,588 COMPZ WELLPF FCO T Obtain parameters: PU=65K, SO= 65, 60 RPM=600 ft-lbs, 9 BPM = 1800 psi. Tagged at 1588'attempted to mill over junk on top of RBP fish neck. Dry/wet mill not making any hole. 06:30 07:30 1.00 1,588 0 COMPZ WELLPF TRIP T POOH with BHA 66. Recovered more of the ES cementer and the top shifting collets from the RBP. 07:30 09:00 1.50 0 0 COMPZ WELLPF TRIP T Discuss with Eng and Baker on next operation run 09:00 10:00 1.00 0 1,589 COMPZ WELLPF TRIP T RIH with BHA#67 RCJB.tagged top of RBP @ 1588 ft worked down to 1588.5 ft taking 5K in weight. 10:00 11:00 1.00 1,589 0 COMPZ WELLPF TRIP T POOH with BHA#67. recovered more of the ES cementer. 11:00 11:30 0.50 0 0 COMPZ WELLPF PULD T Lay down RCJB assembly 11:30 12:00 0.50 0 0 COMPZ WELLPF PULD T Plck up BHA#68.4 11/16 overshot W/2 1/8"graple 12:00 13:00 1.00 0 1,593 COMPZ WELLPF TRIP T RIH W/BHA#68 engaged plug. swallowed to 1589.5. sat 10 K down pulled 4 K over pull.dropped down to 1593 ft. plug free. 13:00 14:30 1.50 1,593 0 COMPZ WELLPF TRIP P POOH with RBP. Plug on. Broke off over shot. 14:30 16:30 2.00 0 4,920 COMPZ WELLPF TRIP P RIH with BHA#69. RBP retrieving tool assembly Page 29 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 4,920 4,920 COMPZ WELLPF CIRC P Condition mud above RBP @ 5000 ft. -@ 6 BPM @ 1125 psi. 17:30 19:30 2.00 4,920 4,976 COMPZ WELLPF MPSP T Engage RBP @ 4975 ft unable to get retrieving tool over the top of the plug. Circulate down @ 2 BPM @ 460 psi. attempted to rotate over with out success. Stage pumps up to 6 bpm 1020 psi and wash over to 4975.5'. Unable to latch onto RBP. 19:30 20:00 0.50 4,976 4,970 COMPZ WELLPF CIRC T Pick up to 4970'Circulate annular volume at 6 bpm 1070 psi. 20:00 20:30 0.50 4,970 4,970 COMPZ WELLPF OWFF T Monitor well, static. 20:30 23:00 2.50 4,970 0 COMPZ WELLPF TRIP T POOH with BHA 69 RBP retrieval tool. 23:00 00:00 1.00 0 293 COMPZ WELLPF PULD T PJSM M/U BHA#70 Overshot with short catch 2-7/8"Grapple. 31/07/2015 RIH with BHA#70, overshot with 2-7/8"grapple to 4,976.5'. Engage RBP#1, circulate annular volume and monitor well, static. POOH, hanging up on collars with 10-15K over pull. UD RBP. Clean out BOPE stack. P/U BHA#71 Itco Spear. RIH to 7,561, circulate and condition mud. RIH and engage PBR,swallow spear down to 7,642'. Jar packer free. Circulate annular volume x1.5, monitor well, static. Work packer up to 7,580'; drag increasing to 90K over. RIH to reset jars and work pipe from 7,631'to 7,580'. Establish circulation and work pipe up to 7,500'. Perform post jarring derrick inspection. 00:00 02:30 2.50 293 4,970 COMPZ WELLPF TRIP T RIH with BHA#70 Overshot with 2-7/8"grapple to 4970'. PUW 100K, SOW 85K. 1200 ft-lbs free torque at 15 rpms, ROT wt 95K 02:30 03:00 0.50 4,970 4,983 COMPZ WELLPF MPSP P Continue RIH, Observe fish at 4976.5', swallow to 4977', stack 7K. Pick up to 4971'and observe 7k overpull dropping off. Slack off to 4983 without tagging up. 03:00 03:30 0.50 4,983 4,983 COMPZ WELLPF CIRC P Circulate annular volume at 4 bpm 1100 psi. 03:30 04:00 0.50 4,983 4,983 COMPZ WELLPF OWFF P Monitor well,static. 04:00 09:00 5.00 4,983 0 COMPZ WELLPF TRIP P PJSM POOH with BHA#70 and RBP. Observe 10-15K overpull on casing collars; slack off and work through tight spots. 09:00 11:00 2.00 0 COMPZ WELLPF WWWH P Wash out BOPE stack to clear any debris letf. 11:00 15:30 4.50 0 7,561 COMPZ RPCOM TRIP P RIH with BHA#71. spear assembly 15:30 16:30 1.00 7,561 7,561 COMPZ RPCOM CIRC P Circulated to condition mud. @ 5 BPM @ 3600 psi. pumped 277 BBLs 1-hole vov. 16:30 18:00 1.50 7,561 7,642 COMPZ RPCOM FISH P Up wt= 135 K. Dwn wt= 105 K attempt to engaged spear into the PBR.dropped in.set graple @ 7642 ft. Straight pull 75K over no movement. Begin jarring operations. Hitting with 40 over and pulling 65 over. pulled free. 18:00 20:00 2.00 7,642 7,642 COMPZ RPCOM CIRC P Circulate 1.5 x annular volume 2.5 bpm 1800 psi-no indication of packer gas. Blow down top drive Page 30 of 38 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 20:00 20:30 0.50 7,642 7,642 1COMPZ RPCOM OWFF P Monitor well,static. 20:30 23:00 2.50 7,642 7,500 COMPZ RPCOM JAR P Attempt to POOH with fish. Observe 10K drag at 7,627', increasing to 90K over at 7,580'. Drop back down to 7,631 and reset jars. POOH to 7,580'with same drag;jars firing between 7,605 and 7,595'x 10. Establish circulation at 2 bpm 1200 psi and continue working pipe from 7,631'to 7,580'. Work pipe up to 7,500' PUW 140K with 10K-20K drag. 23:00 00:00 1.00 7,500 7,500 COMPZ RPCOM SFTY P Post Jarring derrick inspection. 31/08/2015 Continue to POOH with HB Packer and tail pipe assembly. M/U BHA#72 mill tooth bit and RIH to 7646'. Establish SPR. Circulate at 7 bpm. Gas observed at surface after 110 bbls pumped;2.8 bbls gain. Shut well in; SIDP 50 psi, SICP 50 psi. Circulate gas out through gas buster. SIDP 0 psi;SICP 0 psi. Open well, static. Wash down at 8 bpm to 7,711'tag cement. Drill cement from 7,711'to 7,900'WOB 5-10K, 100 rpms, ROP 25-40 fpm. 00:00 08:00 8.00 7,500 0 COMPZ RPCOM TRIP P Continue to POOH with HB packer and lower tail assembly from 7,500'. Intermittent drag 20K-30K over from 5,850'-5,450';5,050'-4,950';4,725'; 4,605'to 4,330'. Work tight spots once with no drag observed on second pass. Laid down packer assembly.Also recover more cast iron from ES cemanter on top of PBR. 08:00 09:30 1.50 0 0 COMPZ RPCOM OTHR P Clean off tools from floor for return to Baker 09:30 10:30 1.00 0 331 COMPZ WELLPF PULD P Pick up BHA 72. Drilling/mill assembly 10:30 14:00 3.50 331 7,646 COMPZ WELLPF TRIP P RIH with BHA#71 14:00 17:00 3.00 7,646 7,646 COMPZ WELLPF CIRC P EST slow PR @ 2 BPM @ 670 psi. kick circulation up to 7 BPM 110 bbls back gas to surface.shut well in 2.8 BBL gain. SIDP=50 psi SICP 50 psi.circulate @ 2 BPM @ 900 psi thru gas buster. FCP DP=790 psi FCP IA= 120 psi. let well stabilize. 0 psi both sides. 17:00 00:00 7.00 7,646 7,900 COMPZ WELLPF DRLG P Broke circulation @ 8 BPM, 2500 psi. Drilled out cement from 7711'to 7900. 100 rpms 2500-3000 ft-lbs torque,WOB 5-10K. ROP 25-40 fpm. Vary parameters to attempt and increase ROP unsuccessful. 01/09/2015 Continue drilling cement from 7,900'to 7,915'. Broke through cement; observe sand and frac sand coming back. Wash down to 8,110'with rotary; S/D rotary and wash to 8,115'and tag with 5K down. Pump sweep and circulate hole clean. POOH above perfs to 7,666'. Monitor well, static. Slip and cut drilling line. POOH to 3,000'. M/U storm packer and RIH to 100'. Set storm packer and test. POOH. Pull W/R,set test plug. Test BOPE's. RIH and engage storm packer. CBU. POOH to 220'. Page 31 of 38 9 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 7,900 7,915 COMPZ WELLPF DRLG P Continue drilling cement from 7,900' to 7,915'. WOB 8-12K;6bpm, 1790 psi 100 rpms 3500 ft-lbs. Broke through cement at 7,915. Observe sand coming over shakers WOB drop to 0. 00:30 02:30 2.00 7,915 8,115 COMPZ WELLPF WASH P Circulated out sand from 7,915'to 8,115'at 6 bpm 1870 psi, 100 rpms 3400 ft-lbs. KB corrected CIO depth 8120 ft.solid tag on FC @ 8115 ft. 02:30 05:00 2.50 8,115 8,115 COMPZ WELLPF CIRC P Circulate 30 bbls high vis sweep at 6 bpm 2300 psi. Continue circulating hole clean. Sand and frac sand observed coming back. CBU x4 staging pumps up to 8 bpm 2800 psi. 05:00 05:30 0.50 8,115 7,666 COMPZ WELLPF TRIP P Pulled tail above perfs to 7666 ft 05:30 06:00 0.50 7,666 7,666 COMPZ WELLPF OWFF P Flow check 30 min's. 06:00 08:00 2.00 7,666 7,666 COMPZ WELLPF SLPC P Slip and cut Drill line 08:00 11:00 3.00 7,666 3,000 COMPZ WELLPF TRIP P POOH with drill pipe to 3000 ft. 11:00 12:00 1.00 3,100 0 COMPZ WELLPF MPSP P Pick up and RIH with storm packer. Set packer @ 100 ft. PT to 500 psi. 12:00 14:30 2.50 0 0 COMPZ WHDBO RURD P Pulled wear ring. Install test plug. wash BOPE stack 14:30 20:00 5.50 0 0 COMPZ WHDBO BOPE P Prep&begin BOPE testing 250/ 4000 psi. 1)BR, Kill#13, HCR TD,3.5 IF dart, choke 4,11,12 pass 2) Kill HCR, Man TD, 3.5" If FOSV, choke 3,7,9,10 Pass. 3) LPRs, 3.5 TJ, choke 2,5,8, 3.5 8rd FOSV pass 4)annular w/3.5 TJ Pass 5)LPR W/4.5 TJ, Choke 6 pass 6)UPR w/4.5 TJ, Choke 1 Pass 7)Ann w/4.5,TJ man choke Pass 8)Man Kill, Choke HCR-pass Draw Down test-Initial pressure 3000 psi,final pressure 2000 psi. Recharge- initial 200 psi 19 seconds;total recharge 86 seconds 4x N2 at 1900 psi. 20:00 20:30 0.50 0 0 COMPZ WHDBO RURD P R/D testing equipment. 20:30 21:00 0.50 0 3,500 COMPZ WELLPF MPSP P RIH to 100'and engage storm packer. 21:00 22:00 1.00 3,500 3,500 COMPZ WELLPF CIRC P Circulate annular volume. 22:00 00:00 2.00 3,500 220 COMPZ WELLPF TRIP P POOH with BHA 72 to 220' 01/10/2015 L/D BHA. M/U 4-1/2"shoe track and check floats-good. Rlh with 4-1/2"liner on Baker HRD-E ZXP Packer to 7,947'. R/U E-Line and coorelate on depth. R/U Schlumberger cementers. Pump cement as per detail: 5 bbls fresh water, 15 bbls Mud Push, 15 bbls 15.8 ppg Class G cement, 5 bbls of water 54 bbls 12.2 ppg mud; bump plug. Pressure up and set liner hanger. Slack off, and pressure up to set packer. 00:00 01:00 1.00 220 0 COMPZ WELLPF PULD P UD BHA Page 32 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 0 0 COMPZ RPCOM RURD P Kick out Baker tools. Clean and clear rig floor. R/U to RIH with 4-1/2" Liner. 02:30 03:00 0.50 0 0 COMPZ RPCOM SFTY P Safety Stand down. Discuss recent incidents and ways to refocus on safety. 03:00 05:00 2.00 0 260 COMPZ RPCOM PUTB P PJSM. M/U shoe track and RIH with 4-1/2"Liner. Check floats after making up shoe track-good. 05:00 13:00 8.00 260 7,947 COMPZ RPCOM RUNL P RIH with liner assembly on drill pipe. Fill pipe every 10 stands 13:00 19:00 6.00 7,947 7,947 COMPZ RPCOM ELOG P PJSM. RU Eline to run correlation log. K-1 mark not identifiable correlated to hot zone @ 7377ft. 3 down adjustment to place kick out jt on depth. POOH with Eline. 19:00 00:00 5.00 7,947 7,947 COMPZ RPCOM CMNT P Spot up Schlumberger. PJSM. PT lines to 4500 psi. pump 5 bbls fresh, 15 BBIs mud flush, 15 BBLs G neat cement, dropped dart, displaced with 5 fresh, 55 12.2 mud. Bumped plug Cement in place©23:40 hrs. Slack off 25 K. Pressured up to 4200 psi. Set anchor&packer. Bleed off pressure and check floats-good. Rotate 15 turns to release liner. 01/11/2015 Release liner setting tool, slack off 30K on liner top. Pick up and circulate out excess cement at 8 bpm 2600 psi. Slack off and tag liner top with 40K down. Wait on cement. PT liner packer and casing 250 psi(good) and 3000 psi (lost all pressure). Monitor well. POOH with liner setting tool. M/U test packer, RIH to 3,970'. PT below good; above unable to pressure up. Continue to test casing with test packer; determine hole is between 973'and 1069'. 00:00 01:15 1.25 7,947 7,687 COMPZ RPCOM CIRC P Pressure up to 500 psi and pick up on setting tool. Observe pressure drop. Slack off and tag liner top with dogs setting 30 K down. Pick up and Circulate out excess cement at 8 bpm 2600 psi. Slack off, observe packoff entering liner top. Slack off 40K on liner top, rotate 5 turns to confirm packer set. 01:15 07:00 5.75 7,687 7,687 COMPZ RPCOM WOC P Wait on Cement. Simops: Clean pits and prep for displacement. 07:00 10:00 3.00 7,687 7,680 COMPZ RPCOM PRTS T Pressure test liner packer and casing to 250/3000 psi for 30 min;s Low test held.while building pressure up reached 3250 psi lost all pressure. check surface equipment no leaks. Est circulation @ 8 BPM @ 2020 psi lost 10+bbls during circulation. 10:00 10:30 0.50 7,680 7,680 COMPZ RPCOM OWFF T Monitor well for flow 10:30 11:30 1.00 7,680 7,680 COMPZ RPCOM COND T Take mud back on to rig&condition 11:30 15:30 4.00 7,680 0 COMPZ RPCOM TRIP T POOH with liner setting assembly standing back DP Page 33 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 19:15 3.75 0 3,970 COMPZ RPCOM TRIP T Pick up& RIH with test packer w/ liner pack off assembly. BHA#73 to 3,970'. 19:15 00:00 4.75 3,970 1,069 COMPZ RPCOM PRTS T Set packer @ 3,970' COE and test to 2000 psi-below good, unable to pressure up above. POOH to 3004'; PT to 2000 psi below-good. POOH to 2,037' PT to 2000 psi below,good. POOH to 1,552'. Check circulation- good. Test below to 2000 psi good. Test above, unable to pressure up. POOH to 973'; attempt to PT below, unable to pressure. PT above lost 150 psi in 4 minutes(annular seating)flatline at 1850 psi. RIH to 1069'and test below-good. 01/12/2015 Continue looking for hole in 7"casing with test packer. Determine hole depth between 1,060'and 1,065. POOH with test packer. R/U E-Line. RIH with Multi-Finger Caliper log. R/D E-Line. Consult with town. Wait on Weatherford Patch running tool. RIH to 7,687'to displace fluid. Clean pits. 00:00 03:00 3.00 1,069 1,065 COMPZ RPCOM PRTS T POOH 1,029'and attempt to test below, unable to. PT above to 2000 psi lost 150 psi in 3 minutes (element seating)and flatlined at 2050psi. Set packer at 1,037', PT below unable to pressure up. PT above good. Attempt and set packer in 14'pup joint between ES cementer and Bowen Patch. Packer will not set. Set packer at 1,054'(packer dogs in Bowen patch, element in pup joint). Unable to pressure up below, PT to 2000 psi above, good. Set packer at 1,060', unable to pressure up below, PT to 2000 psi above- good. Set test packer at 1,065' PT below to 2000 psi,good; unable to pressure up above. Leak between 1,060'and 1,065'. well taking 2 BPM @ 90 psi while attempting to test. 03:00 04:30 1.50 1,065 0 COMPZ RPCOM TRIP T POOH with test packer. 04:30 11:30 7.00 0 0 COMPZ RPCOM ELNE T R/U dutch riser and E-Line. Run multi-finge caliper log from 4000 ft to surface 11:30 13:00 1.50 0 0 COMPZ RPCOM OTHR T Wait on orders.Wait on Weatherford equipment 13:00 18:30 5.50 0 7,687 COMPZ RPCOM TRIP T Wait on Weatherford equipement. Sim-ops RIH with Drill pipe to 7687 ft. For fluid swap over. 18:30 00:00 5.50 7,687 7,687 COMPZ RPCOM OTHR T Wait on Weatherford equipment. Sim-Ops: Clean pits,wait on inhibitied fluid. Fluid on location 23:30. t_ _ Page 34 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/13/2015 24 hr Summary Continue to wait on Weatherford Patch. Sim-Ops; clean pits, displace well to 8.6 ppg seawater with Conqor 303A. POOH with drill pipe laying down all but 3000'of drillpipe. Weatherford personnel and equipment on loaction at 20:30. Offload trucks, check equipment, load pipeshed. 00:00 04:00 4.00 7,687 7,687 COMPZ RPCOM OTHR T Wait on Weatherford equipment. Sim-Ops: Clean pits, Take on fluid; build spacer. 04:00 07:30 3.50 7,687 7,687 COMPZ RPCOM DISP T Wait on Weatherford equipment. Sim-Ops: PJSM displace well to 8.6 ppg seawater with 1%Conqor 303A: 100 bbls high vis spacer, 80 bbls seawater, 290 bbls seawater. 07:30 08:00 0.50 7,687 7,687 COMPZ RPCOM OWFF T flow check 30 min's. 08:00 20:30 12.50 7,687 0 COMPZ RPCOM PULD T Continue to wait on Weatherford patch: Si-ops POOH lay down drill pipe 20:30 00:00 3.50 0 0 COMPZ RPCOM OTHR T Casing patch and personnel on location. Offload trucks, check equipment and start loading pipeshed. 01/14/2015 Continue loading Weatherford Patch equipment. R/U and RIH with 114'casing patch to 1,121'. Pressure up to 4000 psi to set casing patch Anchor. Pull cone through remaining patch to expand. Patch set from 1,011' to 1,121'post expansion. POOH. LID setting tool. L/D drill pipe. R/U and RIH with 4-1/2"completion as per detail to 5,010'. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD T Continue loading casing patch equipment and tally. R/U to RIH with casing patch. 01:30 05:00 3.50 0 114 COMPZ RPCOM PULD T PJSM. Pick up 3-1/2"innerstring for casing patch. M/U and stand back. Pick up 5.5"expandable casing RIH to 114'. RIH with inner string and latch onto liner. 05:00 06:30 1.50 114 1,121 COMPZ RPCOM TRIP T RIH with casing patch on drill pipe. 06:30 08:00 1.50 1,121 1,010 COMPZ RPCOM PACK T P/U weight 52K, down 55K. Begin pressuring up on MCL, straddled from 1121'to 1010'. Increase pressure to 2600psi,first expansion, increase to 4000 psi. Stop pumping, Weight increase to 90K. Good set. Break off lines at surface. P/U weight swings 100K over, single out 4 joints, broke over @ 112'OOH. 08:00 10:00 2.00 1,010 0 COMPZ RPCOM PULD T TOOH laying down DP&MCL setting equipment. 10:00 11:00 1.00 0 0 COMPZ RPCOM PRTS T Pressure test casing to 3000 psi/30 minutes. Good test. 11:00 13:00 2.00 0 0 COMPZ RPCOM RURD T RD Weatherford equipment, C/O elevators and floor equipment. 13:00 16:00 3.00 0 0 COMPZ RPCOM TRIP T TIH with remaining stands of DP, TOOH sideways and K/0 DP. 16:00 16:45 0.75 0 0 COMPZ RPCOM RURD P C/O floor equipment, review running order, stage pipe. PJSM for P/U completion. Page 35 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 00:00 7.25 0 5,010 COMPZ RPCOM PUTB P P/U 4.5"completion as per running order to 5,010' 01/15/2015 Continue to RIH with 4-1/2"completion to 7,687'. Observe seals enter Liner top. No-Go seals. Space out and make up hanger and landing joint. Reverse circulate 275 bbls of diesel 3 bpm 500 psi. Monitor well, static. Land tubing, RILDS. MIT-T to 3500 psi for 10 minutes, MIT-IA 3000 psi-both good. R/D Little Red. Set BPV with test dart. N/D BOPE, N/U tree and test 250/5000. Pull test dart and set'H' BPV. Clean pits. 00:00 03:30 3.50 5,010 7,687 COMPZ RPCOM PUTB P Continue to RIH with 4-1/2" completion to 7,687'. Pumping 1 bpm and observe pressure increase as seals enter Liner tie-back sleeve. Slack off and observe pipe No-Go with 5K down. 03:30 04:30 1.00 7,687 0 COMPZ RPCOM HOSO P Space out 1.16'from no-go. L/D 2 joints and partial. M/U space out pups,joint and Hanger. 04:30 07:30 3.00 0 0 COMPZ RPCOM FRZP P PJSM. R/U to displace well to diesel. R/U Little Red Service, pressure test lines to 3500 psi. Start pumping 2 bpm @ 300 psi down IA up tubing. Increase rate to 3 bpm @ 500 psi. Pump total of 275 bbls down wel to kill tank. Blow down all lines 07:30 08:00 0.50 0 0 COMPZ RPCOM OWFF P observe well for 30 minutes-no flow, suck out stack, open annular. 08:00 10:30 2.50 0 0 COMPZ RPCOM PRTS P Land tubing hanger. RILDS. Test tubing with diesel to 3500 psi/10 minutes, IA open with no leaks. Good test, bleed down tubing to 500 psi.Test IA with diesel to 3000 psi/10 minutes. Good test. 10:30 11:30 1.00 0 0 COMPZ RPCOM RURD P RD little red, pull landing joint& monitor well. Good-Set BPV 11:30 15:30 4.00 0 0 COMPZ WHDBO NUND P PJSM-suck out stack, blow down flow cross, open up ram doors, inspect stack and Clean out cavities. Offload pipe, threadies, drifts, cameron equipment. 15:30 17:30 2.00 0 0 COMPZ WHDBO NUND P NDBOPE 17:30 19:30 2.00 0 COMPZ WHDBO NUND P Call DSO-NU tree 19:30 21:30 2.00 COMPZ WHDBO PRTS P R/U and PT tree and packoffs 250/5000-good 21:30 22:00 0.50 COMPZ WHDBO MPSP P Pull test dart, set 4"'H' BPV 22:00 00:00 2.00 DEMOB MOVE RURD P Clean pits. Clear rig of crossovers 31/16/2015 Slip and cut drilline, clean pits 3&4, remove all CPAI comms from rig and support equipment. Rig off Hi-line @ 11:30 hrs. Rig release from 30-16A network number @ 12:00(noon). Continue with Rig Demob, clean pits 1 &2, sumps,trip tanks,gas buster, auger trough,shaker room, possem belly&cutting tank. Empty oily waste&SAA areas,empty used oil totes. Offload equipment from rig and ship back to Tool house. 12 hours charged to Demob network number. 00:00 05:00 5.00 DEMOB MOVE RURD P Continue cleaning pits, drag chain, pit room. 05:00 07:30 2.50 DEMOB MOVE RURD P PJSM Slip and cut drilling line. Page 36 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 11:30 4.00 DEMOB MOVE RURD P Continue cleaning pits Pit#1 &2, auger trough,trip tank and shaker room. Hard line crew rig down hard line& kill tanks. Oily waste and SAA accumulation removed from rig. 11:30 12:00 0.50 DEMOB MOVE RURD P Rig off Hi-line as of 11:30 hrs. ***Rig Release 12:00 hrs*** Charges from this point changed to AFE#10308519-Demob 12:00 00:00 12.00 DEMOB MOVE RURD P Continue cleaning pits 1 &2, auger box,suction and trip tank. Lack of vac trucks in field,waiting on truck to round trip to complete cleaning pits. Backload CPAI equipment off rig, X-overs, pump subs, lifting subs and drifts. Warm up rig moving system. *Road graded and cleared of snow at 23:00* 01/17/2015 RDMO. Clean up well and pad. Wait on road equipment due to phase conditions during rig move. Move rig from 30 pad to KDTH.24 hours charged to Demob network number. 00:00 01:30 1.50 DEMOB MOVE RURD P ***Rig Release 12:00 hrs on 1/16/2015**** Continue cleaning pits 1 &2, auger box,suction and trip tank. Warm up rig moving system. 01:30 04:00 2.50 DEMOB MOVE DMOB P Back well off rig. Clean up Cellar and Pad. Inspect road, observe snow drifts to large for Rig from Ugnu Pad to CPF-3, built up since 23:00. 04:00 05:30 1.50 DEMOB MOVE DMOB P Clear access road of snow drifts. Move rig to Y access near main road. 05:30 07:30 2.00 DEMOB MOVE DMOB P Stop for field wide crew change. Phase 2. 07:30 10:30 3.00 DEMOB MOVE DMOB T Wait on blade/blower to clear road prior to leaving. Phase 2 10:30 16:00 5.50 DEMOB MOVE DMOB P Continue with Rig move. 16:00 19:15 3.25 DEMOB MOVE DMOB P Stop at CPF3 for field wide crew change. Drive and inspect roads, all roads cleared and good to continue on for rig move. 19:15 00:00 4.75 DEMOB MOVE DMOB P Continue Moving rig from CPF3 to KTDH 01/18/2015 Nordic Rig 3 reached KRU boundary @ 14:30 hrs.Total hrs charge to Demob network number=50.5 hrs Page 37 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 DEMOB MOVE DMOB P Continue moving rig from KDTH to KOC. 05:00 08:00 3.00 DEMOB MOVE DMOB P Field wide crew C/O. Clean drifts to 1C-access for by-pass traffic. 08:00 14:30 6.50 DEMOB MOVE DMOB P Continue with Rig move. `*"Nordic rig 3 completed Demob to KRU boundary @ 14:30 hrs*". Total hrs charged to Network#10308519=50.5 hrs. Page 38 of 38 253(0%. WELL LOG TRANSMITTAL DATA LOGGED 2_/5/2015 v1 K BENDER To: Alaska Oil and Gas Conservation Comm. February 3, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ._:,, F 4 A , D Anchorage, Alaska 99501 R052015 RE: Radial Bond Log/MultiFinger Caliper/Sting Shot: 30-16A Run Date: 12/27/14-12/28/14 IA-X :- The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 30-16A Data in LAS format, Digital Log Image files, Interp. Report, 3D viewers 1 CD Rom 50-029-21796-01 Radial Cement Bond Log 1 Color Log 50-029-21796-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'T1'FNTION OF: Halliburton Wireline&Perforating Attn: Chris Gullettt 4�t+1', 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • Vof r4, THE STATE Alaska Oil and Gas ' v sw =��.- '� fALAS� o Conservation Commission � - -� � 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASIP Fax. 907.276.7542 www.aogcc.alaska.gov Jason Burke sLWOO CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 30-16A Sundry Number: 315-038 Dear Mr. Burke: 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 P. oerster Chair DATED this 3`'day of January, 2015 Encl. STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMMIo6ION ` , • APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Ft?rforations r Perforate r. Pull Tubing r Time Extension r Operational Shutdow n r Re-enter Susp.Well r Stimulate r Alter casing r Other: f 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 188-043 • 3.Address: 6.API Number: Stratigraphic r Service r . P.0. Box 100360,Anchorage,Alaska 99510 50-029-21796-01 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C0432C Will planned perforations require spacing exception? Yes r No � , KRU 30-16A - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25513 • 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): 8351 - 6901 ' 8118' • 6709' ' 7790' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 2340 9.625 2375' 2215' RECEIVED LINER 8168' 7 8201' 6778' LINER 238' 4.5 7945' 6571' JAN 2 3 2015 09-5�AOGCG� l 5 Perforation Depth MD(1 7794-7804, Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7838-7848,7850-7860,7869-7889,7908-7928 16444-6452,6480-6488,6489-6498,6505-6522,6537-6553 4.5 L-80 7707 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-5"x 7"ZRN ZXP LINER TOP PACKER • MD=7687 TVD=6347 NO SSSV 12.Attachments: Description Surrmary of Proposal p. 13. Well Class after proposed work: Detailed Operations Program E BOP Sketch r Exploratory r Stratigraphic r Development r Service r , 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: -642 2/6/2015 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ 1 GINJ r WAG IV Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Burke @ 265-6097 Email. Jason.Burkena conocophillips.com Printed Name Jason Burke Title. CTD Engineer r Signature Phone:265-6097 Date /-2Z--/S Commission Use Only Sundry Number: v Conditions of approval: Notify Commission so that a representative may witness 3\G— C.)3 O Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10 — 401- APPROVED 0APPROVED BY Approved by: ,7 11 �t/`— COMMISSIONER THE COMMISSION Date: �� ��� A prov Ica 10 1 valid for 2 months tro thydate of approval. �+ n Form 10-403(Revised 10/2012) 1)14 //lc, �� Submit Forma ttDachme�'ntsiDuplibte _ 2015 VTC 1/28/1 ' ,C c /yid/3o JS t � RECEIVED ConocoPhillips JAN 2 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 20, 2015 Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. submits a sundry application to re-perforate the A sand in the KRU 30-16A well. This operation will allow us to prepare the well for CTD operations by monitoring bottom hole pressure in the newly worked over well. CTD operations are slated to start in February of 2015. Attached to this application are the following documents that explain the proposed job operations. — Sundry summary — Sundry application form for 30-16A — Current wellbore schematic — Proposed CTD schematic If you have any questions or require additional information please contact me at my office 907-265-6097. Sincerely, Jason Burke ConocoPhillips Alaska Coiled Tubing Drilling Engineer , KRU 30-16A CTD Summary for Perforating Sundry (10-403) Summary of Operations: Well 30-16A is a Kuparuk A sand injection well equipped with 41/4"tubing and 4 '/2" liner. Three laterals from well 30-16A will be drilled to the southwest of the parent well to improve sweep in an immature A sand pattern. Operations will be targeting the A3, A2 and Al sand intervals. Recently a rig work over was completed on this well and new 4 '/2"tubing was installed and cemented in place. We will need to go down and perforate the A sand and obtain a current bottom hole pressure. CTD Drill and Complete 30-16A Laterals: February 2015 Pre-CTD Work 1. Coiled Tubing: Clean out tubing down to 7930' MD.. 2. E-line: Perforate the A sand from 7908' —7928`, 7869` —7889' & 7838' —7860` MD. Setting plugs inbetween 3. Pumping: Breakdown and pump into each perf cluster at 2 BPM. 4. Slickline: Fish plugs out of the well. Run a dummy whip-stock down to 7830' MD& Obtain a static bottom hole pressure 5. E-Line: Set a 4 '/2" starburst whip-stock w/packer at 7815' MD 6. Prep site for Nabors CDR2-AC, including setting BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2-3/8"coil tubing. NU 7-1/16"BOPE,test. 2. 30-16AL1 Lateral (A2 sand - Southwest) a. Mill 3.80"window at 7815' MD b. Drill 4.125"bi-center lateral to target depth of 8815' MD c. Run 3 '/2"blank liner with a 6' seal bore deployment sleeve back to 7810' MD d. Cement liner in place e. Swap 2-3/8"CT back to 2"CT f. Drill out the cement shoe and drill 3"bi-center lateral to TD of 10650' MD g. Run 2%" slotted liner with an aluminum billet from TD up to 8925' MD 3. 30-16AL1-01 Lateral (A3 sand- Southwest) a. Kick off of the aluminum billet at 8925' MD b. Drill 3"bi-center lateral to TD of 10650' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 8885' MD 4. 30-16AL1-02 Lateral(Al sand - Southwest) a. Kick off of the aluminum billet at 8885' MD b. Drill 3"bi-center lateral to TD of 10650' MD c. Run 2%" slotted liner with an aluminum billet from TD up to 7810' MD Page 1 of 2 1/22/2015 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. MIRU CT and N2 lift well for flow back(less than 30 days) 4. Return to operations Page 2 of 2 1/22/2015 7 m G CD V a� 03 a L CO ` LI Q Y O O p as U — W 3 O Y r- a a afo M a N 2-E d m zv iv En in C E .q = rs & v J a m = o c a m E 1 x r, Ce N K U UT M K Et mm co it al- %Zs::Z'vn.L.1:;:iVei.ii,::;;;;.;::':::,•;"'51..n;';''''....‘'4441*•:::: 113:L21. 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J 3 O o \ / cr m c (n o N U �#co a) g o ijc e X N aU ra• ::::::.-: aN NNm NiO.0Qi 'X O .O O / O N(� Qo i. .;I \NO • V Y u rl o f m w� Lb mom IU � t�j3 '^'�' .�%�2'lirr:`., a� J5k c% tt:�t erg.i rr kx £.�1� ( I NYr,4k ry/ � 44 L LNa NP {!yto u a a Li ..,LLLLLL..T .YJ LL, ,i, '17:4•.:„.:,;::17::::::::- Y .L L:•'.+.t•'o ::0,�::,,,.,:::'r..: :„„z„�•:i z:c.L.Lw.•Y;'..:'`.::,,,..' �'iai,;`�':'•:::i.. .,..,Wit:`;",`c. CL N I E0 rt Q c 0000 a) o o U 03 V �� NOO)c0 NQ 1 N O Y 7 (OcoN i M 2� ��a —a 0 0� 0_r,, -0-C) QI,-h-h- L9 - CO N O L LI) L N-r 0)O f0 V Q.— (6 coo c0 co N 00 UN- y(0 O N LI) O0) Op U M(0 0 NN- m C2 0)innN co co Ur a2 Q`NN N@)I Bettis, Patricia K (DOA) From: Burke, Jason <Jason.Burke@conocophillips.com> Sent: Monday, January 26, 2015 7:37 AM To: Bettis, Patricia K (DOA) Subject: RE: Sundry Application for KRU :O-1. sq. e 0 WAG should be checked, sorry for the error. Thanks Jason ConocoPhiiiips Jason Burke CT1) 'Engineer - (ireater 3Cupariuk area 700 G St#1210 Anchorage, AX 99501 (0): (9o71-265-6o97 (.Jti1): (9o7)-231-4568 Jason.Burke@conocophillips.com From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, January 23, 2015 3:49 PM To: Burke, Jason Subject: [EXTERNAL]Sundry Application for KRU 30-16A Good afternoon Jason, On the Form 10-403, Box 15 Well Status after proposed work, CPAI has checked WINJ. Is this correct or should WAG be checked? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the Original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~ ~~- ¢/~/_~ Well History File Identifier Organization (do°e) ~wo-Sided RESCAN DIGITAL DATA o Color items: [] Diskettes, No. © Grayscale items: o Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES: NOTES' ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Project Proofing PROOFEO BY BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs ol various kinds [] Other /SI [] Staff Proof ~i B~, D;; r. , IS~ Scanned (done P~--G E S: SCANNE06Y ~,EVERL¥ E~REN VINCE~M,cR;z LOWELt ReScanned (done} RESCANNEOBYi BEvERtY BREN VINCEN] SHERYt M,~qlA LOWEL( DAlE IS' General Notes or CO~T'~menls about lh~s l~le PAGES Oual~ty Checked STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMIVIINION REPORT OF SUNDRY WELL OPERATIONS DEC 0 4 2013 1.Operations Performed: Abandon r Repair w ell r Rug Perforations J Perforate r • e `^,��a, Alter Casing Pull Tubing r Stimulate-Frac r Waiver r Time Exten- • • `�^ '°° Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188-043 3.Address: 6.API Number: P.0. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service W 50-029-21796-01 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25513 • 30-16A . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 8351 feet Plugs(measured) none true vertical 6901 feet Junk(measured) none Effective Depth measured 8118 feet Packer(measured) 986, 1043,7648 true vertical 6709 feet (true vertical) 986, 1043,6325 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 SURFACE 2340 9.625 2375 2215 PRODUCTION 8168 7 8201 6778 sCAHHED DLL- ' 1'3 Perforation depth: Measured depth: 7794-7804,7838-7848,7850-7860,7869-7889,7908-7928 True Vertical Depth: 6444-6452,6480-6488,6489-6498,6505-6521,6537-6553 Tubing(size,grade,MD,and ND) 2.875,J-55,7722 MD,6385 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER AL-5 DUAL PACKER @ 986 MD and 986 ND PACKER-BAKER AL-5 DUAL PACKER @ 1043 MD and 1043 TVD PACKER-BAKER HB PACKER @ 7648 MD and 6325 TVD SSSV-BAKER FVLD SSSV @ 1786 MD and 1745 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7790'-8200' Treatment descriptions including volumes used and final pressure: 17 bbls of 15.8 Class G 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r. Stratigraphic r 16.Well Status after work: Oil J"' Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ r WAG rt7 • GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-256 Contact Tyson Wiese Cad 263-4250 Email Tyson.M.Wiese(a�cop.com Printed Name T Son -se Title Senior Wells Engineer Signature Phone:263-4250 Date R,-1- 1,..013 VLF /2/7"/6/'3 a r,M DEC 1320 Form 10-404 Revised 10/2012 /21" Submit Original Only .30-16A Well Work Summary • DATE SUMMARY 2/12/2013 ( USING 1" SLINKY TOOLSTRING ) UNABLE TO DRIFT 1 3/8" DUMMY SPLIT SHOT PAST 1000' SLM. DRIFT W/ 1" SPLIT SHOT W/ 1.3" BULL NOSE DOWN TO PACKER @ 7648' RKB. E-LINE NEXT STEP. 3/13/2013 SET UP TO PUMP DIESEL W/766 AND DISCOVER TEMP OF DIESEL IS TO HIGH. JOB POSTPONED UNTIL DIESEL GETS TO AMBIENT TEMP. 3/19/2013 WITH SINGLE SPARTEK GAUGE ON 1" SLINKY TOOLSTRING MEASURED BHP @ 7861' RKB: 4009 PSI. COMPLETE. 3/28/2013 SURFACE CASING LEAK INCONCLUSIVE. UNABLE TO PRESSURE OA ABOVE 630 PSI. FLUID LEVEL APPEARS TO BE @ 948'. BUT MAY BE DEEPER SINCE IT HAS KNOWN SHOE LEAK. KNOWN CORKSCREWED TUBING/CASING IN PROXIMITY MAY BE CREATING FALSE FLUID LEVEL. 4/10/2013 DSPL TBG W/200 BBLS OF SLICK DSL. USING SLINKY 1.5"TS UNABLE TO PASS 999'W/2.25" CA-2 PLUG; UNABLE TO PASS 1021'W/ D-RUNNING TOOL; USING SLINKY 1"TS UNABLE TO PASS 1000'W/ 1 3/8" SPLIT SHOT DRIFT. DRIFTED TO 7887' SLM W/ 1.25" X 68" DRIFT BOBBLE © 1004'W/RIH @ 125 FPM ). COMPLETE. 4/30/2013 (AC EVAL) UNABLE TO ESTABLISH IA LLR DUE TO LARGE FILL UP VOLUME. PUMPED 5 BBLS OF DIESEL DOWN IA TO ATTEMPT TO LOAD. 5/2/2013 (AC EVAL): ESTABLISHED LLR OF 0.47 GPM. 7/9/2013 CEMENT SQUEEZE PLUG INTO THE PERFS. PUMPED/BULLHEADED THE FOLLOWING DOWN THE TBG. 10.5# PPG INHIBITED BRINE, 68 BBLS FOR WELL KILL &STEP RATE INJECTION, 5 BBLS WATER SPACER, 17 BBLS OF 15.8 CLASS G CEMENT, DROPPED 4" FOAM BALL, 5 BBLS WATER SPACER, 27 BBLS OF 10.5# INHIBITED BRINE, 12 BBLS OF DIESEL FOR FREEZE PROTECT. ALLOW CEMENT TO SET UP FOR AT LEAST 24 HOURS PRIOR TO PT, IN PROGRESS. NOTE: PUMP REPORT IN ATTACHMENTS. 7/11/2013 PRESSURE TEST CEMENT PLUG TO 2000 PSI, PASSED, IN PROGRESS. 7/18/2013 (SW) JOHN CRISP (WAIVED) MIT-T(PASSED), T-DDT (FAILED), IA-DDT (FAILED). 8/10/2013 ATTEMPT TO SHOOT SPLIT SHOT AT 7610'. COULD NOT GET PAST 7290'. INSTRUCTED BY CWG REP TO SHOOT SPLIT SHOT AT 7280'. LOADED TUBING WITH DIESEL USING THE TRIPLEX TO OBTAIN A TUBING PRESSURE OF 1400 PSI AND IA PRESSURE OF 400 PSI. AFTER FIRING SPLIT SHOT , DID NOT NOTICE IMMMEDIATE PRESSURE EQUALIZATION. WHILE POOH NOTICE GRADUAL PRESSURE DROP IN TUBING. VISUALLY INSPECT THE SPLIT SHOT AND INDICATED THAT IT FIRED. INSTRUCTED TO RIG UP A SECOND SPLIT SHOT AND SHOOT AT 7145'. LOADED TUBING AGAIN TO 2000 PSI AND IA AT 400 PSI. NO IMMEDIATE PRESSURE DROP AFTER FIRING SECOND SHOT, NOTICE GRADUAL PRESSURE DROP WHILE POOH. VISUAL VERIFICATION OF STRING SHOT FIRED IS GOOD. RIG DOWN, TURN WELL OVER TO DSO. 8/14/2013 (AC EVAL): MITT (PASSED @ 2200 PSI). 11/9/2013 FIRED SPLIT SHOT AT 6985'. LOG CORRELATED TO TUBING DETAIL RECORD. SPLIT SHOT FIRED WITH TUBING AT 1700 PSI AND IA AT 450 PSI. TUBING IMMEDIATELY BLED TO 0 PSI UPON FIRING. PUMPED ON TUBING TO TEST COMMUNICATION WITH IA AND IA SHOWED INCREASE IN PRESSURE TO CONFIRM. JOB COMPLETE. 11/18/2013 Performed injectivity test with diesel pumping from Tubing to IA taking returns to process. Established rate of 2.5 bpm @ 250 psi. - Ready for KW brine. 11/22/2013 PUMPED 267BBL OF 12.2# INHIBITED NaBr DOWN TUBING, TAKING RETURNS THROUGH IA TO TIGER TANK. FREEZE PROTECT BY U-TUBING 7.5BBL OF DIESEL. NO PRESSURE ON WH OR IA, JOB COMPLETE. ° 1114 KUP INJ 30-16A• ConocoPhillips Well Attributes Max Angle&MD TD /�,iyr 1,1,, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corlett'r 500292179601 I KUPARUK RIVER UNIT IINJ 43.381 2,600.00 8,351.0 ... Comment I H2S(ppm) I Date Annotation 'End Date KB-Grd(ft) Rig Release Date 30-16A,11/16/201311,10,40 AM SSSV:TRDP Last WO: 9/19/1988 34.98 4/23/1988 Vemcal schematic(actual) Annotation Depth(MKB) End Date Annotation (Last Mod By 'End Date _...Last Tag:SLM 7,887.0 4/22/2012 Rev Reason:TUBING PUNCHES fast 11/16/2013 HANGER;330 g __ Casing Strings Casing Description OD(in) ID(in) Top(ttK8) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade lop Thread �1 � C� CONDUCTOR 16 (in) B) 1B) 115.0 62(50 H-40 WELDED Thr Coning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 2,374.9 2,214.8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(11KB) Set Depth(ftKB) Set Depth(ND)...Wt/Len p...Grade Top Thread PRODUCTION 7 6.276 33.0 8,201.2 6,777.8 26.00 J-55 BTC CONDUCTOR;36.0-115.0 - Tubing Strings • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...WI(lb/ft) Grade Top Connection BUSHING;981.9 .[> TUBING WO 27/8 2.441 33.0 7,721.9 6,385.3 6.50 J-55 EUE8RDABM ��l Completion Details 1 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Intl(°) Item Des Com (in) PACKER;9866, „i'li.L 33.0 33.0 0.03 HANGER CIW TUBING HANGER 2.845 SWIVEL;989.3 f1 986.5 986.4 0.64 PACKER BAKER AL-5 DUAL PACKER 2.380 14:1 1,043.2 1,043.2 2.72 PACKER BAKER AL-5 DUAL PACKER 2.380 Ili 1,786.4 1,744.7 30.57 SAFETY VLV BAKER FVLD SAFETY VALVE,AS PER DESIGN,2.31" 2.310 FVLD FLAPPER CANNOT BE LOCKED OPEN.ONLY ill HYDRAULIC SHEAR SLEEVE CAN BE OPENED. a 7,633.8 6,313.9 36.13 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/12"SEALS 2.406 SAFETY JT;1,033.7 1 Ii' 7,634.8 6,314.7 36.12 PBR BAKER PBR 2.400 7,648.0 6,325.4 36.06 PACKER BAKER HB PACKER 2.362 • 7,687.0 6,356.9 35.88 NIPPLE CAMCO D NIPPLE 2.250 PACKER;1,043.2 °- 7,721.0 6,384.6 35.78 SOS BAKER SHEAR OUT SUB,TTL ELMD 7710'SWS 2.441 427/1988 11 Tubing Description String Ma...ID(in) Top(ftKB) Bet Depth(ft..Set Depth(ND)(...Wt(INS) Grade Top Connection l IS TUBING WO 1.9 1.625 981.9 1,055.5 1,055.4 2.72 BUSHING;1,051.0 '? Short String Completion Details R Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inc!(°) Item Des Corn (in) 1 981.9 981.8 0.63 BUSHING NYLON BUSHING 1.625 SAFETY VLV,1,786.4 ?'.1. 989.3 989.3 0.64 SWIVEL BXP TELESCOPING SWIVEL 1.625 1,033.7 1,033.7 2.27 SAFETY JT SHEAR OUT SAFETY JOINT 1.625 1,051.0 1,051.0 3.10 BUSHING NYLON BUSHING 1.625 SURFACE;35.02,3719-.- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top led GAS LIFT;2,831.6 Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 6,985.0 5,801.3 38.96 TUBING 1"SPLITSHOT 11/9/2013 2.441 PUNCH GAS LIFT;4,844.9 1. 7,145.0 5,925.8 38.80 TUBING 1"SPLITSHOT 8/10/2013 2.441 PUNCH GAS LIFT;5,857.6 7,280.0 6,031.4 38.09 TUBING 1"SPLITSHOT 8/10/2013 2.441 PUNCH GAS LIFT;6,315.0 Perforations&Slots ® Shot GAS LIFT;6,740.2 • Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn TUBING PUNCH;6,985.0 $1 7,794.0 7,804.0 6,443.8 6,451.9 C-1,UNIT B, 3/16/1989 ' 12.0 IPERF 60 deg.phasing;2 1/8" 30-16A EnerJet TUBING PUNCH;7,145.0 7,838.0 7,848.0 6,479.6 6,487.7 A-5,A-3,30- 3/16/1989 6.0 IPERF 30 deg.phasing;2 1/8" 16A EnerJet GAS LIFT;7,161.3 l l 7,850.0 7,860.0 6,489.4 6,497.5 A-3,30-16A 3/16/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet TUBING PUNCH;7,280.0 S. 7,8690 7,889.0 6,504.9 6,521.2 A-2,30-16A 3/16/1989 12.0 IPERF 60 deg.phasing;2 1/8" EnerJet GAS LIFT;7,585.7 Ill 7,908.0 7,928.0 6,536.7 6,553.1 A-1,30-16A 6/22/1988 8.0 APERF 45 deg.phasing;41/2" Ultrapak Csg Cement Squeezes SEAL ASSY;7,6318 - Top(ND) Btm(ND) • Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn PBR;7,634.0 •1 7,790.0 8,200.0 6,440.5 6,776.8 CMT PLUG 7/9/2013 CEMENT SQUEEZE PLUG INTO THE PERFS. PACKER;7,648.0 - PUMPED/BULLHEADED THE FOLLOWING DOWN a THE TBG.10.5#PPG INHIBITED BRINE,68 BBLS FOR WELL KILL 8 STEP RATE INJECTION,5 BBLS NIPPLE;7,687.0 I WATER SPACER,17 BBLS OF 15.8 CLASS G i CEMENT SOS;7.721.0 ! Mandrel Inserts St ati C on Top(ND) Valve Latch Port Size TRO Run 0 No Top(ftKB) (11KB) Make Model OD(in) Sery Type Type (in) (psi) Run Data m IPERF;7,794.0-7,004.D-- 7 2,831.6 2,550.1 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 2 4,844.9 4,118.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 3 5,857.6 4,929.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 IPERF;7,838.0-7,848. • 4 6,315.0 5,282.8 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 5 6,740.2 5,611.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 IPERF;7.850.0-7,860.0- 6 7,161.3 5,938.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7 7,585.7 6,275.1 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/3/2000 IPERF;7,869.0-7,8890- Notes:General&Safety End Date Annotation APERF;7,908.0-7,928. • 9/19/1988 NOTE:Dualstring PKR's run w/1.9"TBG,Parallel to 2 7/8"TBG 8/18/2007 NOTE:POSSIBLE CORKSCREWED TUBING FROM 1020'TO 4036'RKB 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 • 4/22/2012 NOTE:TBG OBSTRUCTION @ 1024'SLM.1"SLINKY TOOLSTRING REQUIRED TO PASS BY. CMT PLUG;7,790.0 PRODUCTION;33.0-8,201.2 • 7,''‘ THE STATE and Gas ®f Ll l Conservation Commission ATE'. r GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 Fax: 907.276.7542 SCANNED MAY 31 2013 Tyson Wiese Senior Wells Engineer ConocoPhillips Alaska, Inc. o Li- 3 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 30 -16A Sundry Number: 313 -256 Dear Mr. Wiese: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4 :30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P > oerster Chair DATED this Z day of May, 2013. End. flGalh,G! V LlJ STATE OF ALASKA �`���, . A OIL AND GAS CONSERVATION COMMI N y(��j APPLICATION FOR SUNDRY APPR ALS — 1 ( 6 , 1/ ( A �� 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations (iI' Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well E Stimulate r Alter casing r Other: C 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188 - 043 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21796 - 01 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No rd 30 -16A ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25513 • 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): 8351 6901 Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 2340 12 2375' 2215' PRODUCTION 8168 7 8201' 6778' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7794 - 7804, 7838 - 7848, 7850 - 7860, 7869 - 7889, 7908 - 7928 6444 - 6452, 6480 - 6488, 6489 - 6498, 6505 - 6521, 6537 - 6553 2.875 J -55 7721 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER AL -5 DUAL PACKER MD= 986 TVD= 986 PACKER - BAKER AL -5 DUAL PACKER MD= 1043 TVD= 1043 • PACKER - BAKER HB PACKER MD= 7648 TVD= 6325 SSSV - BAKER FVLD MD = 1786 TVD = 1745 - 12. Attachments: Description Summary of Proposal r; • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r7 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2013 Oil l Gas r WDSPL r Suspended l 16. Verbal Approval: Date: WINJ r✓ • GINJ r WAG r Abandoned r Commission Representative: GSTOR r" SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Email: Tvson.M.Wieseaa.cop.coni Printed Name Tyson Wie Title: Senior Wells Engineer Signature n Phone: 263 -4250 Date 5 J').,1 /WS Commission Use Only Sundry Number: 313 ' 2 510 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity V BOP Test r Mechanical Integrity Test r Location Clearance r \ .E RBDMS MAY 31 201 Other: Spacing Exception Required? Yes ❑ No Er Subsequent Form Required: /`: g I / / 7 / APPROVED BY Approved by: (/ C/ rj�L,>/ TL`,�' COMMISSIONER THE COMMISSION Date: 5 — L 1 Approved application is valid for 12 months from the date of approval. Form 10 -403 (Revised 10/2012) Submit Form and Attachments in Duplicate ?� \ \ \' v`iF51Ai13 ORIGINAL ��o 5 N 7 ■. -- I a _. 1t 9 I A.... ■ 1 • • 30 -16A Cement Squeeze Permit to Drill #: 188 -043 The objective of the proposed 30 -16A cement squeeze is to isolate the Kuparuk formation. The well will not pass an MIT -IA, will not pass an MIT -OA due to failed surface casing shoe, has a known 7" casing leak that is currently straddled, and there is a tubing restriction at approx. 1,002', that will only allow 1" slinky tool string to drift. The well is planned for a subsidence style RWO /CTD setup to restore injection in the area, but needs to be secured with cement while we can still access the wellbore and create a circulation point for KWF, due to well control barrier concerns. Proposed Cement Squeeze Procedure: Schlumberger Pumping Services: 1. Ensure 10 -403 has been approved by the AOGCC. 2. Pump a 17 bbl 15.8# Class G fullbore cement plug, squeezing 10 bbls into the A and C sand perfs. 3. Estimate TOC after displacement is across the bottom packer @ 7,648' KB. RDMO Slick Line / Little Red / DHD: 1. Notify AOGCC Inspector by email (AOGCC.Inspectorst7alaska.gov) 24 hours before plug tests. 2. WOC for 24 hours or until 2,000 psi compressive strength is developed. ,Note r-y 3. Pressure Test the cement plug to 2,000 psi. Record Results 4. RIH with 1" tools to drift through restriction and tag TOC @ approx. 7,648' KB. Record Results. ti 5. Dummy drift for 1" split shoot tool string for upcoming E -line step. w`o" 6. Perform DDT on Tubing and IA, ensure well will pass a 30 min no flow test. Record Results. RDMO E -line / Little Red: 1. RIH with 1" slinky tool string and 1" split shot. Detonate split shot @ approx. 7,610' KB. Middle of 1 full joint above the bottom packer. 2. Pump 20 bbls diesel to confirm communication with the IA. 3. Once IA communication is confirmed, Pump 268 bbls of 12.2# Inhibited NaBr (KWF) and 7.5 bbls diesel to freeze protect well to 200' KB. Well should be approx. 50 psi overbalanced at this point. 4. RDMO. 1 �pn Gv�• y���� TW TOC @ 6, • • 353' TV 30 -16A PTD #: 188 -043 Cement Squeeze Kuparuk A and C S and Perfs KB Current Completion Proposed Cement Squeeze J L. 16' 62.50# H -40 Casing @ 115' KB 1 ": Baker AL -5 Dual Packer @ 986' KB 1.) Pump 17 bbls of 15.8# Class G 4 — 7" Casing Leak between straddle ► Cement Fullbore down tubing to <,.. _ , Tubing Restricted to 1° wireline isolate the perfs. tools @ appr 1 _ Baker AL -5 Dual Packer ker @ 1,00 43' KB 2.} WOC 24 hours. Notify AOGCC of upcoming cement plug tests / (� Baker FVLD SSSV @ 1,786' KB • .: 3.) PT cement plug to 2 psi. j / Record Results 9 518" 36# J-55 Casing @ 2,375' KB ,/' 4.) Perform DDT on • � . �Foiied OA Surface Shoe ..�. ' Tubing and IA. Confirm No -Flow tests will pass. II 5.) Tag TOC. GLh1's: Record Results. DMY @ 2,832' KB Dummy drift for 1" DMY @ 4,845' KB split shot E -line DMY @ 5,858' KB tool. DMY @ 6.315' KB DMY @ 6,740' KB 11 6.) RIH wr 1" split DMY @ 7,161' KB shot and shot hole DMY @ 7,586' KB NO in tubing @. 7,610' ■ KB. 7.) Confirm IA communication and Toad the well with III KWF (heavy brine) and diesel F.P. mi Baker HB Packer @ 7,648' KB rroommo — roc 76 is 7/1` P riltif,-_,...„2" 7 red I 225" D Nipple @ 7,687 KB MO ria And mom 2718 " "6.`#J55 Tubing (a?7,721'KB $3 I Tdr p C .,. ...-7. " — Ma = C -Sand Perfs: 7,794' - 7,804' KB A -Sand Perfs: 7,838' - 7,848' KB ... / : : :::!: :: :;i: `: 7,850' - 7,860' KB _ 7,869' - 7,889' KB `� ;::i:: :' :':' 7,908' - 7,928' KB Fill @ 7,887' KB Ad11:: i i : i : , ' lib. 7" 26# J - -55 Casing @ 8,201' KB TW KUP s 30 -16A 01.- Conoc©Phillips Well Attributes `� Max Angle & MD TD Alaska .lm Wellbore API /UWI Field Name Well Status Ind (°) MD (ftKB) Act Btm (ftKB) Comm;Maps 500292179601 KUPARUK RIVER UNIT INJ 43.38 2,600.00 8,351.0 • - Comment H2S (pprn) Date Annotation End Date KB (ft) Rig Release Date "- SSSV: TRDP Last WO: 9/19/1988 34.98 4/23/1988 Well Congo: - 30.16A, 424/2012 9'.37:35 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag' SLM 7,887.0 4/22/2012 Rev Reason: TAG, NOTE ninam 4/24/2012 Casing Strings Casin Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 33 !A CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd RE . 35.0 2,374 2 ,214.8 36. BTC M r Casing Description String 95/8 0... String ID ... Top (RKB) Set Dept (f... Set De pth (ND) ... String Wt. .. String J - 55 ... String Top Thrd PRODUCTION 7 6.276 33.0 8,201.2 6,777.8 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 0ONDUC706, TUBING 27/8 2.441 33.0 7,721.9 6,385.5 6.50 J -55 EUE8RDABM 36 -115 Completion Details EE Top Depth (N0) Top Intl Nomi... Top (ftKB) (ftKB) ( °) Item Deacription Comment ID (18) 33.0 33.0 0.02 HANGER CIW TUBING HANGER 2.845 PACKER, 986 986.5 986.4 0.64 PACKER BAKER AL -5 DUAL PACKER 2.380 1,043.2 1,043.1 2.97 PACKER BAKER AL -5 DUAL PACKER 2.380 1,786.4 1,744.6 30.57 SAFETY VLV BAKER FVLD SAFETY VALVE, AS PER DESIGN, 2.31" FVLD 2.310 FLAPPER CANNOT BE LOCKED OPEN. ONLY HYDRAULIC SHEAR n SLEEVE CAN BE OPENED. A, 7,633.8 6,313.9 35.96 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/ 17' SEALS 2.406 7,634.8 6,314.7 35.95 PBR BAKER PBR 2.400 7,648.0 6,325.4 35.93 PACKER BAKER HB PACKER 2.362 7,687.0 6,356.9 35.85 NIPPLE CAMCO D NIPPLE 2.250 PACKER, 1,043 7,721.0 6,384.8 35.97 SOS BAKER SHEAR OUT SUB, TTL ELMD 7710' SWS 4/27/1988 2.441 Perforations & Slots Shot Top (TVD) Btm (ND) Dens Top (ftKB) Btm (ftKB) (RKB) ((KB) Zone Date (sh - Type Comment 7,794 7,804 6,443.8 6,452.2 C -1, UNIT B, 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet 30-16A SAFETY VLV 1,788 o 1 I 7,838 7,848 6,479.7 6,487.8 A -5, A -3, 30 -16A 3/16/1989 6.0 IPERF 30 deg. phasing; 2 1/8" EnerJet 7,850 7,860 6,489.4 6,497.6 A -3, 30 -16A 3/16/1989 12.0 IPERF 60 deg. phasing; 21/8" EnerJet i 7,869 7,889 6,504.9 6,521.2 A -2, 30 -16A 3/16/1989 12.0 IPERF 60 deg. phasing; 21/8" EnerJet t 7,908 7,928 6.536.7 6,553.1 A -1, 30 -16A 6/22/1988 8.0 APERF 45 deg. phasing: 4 1/2" Ultrapak Csg SURFACE, l Notes: General & Safety 35 -2,375 • End Date Annotation 9/19/1988 NOTE: Dualstring PKR's run w/ 1.9" TBG, Parallel to 2 7/8" TBG GAS LIFT, z,e3z 8/18/2007 NOTE: POSSIBLE CORKSCREWED TUBING FROM 1020' TO 4036' RKB 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 4/22/2012 NOTE: TBG OBSTRUCTION @ 1024' SLM. 1" SLINKY TOOLSTRING REQUIRED TO PASS BY. 4,845 GAS LIFT, 5,858 GAS LIFT, 8,31 3 5 GAS LIFT, 6,740 GAS LIFT, 7,161 GAS LIFT, 7,586 SEAL ASSY, 7,634 PBR, 7,635 PACKER, 7,648 NIPPLE, 7,687 506, 7,727 - PERF, 7,7947,804 Mandrel Details IPERF, Top Depth Top Port 7,838 -7.e48 (ND) Inc! OD Valve Latch Size TRO Run Stn Top (RKB) (ftKB) ( Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, ® 1 2,831.6 2,550.4 40.47 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 7,850 -7,860 2 4,844.9 4,118.5 38.80 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 -IN IPERF, 3 5,857.6 4,929.8 39.38 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7,889 -7,889 4 6,315.0 5,282.8 39.45 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 APERF, 5 6,740.2 5,611.6 39.30 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7,908 -7,926 M El 6 7,161.3 5,938.6 38.77 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7 7,585.7 6,275.1 36.35 MERLA TGPD 1 12 GAS LIFT DMY RK 0.000 0.0 4/3/2000 PRODUCTION, 33 - 8,201 • TD (30.16A), 8,351 • C1 30,- 1A- Pr Ij 43c Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Friday, April 13, 2012 11:03 AM e 1 4 6 31 t v To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: RE: 30 -16A (PTD 188 -043) Report of suspect TxIA communication while on MI injection Jim, Guy The follow up MITIA has failed indicating the leak has worsened. Further diagnostics will be performed with Slickline and potentially E -Line. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Li 2 Pager (907) 659 -7000 pgr. 909 , APP 1 From: NSK Problem Well Supv Sent: Sunday, March 18, 2012 10:52 AM To: 'Regg, James B (DOA)'; Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: RE: 30 -16A (PTD 188 -043) Report of suspect TxIA communication while on MI injecti• Jim, Guy Following up with the report below. The well was WAG'd to water injection on 03/07 2. On 03/12/12, a passing MITIA (see attached form), a passing IA draw down test and tubing packoff tests were p- ormed. After monitoring the pressure trends for a couple of days following the tests, the IA pressure rose back up a repeated bleeds were performed due to suspected thermal expansion. On 03/16/12 the trends would indicate the pr- sure increase is not due thermal issues and the well was SI on 03/17/12 which was as soon as could be done safely de to the North Slope weather. A follow up MITIA and draw down test will be performed to identify if e previous situation has changed. Any appropriate paperwork will be submitted for repair or continuing injection. Please let me know if you have any questions. « File: MIT KRU 30 -16A 03- 12- 12.xls » Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 f Pager (907) 659 -7000 pgr. 909 ' From: NSK Problem Well Supv ;� Sent: Tuesday, March 06, 2012 8:1, AM To: 'Regg, James B (DOA)'; 'guy.,schwartz @alaska.gov' Subject: 30 -16A (PTD 188 -0 Report of suspect TxIA communication while on MI injection 03 -06 -12 Jim, Guy Kuparuk injection well 30 -16A (PTD 188 -043) was reported to have suspect TxIA communication due to pressure monitoring and frequent bleeds on the IA. The well is currently on MI injection and will be WAGed to water as soon as • • qtr _ 1'360430 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] er7 . 3I aI I � Sent: Sunday, March 18, 2012 10:52 AM � I I To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: RE: 30 -16A (PTD 188 -043) Report of suspect TxIA communication while on MI injection Attachments: MIT KRU 30 -16A 03- 12- 12.xls; 30 -16A 90 day TIO.ppt; 30 -16A schematic.pdf Jim, Guy Following up with the report below. The well was WAG'd to water injection on 03/07/12. On 03/12/12, a passing MITIA (see attached form), a passing IA draw down test and tubing packoff tests were performed. After monitoring the pressure trends for a couple of days following the tests, the IA pressure rose back up and repeated bleeds were performed due to suspected thermal expansion. On 03/16/12 the trends would indicate the pressure increase is not due thermal issues and the well was SI on /03 17/12 which was as soon as could be done safely due to the North Slope weather. A follow up MITIA and draw down test will be performed to identify if the previous situation has changed. Any appropriate paperwork will be submitted for repair or continuing injection. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 b? ik',,; - BAR nyz. Pager (907) 659 -7000 pgr. 909 From: NSK Problem Well Supv Sent: Tuesday, March 06, 2012 8:19 AM To: 'Regg, James B (DOA)'; 'guy.schwartz @alaska.gov' Subject: 30 -16A (PTD 188 -043) Report of suspect TxIA communication whi - on MI injection 03 -06 -12 Jim, Guy Kuparuk injection well 30 -16A (PTD 188 -043) was reported to ha • suspect TxIA communication due to pressure monitoring and frequent bleeds on the IA. The well is currently •n MI injection and will be WAGed to water as soon as possible. After the WAG, initial diagnostics are planned to i ude tubing packoff testing, an MITIA and an IA DD test if the MITIA passes. An update will be sent following those • agnostics and if the MITIA fails, the well will be SI and freeze protected while awaiting further diagnostics with Slickli and possibly E -Line. The well will be added to the monthly report. Pens' g the outcome of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as nee• -d. Attached is the schematic and 90 day TIO • ot. Please let me know if you have any • uestions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, In Desk Phone (907) 659 - 24 Pager (907) 659 -700ti pgr 909 Prb i Q8043G Well Name 30 -16A Notes: TxIA communication while on gas Start Date 1217,2011 Days 90 End Date 3/6/2012 Annular Communication Surveillance 4500 - 1(V11P - 140 I - - 120 3600 - 100 3000 - 80 . 2500 u. 0 2000 - 60 1500 - 40 1000 - 20 500 0 0 • Dec -11 Jan -12 Feb -12 Mar -12 DGI (v11,1 - PWI SWI - BLP 8 -A too 100 Dec -11 Jan -1 Feb -12 Mar -12 Date w ,,, l KUP 30 -16A ConocoPl illips m `4 ° . , Well Attributes Max Angle & MD TD Alaska' Irir; . Wel!bore API /UWI Field Name Well Status Inc! (°l MD (ftKB) Act Btm (ftKB) GenoaoPfalllps 500292179601 KUPARUK RIVER UNIT INJ 43.38 2,600.00 8,351.0 "'"'" Comment H25 (ppm) Date Annotation End Date KB (ft) Rig Release Date Well Conti. • 30 2/28/2012 4 .28 30 PM SSSV: TRDP Last WO: 9/19/1988 34.98 4/23/1988 chemehc teal Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 7,925.0 11/19/2004 Rev Reason: FORMAT UPDATE ninam 2/28/2012 Casing Strings ti Casing Description String 0... String ID ... Top (RKB) Set Depth (r... Set Depth (TVD) ... String Wt...' String .. String Top Thrd MANGER, 33 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top )RKB) Set Depth (L.. Set Depth (TVD) ... String Wt... String ... String Top Thrd 95/8 8.921 35.0 2,374.9 2,214.8 36.00 J BTC Casing Description String 0 String ID ... Top (RKB) Set Depth (L. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 33.0 8,201.2 6,777.8 26.00 J-55 BTC Tubing Strings l i .0 az Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... string Top Thrd CONDUCTOR, TUBING 27/8 2.441 33.0 7,721.9 6,385.5 6.50 J -55 EUE8RDABM 36118 Comp Detaiisli i< Top Depth (ND) Top Mel 591111... p` , ' Top (1IKB) (RKB) (.) nem Deecriptlon Comment ID On) 33.0 33.0 0.02 HANGER CIW TUBING HANGER 2.845 PACKER, 966 986.5 986.4 0.64 PACKER BAKER AL -5 DUAL PACKER 2.380 1 1,043.2 1,043.1 2.97 PACKER BAKER AL -5 DUAL PACKER 2.380 1,786.4 1,744.6 30.57 SAFETY VLV BAKER FVLD SAFETY VALVE 2.310 7,633.8 6,313.9 35.96 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/ 12" SEALS 2.406 7,634.8 6,314,7 35.95 PBR BAKER PBR 2.400 7,648.0 6,325.4 ' 35.93 PACKER BAKER HB PACKER 2.362 IN 7,687.0 6,356.9 35.85 NIPPLE CAMCO D NIPPLE 2.250 7,721.0 6,384.8 35.97 SOS BAKER SHEAR OUT SUB, TTL ELMD 7710' SWS 4/27/1988 2.441 PACKER. 1.043 Perforations & Slots Shot 'ff Top (TVD) Btm (TVD) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (sh••• Type Comment 7,794 7,804 6,443.8 6,452.2 C -1, UNIT B, 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet 30-16A 7,838 7,848 6,479.7 6,487.8 A -5, A -3, 30 -16A 3/16/1989 6.0 IPERF 30 deg. phasing; 2 1/8" EnerJet 7,850 7,860 6,489.4 6,497.6 A -3, 30 -16A 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet SAFETY VLV, 1 7,869 7,889 6,504.9 6,521.2 A -2, 30 -16A 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet ate: 7,9081 7,928 6,536.71 6,553.1 A -1, 30 -16A 1 6/22/1988 8.0 APERF 45 deg. phasing; 4 1/2" Ultrapak Csg ■ Notes: General & Safety End Date Annotation 9/19/1988 NOTE: Dualstnng PKR's run w/ 1.9" TBG, Parallel to 2 7/8" TBG SU 35- 75 8/18/2007 NOTE: POSSIBLE CORKSCREWED TUBING FROM 1020' TO 4036' RKB 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IC OAS LIFT, 2,832 GAS LIFT, ilt 4,845 II GAS UFT. 5.858 °-,g6 II it OAS LIFT, it 8,740 it OAS LIFT, 7,181 GAS UFT. 7.586 AC SEAL ASSY, 7,634 PBR. 7.835 PACKER, 7,648 te NIPPLE. 7.687 it SOS, 7,721 -.. IPERF, 7,794 -2804 IPERF, Top Depth Top _ Port 7,8367,848 (ND) 1001 OD Valve Latch Size TRO Run Stn Top (RKB) (RKB) P) Make Model (in) Sery Type TYPe ON (pei) Run Date Com... PERF, III 1 2,831.6 2,550.4 40.47 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 7,8667,860 2 4,844.9 4,118.5 38.80 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 IPERF, _ 3 5,857.6 4,929.8 39.38 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7,86&7,869 -- - - _. - - 4 6,315.0 5,282.8 39.45 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 5 6,740.2 5,611.6 39.30 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 APERF, 7.9067928 6 7,161.3 5,938.6 38.77 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7 7,585.7 6,275.1 36.35 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/3/2000 PRODUCTION. 33-5.201N, TD (30 -18A), 8.351 0 Ornhh. KUP • 30 -16A Conoco Phil ips Alaska. Inc. V '4 '111 c«Iwwtathps "` Annotation End Date KB-Ord (M) Rig Release Date ••• (Last WO: 34.98 4/23/1988 40 Well COnfi9: - 30 -1 em 6A atic-Ac , 2282tual 012428:�PM i ' - - -- -- . • -_. HANGER 33 I r CONDUCTOR, 36115 li PACKER. 986 ID PACKER. 1,043 _ it it SAFETY VLV, _ 1.786 l SURFACE, A 362,375 GAS LIFT, 2,832 Ott" GAS LIFT, 6,865 0 a GAS LIFT, 5,858 GAS UFT, 8,315 li lt GAS LIFT, _ 6.740 1 GAS .16 7,787 OK: GAS LIFT, 7.586 SEAL ASSY, 7.634 PBR, 7.635 - PACKER, 7,648 NIPPLE, 7.687 ,[ SOS, 7,721 !_:... IPERF, = -`... 7,7947,804 IPERF, 7,8367,818 IPERF, 7,850.7.860 1° _�..r. IPERF, 7,8647,889 APERF, 7,9067,928 TT.... _,,,, 1 PRODUCTION, 338,201 ' TD (30 -16A), 8,351 • • ICS,( 3D - ' ati3o Regg, James B (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] 6/ Sent: Tuesday, March 06, 2012 8:19 AM " To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: 30 -16A (PTD 188 -043) Report of suspect TxIA communication while on MI injection 03 -06 -12 Attachments: 30 -16A 90 day TIO.ppt; 30 -16A schematic.pdf Jim, Guy Kuparuk injection well 30 -16A (PTD 188 -043) was reported to have suspect TxIA communication due to pressure monitoring and frequent bleeds on the IA. The well is currently on MI injection and will be WAGed to water as soon as possible. After the WAG, initial diagnostics are planned to include tubing packoff testing, an MITIA and an IA DD test if the MITIA passes. An update will be sent following those diagnostics and if the MITIA fails, the well will be SI and freeze protected while awaiting further diagnostics with Slickline and possibly E -Line. The well will be added to the monthly report. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as needed. Attached is the schematic and 90 day TIO plot. 7 Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 ` t.y t!' * MAR 7 ZU12 1 t 0 1 . 1 3 0 Prt Well Name 30 -16A Notes: TxIA communication while on gas Stan/ Date 12/7/2011 Days 90 End Date 3.612012 Annular Communication Surveillance 4500 WHP - 140 IAI 4000 - OAP WNT - 120 3500 - 100 • 3000 - 80 2500 ML 0 2000 'a - so 1500 - 40 1000 - 20 500 0 0 • Dec -11 Jan -12 Feb -12 Mar -12 DOI 61431 -PW1 SW1 -BLPD y zoo zoo too li oil Dec -11 Jan-1 2 Feb -12 Mar -12 Date �yy ��ry¢ rya p - KU P 30 16A Coi iSico ' ail li ' IDM ,,,k40;1;:,( -. r is i ---- 1 • ° -p 11 ::. a r t E We11 I :I C' : , 1NI. Inc - W I lbore A P W WI Field N ame - c Well Sta I ( °) MD (RKB) Act Btm (ftKB) ' ' 500292179601 KUPARUK RIVER UNIT INJ 43.38 2,600.00 8,351.0 """ Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date . °. well ccws, - 3O - 16A i 228Pm12 4.2830 PM SSSV: TRDP Last WO: 9/19/1988 34.98 4/23/1988 S c he mat w- Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: RKB 7,925.0 11/19/2004 Rev Reason: FORMAT UPDATE ninam 2/28/2012 _ - Casg esc Dription String O,. String ID , Top (818(8)) Set De (f.. Set Depth ( .. HANGE 33 String Wt... String ... String Top Thrd x , CONDUCTOR 16 15.062 36. 115.0 115.0 62.50 H-40 WELDED ,.. PRODUC cripti n Stri g 0... Stri 6.276 ID Top 33 0 ) Sot Depth ( Set D th (TVD)... D) String in 0 . String r 55 ... String Thrd Top i � Casing Descnpho String O Strang ID Top ( Set D (f Set Depth Strin Wt . String Strang Top Thrd r '. �;,1 I ti �� 1 1 1 III M' r 4 p 1 ( _ . F t ,:.a I a . String .. St Top Thrd �i l iL l 'I_ Tubing Description String 0... String ID ... To (ttK8 Set Depth (f... Set Depth (TVD)... String Wt.. .rang Top CONDUCTOR. TUBING 2 7/8 2.441 33 0 7 721 9 6,385.5 6 50 J EUE8RDABM 36-115 , i i _ D etei . sill r r . 1 L.. 1 I' _- r I iI 1 1 n �I, m - Top Depth (TVD) Top Intl Nomi... - -- Top (ttK8) (ttK (°) Item Description Comment ID (in) 33.0 33.0 0.02 HANGER CIW TUBING HANGER 2.845 PACKER, 988 986.5 986.4 0.64 PACKER BAKER AL -5 DUAL PACKER 2.380 in 1,043.2 1,043.1 2.97 PACKER BAKER AL -5 DUAL PACKER 2.380 1,786.4 1,744.6 30.57 SAFETY VLV BAKER FVLD SAFETY VALVE 2.310 7,633.8 6,313.9 35.96 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY w/ 12" SEALS 2.406 7,634.8 6,314.7 35.95 PBR BAKER PBR 2.400 7,648.0 6,325.4 35.93 PACKER BAKER HB PACKER 2.362 7,687.0 6,356.9 35.85 NIPPLE CAMCO 0 NIPPLE 2.250 7,721.0 6,384.81 35.97 SOS BAKER SHEAR OUT SUB, TTL ELMD 7710' SWS 4/27/1988 2.441 PACKER. 1.043 ... ; if ? ( .w . b1" i hot „i ll rll• ' 1 R r�bratl� si &Slots S Top (TVD) Btm (TVD) Dens Top (RKB Btm (118(8) MB) (ttK8) Zone Date ( Type Comment 7,794 7,804 6,443.8 6,452.2 C-1, UNIT B, 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet N1 30-16A 7,838 7,848 6,479.7 6,487.8 A-5, A -3, 30 -16A 3/16/1989 6.0 IPERF 30 deg. phasing; 2 1/8" EnerJet SAFETY VLV, _ 7,850 7,860 6,489.4 6,497.6 A -3, 30-16A 3/16/1989 12.0 IPERF 60 deg. phasing; 2 1/8" EnerJet 1,788 Irs1 7,869 7,889 6,504.9 6,521.2 A -2, 30 -16A 3/16/1989 12.0 IPERF 60 deg. phasing; 21/8" EnerJet 7,908 7,928 6,536.7 6,553.1 A -1, 30 -16A 6/22/1988 8.0 APERF 45 deg. phasing; 4 1 /2" Ultrapak Csg Notes: General &.Safety End Date Annotation 9/19/1988 NOTE: Dualstnng PKR's run w/ 1.9" TBG, Parallel to 2 7/8" TBG suRF Z37 5 6 ' 8/18/2007 NOTE: POSSIBLE CORKSCREWED TUBING FROM 1020' TO 4036' RKB GAS LIFT, 12/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2.832 lig GAS LIFT. IL 4,845 I OAS LIFT, .-_.,;,. 5,858 O GAS LIFT, 6.315 I I GAS UFT, 8,740 GAS LIFT, 7,161 GAS LIFT, let:: 7,586 III Si SEAL ASSY, 7,634 P812, 7,635 t PACKER, 7,648 ir- NIPPLE, 7,687 iii SOS. 7,721 IPERF, - 7,794.7,804 - - - Mandrer J r . 9 k' € 9 E3, u ( 1 111 i ' IPERF, - m Top Depth Top Port 7.836.7,848 (TVD) Inel OD Valve Latch Size TRO Run Stn Top (ttK8) (RKB) ( °) Make Model (in) Sery Type Type On) (pal) Run Date Corn... IPERF, = 1 2,831.6 2,550.4 40.47 McMu.., FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 Tsso -Tes° 2 4,844.9 4,118.5 38.80 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 IPERF. - 3 5,857.6 4,929.8 39.38 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7.869.7,889 - 4 6,315.0 5,282.8 39.45 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 3/14/1990 5 6,740.2 5,611.6 39.30 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 APERF, zs08-7,928 - = 6 7,161.3 5,938.6 38.77 McMu... FMHO 1 GAS LIFT DMY BK 0.000 0.0 9/19/1988 7 7,585.7 6,275.1 36.35 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/3/2000 1 1 PRODUCTION, 33 -8.201 TD (30 -16A), 8,351 KU P • 30 -16A I t Conoco , Inc. a UnxserdM'u8.P5 <� Annotation End Date KB-Ord (K) Rip Release Date ••• Well Confi9 M 3O-18A 22812012428.30'.P LBSt WO: 34.98 4/23/1988 Schematic • Actual HANGER, 33 CONDUCTOR, I 36-115 PACKER.986 it it gi- ll PACKER, 1,093 - -_ H I SAFETY VLV, 1.786 II SURFACE, a 352.375 GAS LIFT, • 2.832 GAS LIFT, 4.845 IL GAS LIFT. 5,858 4K . GAS LIFT, 6,315 • GAS LIFT, _ • 6.740 ". ',. IL GAS LIFT, 7,161 it GAS LIFT, 7 ,586 It SEAL ASSY, 7.634 PBR. 7.635 PACKER. 7.648 NIPPLE, 7.687 5O5. 7,721 IPERF. 7.794 -7,804 IPER 7,638 -7,848 F, IPERF, 7,850.7.860 -. ... ... - IPERF. 7,869 -7,889 APERF, 7.9057,928 I PRODUCTION. 308.20 �� TD (30-16A), 8.351 1 ~ ~REC~IVED ~onocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: APR 0 ~ ~~2fl1Q ~1~il~GasC~ns.C~~~ ~~ 0 ~' 3 tg~, ~ ~A Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRII). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor i • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/31/10 ~e_ sR ~r. ~r. ~W ~i ~i inn ~n ~ zR cen~~ ell Name PI # TD # Initial top o cement Vol. of cement um ed - Final top of cement Cement top off date -•. - Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-02 50029214310000 1852050 Surtace n/a 26" n/a 4.25 3/292010 3A-04 50029214330000 1852070 SF n/a 26" n/a 4.25 3292010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3292010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3/292010 3B-10 50029213660000 1851140 6'6" n/a 6'6" n/a 25.5 3/282010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/27/2010 3G-08 50103201280000 1900650 SF 0.65 27" 32/10 5.52 3/28/2010 3G-09 50103201290000 1900670 SF 0.60 22" 32/10 4.67 3/28/2010 3G-22 50103201470000 1901420 SF Na 22" n/a 4.25 3/28/2010 3H-01 50103200840000 1871100 SF n/a 21" Na 4.25 328/2010 3H-03 50103200850000 1871110 17" 0.40 8" 3/21/10 1.7 3/282010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 3/292010 31-02 50029215150000 1853080 SF n/a 22" n/a 2.97 3/292010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3/292010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/282010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/282010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 3/28/2010 3M-05 50029217060000 1870250 SF Na 21" n/a 3.4 3/292010 3M-07 50029217080000 1870270 SF n/a 22" n/a 4.25 3/292010 30-09 50029218250000 1880610 SF Na 23" n/a 4.25 3/27/2010 3O-16A 50029217960100 1880430 SF Na 22" Na 3.52 3272010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3/27/2010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 3/27/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 327/2010 3R-19 50029222690000 1920460 1" Na 21" n/a 5.1 327/2010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3/272010 ~ I • • MEMORANDUM To: Jim Re ~~ P.I. Supgi~gvisor , ~~' 7r~Z~v~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July O1, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 30-16A KUPARUK RIV LTNIT 30-16A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARiJK RN iJNIT 30-16A Insp Num: mitCS090630093725 Rel Insp Num: API Well Number: 50-029-21796-01-00 Permit Number: 188-043-0 / Inspector Name: Chuck Scheve Inspection Date: 6/27/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ 30-16A Type Inj. G 'j'~ 6325 jA 1250 2400 i 2120 2060 2060 p.T.D 1880430 TypeTest SPT Test psi 1581.25 QA 320 320 320 320 320 IntePVal 4YRTST P~ P ~ Tubing 3900 3900 3900 3900 3900 Notes• Initial pressures losses likely due to gas in annulus. Well took 8.6 bbls to pressure up. .~ ~, , `'. ~: ~r" .. ._ ff . t 4 (.~ ~ d f' ~ i U (,. Wednesday, July O1, 2009 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~~~ S~::~isor ~tfl 7( z/)- Jü(p DATE: Monday, June 26, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 30-16A KUPARUK RIV UNIT 30-16A ~~ DL\? \C!Q FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::JF;IZ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 30-16A API Well Number 50-029-21796-01-00 Inspector Name: John Spaulding Insp Num: mitlS060620065630 Permit Number: 188-043-0 Inspection Date: 6/17/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 30-16A IType Inj. ! w TVD 6325 I IA 1790 2330 2320 2320 ì I I P.T. i 1880430 ITypeTest ¡ SPT Test psi 1581.25 OA 440 440 440 440 i I Interval 4YRTST PIF P ;/ Tubing 3000 3000 3000 3000 f Notes 1.5 diesel to test pressure "1t:~~i,~¡J ~'iij:':r: .......ioKJ ¡,.¡ ~) ¡,_.,.~. Monday, June 26,2006 Page I of I MEMORANDUM TO: THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission Tom Maunder P.I. Supervisor/~ ~ '[ i I[, /, Camille Taylor ~ DATE: June 28, 2002 Chair SUBJECT: Mechanical Integrity Tests PAl 3O multiple John H. Spaulding KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL WellI 30-14 P.T.D.I 1880390 Notes: P.T.D.J 1880430 Notes: IWelll 3o-~7 J P.T.D. J 1880290 Notes: P.T.D.I Notes: we"I P.T.D.I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type inj. J GI T.V.D. J6420 I Tubing'J 3700 I ,oo I ,oo I J intervalJ 4I Type testJ P J TestpsiJ 1605 JCasingJ 1500J 2080I 2080I 2080I P/F I _PR Type,nj.J G J T.V.D. J6325 J'Tubingl~ I~0 I~0 I~0 J,nterva, J 4 Type testJ P 'jTestpsiJ 1581 J CasingJ 1860J 2540J 254OI 2520J P/F I P; Type,nj.J G J T.V.D. J6391 ~o I~,o I~,oi ~,o J lnterva, J 4 Type testJ 'P J TestpsiJ 1598 JCasingJ 2075 J 2450 J 2450' J 2450 J P/F I El Typel~. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Page 2 of 2. As noted on the preceeding test report forms, no failures were observed. Jon Arend (APC) was the PAl company rep. M.I.T.'s performed: 3 Attachments: none Number of Failures: _0 Total Time during tests: 2 cc: none MIT report form 5/12/00 L.G. 020628-mit(2) kru 30 js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate_ Pull tubing_ Alter casing_ Repair well_ Other _X WI to WAG Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1104' FNL, 3217' FEL, Sec. 22, T13N, R9E, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service__X (asp's 525698, 6021714) 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3O- 16A At top of productive interval 3983' FNL, 703' FEL, Sec. 21, T13N, R9E, UM At effective depth At total depth 3533' FNL, 1355' FEL, Sec. 21, T13N, R9E, UM (asp's 522294, 6019275) 9. Permit number / approval number 188-043 / 10. APl number 50-029-21796-01 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8351 feet Plugs (measured) 6901 feet Effective depth: measured true vertical Casing Length CONDUCTOR 1 15' SUR. CASING 2316' PROD. CASING 8142' feet Junk (measured) feet Size Cemented 16" 175 sxAS I 9-5/8" 900 sx AS III & 300 sx AS II w/100 7" 700 sx TLW & 300 sx Class G & 175 sx AS I Perforation depth: measured 7794-7804; 7838-7848; 7850-7860; 7869-7889; 7908-7928 true vertical 6444-6452; 6480-6488; 6489-6498; 6505-6521;6537-6553 Tubing (size, grade, and measured depth) #N/A Measured Depth 115' 2375' 8201' True verticalDepth 115' 2215' 6778' Packers & SSSV (type & measured depth) BAKER 'AL-5' DUALSTRING @ 986' MD; BAKER 'AL-5' DUALSTRING @ 1043' MD; BAKER 'HB' @ 7648' MD; BAKER 'FVLD'. @ 1786' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mc! Water-Bbl 1235 2325 Casing Pressure Tubing Pressure 2856 3990 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil m Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /-'~"~ ~'~ ~/"?/~'~~~'~"~ Title Production Engineering Supervisor Jeff A.,~pencer Questions? Call Jeff Spencer 659-7226 Prepared by Robert Christonson 659-7535 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 30-16A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary ': ' ii0/26/96:! commencediEOR::injecfi°n:~'~i ' ~: ":' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__.~ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): Phillips Alaska, Inc. Development _,_ 59' RKB 3. Address: Exploratory__, 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service X Kuparuk Unit 4. Location of well at surface: 8. Well number: 1106' FNL, 2060' FWL, Sec. 22, T13N, R9E, UM (ASP: 525698, 6021714 30-16A At top of productive interval: 9. Permit number/approval number: 3983' FNL, 703' FEL, Sec. 21, T13N, R9E, UM (ASP: 522949, 6018829 88-43 At effective depth: 10. APl number: 50-029-21796-01 At total depth: 11. Field/Pool: 3533' FNL, 1355' FEL, Sec. 21, T13N, R9E, UM (ASP: 522294, 6019275 Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 8351 feet Plugs (measured) Tagged Fill at 7927' MD (4/2/00) true vertical 6901 feet Effective Depfl measured 7927 feet Junk (measured) true vertical 6552 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 175 sx AS I 115' 115' Surface 2316' 9-5/8" 900 sx AS III & 2375' 2215' 300 sx AS II, top job w/100 sx AS I Production 8142' 7" 700 sx TLW & 8201' 6778' 300 sx Class G, 175 sx AS I Liner Perforation DepthRECEIVED measured 7794'-7804', 7838'-7848', 7850'-7860', 7869'-7889', 7908'-792[ MAY 01 2001 true vertical 6444'-6452', 6480'-6488', 6489'-6498', 6505'-6521', 6536'-655,' Tubing (size, grade, and measured depth) &ii(;ii0i;,~,.i~ 2-7/8", 6.5~, J-55 Tbg @ 7722' MD; circ string 1.9", J-55, Tbg @ 982-1056' ME: Packers and SSSV (type and measured depth) Baker 'AL-5' Dualstring pkr @ 986' MD; Baker 'AL-5' Duaistring pkr @ 1043' MD, Baker 'HB' pkr @ 7648' ~ Baker 'FVLD' SSSV @ 1786' MD 13. Stimulation or cement squeeze summary Intervals treated (measured~ see attachea Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Water Injector Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _)~ Oil _ Gas _ Suspended _ Service _X 17. I hereby certify thpt the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 ,/ ~' Signed ,i~,~'~,/J",~ Title: Staff Engineer Date Mike M6oney v~ -- Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMIT IN DUPLICATE _~ i i :'ii ...~ i .?,~ 30-16A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 2/18/2000: IRU DOWELL PUMP EQUIPMENT AND PUMP HPBD AT 25 BPM. PUMP SCOUR STAGES OF 20/40 PROPPANT AND DIVERTER STAGES OF ROCK SALT. SAW GOOD DIVERSION ON BOTH STAGES. SAW INJECTIVITY IMPROVEMENT OF OVER 600 PSI AT 25 BPM. FINAL WHTP 7132 PSI AT 25 BPM. [HPBD] Ph -"LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 27, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED MAY O! 2001 .~Jaska Oil & Gas Cons. Cornmissio~ Anchorage Subject: Report of Sundry Well Operations 30-16A (88-43) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the stimulation operations on the KRU well 30-16A. A High-Pressure Breakdown was performed on 2/18/00. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad STATE OF ALASKA ' '; ~ ~:~ AI_A.SKA OIL AND GAS CONSERVATION COMM,o~ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate m Plugging Perforate _ Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1106' FNL, 2060' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1887' FSL, 1053' FEL, Sec. 21, T13N, R9E, UM At effective depth 1803' FSL, 1233' FEL, Sec.21, T13N, R9E, UM At total depth 1746' FSL, 1352' FEL, Sec. 21, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length 8351' 6901' 8116' 6709' Size feet feet feet feet Plugs (measured) Junk (measured) Cemented 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-16A 9. Permit number/Approval number 88-43/90-010 10. APl number 50-029-21 796-01 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth Conductor 8 0' 1 6" Surface 234 0' 9 5/8" 175 sx AS I 115'MD 900 sx AS III & 2375'MD 300 sx AS II - Top Job w/100 sx AS I 115'TVD 2215'TVD 13. 14. Production Liner Perforation depth: 81 68' 7" 700 sx TLW & 8201 'MD 6777'TVD 300 sx Class G measured 7908'-7928', true vertical 6536'-6552', Tubing (size, grade, and measured depth 2 7/8" J-55 tbg w/tail @ 7722' (circ. string f/982'-1056' (WLM) to isolate leak) Packers and SSSV (type and measured depth) Baker 'AL-5' Dual pkr @ 986' & 1043', Stimulation or cement squeeze summary Intervals treated (measured) 7869-7889', 7838-7848', 7850-7860', 7794-7804' 6505-6521', 6480-6488', 6489-6498', 6444-6452' Treatment description including volumes used and final pressure SSSV @ 1786' Tubing Pressure Baker 'HB' pkr @ 7648~ ~. I~al~e[ ;F.V. LI~ KI:L IV P APR 1 7 ]990 Alas~ Oil & Gas Cons, Commi Representative Daily Average Production o~~lSD~ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation (producing) 422 I 99 0 852 148 Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. 35O0 80O 255O Status of well classification as: Water Injector ~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢i~~~)* ~ Title ~¢;~ (~~~' Date Form 10-404 Rev 05/17/89 SUBMIT IN DUPLICATE ALASKA OIL AND GAS CONSERVATION COHHISSION MECHANICAL INTEGRITY TEST PRETEST START 15 NIN 30 MIN *P *1 TYPE OF PKR CASING TBG REO TBG TIME TINE TIME WELL *S - ANNULUS TVD S I ZE/WT/GRADE S I ZE TEST CSG TBG TBG TBG START T I ME & COHHENTS NAME ~ *N FLU I D MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS ~//! , , I ., , , , *TUBING INJECTION FLUID: P = PRODUCE WATER INJ S = SALT,WATER INJ = MISCIBLE INJECTION I = INJECTING N = NOT INJECTING D.EWS.06 ~ev 03/'~ J ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING HUD OTHER OTHER GRAD I ENT ~ AOGCC WI TNESS S I GNATURE CONPANY REP SIGNATURE 20 AAC 25.030(a) ^~ AAC 25.~12ic) :AAC 25.252(d) ADDENDUM WELL: 5/09/88 5/18/88 6/22/88 11/13/88 3/17/89 30-16A RU Schl. Rn 6-1/8" GR f/8110'-surf. Rn CET f/8110'-surface. Rn GCT f/8110'-surf. RD Schl. RU ACT, pmp brine dn hole @ 2200'. When rtns reached 130°, press built up on 7" x 9-5/8" ann f/1000 psi to 2500 psi. Bled back. Pressure up to 2000 psi w/100% Methanol; no chg in 7" x 9-5/8" ann. Cont pmp'g brine. Displ w/25 bbls diesel. RD. RU Otis. RIH, pull 1½" CU f/GLM @ 8601' WLM. RIH, set dummy in GLM @ 8601'. Press tbg to 2000 psi; communication between tbg & ann. RIH w/GR to "D" nipple @ 8716' WLM, RD Otis. Frac Kuparuk A sand perfs 7908'-7928' in eight stages per procedure dated 10/24/88 as follows: Stage 1: Pmp 40 bbls diesel w/5% Musol @ 4.5 BPM, 3340-2860 psi Stage 2: Pmp 150 bbls gel diesel pre-pad @ 8 to 20 BPM, 3900/6300/4360 psi Stage 3: Pmp 225 bbls gel diesel pad @20 to 20.5 BPM, 4425-4260 psi Stage 4: Pmp 18 bbls gel diesel w/2 ppg, 20/40 Carbolite @ 20.5 BPM, 4260 psi Stage 5: Pmp 30 bbls gel diesel w/4 ppg, 20/40 Carbolite @ 20 BPM, 4260 psi Stage 6: Pmp 40 bbls gel diesel w/6 ppg 20/40 Carbolite @ 20-21BPM, 4250 psi Stage 7: Pmp 20 bbls gel diesel w/8 ppg, 20/40 Carbolite @ 21 to 19 BPM, 4260-4930 psi (Went to flush when pressure started rapid build-up) Stage 8: Pmp 49 bbls gel diesel flush @ 19-18 BPM, 4930-5350 psi RU SOS, tst lubr to 3000 psi. Perf as follows: "C" Sand "A-3" Sands "A-2" Sands 7794'-7804' @ 12 SPF, 60° phasing 7850'-7860' @ 12 SPF, 60° phasing 7869'-7889' @ 12 SPF, 60° phasing Shot out of zone from 7838'-7848' w/6 SPF. -~ ifrifling-Supervisor -z~ ~ate : STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,.-~,51ON ,0. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1106' FNL, 2060' FWL, Sec.22, T13N, R9E, UM At top of productive interval 1887' FSL, 1053' FEL, Sec. 21, T13N, R9E, UM At effective depth 1803' FSL, 1233' FEL, Sec.21, T13N, R9E, UM At total depth 1746' FSL, 1352' FEL, Sec. 21, T13N, R9E, UM 12. Present well condition summary RKB 58' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 30-16A 9. Permit number 88-43 10. APl number 5o-029-21 796-01 11. Field/Pool Kuparuk River Field Kuparu~l~v~r ~Oil ~1 !i~. Total Depth: measured 8 3 5 1 ' true vertical 6 9 0 1 ' Effective depth: measured 81 1 6' true vertical 670 9' Casing Length Size feet feet feet feet Plugs (measured) Junk (measured) Cemented Measured dept~'""'~;~'i/ehical depth Conductor 8 0' 1 6" Surface 234 0' 9 5/8" 8168' 7" Production Liner Perforation depth: measured 7908'-7928', true vertical 6536'-6552', Tubing (size, grade, and measured depth 175 sx AS I 11 5'M D 900 sx AS III & 2375'MD 300 sx AS II - Top Job w/100 sx AS I 700 sx TLW. & 8201 'MD 300 sx Class G 7869'-7889', 7838'-7848', 7850'-7860' 6505'-6521', 6480'-6488', 6489'-6498', 115'TVD 2215'TVD 6777'TVD 7794'-78O4' 6444'-6452' 2 7/8" J-55 tbg w/tail @ 7722' (circ. string f/982'-1056' (WLM) to isolate leak) Packers and SSSV (type and measured depth) Baker 'AL-5' Dual pkr @ 986' & 1043', Baker 'HB pkr @ 7648', & Baker FVLD' SSSV @ 1786' 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch Convert well from oil producer to water injector. 14. Estimated date for commencing operation 15. Status of well classification as: December 20, 1989 Oil X Gas __ Suspended 16. If proposal was verbally approved Date approved Service Water Iniector Name of approver 17. I hereby certify that th% foregoing is true and correct to the best of my knowledge. v L~// FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test X,~ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY 10.///o ~r I_I~NNIE C. SMITH IApproval No.F..,-" ~/~) I Commissioner Date /-,,/~)-~3 SUBMIT IN TRIPLICATE Attachment to Application for Sundry Approval Kuparuk River Unit Wells 30-6,14,16a Conversion to Water Injection Service Wells 30-6, 14, and 16a are currently oil producers, as listed on the Application for Sundry Approval. This Application for Sundry Approval is to convert these three wells to water injection service. A Wireline BOPE will be used during the portions of the conversion procedure which require wireline work. Expected static bottom-hole pressures for each well are listed below. No workover fluid will be used during the conversion procedure. MIT's, as required by the State, will be performed on these wells prior to conversion, and the MIT form will be forwarded to the State upon completion. WELL Expected SBHP 30-6 2000 psi 30-14 2000 psi 30-16a 2000 psi 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF H]REL]NE BOP EQUIPMENT i i · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~. GAS 7] SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number 88-43 ARCO A1 aska_ I n~.. 3. Address ' 8. APl Number p n n,,~ ~nn~n ~n,.h,~,=~,~ 4~ qq~ln-n~n 50- 029-21796-01 4. Loc~t[o-n'of-~ll ~ ;~r~;c~e .......... =-' ............. 9. Unit or Lease Name 1106' FNL, 2060' FWL, 5ec.22, T13N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well. Number 1887' FSL, 1053' FEL, Sec.21, T13N, R9E, UM 30-16A At Total Depth 11. Field and Pool 1746' FSL, 1352' FEL, Sec.21, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 58'I ADL 25513 ALK 2554 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 04/24/88 04/26/88 11/13/88'I N/A feet MSL 1,, .. 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8351 'MD/6901 'TVD 8118'MD/6709' TVD YES [] NO [][ 1786' feet MD! 1700'(aDDrOX) · . 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, CAL, GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-D. 0 R~rf 11~;~ 24" !75 Sx AS 9-5/8I' ?,~. O# .I -c~r~ _c,, i r f ? 3,7 c,I 19-1 /hi, Ci~t~ 175 c.". AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/8 spf, 45° Phasing 2-7/8" 7722' 986', 1043', & 7648 7908'-7928'MD/6536'-6552'TVD Circ. String 982'-1056' 986' & 1043' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum, dated 11/17/88, for Fracture data ,,, 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED =~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA ...... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOTE: Drilled RR 4/29/88. Perforated well and ran tubing 6/23/88. r]~aska nil .& Gas G011s. C0nl~i8~[0[[ Workove¢ performed 9/19/88. Fractured well 11/13/88. ~,,!: ~lch0rage Form 10-407 Submit in duplicate Rev. 7-1-80 WC5/084 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS 7772' 7801' 7838' 7969' MEAS. DEPTH TRUE VERT. DEPTH 6425' 6449' 6479' 6586' 30. FORMATION TESTS Include interval tested~ pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendums (dated 10/26/88 & 11/17/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Area Drilling Engineer Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". er)tm 1 O-407 ADDENDUM WELL: 9123188 9~28/88 30-16 ~ MIRU Gearhart. Tst lub to 3500 psi. RIH w/CCL/GR to _+1500' & log to surface. Release well to Production. Tst tubing/annulus pressures. Pressure 9-5/8" x 7" packoff to 3000 psi; bled to 1750 psi in 8 hrs. ..,iask~ Oil & G~s C,o~so Corn:'~-iss~u~ ..~ ~A~tchorage Drillin$ Supervisor / g~te ADDENDUM WELL: 5/09/88 5/18/88 6/22/88 11/13/88 30-16A Ru Schl. Rn 6-1/8" GR f/8110'-surf. Rn CET f/8110'-surface. Rn GCT f/8110'-surf. RD Schl. RU ACT, pmp brine dn hole @ 2200'. When rtns reached 130°, press built up on 7" x 9-5/8" ann f/lO00 psi to 2500 psi. Bled back. Pressure up to 2000 psi w/100% Methanol; no chg in 7" x 9-5/8" ann. Cont pmp'g brine. Displ w/25 bbls diesel. RD. RU Otis. RIH, pull 1½" CU f/GLM @ 8601' WLM. RIH, set dummy in GLM @ 8601'. Press tbg to 2000 psi; communication between tbg & ann. RIH w/GR to "D" nipple @ 8716' WLM, RD Otis. Frac Kuparuk A sand perfs 7908'-7928' in eight stages per procedure dated 10/24/88 as follows: Stage 1: Pmp 40 bbls diesel w/5% Musol @ 4.5 BPM, 3340-2860 psi Stage 2: Pmp 150 bbls gel diesel pre-pad @ 8 to 20 BPM, 3900/6300/4360 psi Stage 3: Pmp 225 bbls gel diesel pad @20 to 20.5 BPM, 4425-4260 psi Stage 4: Pmp 18 bbls gel diesel w/2 ppg, 20/40 Carbolite @ 20.5 BPM, 4260 psi Stage 5: Pmp 30 bbls gel diesel w/4 ppg, 20/40 Carbolite @ 20 BPM, 4260 psi Stage 6: ~Pmp 40 bbls gel diesel w/6 ppg 20/40 Carbolite @ 20-21BPM, 4250 psi Stage 7: Pmp 20 bbls gel diesel w/8 ppg, 20/40 Carbolite @ 21 to 19 BPM, 4260-4930 psi (Went to flush when pressure started rapid build-up) Stage 8: Pmp 49 bbls gel diesel flush @ 19-18 BPM, 4930-5350 psi Drilling Supervisor Date LOG W~.L LOG INVENTORY LOG COUNT PAGE ! of DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ lithe-density) CFD (compensated formation density) BHC/SL (borehole compensate~l sonic) LSS (long spaced sonic) SSS (short spaced sonic) CYB (cyberlook) GCT (groscopic survey) DIPMETER SAMPLES: Require,~i yes Date Received: -: 'Comments: W. ua, SI, ¥¥ · CHRi STENSEN REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, Inc. Pad 30, Well Number: 16/16A Kuparuk Field, North Slope, Alaska JOB NUMBER 450-458 TYPE OF SURVEY SPERRY SUN Mwd DATE 16-APR-88 23-APR-88 Survey By B LENT / R BARNARD Office Anchorage, Alaska ERSTMRN CHRISTENSEN 6324 Nielson Way, Anchorage, Alaska 99518, Phone: (907) 563-3269 Date: May 18, 1988 ARCO ALASKA, INC. P.O. BOX 1479 Anchorage, Alaska 99510 Well Number: Pad 30, Well No: 16/16A Location: Kuparuk Field, North Slope, Alaska Type of Survey: SPERRY SUN Mwd Date: 16.APR-88 / 23-APR-88 Method of Computation: Radius of Curvature Surveyor/Driller: B LENT / R BARNARD Job Number: 450-458 Attn: Mr. R. A. Ruedrich Dear Mr. Ruedrich: We'are enclosing the original and one (1) copy of the sur- vey run on the above mentioned well. To date, the following distributions have been accom- plished: A. 1 Copy delivered to drilling in-house distribution. B. 5 Copies noted for oil company represent at ives. C. 3 Copies for E/C permanent well files. We wish to take this opportunity to thank you for using EASTMAN CHRISTENSEN and look forward to being of service in the furture. Sin TJ:rh cc/file cc: P.A. Dimmock - BP Alaska Exploration Victoria Aldrid§e - Standard Alaska Production Co. Dick Stewart - Union Oil Co. T.A. Edmondson - Chevron U.S.A. N.H. Smith, Jr. - Mobil Oil Corp. Ei~STMAN CHRIST~NSEN REC:ORD OF SIJRVEY FOR * OPERATOR * STRLICTURE 45 LOCATION * .JOB NUMBER , * RIG : DoYon 14 ~ DECLINATION : * RKB TO SRA : 5$7.O ARCO A[ASEA, INC. . . Pm.d 30 . .1../-, ( 06f,-;~41 /'/-I~) .SI..OT : .1/.", ~.'.uP-~r',Jk Field, N,:,r. th._,C'loPe, Alms$.".a . 30.14 E . PI..ANE OF VERT I CAl...=,E..T I ON . . D!RECTION : :F..: 44 5'~ W . EC DISTRICT :Anchor. a~e, Alaska /7-7 Eastman RCO ALASKA, INC:. md 30 u~mruk Field, Nor. th Slope, Almskm SI OT : .~ 6 DATE F'RINTED : 17-MAY-8:--: WELL : 16 (O,~/~,~,~!,A~IE.) OUR REF. NO. : :.-];074 t 1. :..-.'AR F'BHL : -~ 44 59 W ,_IDB NUMBER : 5/~o_~8 PAGE NO. ":'.. ' EASURED OR IFT DRIFT COURSE TRUE VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U-R E DOGLEG DEPTH ANGLE DIRECTION LENGTH VERTICAL SECTION TVD E: 0 0 R D I N A T E S DISTANCE DIRECTION SVRTY D M D M DEPTH D M 0.00 0 0 N 0 0 E 0.00 0.00 453.00 0 30 S 80 24 E 453.00 452.99 935.00 0 36 N 74 18 E 482.00 934.97 1122.00 6 12 S 42 0 W 187.00 112~.57 1313.00 13 30 S 50 24 W 1~1.00 1307.63 0.00 -57.00 0.00 N 0.00 E 0.00 S ~0 0 E 0.00 -~.14 373.97 0.33 S 1.~5 E 1.98 S 80 24 E 0.11 -4.56 875.~7 0.0? S 6.53 E 6.53 S 87 15 E 0.05 -2.67 1062.57 7.10 S 10.89 E 13.00 S 56 53 E 3.59 2~.~4 1250.63 29.68 S 12.66 W 32.27 S 23 5 W 3.8~ 1504.00 20 48 S 48 18 W 191.00 1492.01 1693.00 27 30 S 44 48 W 189.00 1664.37 1882.00 31 36 S 47 36 W 189.00 1828.75 2072.00 35 48 8 51 48 W 190.00 1986.79 22~4..00 41 48 S 51 6 W 222.00 2;59.72 86.06 1433.0; 163.30 1605.37 256.46 1769.75 361.47 1~27.79 4~.63 2100.72 66.2:5 ':' 55 :~6 W ,:,6 4.1._ ._,c- ~:9_. 50 W 84 · ._! mm _ . m 119..49 S 111.45 W 163.:~9... ._.¢' 43 0 W 2 1°':. ¢~'-' ¢' 17:~ 71 W 256, 48 S 44 10 W 2 2~ ,_,.-,. ; C' --, - . - · , · ~__.s,.~ 2, 1 ._-." '.3 ,._..'-.' ~'~, 07 W :3. 61 ,51 '.3 45 47 W '2, 53 .:,.:,.:, ,, 79 S :_--.: 67. ,_.':' 1 W F,_ ¢). (').. 06 <'._, 4721 W 2 .71 2542.00 43 18 S 53 12 W 248.00 2342.41 666.01 2283.41 441.68 S 500.22 W 667.31 S 48 33 W 2~84.00 38 48 S 48 18 W 442.00 2675.66 ~54.65 2616,66 625.23 S 724.88 W 957.27 S 4~ 13 W 3364.00 3~ 48 S 45 30 W 380.00 2~6~.71 11~5.,I7 2~10.7l 78?.67 S ~00.60 W 1177.77 S 48 45 W 3872.00 3~ 36 S 40 30 W 508.00 3360.58 151~.3P 3301.58 1026.~2 S 1~21.84 W 1520.8~ S 47 32 W 4347.00 41 0 $~ 41 18 W 475.00 37~2.83 1825.82 3663.83 1257.14 S 1322.~? W ,1826.4.0 S 46 25 W 0.83 I. 25 0.54. 0.63 0.31 4663.00 39 18 S 39 48 W 3;6.00 3964.36 2028.96 3905.36 1413.95 S 1455.45 W 2029.18 S 45 50 W 5107.00 37 18 S 44 6 W 444.00 4307.95 230?.72 4248.~5 1623.05 S 1643.37 W 2309.77 S 45 21W 5425.00 38 48 S 43 24 W 3;.8.00 4554.~1 2510.01 4495.9; 1767.76 S 1781.93 W 2510.03' S 45 14 W 5744.00 38 18 S 42 42 W 317.00 4804.38 2708.69 4745.38 1913.03 S 1917.63 W 2708.6? S 45 4 W 6060.00 38 36 S 41 18 W 316.00 5051.86 2904.92 4992.86 2059.06 S 204~.11W 2904.92 S 44 52 W 6378.00 38 48 S 39 48 W :318.00 5300.0:3 3103.14 5241.03 2210.12 S 2178.36 W 3103.21 S 44 35 W 6630.00 3~ 0 S 40 30 W 252.00 54~6.15 3260.83 5437.15 2331.0~ S 2280.40 W 3261.01 S 44 22 W 7042.00 3~ 0 S 40 30 W 412.00 5816.34 ' 35l?.32 5757.34 2528.24 S 2448.7~ W 3517.74 S 44 5 W 7487.00 3~ 12 S 40 30 W 445.00 6;61.67 37~..10 6102.67 2741.65 S 2631.05 W 37~.88 S 43 47 W 7868.00 38 24 S 41 18 W 381.00 6458.60 4037.23 6:3~,60 2~22.09 S 2787.36 W 40':38.32 S 43 39 W 0.62 0.61 0.2~ 0.21 O. 29 ,- . ._~ O. 1'.-) O. O0 0.04 O. 25 ,~ ~ '~' '~ . ~).J 22 ¢' 43 37 W . ()., 3037 :'-' '" ,:,1'2 00 .:,4 15 ~ 44 0 W 2A5 00 AA72 05 4194.03 661 ........... ' .::~ ......... ._, ~ ~, 289:3 68 W 4 ~ ~ = 4z~.Z~ 74 S 43 37 · -' 2913. ~9 W W ._:~1°4._, . 00 33. 45 ._. ~ 44 31 W 51 . 00 6714. o3 ~.~.~'~'"'?. ~46AS~. '=,'='._.._. :~OM7. '74._.c' _. -~.--..- I, 68 1.1.3 CLOSURE - DISTANCE : 4223.74 DIRECTION. : ._.c- 43 37 W REPORT UNITSFeet .=,I_RVEY CAt..CIJLATION METHOD . Ra. dius ot: curvmtur, e Eastman SURVEY RUN INFORMATION Oir-ectionml Driller: B LENT Sur. veY Tool: SPERRY SUN Mwd SPud date: 16-APR-88 ,Jo[, Number.: 450-458 Note~' 8133 Md is Magnetic Single Shot Sur. veY 8184 Md is PPoJected d~t~ only - no sur've'.,- Origin,si hole sidetracked 23-APR-88 - See Redr-ill Sur-veY EAS'I'N~N CHRISTENSEN RECORD OF SURVEY FOR OPERATOR STRUCTURE : Pa.d 30 WELL : 16-A, LOCATION dOB NUMBER : RIG : Do¥or, 14 DECLINATION : RKB TO SEA : 59.0 : ARCO ALASKA, INC. , .:,I.:OT : 16 : K u P~ r. u k F i e 1 d · N c, r. t h ,.E; 1 0 P 30.14 E PLANE OF VERTICAl....:,ECTICN DIRECTION : E; 44 59 W * EC DISTRICT : Anchor-m_qe, Al a._~ka Eastman/ Whipstock l ~CO ALASKA, INC. ~d 30 jpar. uk Field, North Slope, Alaska SLOT : ] 6 WELL : t6-A PBHL : S 44 59 W DATE PRINTED : J7-MAY-88 OUR REF. NO. : S07482.2AR dOB NUMBER : PAGE NO. 2 ~ASURED DRIFT DRIFT COURSE TRUE VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG )EPTH ANGLE DIRECTION LENGTH VERTICAk. SECTION TV[I C 0 0 R D I N A T E S DISTANCE DIRECTION SVRTY D M D M DEPTH D M ~107.00 39 18 S 44 6 W 444.00 4307.95 2309.72 4248.95 1623.05 S 1643.37 W 2309.77 S 45 21W 5241.00 36 18 S 49 0 W 134.00 4413.82 2391.78 4354.82 1679.5; S 1702.97 W 2391.85 S 45 24 W ~400.00 33 ~8 S 58 48 W 157.00 4543.97 2481.87 4484.~7 1733.24 S 1776.68 W 24:32.08 S 45 43 W 5526.00 33 6 S 64 30 W 126.00 464~.10 2548.38 4590.10 1766.21S 1837.77 W 2548.~0 S 46 8 W ~653.00 35 18 S 68 0 W 127.00 4754.13 2614.87 4695.13 1794.~5 S 1903.10 W 2616.03 S 46 41W 0.61 3.17 3.87 2.55 2.32 ~747.00 38 36 S 67 18 W 94.00 4829.25 2667.02 4770.25 1816.43 S 1955.35 W 2668.86 S 47 7 W ~937.00 37 24 S 67 24 W 170.00 4776.~0 2776.77 4917.90 1860.54 S 2066.48 W 2780.64 S 48 0 W S063.00 39 30 S 72 12 W 126.00 5074.20 2848.84 5015.20 1886.87 S 2~42.08 W 2854.61 S 48 37 W )380.00 ~39 12 S 69 24 W 317.00 5319.33 3029.75 5260.33 1752.97 S 2331.88 W 3041.67 S 50 3 W ~697.00 39 6 S 68 42 W 317.00 5~65.17 3212.48 5506.17 2024.53 S 2518.79 W 3231.56 S 51 13 W O{ 1.41 O. 57 0.14 · .-3 52 W ~150 O0.-,~'~..v 0 S 67 30 W 4...3F, ........ 00 5916.96 .:,47Z. 94 5857.96 2126. c,.:, .~'-' ~7~:,._' ~'5.._,'-~8 W :-~o4. ~" .~'" :~'9... %45.00 36 0 S 65 12 W 4~5.00 6309.62 3751:50 6250.62 2242. :33 S :3063. :38 W 37~6.36 S 53 48 W ~200.00 34 6 S 64 30 W 555.00 6763.~5 4051.25 6704.~5 2377.78 S 3351.88 W 4109.62 S 54 39 W ~:351.00 32 54 S 63 0 W 151.00 6889.87 4130.15 6830.87 2414.64 '.E; 34.26.63 W 4191.93 S 54 50 W CLOSURE - DISTANCE : 4191.93 REPORT UNITSFeet DIRECTION : S 54 50 W SURVEY CALCULATION METHOD : Radius oF curvature 0.11 0.80 O. 35 0.97 SURVEY RUN INFORMATION Directionml Driller: B LENT / R BARNARD Survey Tool: SPERRY SUN Mind SPud da. re: (be~ir, nir,~ da. te for. redrill) 23-APR-88 Job Number: 450-458 /-/-7 Eastn n I .... , . 1000 TVD ?000 2OOO lOC0 6378 7'021 1000 44.4g 1303 1848 ICC0 II I ! , ! I .......... 000 0 1000 ~)00 3000 4000 SO00 ~ ARCO ALASKA, INC' ~ ~ P d 0 ,~.,.'.k ~,'~d. ~10~ S,o,,.. ^,..,,. 2484. : SCALE I $ UB-$ URFA CE DIRECTIONAL SURVEY [~]UIDANCE F~IONTINUOUS F'fl OOL Company ARC0,, ,, ALASKA, INC. Well Name 30-16A (110..6' FNL,20..60' FWL,SEC22)T13N)R9E)UM) FieldlLocation KUPARUK, NOR. T..,H SLOPE. ALA~;I<;/~ . ., Job Referen.ce No. 72761 Log{3ed By: PEPPEL Date 10-MAY-88 Computed By: KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC, JO-16A KUPARUK NORTH SLOPE, ALASKA SURVEY DATES lO-MAY-88 ENGINEERS PEPPEL METHODS OF COMPUTATION TOOL LOCATIONS TANGENTIAL- Averaged deviation and azimuth INTERPOLATIONS LINEAR VERTICAL SECTIONS HORIZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 44 DEG 59 MIN ~EST ARCO ALASKA, INC. 30-16A KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATES 19'MA¥'88 PAGE 1 DATE OF SURVEY1 10~MAY-88 KELLY BUSHING ELEVATION= 58,00 FT ENGINEERS PEPPEL INTERPOLATED VALUES FOR EVEN !00 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG SIN DEG MIN 90 , 0 O0 lO0 O0 2OO O0 300 O0 400 O0 5O0 O0 599 99 699 99 799 99 899 98 -58.00 0 0 N 0 0 E 42,00 0 5 N 4 43 N 142,00 0 11 N 85 46 g 242,00 0 14 S 87 18 E 342,00 0 20 N 89 ! E 442,00 0 21 N 89 26 E 541,99 0 24 N 86 55 E 641,99 0 29 S 88 9 E 741,99 0 30 S 89 50 E 841,98 0 3.4 N 83 35 E 1000 O0 1100 1200 13o0 1400 1500 1600 1700 800 9OO 999,98 941,98 0 38 O0 1099,82 1041,82 5 26 O0 1198 83 1140,83 9 48 O0 1296 92 1238,92 13 3 O0 1393 28 1335.28 17 37 O0 1487 60 1429,60 21 12 O0 1579 52 1521,52 24 29 O0 1669 38 1611,38 28 12 O0 1756 02 1698,02 30 56 O0 1841,16 1783,16 32 39 2000 O0 1923 84 1865,84 35 18 2100 O0 2004 95 1946,95 36 44 2200 2300 2400 2500 2600 2700 2800 2900 O0 2083 24 2025,24 39 56 O0 2158 86 2100,86 41 44 O0 2232 79 2174,79 42 40 O0 2305 92 2247,92 43 14 00 2378 68 2320.68 43 22 O0 2451 35 2393,35 43 1 O0 2525 49 2467,49 41 15 O0 2601,62 2543,62 39 34 3000 O0 2679 45 2621,45 38 16 3100 O0 2758 55 2700,55 37 27 3200 O0 2837 62 2779.62 38 5 3300 O0 2915 59 2857°59 39 44 3400 O0 2992 41 2934.41 39 5 3500 O0 3071,11 3013,11 37 4 3~00 00 3151.90 3093,90 35 23 37 O0 00 3233.30 3175,30 37 14 3800 O0 3310,75 3252.75 39 46 3900 00 3387,73 3329.73 39 14 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET bEG 0.00 0.00 0.00 N '0.04 0.22 0,11 N '0.24 0.17 0.22 N '0,52 0,03 0,21 N '0,87 0,06 0,2! N '1 31 0,11 0.22 N '1~78 0,39 0.24 N 2,40 0,08 0,27 N 2,98 0,15 0,23 N 3,72 0,04 0,31 N 0,00 E 0.05 W 0 12 E 0 52 E 102 E 1 63 E 228E 3 13 E 3 99 E 4 95 E 0 00 N 0 0 E 0 12 N 22 58 W 0 25 N 28 7 E 0 56 N 67 46 E I 04 N 78 22 ~ 1 65 N 82 11 2,29 N 84 2 E 3,14 N 85 5 E 3,99 N 86 39 E 4,96 N 86 23 E S 28 29 g '4.34 4.10 0.29 S 37 49 W 0.38 5.55 3.92 S 47 20 W 14.22 2.25 13.87 S 50 24 W 33.52 4.45 26 52 S 50 9 W 59.96 4.06 43:33 S 48 7 W 93.03 4.36 65:03 S 46 54 W 132 30 1,63 91 62 S 45 29 W 176~09 4.13 122.04 S 46 29 W 226.00 1.81 156.86 S 50 18 W 278.34 4.02 191.79 5.86 E 5.86 N 87 11 E 3,39 E 5,18 S 4048 E 6,23 W 15,21 S 24 11W 41.47 W 59.98 S 4344 W 66.54 W 93 04 S 45 39 W 95.48 W 132,33 S 46 10 W 127 O0 W 176,13 S 46 8 W 162:76 W 226.04 S 46 3 W 201'84 W 278.43 S 46 27 W S 52 29 W 334,15 S 53 0 W 392,11 S 52 15 W 453,68 S 51 6 W 518,69 S 51 23 W 585,64 S 51 57 W 653,36 S 51 48 W 721.45 S 48 52 W 789.81 S 48 5 W 856,81 S 47 39 W 921,55 1,24 3,03 2.26 I 73 0 78 0 34 0 93 2 55 1.70 1.56 226 56 S 246,00 W 334,44 S 47 21 W 262 O1S 292 54 W 392,72 S 48 9 W 299 41S 342 20 W 454,70 S 48 48 W .07 S 49 W 34O 19 S 393 382 43 S 445 424 68 S 499 466 87 $ 553 510,61S 606 555,32 $ 656 598,76 S 704 37 W 520 8 82 w 587,37 S 49 22 W 34 W 655,51 S 49 3T ' 45 w 724,07 S 49 51 38 W 792.73 S 49 54 W 43 W 859.81 S 49 46 W 54 W 924.60 $ 49 38 W S 46 58 W 984,29 S 46 31 W 1045,43 S 45 36 W 1106,63 S 45 5 W 1169,23 S 44 38 W 1233,26 S 44 24 W 1294,93 S 44 5 W 1353,85 S 43 19 W 1411,92 S 41 50 W 1475,10 S 41 2 W 1538,80 1 02 0 97 0 59 1 54 2 05 2 17 1 07 5 92 0 71 I 67 641 37 S 750.67 W 987.35 S 49 29 W 683 20 S 795 30 W 1048,46 1109,57 S 49 8 W 725 769 815 859 901 943 989 1037 S 49 20 w 77 S 839 29 w 71S 883 87 W 1172.04 S 48 56 w 14 S 928 99 w 1235.91 S 48 44 w 11S 972 24 w 1297.43 S 48 32 W 28 S 1013 40 W 1356.20 S 48 21W 19 S 1053,61 W 1414,11 S 48 9 W 81S 1096,33 W 1477,05 S 47 55 W 65 S 1138,58 W 1540,48 S 47 39 W ARCO ALASKA~ INC. 30-16A KUPARUK NORTH SLOPEr ALASKA COMPUTATION DATEI 19-MAY-88 PAGE 2 DATE OF SURVEY1 lO-MAY-88 KELLY BUSHING ELEVATIONI 58,00 FT ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HURZZ, DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SUUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET 4000 O0 3465 83 3407 83 38 3 4100100 3545 08 3487 08 37 36 42- 00.00 3623 85 3565 85 39 6 4300,00 3700 10 3642 10 40 50 4400,00 3775 69 3717 4500,00 3851 60 3793 4600.00 3928 29 3870 4700,00 4005 60 3947 4800,00 4083 4900,00 4160 $ 40 17 W lbOi 07 $ 39 31 w 1661 S 39 42 w 1723 S 39 55 W 1787 69 40 54 S 39 51 w 1852 60 40 12 S 39 56 w 1917 29 39 39 S 39 37 W 1981 60 39 14 S 39 20 W 2044 14 4025,14 39 2' S 38 58 W 2107 91 4102,91 82 14 55 77 6! 53 66 48 38 58 $ 39 8 W 2169,99 5000 O0 4238.45 4180,45 39 17 5100 O0 4315.84 4257,84 39 1 5200 O0 4394,61 4336,61 36 47 5300 O0 4475 56 4417 56 35 6 5400 O0 4558 13 4500113 33 50 5500 O0 4641 57 4583;57 33 15 560.0 O0 4724 95 4666,95 34 13 5700 O0 4806 25 4748,25 37 10 5800 O0 4884 47 4826,47 39 11 59 O0 O0 4961 92 4903.92 39 27 S 42 1 W 2232,92 S 43 49 w 2296,22 S 47 14 W 2357,78 S 52 34 W 2416 26 S 57 33 W 2471 75 S 62 13 W 2524 97 $ 64 56 W 2577 22 S 67 26 W 2631 45 S 68 20 W 2688 76 S 70 23 W 2746 34 6000 O0 5039 O0 4981.00 39 37 6100 O0 5116 11 5058.11 39 26 6200 6300 6400 6500 6600 6700 6800 6900 O0 5193 31 5135,31 39 25 O0 5270 57 5212,57 39 28 O0 5347 84 5289,84 39 17 O0 5425 19 5367,19 39 23 O0 5502 47 5444,47 39 22 O0 5579 81 5521,81 39 17 O0 5657 20 5599,20 39 18 O0 5734 63 5676,63 39 9 S 70 34 W 2803,77 S 70 19 W 2861,25 S 70 3 W 2918,79 $ 70 1 W 2976.29 S 69 45 W 3033,83 S 69 18 W 3091,49 S 69 2 W 3149,38 S 68 49 w 3207 31 $ 68 37 W 3265:29 S 68 25 W 3323,29 7000 O0 5812 25 5754,25 7100 5832.07 7400 7500 7800 7900 38 55 S 67 54 W 3381,23 O0 5890 07 38 52 21 3439 O0 5967 98 5909 98 38 ,44 37 56 S 66 37 W 3554.69 O0 6125 61 6067.61 37 16 S 65 57 W 3611,61 O0 6205.49 6147,49 36 44 S 65 32 W 3667.88 O0 6285,84 6227,84 36 17 S 65 26 W 3723,64 O0 6366,73 6308,73 35 49 $ 65 36 W 3778,69 O0 6447,92 6389,92 35 37 S 65 24 W 3833,36 O0 6529,40 6471,40 35 11 S 64 57 W 3887,75 I 88 0 42 3 14 0 38 0 29 0 69 0 85 0 17 0 30 1 O0 2 46 1 58 3 54 3 80 2 83 2 15 2 56 3 58 0 60 0 85 0 0 10 0 40 0 37 0 25 0 19 0 19 0 O9 0 46 0 48 0 40 0 44 0 6O 0 71 00 63 0 3O 0 21 0 51 FEET FEET DEG NIN 1085 02 S 1179,28 W 2602 48 S 47 23 W 1131 87 S 1218 97 S 47 6 W 1179 1228 1279 1329 1378 1427 1476 1525 1573 1619 1663 70 173t 1 1760 1785 1808 1831 1854 ,34 ~ 1662 8 S 1257,53 W 1724 9 $ 1299,02 W 1788 25 S 1340,99 W 1853 15 $ 1382.79 W 1918 45 $ 1423 88 W 1981 41S 1464:19 W 2044 37 $ 1504,07 W 2107 32 $ 1543,52 W 2170 04 $ 46 50 W 26 S 46 35 W 30 $ 46 20 ,v O0 S 46 'i ) 80 S 45 55~ 83 S 45 43 W 58 $ 45 31W 03 S 45 20 W 49 S 1584.34 W 2232 94 S 45 11W 65 S 1627,70 W 2296 23 S 45 8 W 12 S 1671,29 W 2357 79 S 45 8 W 03 S 1716 08 W 2416 29 S 45 15 W 20 S 1762 38 ~ 2471 84 S 45 28 W 81S 1810 05 W 2525 22 $ 45 47 W 18 S 1859 59 W 2577 77 S 46 10 W 64 S 1912 83 W 2632 51 S 46 36 W 94 $ 1970 59 W 2690:58 S 47 5 W 15 $ 2029 82 W 2749,19 S 47 35 W 1875 29 S 2089,92 , 2807,9J S 48 5 W 1896 59 $ 2149,92 W 2866,92 S 48 34 W 1918 18 S 2209,71 W 2926,13 $ 49 2 W 1939 84 S 2269,39 W 2985,48 S 49 28 W 1961 60 S 2329.01 W 3045,02 S 49 53 W 1983 79 S 2388,38 k 3104,80 S 50 1~ ] 2006,35 S 2447,69 W 3164,91 S 50 3~ . 2029,14 $ 2506,85 W 3225,17 S 51 0 W 2052.13 $ 2565,87 W 3285,56 S 51 20 W 2075,28 S 2624,76 W 3346,06 S 51 40 W 2098 6~ S 2683 31 W 3406.55 S 51 58 W 2122 65 S 2741 36 k 3467,09 S 52 14 W 2146 80 S 2799 21 ~ 3527,65 S 52 30 W 3587,72 3647,15 S 52 59 W 2171 2195 2220 2245 2269 2293 2317 10 S 2856 24 W S 52 45 W 65 S 2912 18 W 42 S 2967,00 W 3705.85 S 53 11W 12 $ 3021,17 W 3764,04 S 53 22 W 48 S 3074,68 W 3821,54 S 53 34 W 68 S 3127,81 W 3878.67 S 53 44 W 97 ~ 3180,44 ~ 3935,51 S 53 54 W ARCO ALASKA, INC. 30-16A KUPARUK NORTH SLOPEr ALASKA COMPUTATION DATE: 19-MAY-88 PAGE DATE OF SURVE¥~ 10~MAYo88 ENGINEER: PEPPEb INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WE~T DI~T, AZIMUTH FEET DEG/IO0 f'EET f'EET FEET DEG 8000 O0 6611 29 6553.72~ ]~, 42 8100 O0 6693 71 66]5. 30 8200 O0 6776 11 6718,11 34 30 8300 O0 6858 51 6800,51 34 30 8351 O0 6900 53 6842,53 34 30 5 64 41 W 3941,78 S 64 38 W 3995,07 $ 64 38 w 4048,43 $ 64 38 W 4101,79 $ 64 38 W 4129,00 1,22 0 O0 0,00 0,00 0,00 2342 47 $ 3232,35 W 3991.90 $ 54 4 W 2366 67 $ 3283,54 W 4047,56 S 54 13 W 2390 93 $ 3334.74 W 4103,30 $ 54 21 w 2415 20 $ 3385.95 W 4159,06 $ 54 29 W 2427 57 $ 3412,06 W 4187e51 / COMPUTATION DATEC 19-~AY-88 PAGE 4 AR.C~ ALASKAN INC, ~0 6A KUPARUK NORTH SLOPEw ALASKA DATE UF SURVEY: lO,MAY-88 KELLY BUSHING ELEVATION{ 58.00 ENGINEER{- PEPPEb ' INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET PEG M~N 0 O0 1000 2000 3000 40OO 5000 6OO0 7000 8000 8351 O0 999 O0 1923 O0 2679 O0 3465 O0 4238 O0 5039 O0 5812 O0 6611 O0 6900 0 00 "58,00 0 0 98 941,98 0 38 84 1865,84 35 18 45 2621,45 38 83 3407,83 38 3 45 4180,45 39 17 O0 4981,00 39 37 25 5754,25' 38 55 29 6553,29 34 42 53 6842,53 34 30 N 0 0 E S 28 29 g $ 52 29 W 334 S 46 58 W 984 S 40 17 W 1601 $ 42 1 w 2232 $ 70 34 w 2803 $ 67 54 w 3381 S 64 41 W 394 1 ,5 64 38 W 4!29 0,00 -4 34 15 29 O7 92 77 23 78 O0 0 O0 4110 02 1 88 2 46 0 31 0 48 1 22 0 O0 0,00 N , 0 29 N 5,8b g 5 226:56 S 246,00 W 334 641,37 S 750,67 W 987 1085,02 S 1179,28 W 1602 1573,49 $ 1584,34 W 2232 1875,29 $ 2089,92 W 2807 2098,68 S 2683,31 N 3406 2342,47 S 3232,35 W 3991 2427,57 S 3412,06 ~ 4187 0 00 E 0 00 N 0 0 E 86 N 87 11 E 44 S 47 21W 35 S 49 29 w 48 S 47 94 $ 45 1, 93 $ 48 5 w 55 S 51 58 W 90 S 54 4 W 51 $ 54 34 W ARCO ALASKA, 30-16A KUPARUK' NORTH SLOPE, ALASKA COMPUTATION DATE: 19-~AY-88 PAGE 5 DATE OF SURVE¥t lO~MAY-S8 KELLY BUSHING ELEVATZONI 58,00 FT ENGINEERt PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZIRUTH DEPTH DEPTH DEPTH DEG MIN DEG MZN 0 O0 58 O0 158 O0 258 O0 358 O0 458 O0 558 01 658 01 758 01 858 O2 0 O0 58 O0 158 O0 258 O0 358 O0 458 O0 558 O0 658 O0 758 O0 858 O0 -58 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600,00 700,00 800,00 0 0 N 0 0 E 0 7 N 29 24 ~ 0 7 N 58 8 E 0 14 $ 88 55 E 0 18 N 89 29 g 0 21 N 88 23 g 0 22 N 88 53 g 0 30 N 88 2 E 0 28 S 87 4 E 0 33 N 84 7 g 1576 1687 1802 1919 958 02 06 1058 63 1158 19 1258 12 1358 36 1458 37 1558 i? 1658 32 1758 96 1858 958 O0 900,00 0 32 O0 1000,00 3 10 O0 1100,00 8 21 O0 1200,00 11 26 O0 1300,00 16 O0 1400,00 19 55 O0 1500,00 23 59 00 1600,00 27 38 O0 1700o00 30 58 O0 1800,00 33 16 N 86 25 E S 30 32 W S 44 28 w 2041,]~ 1958 2167. '§~ 2058 2298 * 257'1 ' 2843 3099 ' 1900.00 35 44 2000.00 39 2100.00 41 43 2200.00 42 53 2300.00 43 20 2400.00 42 52 2500,00 40 31 2600,00 38 36 2700,00 37 27 2800,00 38 19 3355 3483 3601 373 3861 3990 4116 4244 4376 4508 38 2958,00 2900,00 39 48 61 3058,00 3000,00 37 25 48 3158.00 3100.00 35 17 55 3258,00 3200,00 38 37 45 3358,00 3300,00 39 38 O0 3458,00 3400,00 38 10 33 3558,00 3500,00 37 39 46 3658,00 3600,00 40 13 60 3758,00 3700,00 40 54 38 3858,00 3800,00 40 8 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG 0,00 0,00 '0,0! 0 23 '0,14 0i21 '0,40 0 02 '0.70 0.04 '1 12 0,05 '1~58 0,04 '2,14 0,06 '2,74 0,02 '3,39 0,11 -4 17 -2 72 7 50 2O 28 88 55 18 20 O0 S 49 24 W 25 S 50 42 W 49 S 48 46 W 81 S 47 8 W 122 S 45 36 W 170 S 46 33 w 227 S 51 4 W 289 S 52 41 w 358,34 S 52 49 W 433,01 S 51 6 ~ 517,93 S 51 36 k 608,82 S 51 59 W 702,09 S 48 42 W 795,99 S 47 56 W 884 94 S 47 6 W 967,25 S 46 31W 1045,02 S 45 31W 1122,63 0 0O N 0 04 N 0 19 N 0 22 N 0 21N 0 22 N 0.23 N 0,27 N 0.24 N 0'27 h 0,00 0,02 0.00 0.34 0,79 1.37 2.00 2,76 3,63 4,53 0,00 N 0 0 E 0,04 N 28 22 W 0,19 N i 19 g 0.41 N 57 19 E 0 81 N 75 1P '3 I 39 N 80 5i ! 2 ol ~ 83 26 ~ 2 78 N 84 28 E 3 64 N 86 8 E 4 54 N 86 36 E S 44 46 w 1204,86 S 44 26 W 1285,10 S 44 3 W 1358,18 S 42 48 W 1431,53 S 41 22 W 1514,31 S 40 21 W 1594.88 S 39 29 W 1671,76 S 39 54 W 1751,48 S 39 51 W 1837,52 S 39 55 W 1923,01 0 31 5 59 5 16 3 79 4 95 3 64 2 56 4 41 I 83 4 25 0 38 N 1 9 21 36 57 84 117 157 198 5,53 E 5 54 N 86 6 E 34 $ 5,19 g 5 36 $ 75 33 E 24 S 1,37 w 9 34 S 8 26 W 15 S 14 49 W 25 63 S 34 24 W 50 S 33 19 W 49 34 S 42 16 W 60 S 58 20 ~ 81 88 S 45 17,w 99 S 88 32 W 122 58 S 46 6 W 89 S 122 78 W 170 22 $ 46 9 W 68 S 163 63 ~ 227 24 $ 46 3 W 54 $ 210 17 W 289 12 $ 46 37 W 0 88 3 53 1 76 0 86 0 43 2,45 1,79 1,26 0,96 1,01 241 36 S 265.41 W 358.74 S 47 42 W 286 77 S 325.61 W 433,89 S 48 37 W 339 71 $ 392, 519,30 S 49 8 W ,07 W 396 454 514 574 629 682 736 77 ~ 95 S 464 610 68 S 49 27 W 88 S 538,05 W 704 57 S 49 47 w 73 S 611.O0 w 798 92 S 49 57 16 S 677,37 k 887 97 S 49 42 74 S 738,19 W 970 31 S 49 31 w 92 $ 795,00 w 1048 05 S 49 20 W 96 S 850,72 w 1125 54 S 49 5 W I 25 2 47 0 85 4 01 0 78 I 43 0 36 I 94 0 o 794 852 904 957 1019 1080 1139 1201 1267 1333 95 S 909,02 W 1207,58 S 48 49 W 08 S 965,36 W 1287,62 S 48 34 W 38 S 1016,4! W 1360 51 S 48 20 W 54 S 1067 O0 W 1433 65 S 48 5 W 19 S 1122 40 w 1516 09 S 47 45 W 29 S 1175 24 W 1596 32 S 47 24 W 57 S 1224 68 w 1672 86 S 47 3 W 23 S 1275 76 W 1752 29 S 46 43 W 49 S 1331 18 N 1838,09 S 46 24 ~ 30 S 1386 26 h 1923,38 S 46 6 W ARCO ALASKA, INC, 30-16A KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATE~ 19-~A¥-88 PAGE 6 DATE OF SURVEYI 10~AY-88 KELLY BUSHING EbEVATiON~ 58,00 FT ENGINEER~ PEPPEb INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG HIN PEG MIN 50 3958 O0 3900 O0 39 24 62 4058 O0 4000 O0 39 7 26 4158 O0 4100 O0 38 58 27 4258 O0 4200 O0 39 17 99 4358 O0 4300 O0 37 53 46 4458 O0 4400.00 35 28 84 4558 O0 4500.00 33 50 65 4658.00 4600 O0 33 18 19 4758,00 4700:00 35 16 83 4858,00 4800,00 38 52 46 4896 5O 5278 53 5894 92 4958 O0 4900,00 39 25 O0 5000.00 39 36 28 5~58 73 5258 12 5358 6 5458 2 5558 03 5658 12 5758 O0 5100,00 39 28 O0 5200,00 39 27 O0 5300.00 39 17 O0 5400,00 39 23 O0 5500,00 39 18 O0 5600,00 39 18 O0 5700,00 39 7 6024,68 5058 62 o 6413, 6542, 6671, 6801. 70 ,79 5858 O0 5800,00 38 55 UU.oo , 6058 O0 60 ,00 , 6258,00 62 , g.oo VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG $ 39 29 W 2005.91 S 39 5 W 2087.18 $ 39 b W 2167,66 $ 42 42 W 2248.92 $ 45 13 W 2329,93 S 51 22 W 2403,87 S 57 33 W 2471,66 S 62 54 W 2535,23 $ 65 54 W 2598.65 $ 68 9 W 2668,90 0 61 0 37 0 9O 1 43 3 65 3 74 2 83 1 86 3 29 I 65 1397,33 S 1439,47 W 2006 15 S 45 51W 1460,52 S 1491,22 w 2087 30 S 45 35 W 1523,49 $ 1542, ,24 S 1595,21 W 2248 S 45 10 W 04 W 2167 1585 1643 79 $ 1651,22 W 2329 1693 30 $ 1706 30 ~ 2403 1733 lb S 1762 31W 2471 1765 73 S 1819 64 W 253 1794 70 S 1860 37 W 2599 1823 90 $ 1950 54 W 2670 70 S 45 20 W 93 93 $ 45 7 89 $ 45 13 ) 75 S 45 28 ~ 53 S 45 51W 37 S 46 20 W 43 S 46 55 W $ 70 20 w 2743 42 S 70 31 W 2817 S 707 W 2892 $ 70 1 W 2966 S 69 41W 3041 S 69 11 W 3116 S 68 53 W 3191 S 68 37 w 3265 S 68 18 w 3340 S 67 30 W 3415 98 47 93 38 06 O0 89 74 29 0,99 0 52 0 27 0 27 0 40 0 16 0 19 0 09 0 46 0 56 1853,08 S 2026,77 ~ 2746,21 S 47 33 W 1880 54 ~ 2104,77 W 2822 49 $ 48 13 W 1908 27 S 2182,40 W 2899 03 S 48 50 W 1936 31S 2259 68 W 2975 81 $ 49 24 W 1964 48 S 2336 81 W 3052 84 S 4956 w 1993 34 S 2413 59 ~ 3130 30 S 50 26 W 2022 70 S 2490 21 W 3208 19 $ 50 54 W 2052 37 $ 2566 48 W 3286 18 $ 51 2t W 2082 29 $ 2642 43 W 3364,28 S 51 45 ~ 2112 70 S 2717 47 W 3442,11 S 52 8 W $ 67 15 W 3489,79 S 66 31 W 3563.05 S 65 43 W 3634,55 $ 65 28 W 3704,42 S 65 37 W 3772,80 S 65 22 W 3840,13 S 64 46 W 3906,68 S 64 38 W 4129,00 0,41 0,46 0,70 0,40 0,30 0,25 0,46 0,00 2143 2174 2205 2236 2266 2296 2326 2427 72 S 2791,82 W 3519.91 S 52 28 W 67 S 2864,49 W 3596,46 S 52 47 W 71 $ 2934.58 W 3671,09 $ 53 4 W 60 $ 3002,50 W 3743,98 $ 53 19 W 89 S 3068,94 W 3815,39 $ 53 32 W 68 S 3134,37 W 3885,75 S 53 4~er} 52 S 3198,66 W 3955,27 S 53 58 ,, 57 S 3412,06 W 4187,51 S 54 34 W ARCO ALASKA, INC, 30-16A KUPARUK NORTH SLOPB~ ALASKA ~ARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD CO~Pt. ITATION DATE~ 19-HA¥-88 PAGE 7 DATE OF SURVEY1 lO-MAY-88 KELLY BUSHING ELEVAT[ONI 58,00 FT ENG[NEER~ PEPPEL INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGEN= 1106 FNL, 2060 FWb. SEC 22. TI3N RgE, U TVD RECTANGULAR COORDiNaTES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 7772 O0 7801 O0 7838 O0 7969 O0 8118 O0 8351 O0 6425,16 6367,1b 6448,73 6390 ~3 6585, 6527,87 6900,53 6842 3 2286 90 $ 2293 92 $ 2302 90 S 2334 88 $ 2371 03 S 2427 57 $ 31 34 w 3147 9! w 3216 31 k )~ 3292 75 w 3412 06 w ARCO ALASKA~ IN¢, KUPARUK NORTH SLOPEr ALASKA COMPUTATION DATE~ I9-MAY-88 PAGE DATE UF SURVEY1 10¢MAY-88 KELLY BUSHING ELEVATION~ 58.00 ENGINEERS PEPPE~ MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASB KUPARUK A PBTD TD MEASURED DEPTH BELOW KB SURFACE LOCATION AT URIGIN= 1106 FNL, 2060 FWb. SEC 22. Tt3N. AgE, U TVD RECTANGULAR COOED/NATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 7772,00 6425,16 801,00 6448,7] ~B38,00 6478,81 7969,00 6585.87 8118,00 6708 55 8351,00 6900:53 6367,1b 2286.90 S 3112,97 W 6390,73 2293,92 S 312B.34 W 6420,81 2302 90 S 3147.91W 6527.87 2334:88 $ 3216m31 k ) 6650,55 2371,03 S 3292,75 W 6842,53 2427,57 $ 3412,06 W FINAL WELL LOCATION AT TRUE MUM-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG SIN 8351,00 6900.53 6842,53 4187,51 S 54 34 W SCHLUME}EROER D ~ REC T ]~ ONAL SUR V E Y COMPANY ARCO ALASKA, INC. WELL 90- 16A FIELD KUPARUK COUNTRY U .S .A. 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F'"~'"'~'"~ ....... ~-'~"'~"'T"' Y'T"~'"~'"~'"~'"T-T"T'''~ ...... ~mn'n~'"~'"~'"'~....... ~'"~'"'["'~'"T"'~'"~"'~'"~....... ?"~'"~"'T"'~'"~'"~' 'T"'~ '"~'"~"'"F'"]"'?"'~""F'"~""~ ....... ~""["T"~'"!'"~-~'"~-T ....... S~ f'rl I"rl II ,.=.. o o PROJECTION ON VERTICAL PLANE SW - NE SCALED IN VERTICAL DEpTHs HORIZ SCALE = l/1000 IN/FT STATE OF ALASKA AL, A OIL AND GAS CONSERVATION COMMIS, ,ON REPORT OF SUNDRY WELL OPEP, ATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging m Perforate __ Pull tubing __ Alter casing __ Repair well __ Pull tubing'%4 Other% WORKOVER 2. Name of Operator ARCO Alaska, inc. 3. Address P.0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1106' FNL, 2060' FWL, 5ec.22, T13N, RgE, UH At top of productive interval 1887' FSL, 105:3' FEL, Sec.21, T13N, RgE, UN At effective depth 180:3' FSL, 12:33' FEL, Sec.21, TI:3N, R9E, UM At total depth 1746' FSL, 1:352' FEL, Sec.21, TI:3N, R9E, UM 5. Type of Well: Development"~ Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 58 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 30-16A 9. Permit numbedapproval number 8S-z~/8-653 10. APl number 50-- 029-21796-01 11. Field/Pool Kuparuk River 0il Pool feet 12. Present well condition summary Total depth: measured true vertical 8351 'MD feet Plugs (measured) None 6901 ' TVD feet Effective depth: measured true vertical 8118 'MD feet Junk (measured) None .6709 ' T VD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length 80' 2340' 8168 ' Size Cemented Measured depth True vertical depth 16" 175 sx AS I 115'MD ll5'TVD 9-5/8" 900 sx AS ill & 2:375'MD 2215'TVD :300 sx AS II - Top Job w/lO0 sx AS I 7" ' 700 sx TLW & 8201 'MD 6777'TVD 300 sx Class G 7908'-7928'MD true vertical 6536'-6552'TVD Tubing (size. grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 7722' (circ. string f/982'-1056' [WLM] to isolate leak) Packers and SSSV (type and measured depth) Baker 'AL-5' Dual pkr @ 986' & 1043', Baker 'HB' pkr @ 7648', & Baker 'FVLD' S$5V ~ 1786'. 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run_,.__ ! Daily Report of Well Operations ",4 , Oil ._~ Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of mY knowledge. Form 10-404 Rev 06/15/88 ( Dan i ) SW0:3/052 * Workover Well Hi story Service Date SUBMIT IN DUPLICATE ARCO Oil and Gas Company ,'~ Well History - Initial Report - Dally Instructlona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth, or W.O. ne....... ICounty, pa~%~%b~rO~om E Lease or IJ~L: 25513 Title COMPLETE JState AK 30_16p~]Well no. API: 50-029-21796 Operator ARCO Spudded or W.%~t~T Date and depth as of 8:00 a.m. 09/18/88 ( TD: PB: 8118 SUPV:JWH 09/19/88 ( TD: PB.' 8118 SUPV: JWH ARC%W61'. 0000 IDate 09/17/88 IHour 1430 HRS JPrior status if a w.o. Complete reco~l(~(J;~[~,~ d~y reported ¸o) 1) GIH W/PKR.TO FIND CSG LEAK 9-5/8"@ 2375' MW:10.0 BRINE MOVE RIG TO 30-16A. ACCEPT RIG AT 1430 HRS, 9/17/88. CIRC 10.0 PPG BRINE IN WELL. ND TREE AND NU BOPE. TEST SAME. POH W/TBG. GIH W/PKR TO PINPOINT LEAK IN 7". DAILY:$48,717 CUM:$1,529,800 ETD:$1,529,800 EFC:$1,285,000 ND BOPE 9-5/8"@ 2375' MW:10.0 BRINE PINPOINT LEAK IN 7" CSG BETWEEN 1002'-1016'. RERUN 2-7/8" COMPL W/ DUAL BAKER PKRS W/CIRC STRING TO ISOLATE LEAK. , , ,~10~' LONG STRING: BAKER AL-5 PKR @ 986 , BAKER 'FVLD' SSSV @ 1786', BAKER ~HB' PKR_@ 7648', & TT @ 7722'. SHORT STRING: PKR @ 982 & ~056 . 'x~ST ANNULUS TO 2500 PSI-OK. TEST TBG AND SSSV-OK. SET BPV AND ND BOPE. DAILY:S87,159 CUM:$1,616,959 ETD:S1,616,959 EFC:$1,285,000 The ab~m-4~s correct Slgn~~ ~ For form prepar~o~ ~nd distributi~-.-~, see Procedure~M~)tlual, Section 10, Drilling, Pages ~e"and 87. IDate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code ARCO Alaska, Inc. District I County or ~M SLOPE Lease or U~bL: 25513 Title COMPLETE State AK 30_16/~ Well no. Field KUPARUK RIVER UNIT Auth. or W.O. n~K3081 API: 50-029-21796 Operator ARCO A.R.Co. W~6' 0000 Spudded or W.O~i~i~)T Date 09/17/88 Date and depth as of 8:00 a,m. Old TD Released rig 09/20/88 ( TD: PB: 8118 SUPV:JWM Classifications (oil, gas, etc.) Producing method Complete reCO~of~)~a(~h (j.ay reported I otal number of wells (active or inactive) on this est center prior to plugging and I bandonment of this well I our 1430 MRS IPrior status if a W.O. I .)2) RIG RELEASED 7" @ 8201' MW:10.0 NACL FIN NU TREE. TEST SAME-OK. DISPLACE WELL W/DIESEL. RELEASE RIG AT 1400 MRS, 9-19-88. DAILY:S18,974 CUM:$1,635,933 ETD:S1,635,933 EFC:$1,285,000 New TD Date PB Depth K nd of r g Type completion (single, dual, etc.) Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is corre~c,t Signature ~ ~ For form preparation ~d~listribution, see Procedures Manu~q~, Section 10, Drilling, Pages 86 and 87. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM~o$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing CJ Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing'~Amend order ~ Perforate ~ Other~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, inc. RKB 58' feet 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1106' FNL, 2060' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1887' FSL, 1053' FEL, Sec. 21, T13N, RgE, UM At effective depth 1803' FSL, 1233' FEL, Sec. 21, T13N, RgE, UM At total depth 1746' FSL, 1352' FEL, Sec. 21, T13N, RgE~ UN 7. Well number 30-1 6A 8. Permit number 88-30 9. APl number 50-- 029-21796 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: 8351 'MD feet 6890 ' TVD feet Casing Conductor Surface measured 811 8 'MD true vertical 6697 ' TVD Length Size 80 ' 1 6" 2340 ' 9-5/8" Producti on 81 68 ' 7" Perforation depth: measured Plugs (measured) None feet feet Junk (measured) None Cemented Measured depth 1 75 sx AS I 900 sx AS Iil & 300 sx AS Ii Top job w/lO0 sx AS I 700 sx TLW & 300 sx Class O 7908'-7928' 115'MD 2375'MD 8201 'MD True Vertical depth ll5'TVD 2215 ' TVD 6777'TVD true vertical 6536'-6552' Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail @ 7725' Packers and SSSV (type and measured depth) HB packer @ 7651', FVLD SSSV @ 1785' Description summary of proposal 12.AttachmentS Detailed operations program Fq BOP sketch 13. Estimated date for commencing operation September 4~ 1988 14.Namelf propoSalof approverWaS verbally approved , i- Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)(/~/~,0/,~' ~J~L,~ Title Associate Engineer Commission Use Only (SA3/0033) (JG) Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test .AE~~l~§i~rance I Returned Form 10-403 Rev 12-1-85 SIGNED · LONNIE C. SMITH Commissioner Date by order of the commission Date ~f;',~ ~ Subm~t~n triplicate KRU 30-16A General Workover Procedure Isolation of Casing Leak Pre-Rig Operations 1. Set BP in D-Nipple. 2. Set BPV. Rig Operations 1. MIRU Nordic #1. Kill well with completion brine.pump. ND tree. NU BOPE. 2. Shear off of SBR. POH with tubing. 3. PU RTTS packer on drill pipe. RIH and locate suspected leak at 1000' MD. POH 4. Rerun completion assembly with two dual retrievable packers to isolate casing leak 5. Release rig. Estimated BHP= 3000 Psi Completion Fluid= NaCI/NaBr Brine Anticipated Start Date= Sept. 4, 1988 ANNULAR PREVENTER 6 PIPE RAMS 4 BLIND RAHS 5 TUBING HEAD 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2, 11"-3000 PSI STARTING HEAD 3. 11 "-3000 PSi X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5, 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1, CHECK AND FILL ACCUMIJLATOP P. ESEPVOIP TO PROPEF~ LEVEL WITH HYDRAULIC FLUID, '-'.,, ASSURE. THAT ACCUMLILATOP PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR, 3, 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 ARCTIC DIESEL. 2, 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, 3, CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4, TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS, 7, INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE RAMS, BACKOFF RUNNING JOINT AND PULL OUT OF HOLE, CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES, BLEED TO ZERO PSI. lO. 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, 12, TEST KELLY COCKS AND INSIDE BOP TO :3000 PSI WITH KOOMEY PUMP, 13, 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, JG JULY 28, 1986 (NORDIC RIG 9-5/8") STATE OF ALASKA ~" ALAS,.., OIL AND GAS CONSERVATION COM, SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~,, Alter Casing X~ Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P,0. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 1106' FNL, 2060' FWL, Sec.22, T13N, RgE, UM At top of productive interval 1887' FSL, 1053' FEL, Sec.21, T13N, RgE, UN At effective depth 1803' FSL, 1233' FEL, Sec.21, T13N, R9E, UN At total depth 1746' FSL, 1352' FEL, Sec.21, T13N, R9E, UM Stimulate ~ Plugging ~ Perforate ~ Pull tubing COHPLETE 5. Datum elevation (DF or KB) RKB 58 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 30-16A 8. Approval number 9. APl number 50--029-21796-01 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2340' Production 8168' Perforation depth: measured 8351'MD 6901'TVD 8118'MD 6709'TVD Size 16" 9-5/8" 7" 7908'-7928'MD feet feet feet feet Plugs (measured) (30-16 P & A) 5122'-5195' w/194 sx Class G 7680'-7980' w/183 sx Class G Junk (measured) None Cemented Measured depth 175 sx AS I 900 sx AS III & 300 sx AS II Top job w/lO0 sx AS I 700 sx TLW & 300 sx Class G 115'MD 2375'MD 8201'MD True Vertical depth 115'TVD 2215'TVD 6777 ' TVD true vertical 6536'-6552'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7725' Packers and SSSV (type and measured depth) ..... HB pkr (~ 7651' & FVLD 555V @ 1785" 12. Stimulation or cement squeeze summary N/A 'Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments _ __(Comol. Well Hi~tory w/Addendum, dated 5/24/88) Daily Report of Well Operations ~ Copies of Logs and Surveys R,un ~2 Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~_~i~-,'.'7~ . J-"- / ~" Form 10-404 Rev. 12-1-85~ Title Associate Engineer Date (Dani) 5W03/014 Submit in Duplicate(~ ADDENDUM 5/O9/88 5/18/88 30-16A RU Schl. Rn 6-1/8" (~ f/8110'-surf, l~n ~ f/8110'-surface. Rn (}CT f/8110'-surf. 1RD Schl. RU ACT, ~ brine dn hole @ 2200' 130°, press built up on 7" x 9-5/~" Whenann f/1000rtns reachedpsi to 2500 psi. Bled back. Pressure up to 2000 psi w/100% Methanol; no chg in 7" x 9-5/8" ann. Cont pmp'g brine. Displ w/25 bbls diesel. I{D. ARCO Oil and Gas Company Well History - Initial Report. Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no, AK3081 County. parish Or borough ,J NORTH SLOPE ILease or Unit ADL: 25513 Title COMPLETE IState AK 30-16~, JWell no. API: 50-029-21796-01 Operator ARCO Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 06/19/88 ( 1, TD: PB: 8118 SUPV:WM 06/20/88 ( 1 TD: PB: 8118 SUPV:WM 06/21/88 ( 1 TD: PB: 8118 SUPV:TM 06/22/88 ( 1' TD: PB: 8118 SUPV:WM 06/23/88 ( 1 TD: PB: 8118 SUPV:JH JDate Complete record for each day reported NORDIC 1 IARCO W i 56.0000 Prior status if a W.O. 06/19/88 JHour' 0145 HRS NU DRILLING SPOOL 9-5/8"@ 2375' MW: 0.0 ACCEPTED RIG @ 0145 HRS, 6/19/88. PULLED SEAL ASSY. DRILLING SPOOL. NU DAILY:S21,275 CUM:$1,203,673 ETD:S1,203,673 EFC:$1,285,000 POOH W/FREEPOINT TOOL 9-5/8"@ 2375' MW: 9.5 TESTED BOPE. CIRCULATE BRINE TO 9.5 PPG MUD. CUT CASING BELOW HANAGER. DETERMINE 7" CASING FREE POINT. DAILY:S29,100 CUM:$1,232,773 ETD:S1,232,773 EFC:$1,285,000 MW: 9.5 LIGNO MUD TESTED 9-5/8" CSG RIH WITH 7" CASING 9-5/8"@ 2375' BACKOFF 7" CASING. POOH WITH 7" CASING. TO 2000 PSI. RIH WITH NEW 7" CASING. .. CUM:S1 261,873 ETD:S1,261,873 EFC:$1,285,000 DAILY:S29,100 CIRCULATE FILTERING BRINE 9-5/8"@ 2375' MW:10.0 BRINE RIH WITH 7", 26~ J-55 CASING. SCREW INTO STUB @ 1011'. PUMP DIESEL DOWN ANNULUS. RUN SCRAPER. CIRCULATE HOLE WITH BRINE. DAILY:S67,974 CUM:$1,329,847 ETD:S1,329,847 EFC:$1,285,000 SHEAR PBR 9-5/8"@ 2375' MW:10.0 BRINE FINISH FILTER BRINE. POOH. LDDP. PERFORATE 'A' SAND FROM 7908'-7928'. RIH WITH 2-7/8" COMPLETION EQUIPMENT. LAND TUBING. SET PACKER. TEST TUBING TO 2500 PSI. (PERF'D WITH 8 SPF, 45 DEGREE PHASING. DAILY:S46,400 CUM:$1,376,247 ETD:S1,376,247 EFC:$1,285,000 The above is correct Signature n ~"~d For form preparatio distribution, see Procedures Manu/M, Section 10, Drillino. Paoes 86 and 87. IDate I Title ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: t,P, repare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold· "Final Repot should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporfing the entire operation if space is available. KUPARUK RIVER UNIT Auth. or W.O. no. AK3081 District ICountyorParish fState ARCO Alaska, Inc. J NORTH SLOPE BOROUGH AK Field I Lease or'Unit J ADL: 25513 I Title J COMPLETE API: 50-029-21796-01 Operator I A.R.Co. W.I. ARCO I 56.0000 Spudded or W.O. begun JDate ACCEPT J 06/19/88 Date and depth Complete record for each day reported as Of 8:00 a.m. NORDIC 1 06/24/88 ( 1 TD: PB: 8118 SUPV:DL Accounting cost center code 30-16/~ Jwell no. Iotal number of wells (active or inactive) on this dst center prior to plugging and I bandonment of this well 1 our ~ Prior status if a W.O. 0800 RIG RELEASED 9-5/8"@ 2375' MW: 0.0 DIESEL TEST TUBING (235 JTS OF 6.5# J55 IPC 2-7/8" TUBING, TAIL @ 7725', PKR @ 7651', FVLD SSSV @ 1785{ NU & TEST TREE. DISPLACE WELL WITH DIESEL. TEST CV TO 1000 PSI. SET BPV. SECURED WELL & RELEASED RIG @ 1330 HRS 6/23/88. DAILY:S104,836 CUM:$1,481,083 ETD:S1,481,083 EFC:$1,285,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) i Type completion (single, dual, etc.) I Producing method /Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ,,, Pump size, SPM X length Choke size T.P. C,P. Water % GOR I Gravity Allowable Effective date corrected ,., The above is correct Signature Date J Title ~CIATE ENGINEER Drilling, Pages 86 and 87. ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7165 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~"~'30-16A 5" Dual Induction 4-27-88 4600-8337 ~30-16A Cyberlook 4-27-88 7500-8200 ~O-16A 2" Dual Induction 4-27-88 4600-8337 ~1~,30-16A 2" & 5" Porsity FDC 4-27-88 7450-8311 O-16A 2" & 5" Raw FDC 4-27-88 7450-8311 O-15 5" Dual Induction 5-05-88 2773-9291 .~m~30-15 2" Dual Induction 5-05-88 2773-9291 ,.~___,.,330-15 2" & 5" Porosity FDC 5-05-88 2773-9265 O-15 2" & 5" Raw FDC 5-05-88 2773-9265 30-15 Cyberlook 5-05-88 8700-9291 ~30-14 Cyberlook 5-13-88 7490-8000 14 2" &5" Raw FDC 5-1 3-88 7490-8021 ~"'~"3 O- 14 2"&5" Porosity FDC 5-13-88 7490-8021 '",3O 14 2" Dual Induction 5-1 3-88 2364-8046 ""'",,,30-14 5" Dual Induction 5-13-88 2364-8046 ""='~3 O- 13 2" Dual Induction 5 - 21 - 88 4340 - 7945 ~30-13 5" Dual Induction 5-21-88 4340-7945 ~"'30-13 Cyberlook 5-21 -88 7300-7900 30-13 2" & 5" Porosity FDC 5-21 -88 71 96-7919 30-13 2" & 5" Raw FDC 5-21 -88 71 96-7919 265-6835. Alaska Oi~ & Gas Cons. oommiaion Receipt Acknowledged: ........................... Date' - ........... DISTRIBUTION: NSK Drilling Franzen D & M State of Alaska(+sepia) Lucille Johnston (vendor package) E Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: May 26, 1988 TranSmittal #: 7168 RETURN TO: -- ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles ~ Kuparuk Records Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H - 21 Cement Evaluation Log 4 - 2 0 - 8 8 4 6 0 0 - 1 I 1 9 8 · 3 H - 1 8 Cement Evaluation Log 5 - 0 5 - 8 8 8 8 9 3 - 1 0 0 81 30-16A Cement Evaluation Log 5 - 0 9 - 8 8 90-8111 3 O- 1 8 Cement Evaluation Log 5 - 0 9 - 8 8 2 6 9 0 - 7 51 5 30-1 7 Cement Evaluation Log 5-09-88 2490-7968 3 H - 1 6 Cement Evaluation Log 5 - 2 1 - 8 8 7 7 9 5 - 9 61 4 If you have any questions, concerning this or any other transmittals please call me at 265-6835. -. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION; NSK illing E ~ ~ D state ka (+sepia) r - ~ Al[[ska 0il & C-~s Cons. comm', ~ &nchoraflo · ARCO Alaska, Inc. Date: May 26, 1988 Transmittal #: 7162 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 30-1 6A Open Hole Tape and Listing 5 - 0 5 - 8 8 #72 71 6 3 O- 1 5 Open Hole Tape and Listing 5 - 1 5 - 8 8 # 7 2 7 4 6 3 O- 1 4 Open Hole Tape and Listing 5 - 1 8 - 8 8 # 7 2 7 6 0 3 O- 1 3 Open Hole Tape and Listing 5 - 2 5 - 8 8 # 7 2 7 6 5 If you have any questions, concerning this or any other transmittals please call me at 265-6835. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Lynn Goettinger State of Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK,. OIL AND GAS CONSERVATION COMM,_,$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend D Operation ShutdownXD Re-enter suspended well [] Alter casing _y; Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing I-q Amend order [] Perforate ~ Other 2. Name of Operator 5. Datum elevation(DE Or KB) ARCO Alaska, Inc. RKB 59' feet 3. Address 6. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1106' FNL, 2060' FWL, Sec.22, T13N, RgE, UM At top of productive interval' 1320' FSL, 729' FEL, Sec.21, T13N, RgE, UH (approx) At effective depth 1816' FSL, 1249' FEL, Sec.21, T13N, R9E, UM (approx) At total depth 1759' FSL, 1367' FEL, Sec.21, T13N, R9E, UM (approx) 7. Well number 30-16A 8. Permit number 88-30 9. APl number 50-- 029-21 796-O]- 10. Pool Kuparuk River 0il Poo] measured 8351 ' MD feet true vertical 6890 ' TVD feet Plugs(measured) 5122'-5195' w/194 sx Class G 7680'-7980' w/183 sx Class G 11. Present well condition summary Total depth: Effective depth: measured 811 8 ' MD feet true vertical feet 6697 ' TVD Size Casing Length Conductor 80' Surface 2340' P roducti on 81 68 ' measu red 1 6" 9-5/8" 7" None Junk (measured) None Cemented Measured depth 175 sx AS I 900 sx AS III & 300 sx AS II Top job w/lO0 sx AS 700 sx TLW & 300 sx Class G 115'MD 2375'MD 8201 ' MD ~ue Verticaldepth 115'TVD 2206'TVD 6765'TVD true vertical None Perforation depth: Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Description summary of proposal [] Detailed operations program [] BOP sketch 12.Attachments Wel 1 Hi story 13. Estimated date for commencing operation June, 1 988 Date approved 14. If proposal was verbally approved Name of approver Date SA3/92 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ 0/)q,,q/~, ..t~LL~.,I.j Title Associate E nc~ineer ~j Commission Use Only ( D a n i ) Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned Commissioner by order of the commission Date Submit in triplicate Form 10-403 Rev 12-1-85 ARCO Oil and Gas Company Well History. Initial Report - Daily Instructlonl: Prepare and submit the "lnltlll Repod" on the first Wednesday efts! · well Is spudded or workover operations are Iterted. Daily work prior to SPudding should be summarized on the form giving inclusive dates only. District ] County, parish or borough ARCO Alaska, Inc. II NORTH SLOPE Field Lease or Unit KUPARUK RIVER UNIT ADL: 25513 Auth, or W.O. no. JTitle AK3081 I DRILL JStei~K 30-16/30-16A IWell no. API: 50-029-21796 Operator ARCO Spudded or W.O. begun ]Date SPUD j 04/16/88 Date and depth as of 8:00 a.m. 04/17/88 ( TD: 2400'( SUPV:JP 04/18/88 ( TD: 2400'( SUPV:JP o4/~9/88 ( TD: 3490'( SUPV:JP 04/20/88 ( 4 TD: 5995'( 2! SUPV:JP 04/21/88 ( TD: 7768'( 1 SUPV:RB 04/22/88 ( TD: 8100'( SUPV:RB 04/23/88 ( TD: 8184'( SUPV:RB Complete record for each day reposed DOYON 14 ~) 24 00) I ARCO WI. IHour J 56.0000 IPrior status if a W.O, I 0800 HRS ) 0) 1~ ~0) WORK THROUGH TIGHT SPOT 16" @ 115' MW: 9.3 VIS: 52 ACCEPT RIG @ 0030 4/16/88. SPUD @ 0800 4/16/88. DYNADRILL 12- 1/4 HOLE TO 2400'. SHORT TRIP TO 1000'. HIT TIGHT SPOT @ 1869'. WORKING THROUGH TIGHT SPOT. DAILY:S83,493 CUM:$83,493 ETD:S83,493 EFC:$1,285,000 TIH WITH 8 1/2" BHA 9-5/8"8 2375' MW: 8.4 ViS: 29 WASH AND REAM FROM 1869'-2400'. CIR HI VIS SWEEP. SHORT TRIP TO 1700'. DROP SINGLE SHOT AND PUMP PILL. POOH LD BHA. RU AND RUN 59 JTS OF 36# J-55 BTC 9-5/8" SURFACE CASING. FS @ 2375'. CIRC. AND COND MUD. CEMENT CASING WITH 900 SX 12.1 PPG AS III LEAD FOLLOWED BY 300 SX 15.2 PPG AS II TAIL. CIP @ 1845 HR,S 4/17/88. PERFORM TOP JOB WITH 100 SX 15.7 PPG ASI. NU BOPS AND TEST. MU 8-1/2" BHA. ORIENT MWD. TIH. DAILY:S154,962 CUM:$238,455 ETD:S238,455 EFC:$1,285,000 DRILLING 9-5/8"@ 2375' MW: 8.7 VIS: 37 TAG FC @ 2292'. TEST CASING TO 2000 PSI. DRILL OUT FLOAT EQUIPMENT AND 15' OF NEW HOLE. PERFORM LOT. TURBODRILL 8- 1/2" HOLE TO 2632'. TURBINE FAILED. POOH. CHANGE OUT BOTH MOTOR SECTIONS ON TURBINE. SURFACE TEST AND ORIENT. TIH. TURBODRILL 8-1/2" HOLE TO 3169'. TURBINE FAILED. POOH. TEST AND CHANGE OUT BEARING SECTION. TEST AND ORIENT. TIM. TURBODRILL 8-1/2" HOLE TO 3490'. DAILY:S74,258 CUM:$312,713 ETD:S312,713 EFC:$1,285,000 ) DRILLING 9-5/8"@ 2375' MW: 9.1 VIS: 32 35) TURBODRILL 8-1/2" HOLE TO 5995'. ) 73) 32) DAILY:S42,552 CUM:$355,265 ETD:S355,265 EFC:$1,285,000 DRILLING 9-5/8"8 2375' MW:10.0 VIS: 42 TURBODRILL 8-1/2" HOLE TO 7768'. DAILY:S70,132 CUM:$425,397 ETD:S425,397 3EFC:$1,285,000 DRILLING 9-5/8"@ 2375' MW: 9.9 VIS: 39 DRILL 8 1/2" HOLE TO 8008'. PUMP PILL. POOH AND LD BHA. MU BHA #3 AND BIT #4 AND RIH. CUT 59-1/2' OF DRILLING LINE. RIH AND WASH 150' TO BOTTOM. DRILL 8-1/2" HOLE TO 8100'. DAILY:S68,043 CUM:$493,440 ETD:S493,440 EFC:$1,285,000 The above is correct Signature For form preparation and/cJJstribution, see Procedures Manual,/Sllction 10 Drilling, Pages 86 and 8~. ~ RIH F/CLEANOUT 9-5/8"8 2375' MW: 9.9 VIS: 41 34) DRILLED 8-1/2" HOLE TO 8184'. CIRCU~TE BU & PU~ED DRY JOB. SHORT TRIP TO 4000' & RIH. CIRCULATE, DROPPED SINGLE SHOT, & SPOTTED DIESEL PILL. POOH W/ BIT #4. RU SOS LOGGING. RAN DIL/SFL/GR/SP F/1000'-8184', FDC/CNL F/8184'- 7550'~ & CA~ F/8]R4'-2~75'. RD RO~. RIN FOR JNumber all dally well history forms consecutively Page no. as they are prepared for each wall. I I · AR3B-459-1-D ~&-~:~c;:~-': .... ,..-,, ~::'.~'.,*~. .".;"'; :'-';'. ~',7' ', *':'~ .... ~-.:"<' '.'<':~:...'~ ~"';' 7 ~:~.".i~ ¥" :""~' :"".'.'.'""' ..... '~ ..... ~'~':"':"'.'.'*'~'t" ....... ': ?'*,""':' ~'"~'~' ARCO ~,. and Gas Company Dally Well History--Interim Instructloni: This form ia used during drilling or workover operations. If testing coring, or perforating, show formation name In deacrlblng work performed. Number ai drill atem tests sequentially. Attach description of ell cores. Work performed by Produc ng Section will be reported on "lnllrlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not lesa frequently than every 30 days, or (2) on Wednesday of the week in which oil string ia let. Submit weekly for workovers and following setting of oll string until completion. ~lstrict ~ield ARCO Alaska, Inc. County or Parish Istate NORTH SLOPE I AK Lease or Unit 30-16 KUPARUK RIVER UNIT Date and depth Complete record for each day while drilling or workover In progress as of 8:00 a.m. DOYON 14 04/24/88 ( TD: 4900'( SUPV:RB 04/25/88 ( TD: 5591'( SUPV:RB 04/26/88 ( TD: 7240'( SUPV:RB 04/27/88 ( TD: 8351'( SUPV:RB 04/28/88 ( TD: 8351'( SUPV:JP IWell no. 8) O) 9) 691) o) .649) .1) .111) 2) 0) WAITING ON CEMENT 9-5/8"@ 2375' MW: 9.9 VIS: 39 RIH FOR CLEANOUT RUN. CIRCULATE & CONDITION MUD. POOH & STAND BACK BHA. RIH TO 7980'; CIRCULATE & CONDITION MUD. PUMPED PLUG F/7980'-7680' WITH 183 SX CLASS G. POOH. CIRCULATE & CONDITION MUD. POOH TO 5195'. PUMPED PLUG F/ 5195'-4900' WITH 194 SX CLASS G. POOH. CIRCULATE MUD. POOH & LDDP. MU BIT & BHA. RIH TO 9-5/8" CASING SHOE. CIRCULATE & WO CEMENT. (30-16 P&A'D 2230 HRS, 4/23/88) DAILY:S137,683 CUM:$676,249 ETD:S676,249 EFC:$1,285,000 POH & CHG OUT BHA '9-5/8"@ 2375' MW: 9.0 VIS: 37 CIRCULATE @ 9-5/8" SHOE & WO CEMENT. RIH & TAGGED FIRST CMT PLUG @ 4820'. WASHED & DRILLED TO 4915'. SET 70,000~ & PUMPED 100 SPM. CIRCULATED & TREAT MUD. POOH & LD B~A. RIH TO 4795'. WASHED TO 4915'; WOULD NOT TAKE WEIGHT. WASHED F/4915'-5122'. CIRCULATE & TREAT MUD. 30-16A OPERATIONS STARTED 2000 HRS, 4/24/88. SIDETRACKED AT 5122'. DRILLED F/5122'-5591'. PUMPED DRY JOB. POH & LD BHA. DRILLING 9-5/8"@ 2375' MW: 9.2 VIS: 36 RIH. CUT DRILLING LINE. RIH. DRILLED 8-1/2" HOLE TO 7240'. DAILY:S60,102 CUM:$813,577 ETD:S855,828 EFC:$1,242,749 RIH FOR SHORT TRIP 9-5/8"@ 2375' MW:10.0 VIS: 42 ATTEMPT MWD SURVEY. RU & RUN WIRELINE SURVEY. DRILLED 8-1/2" HOLE TO 8351'. CIRCULATE & CONDITION. POOH FOR SHORT TRIP. TIGHT @ 3980'. WORK TIGHT SPOT. POOH TO 9-5/8" SHOE. RIH FOR SHORT TRIP. DAILY:S51,675 CUM:$865,252 ETD:S865,252 EFC:$1,285,000 LDDP 9-5/8"@ 2375' MW: 9.9 VIS: 44 CIRCULATE AND CONDITION MUD. DROPPED SURVEY. SPOT DIESEL PILL. POH & LD BHA. RU SOS AND RAN DIL/GR/SP/SFL F/TD-4600', FDC/CNL F/TD-7450', & CAL FROM TD-4600'. RD SOS. MU BHA & TIH. REAMED F/7900-8315'. CIRCULATE HOLE CLEAN AND SPOT DIESEL PILL. POH. LD DP. DAILY:S94,299 CUM:$959,551 ETD:S959,551 EFC:$1,285,000 The above is correct For form preparatio, t¢'/~nd distribution see Procedures M~t~hl.~l Section 10, Drilling, Pages 86 b~fd 87 IDate ]Title .~-~-<~:) AGGOClATE ENGINEER AR3B-459-2-B INumber all daily well history forms as they are prepared for each well. consecutively IPage no. ARCO Oil and Gas Company Daily Well History-Final Report I.atru¢ll .... Prep ..... d submit the "'Final Report" .on the first W~enddneedSloary after al owable has b ...... Igned .... II Is Plugged Abandoned, or Sold. "Final Report" should be submitted also when operations are suspe. _ . , an ndef n te or apprec able ength of time. On workovers when an official test Is not required upon completion, report completion end representative test asea in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. cost center code District ~. ARCO Alaska, Inc. Field ~" KUPARUK RIVER UNIT :~. Auth. or W,O. no. ·. AK3081 . Operator ARCO Spudded or W.O. beg~n SPUD Date and depth as of 8:00 a.m. 04/29/88 ( TD: 8351'( SUPV:JP IAccounting State AK ICounty or Parish NORTH SLOPE Lease or Unit Title ADL: 25513 DRILL API: 50-029-21796 A.R.Co. W.I. ITotal number of wells (active or inactive) on this Icost center prior to plugging and 56. 0000 labandonment of this well ' Date IHour IPrlor status If a W.O. 04/16/88 / 0800 tiES I Complete record for each day reported DOYON 14 RELEASED RIG 9-5/8"~ 2375' MW:10.0 VIS: FINIStiED POti & LD BHA. RAN 204 JTS 7", 26#, J-55, BTC CASING W/SHOE ~ 8201'. CMTD W/700 SX TLW & 300 SX CLASS G. CIP @ 2115 HRS, 4/28/88. ND BOPE. MAKE FINAL CUT ON 7" CSG AND INSTALLED PACKOFF. INSTALLED TUBINGHEAD AND LOWER SEAL ASSY. TESTED FLANGE TO 3000 PSI. FREEZE PROTECT 30-17 WITH 60 BBLS DIESEL. SECURED WELL AND RELEASED RIG @ 0400 fiRS, 4/29/88. DAILY:S222,847 CUM:$1,182,398 ETD:S1,182,398 EFC:$1,285,000 Old TD I New TD PB Depth I Released rig I Date IKind ofr g I I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) 30-16/30-16A Iwelln°' Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval OII or gsa Tesl lime Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date I Title For form preparation II/~d distribution, see Procedures ManuM', Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forma consecutively as they are prepared for each well, iPage no. Dlvldon ot AtlantlcRIoMleldCompany · '~ STATE OF ALASKA ALASt,., OIL AND GAS CONSERVATION COMN .... 31ON APPLICATION FOR SUNDRY APPROVALS 1. Type. of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing)~!"~ Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 59' 3. Address 6. Unit or Property name P. O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4..Location of well at surface 7. Well number 1106' FNL, 2060' FWL, Sec.22, T13N, R9E, UM 30-16A At top of productive interval 8. Permit number 1320' FSL, 729' FEL, Sec.21, T13N, R9E, UM (approx) 88-30 At effective depth 9. APl number 1816' FSL, 1249' FEL, Sec.21, T13N, R9E, UM (approx) 50-- 029-21796-01 At total depth 10. Pool 1759' FSL, 1367' FEL, Sec.21, T13N, RgE, UM (approx) Kuparuk River Oil Pool feet 11. Present well condition summarY Total depth: measured true vertical 8351 'MD feet Plugs (measured) 6890 ' TVD feet 5122'-5195' w/194 sx Class G 7680'-7980' w/183 sx Class G Effective depth: measured 811 8 'MD feet Junk (measured) None true vertical 6697 ' TVD feet Casing Length Size Cemented Measured depth ~ue Verticaldepth Conductor 80' 16" 175 sx AS I 115'MD 115'TVD Surface 2340' 9-5/8" 900 sx AS I II & 2375'MD 2206'TVD 300 sx AS II Top job w/lO0 sx AS I Production 8168' 7" 700 sx TLW & 8201'MD 6765'TVD 300 sx Class G Perforation depth: measured None .... , Tubing (size, grade and measured depth) Non e '~/" ' [~ ~ '-: 0~- ~ '; A[:S~: 0d & Gas Cons. u0mm[~[0n Packers and SSSV (tyPe and measured depth) None 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch/~,~. 13. Estimated date for commencing operation May 23, 1988 14. If proposal was verbally approved Name of approver ---' - '' Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~ (~'~J)4_,, .~:~'~-~' ,L/,W_~ ~' TitleAssoci ate Engi neet Commission Use Only ('U'~ ) 5A3/92 Conditions of approval Approved by ORIGINAL SIGNED BY LOBNIE C. SMITH Form 10-403 Rev 12-1-85 Notify commission so representative may witness ~ Plug integrity [] BOP Test [] Location clearance Approved Copy Returned Commissioner Date IApprOval NO' by order of the commission Date,<~-- ~-~7~ :,~& Submit in triplicate DS 30-16A GENERAL WORKOVER PROCEDURE 1) 2) 3) 4) 5) 6) 7) 8) 9) MIRU Doyon 14. ND lower tree assembly. Pull primary packoff. NU and test BOPE 3500 psi. Rill w/~2~-~" DP & set ret. bridge plug at 2000'. Spot 20' sand on top of RBP. RU WL. Run free point. RD WL. Rill with 7" casing cutter, cut 7". POOH. Rill, spear 7" casing POOH. Washover 7" casing, cut and pull to 1800' (base of permafrost). PU 8½" bit & 9-5/8" CS~scraper. Rill to 1800'. POOH. Rill with 7", 26#, J-55 BTC casing to 1800'. Circulate Arctic Pack fluid to surface. Screw 7" casing into stub. Test casing to 3500 psi. ! II 10) Rill with RBP retrieving tool on 37 DP. Displace Arctic Pack with 10.0 ppg brine. Circ. out sand. Pull RBP. POOH. 11) ND BOPE. Set slips. NU tubing head and lower tree. Test packoff. Release rig. WORKOVER FLUID: ESTIMATED START DATE: ESTIMATED BHP: 10.0 ppg LSND mud May 23, 1988 3000 psi @ 6000'TVD PW07/16 5-17-88 RECEIVED ~i/-'.':? 1 8, ~ask,a Oil & Gas Cons. Commission Anchorage i ill ii i i I' 5 4 DIAGRAM #1 1~5/8" 5000 PSI RSREA BiP STAC~ i. 16' - 2000 PSI TAt~CO STN~q'IN~ ~ 2. I1' - ~~I ~I~~ 4. i~5/8" - ~ ~I PI~ ~ KILL LI~S ~ 1~5/8" - ~ ~I ~E ~ ~I~ ~ ~ T~, 2 l, i ACC~ATOR ,, ~J~ACITY i TEST I. CI4ECK ~ FILL ACOJM. LATOR I~SEI~OIR TO PROPER LEVEL WITH NYERN. I. IC FLUID. 2. ~ THAT ACO. MA.ATCR PRESStRE IS 3000 PSI WITH 1500 PSI DOV/~TREAM CF TkE REGU.ATOR. 3.-CI~E~ TIIVF_, TFEN CLOSE ALL UNITS SIhU. TAM[OUSLY AN3 REQ3R~ 'rkE TIhE AN) ~ RE~INING AFTER ALL UNITS ARE CLO~ED WITH CHARGING ~ CFF. 4. RECORD ON ~ REPORT, Tk~ ACCE~ABLE LOeER LIMIT IS 45 SECON~ CLOSIM; TIM[ N~) 1200 PSI RE~INING RECEIVED Oil & Gas Cons. Commission Anchora§a 13-5/8" BOP STAQ'K TEST FILL B(]~ STACK AM) CI-CKE MNYlFQ.D WITH ARC'TIC DIESEL. 2. a-ECK THAT ALL LOCK C(]Igq SCRE¥15 IN PELLI-EN:) ARE FILLY RETRACTED. SEAT TEST PLUG IN PELL~ WITH RLN~ING JT A/~. ~ IN L(X](E[I~ SCREP6. 3. CLO~'__ ~ ~NTER AI~ MM~LIAL KILL AM) O.O(E LIAE VALVES ADJ~ TO BCP STACK. ALL OTI-ER VALVES ~ CHOKES SHOLt. D BE CPE~ 4. PRESSLRE UP TO 250 PSI AF~ HQ.D FOR i0 MIlL IN- CREASE PRESSLRE TO tiX~O PSI AM) HOLD FOR I0 MI~ BLEED PRESSLi~ TO 0 PSI. 5. OPEN ~ PR~'VENTER AhD MN~AL KILL N~ CHCKE LIME VALVES. CLOSE TCP PIPE ~ AM) HCR VALVES ON KILL AM) CliChE LIKES. 6, TEST TO 250 PSI /~D 5C130 PSI AS IN STEP 4. 7. CCNTIN. E TESTING ALL VALVES, LIKES, AM) CHOKES WITH A 250 PSI LOW AM) ~XX) PSI HIGH. TEST AS IN STEP 4. DO M3T P~~ TFRT ANY CHOKE THaT IR M3T A FULL CLOSING POSITIVE SEAL CH(~K~, CN..Y FLI~IIUN IEST C~EKE5 THAT DO M31 FULLY CLQ~. 8. CPEN TCP PIPE RAMS AAO CLOSE BOTTOM PIPE P,A~. TEST BOTTOM PIPE ~ TO 250 PSI AM) 5000 PSI. 9. C~EN BOTTOM PIPE P. Ak~ BAQ< OUT RUM~ING JT AAD PU_L OJT CF HOLE. I0. CLOSE BLIND ~6 A~D TEST TO 250 PSI A~D 30CD PSI. Ii. CPEN BLIAD RAMS A~) RETRIEVE TEST PUJEA Maj<E SURE M~NIFCLD N~) LIKES ARE FLU. CF NC~-FREEZlNG FLUID. SET ALL VALVES IN CRILLING PC~ITIC~ 12. TEST STAMiPlPE VALVE.~ KELLY, KELLY CO(X~ CRILL PIPE SAFETY VALVE, A~D INSIDE BOP TO 250 PSI AM) ~ PSI. 13. RECI~RD TEST IhFCR~TION CN BLCMOUT PREVENTER TEST FCR~ SIGN, AM) SEM) TO DRILLING SLPERVlSC~. 14. PERFCRM CCM~LETE ~ TEST AFTER NIPPLIN$ UP AN3 VEEKLY THEREAFTER FLNCTI~Y ~.RATE BCPE DAILY. !!lay 5, 1988 ~r. J. B. Kewtn Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy~ (907) 276-7542 Re: Kuparuk River Unit 30-16A ARCO Alaska, Inc. Permit No. 88-43 Sur, Loc. II06'FNL, 2060'FWL, Sec. 22, T13N, R9E, UM. Btmhole Loc. 189'FSL, 1382'FEL, Sec. 21, T13N, R9E, UM. Dear. Mr. Kewin: Enclosed is the approved application for permit to redrill the above referenced well. The .permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly yours, Chairman of AlaSka Oil and Gas Conservation Commission BY ORDER OF THE COP~IISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASK'. ,.)IL AND GAS CONSERVATION L,,JMMISSION PERMIT TO DRILL 20 AAC 25.005 i la. Type of work Drill [] Redrill 1~ lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] DeepenElI Service [] Developement Gas [] Single Zone f¢ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 59' PAD 24' feet Kuparuk River Field Kuparuk River Oil Poe 3. Address 6. Property Designation P.O. Box 100360, Anchorage, AK 99510-0360 APL 25513 ALK 2554 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1106'FNL, 2060'FWL, Sec.22, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (~ target) 8. Well nu.mber Number 1950'FSL, 1200'FEL, Sec.21, T13N, RgE, UM 30-16A #8088-26-27 At total depth 9. Approximate spud date Amount 189 'FSL, 1382'FEL, Sec.21, T13N, R9E, UM 04/23/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15i~ Proposed depth (MD and TVDI property line 30-1 7 1 76'MD 1894'@ TD feet 25' ~ Surface feet 2560 (6695'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 51 22 feet Maximum hole angle 390 Maximum surface 1140 psig At total depth (TVD) 3033 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" ~26.0~ J-55 BTC 8142' 34' 34' 8176 6695' 400 sx TLW lead & HF-ERW 150 sx Class G tail TOC 500' above UGNU 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 81 84 ' feet Plugs (measured) 51 95 ' -51 22 ' true vertical 6714' feet 7970'-7676' Effective depth: measured 51 22 ' feet Junk (measured) None true vertical 431 9 ' feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80 ' 1 6" 1 75 sx AS I 11 0 ' 11 0 ' 2219' Surface 2340 ' 9-5/8" 900 sx AS I I I & 2375 ' Intermediate 300 sx AS II Production Liner Perforation depth: measured ,~a$~(~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ DiverterSketch [] Drilling program Drilling fluid pr,~g,r~ 1~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby c/~ftify ?at the fore,~~¢~e and~ correct to the best of my knowledge Signed !, /.~/'~¢¢.,/,~'~j~. ~,.4"~",,'¢'~ Title Regional Drilling Engineer Date ",/-/"'-~' "~'~" ' Commission Use Only ~,,~ ",- -- (TEM) PD2/90 See cover Permit Number / I APl number I Approval date I letter ~E~" 4,~ I 50-- O~' 9- Zt ~7~(="-° t I 05/05/88 I for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required L~ Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No Other:Required wo~su~.~,,,/~~~ ("~'~~/~¢~.~1)ref~~,~M; ED 10M; [] 15M, by orderof Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 ! Sub,~i ~ triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 30-16A SIDETRACK 1) After setting open hole plugs, RIH with kick off assembly. 2) Drill 8-1/2" hole to logging point according to directional plan. 3) Run open hole logs. 4) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk Sands. 5) Run and cement 7" casing. Pressure test to 3500 psig. 6) Downsqueeze Arctic pack and cement in 7" x 9-5/8" annulus. 7) ND BOPE and install temporary Xmas tree. 8) Secure'well and release rig. ~ 9) Run cased hole logs. 10) Move in workover rig. NU BOPE. 11) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 12) Perforate and run completion assembly, set and test packer. 13) ND BOPE and install Xmas tree. 14) Change over to diesel. 15) Flow well to tanks. Shut in. 16) Secure well and release rig. 17) Fracture stimulate. DEGASSER MUD CLEANER SHALE S STIR STIR SHAKERS MUD CLEANER CENTRIFUGE Lmc4/ .h TYPICAL MUD SYSTEM SCHEMATIC Density PV DRILLING FLUID PROGRAM SpUd to Drill out 9-5/8" Surface Casin~ to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 15-30 5-15 9-13 yp 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 lO.Minute Gel 15-30 4-8 5-12 Filtrate-AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid STstem: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 12.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200" of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LV~LS/ih ....... ~I0~.-, -- TVD-: .. , 4??5 · ~000 0 V. ~:OTZON PLANE~ TARGET TVD=6460 THD=?8?3 DEP-38?8 SOUTH 2224 k'E:ST 3260 TARGET LOCATION' 1950' FgL. 1200' FEL SEC.. 21. TI3N. RgE. TD LOCATIONt 1893' '~ FSL. 1382' FEI. . SEC.. 21 ._T 13N.. RgE i SCALE 1 '~ 1000FT. 20OO 50OO NOT£~ Ceerdlnetd. rdletlv4 to IIDt$1OZ. 39'18' 2309.72 ~EC. HD~ 57'04. 39'1' HDt817S. 39'1 ' : .* I I " i 000 2OOO 3OO0 4000 50OO S45' O0 '~ ........... gURVEY ~ g07411 ~ 2AR . PROPO~3AL ~ P0053~. 2AR gCALE 1 "~ I OOOFT. ARCO ALASKA. INC. Ku,l,,k Fleldo t, IELL, 16-A ~L.OT! I I ~050 ..... '1001.. I 200 .... I I t250 .... 1 350_. 1400:.. // 1900. 950 / go0 2000' I 2050 I / / / / 1700 2100 2150: I 1 go0: / 500 · .,. 300 2000 300 300. 300 ~ ?00 I *. 300 ~$00 ~00 ~ \ ' roo \ \ f1100 ~ 900 \ \ 300 \ '~ 1100 \ \ \ \ \ \ 2050 21 O0 21 50 2200 I, 2200 .10C _ 10,= _ I1( _11 _12 _12 _13 i i i DIAGRAM #1 13--5/8' 5000 PSI RSRRA BCP STACK I. 16' - 2000 PSI T/k'~(~ STARTING FEAD 4. 1~-5/8' - 50130 PS! PIPE ~ 5, 13-5/8' - 5000 PSI DRILLINS SPOCL W/Q-K)KE AJ~ KILL LIliES 6. 13-5/8" - 5000 PS! DOLBLE RAM W/PIPE RA~ ON TCP, 7. 13-5/8'. - 54300 PS! AltAR ACOJM~ATOR P..APAC;[Ty TEST I. C~ECK ~ FILL ACOJM.I. ATOR R~SERVOIR TO PROPER LEVEL WITH HYDRAi~IC FLUID. 2. ~ THAT ACO.kULATCR PRESSU;~ IS ~ PSI WITH 1500 PSI ~TREAM OF T~E REGU.ATOR. 3. OBSERVE TIbE. TF4~I CLOSE AU_ t.l~lITS SIMJLTAt~EOUSLY AN~ RE~ THE TIIvE AN:) PRE~ REMAINING AFT~]~ ALL UNITS AI~ C~OSED WITH CHARGING PUvP OFF. 4. R~CORD ON NADC REPORT. TkE ACCEPT~ LOAER LIMIT IS 45 SE~ (lOSING TIM~ ~ 1200 PSI REMAINING 2 13-51~" Bop, STACK T[ST FILL Ba:) STAO( ~ Q..O(E blN~IFCLD WITH ARC'tIC DIESEL. Q-ECK THAT ALL LOQ( [X]I~ SCRE~ IN NEI. LHEN3 ARE ~LY ~T~~ ~T TEST ~ IN ~L~ ~TH ~I~ JT ~ ~ IN L~ ~~ 3. ~ ~ ~~ ~ ~ KILL ~ ~ LI~ V~ ~~ TO ~ ST~ ~ ~ V~S ~ ~ ~ ~ ~ 4. ~~ ~ TO ~ ~I ~~DF~ I0~ I~ ~ ~~ TO ~~I ~~DF~ I0 ~ ~ED ~~ TO 0 ~I. 5, ~N~ ~~ ~~ KI~ ~ ~ ~ KI~ ~~ LI~. ~ ~ TO~~I ~~~I ~ IN~ 4. 7. ~I~ ~I~L V~ LI~ ~ ~S ~P4. ~T~~ TZ~~~ T~T Is ~ A ~L ~I~ ~ITI~ ~ ~ ~Y ~I~ ~E~ ~ES ~ ~ ~ ~Y ~. 8. ~ T~ PI~ R~ ~ ~ ~~ PI~ ~. ~ST ~T~ PI~ ~ TO ~ ~I ~ ~ ~I. ~L ~ ~ ~E, ~ ~I~~ ~T~T TO~~I ~~ ~I. ~F~D ~ LI~S ~ F~ ~ ~EZI~ ~UI~ ~T ~L V~ IN ~ILLI~ ~ITI~ 12. ~ST ~~I~ V~ ~ly. ~Y C~ ~I~ PI~ ~E~ V~. ~ I~I~ ~ TO~I ~ ~ ~I. 15. ~~ TEST I~~TI~ ~ ~~ ~ER ~7 F~ SI~ ~ ~ TO ~ILLI~ ~RVI~. 14. ~~ ~~ ~ TE~ ~ ~I~ ~ ~ ~E~Y T~~ F~TI~Y ~TE ~ ~IL~. KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC j DE$(;RIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE ~ OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (3) Admin ~ ~/2&/~ (9 thru 13) (10 and 13) (4) Casg ,~,~.4~ 4/-3o°~ (14 thru 22) Company 1. Is the permit fee attached .......................................... Lease & Well No. YES NO (23 thru 28) (29 thru 31) 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ..' .......... 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... . 10. 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will'all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32 Additional requirements ' . e..e.®.e......e..®.....e.®...s.....~.~.....m~ Is a diverter, system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ...'...~/' ... If an offshore loc., are survey results of seabed conditions predated REMAK~S O ~Z ~O Geology: Engineering: WWB ~1~7 LCS BEW__ rev: 02/17/88 6.011 ,, INITIAL GEO. UNIT ON/OFF POOL CI.d~S STATUS AREA NO. SHORE ~garoo p~v - [ ot~ 89o ! t ~'&o 06J Additional Remarks: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effod has been made to chronologically organize this category of information. LIS TAPE VERIFICATIOM LISTING ,/ '~R' PAGE 1 bVP OlO,H02 VE iFICATIOi~ LISTINC ~ ** REEL HEADER ** SERVICE NAME :EDIT DATE :88/05/ 6 REEL NA~E $72716 gONTINUATION ~ :01 R PREV/OUS EE, L : COMMENTS :LIS TAPE, ARCO ALASKA, INC, 30-16A, API 50-029-21796-01 ** TAPE HEADER ** SERVICE NAME :EDIT DATE :88/05/ 6 ORIGIN :FSIA TAPE NAME CONTINUATION PREVIOUS TAPE : COMMENTS :LIS TAPE, A~C[) ALASKA, INC, 3 O-16A, API 50-029-21796-01 EOF ** FILE HEADER ** FILE NAME :EDIT ,001 SERVICE NAME VERSION # : DATE : MAXI~U~ LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS MNEM CONTENTS CN ~ WN : RANG: TOWN: SECT: COUN: STAT: ARCO ALASKA, INC, 3 0'16A KUPARUK 9E NORTH SLOPE ALASKA ** COMMENTS ** UNIT TYPE CATE SIZE CODE 000 000 018 Ob5 000 000 010 Ob5 000 000 008 065 000 000 002 0~5 000 000 004 Ob5 000 000 002 065 000 000 012 065 000 000 OU6 0~5 ¥~. ;IFiCATION LISTING PAGE 2 bYP OlO.H02 .... R * $CHL[t~SERGER * ALASka COmPUTiNG CENTER COMPANY = ARCO ALASKA, INC. FIE~D = KUPARUK COUNTY = NORTH SLOPE STATE = AbASKA ~OB NU~BE~ AT AKCC; 72716/. DATE ~POTED: 05-NAY-B8 CASING ; 9.6'"25" 82377'(LOGGER) ~ BIT SIZE = 8.5" TO 8345'(50GGE~) DENSITY = 10,0 h~tG RM = ~.62 ~ 6~ OF VISCOSITY = 44,0 S RMF = PM = 0 RMC = 3,~5 ~ 65 DF FIELD REMARKS: I !/2" ~EFL' O'N STAMDOFF AND 2" HOLE FINDER USED ON DIb; ~ATRiX DENSITY = SAND (2,65); HOLE C[~RRECTION = CALIPERJ KICK-OFF POINT FROM ~ELL 30-16 IS AT b122'; LVP O10,tt02 VERIFICATIOiV LISTING PAGE 3 ltd CU~'VE AT 7B5b' OF REPEAT PASS IS NOT REPEATABLE, }i..ilS'~i ' CAUSED ....BY THE%~ INDUCTI(]N DECO~V'O~'LiT,.. IO~ FILTER WHICH IS SOMEWHAT AFFECTED ~Y ~!IGh RESOPU iO~ SA~PLING, REP~ ,~ SECT/ON bOGGED ~ITh t,2" SAMPLI~G, PLAYED BACK AT 6", TOOL ~.YPES/ : DIS 2140 SGC 2646 OIC 2191 PGS !026 CNC 1449 IEM 1448 NLM 13138 ******************************************************************************* ***** THIS DATA, HAM ~0~[ BEEN DEPT~ SHIFTED OVERLAYS FIELD PRINTS SCHLUMB~iRGER LOGS INCLUDED ~ITH THIS FILE (EDIT~O01)I 2" SAMPLED FDC/CNb (SEE FI[~E EDIT,O02 FOR 1, INDUCTI{]N SPHERICALLY FOCUSED LOG FIRS'i' TO LAS~[~ READING: 8337' TO 4597' FORMATIO~ D~NSITY CSMPENSATED bOG (~DC) FIRST TO LAST READI~G: 8~11 TO 7450' FIRST TO LAST READING~ 8296' TO 7450' 5VP OlO,H02 VERIFICATION LISTING PAGE 4 ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE ~EPR CODE ENTRY 2 1 66 0 4 I 66 1 8 4 73 6O 9 4 65 ,lin 16 I 66 1 0 1. 66 0 D.ATtJ~ SPECIFICATION ObOCh. S mN~M SERVICE SERVICE UNIT AP1 AP1 AP1 AP1 FILE SiZE SPb REP~ ID ORDER # LOG TYPE CLAS6 MOD TENS DI~ ~[~ 00 635 21 0 0 4 GR ~DC GAP1 00 3,0 0! 0 0 4 T~ c~ oo 4~0 ox 0 0 4 ~CrT C~ CP~O0 000 000 0 4 ~C~T C~ C,~00 000 000 0 C~C C~ C~ 00 000 00 0 0 4 C~TC C~ C~ O0 0o0 O0 0 0 ~ C~ ~ O0 ~0O~ 0 0 4 PROCESS CODE [OCTAL) 68 00000OO0000000 68 00000O00000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 ~8 00000000000000 68 00000000000~00 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000OO0000000 68 00000000000000 68 0OO00000000000 68 00000000000000 DATa ** DEPT DPHI GR RTNR CNTC 8356.0000 TENS 2,3728 SP 9 6250 TENS 195 $381 GR 5164 0000 SFLU -38i5000 GR 2 4884 QRHO 5164 0000 NPHI 526,5494 RCNT 95,6250 2.4669 95.6250 TENS 0.0652 41.6537 TNRA 1898.4094 CFTC 1,92U0 5164,0000 8,9844 , 4548 57 ,2534 DEPT DPHi GR 8]00 O000 TENS 2i40~0 SP 12 4061 RHO~ 103 8125 TK~S 7520.0000 SFLU -38.5625 GR 2.4453 DRHO 7520.0000 NPHI 2 0586 ILO 103:8125 TENS 0.0277 CAbI 35.4860 TNRA 2,2835 7520,0000 9,1875 3,1344 bVP 0!0,H02 VERIFICATION LISTING PAGE; 5 RTNR 3,2812 RCFT CNTC 1948,7029 GR DEPT 8200 0000 TENS DPHI 1.2,576! Rt,{OB G~N.. 93,9375 TENS RT R 3,1206 RCFT CNTC 2066,4321 GR DEPT 8100 0000 TENS ,3596 8P PHI 8,6952 RHOB GR 89,1250 TEIi'M RTNR 3,0989 RCFT CNTC 2252,~003 GR ~EPT RTNR CNTC DEPT GR RTMR CNTC DEPT DPHI GR RTNR CNTC DEPT DPMI GR RTNR CNTC OEPT GR RTNR CNTC DEPT IL~ 8000 0000 TENS 2 7431 SP 16 0314 RHOM i02 7500 TENS 3 3846 aCFT !811 2085 GR 7900 0000 TENS 8 1354 15 5987 83 1875 TENS 2 8957 RCFT 2~49 6885 7800 0000 TENS 9 3686 SP 0 7935 RS00 69 6250 TENS 3 3977 RCFT 2379 7466 GR 7700 0000 TENS 4:1553 8P 5 800i NHOB 121~5000 TE~$ 3,011~ RCF~ 2073,0566 GR 7600 0000 TENS 2 2290 SP 8 5201 RHOB 122 5625 3 3799 RCFT 1848 8220 7500,0000 2,5550 571.1720 10.8125 7412 0000 SFLU -45 0313 GR 2 4425 DRHO 7412 0000 NPHI 617 9036 RCNT 93 9375 7440 0000 SFbU -47 0938 GR 2 5065 DRHO 7440 0000 NPHI 776 i425 RCNT 89 1250 7240 0000 $FbU -52 5625 GR 2 3855 DRHO 7240 0000 NPMI 507 2700 RCNT 102 7500 7048 0000 SFLU -54 5938 GR 2 3926 DRMO 7048 0000 ~PHI 723 9338 RCNT 83 1875 7080 0000 8FLU -66 0625 GR 2 6369 DRHO 7080 0000 NPHI 819 2274 RCNT 69 6250 6932 0000 SFLU -65 5625 GR 2 5543 DRHO 6932 0000 NPHI 745 0718 RCNT 121 5000 6964 O000 5FL[J -59 5000 GR 2 5094 ORHO 6964 0000 NPHI 474 0828 ~CNT ~22 5625 6740 0000 SFbU -68:0625 GR lU6'7,2856 CFTC 3,3825 iLD 93,9375 TENS 0,0269 CALI .34,7678 TNRA 2051,8643 CFTC 4 4400 iLD 89 1250 TENS 0 002O CALl 32 5782 TNRA 2133 2'120 CFTC 2,6671 102,7500 TENS 0,0217 CA. bi 40,4449 TNRA 1772,1235 CFTC 9,6747 l[,O 83,1875 TENS '0,0116 CALl 32,3224 TNRA 2129,3804 CFTC 9,3054 ILD 69,6250 TENS '0,0138 CALl 31 6366 TNRA 2364:9731 cFTc 4 0469 lbD 121~5000 TENS 0.0552 C~bl 29,8600 TNRA 1986,4629 CFTC 2,0317 122,5625 TENS '0,0155 CAb! 40,9428 TN~A 1781,7468 CFTC 2.8011 ibD 130.7500 TENS 2 9683 741,2 0000 9 03i3 3 0826 669 83il 4,1685 7440,0000 8 8125 2:9372 801'7751 2 6601 7240:0000 8,8203 ~,3756 538,8082 _. 7,9539 7048,0000 8,7734 2,9168 810,1846 8 5359 7080 0000 9 1562 2 9020 828 9231 4 0015 6932~0000 9,8906 2,8440 793,1321 2,1850 6964 0000 9:0781 J,4238 519.9135 2,5744 6740,0000 LVP OlO,H02 VERIFICATION LISTING PAGE 6 DPHI GR RTNR CNTC 20,13o6 R~OM 2 130,7500 TENS 6740 3,7692 RCf'T 405 1697.4324 GR DEPT 7400 0000 TENS 7008 IbM 2' ,1682 EP DPH! -999.2500 RHOS -999 GR -999,2500 TENS -999 RTNR -999.2500 RCFT -999 CNTC -999.2500 GR -999 DEPT 7300,0000 TENS 6912 ILK .999,0370 SP -47 DPMI · ,2500 RHOB -999 GR '999,2500 TENS '999 RTNR '999,2500 RCFT -999 CNTC -999,2500 GR -999 DEPT DPHI GR RTNR CNTC GR RTNR CNTC IbM DpHI GR RTNR CNTC DEPT DPHI GR RTNR CNTC DEPT DPHI GR RTNR CNTC 7200 -999 -999 -999 -999 0000 TEN6 6792 0074 SP -44 2500 RHO~ -999 2500 TENS -999 2500 RCFT -999 2500 OR -999 7100 I -999 -999 -999 -999 0000 TEN~ 6~48 99~8 ~e 34 2500 RHOB -999 2500 TENS -999 2500 RCFT -999 2500 GR -999 700O 2 -999 -999 -999 -999 o000 TENS 6668 4408 aP -41 2500 RHOB -999 2500 TENS -999 2500 RCFT -999 2500 GR -999 6900 2 -999 -999 -999 -999 0000 TENS 6252 6573 SP -48 2500 RHOB -999 2500 TENS -999 ~500 RCFT -999 2500 GR -999 6800 2 -999 -999 -999 -999 0000 TENS 6300 3772 SE -50 2500 RHOB -999 2500 TEN8 -999 2500 RCFT -999 2500 GR -999 .3! 7~ ,0000 .4323 ,7500 0000 1875 2500 2500 2500 2500 0000 0313 2500 2500 2500 2500 0000 5000 2500 2500 2500 2500 0000 ,0313 ,2500 ,2500 .2500 ,2500 0000 5000 2500 2500 2500 2500 0000 5000 2500 2500 2500 2500 0000 0000 2500 2500 2500 2500 ORHO ~PHI RCNT GR DRHO NPH,I RCNT SFhU GR DRH© NPHI RCNT SFLU GR DRHO RCNT GR DRHO NPHI RCNT SFbU GR DRHO NPHI RCNT GR DRHO RCNT SFLU GR DRHO NPH! RCNT 0.0113 47.3423 1641.4529 2.5386 222.5000 -999.2500 -999,2500 -999,2500 3 3884 133 0000 -999 2500 -999 2500 -999 2500 3.9647 186.7500 -999,2500 -999.2500 -999,2500 1.8587 !08,1875 -999.2500 -999.2500 -999.2500 2.1063 104,1250 '999,2500 -999.2500 -999.2500 2.5386 111.6875 -999.2500 -999,2500 -999.2500 2.3037 10 4375 - 9 : soo '999,2500 '999,2500 CAbI TNRA CFTC TEN8 CAbI TNRA CFTC ILO CAbI TNRA CFTC I bD TENS CAbI TNRA CFTC lbo TENS CALl TNRA CFTC ILO TENS CALl TNRA CFTC TENS CALl TNRA CFTC TENS CALX TNRA CFTC 484 449,6833 2 0294 -999 2500 -999 2500 -999 2500 -999 2500 2,9270 -999,2500 -99~,2500 -999,2500 -999,2500 2 8178 -999 2500 -999 2500 -999 2500 -999 2500 1 8426 -999 2500 -999 2500 -999 2500 '999 2500 2 3822 -999 2500 -999 2500 -99~ 2500 -999 2500 2 5721 -999 2500 -999 2500 -999 2500 -999 2500 2,2889 -99~.2500 -999,2500 -999 2500 -999:2500 bVP 010,H02 YERIFICATiON I~ISTING PAGE 7 DEPT OPH! RTNR CNTC 6700 0000 TENS 2 7153 SP -999 2500 RHOO -999 2500 TENS -999 2500 RCFT -999 2500 GR 6192 0000 -49 53!3 GR -999 2500 -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DPHI GR CNTC 6600 0000 TENS 3 3436 -999 2500 RHOB =999 2500 -999 2500 RCFT -999 2500 GR 5952 0000 8FhU -53 5625 GR "999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2:500 DEPT DPM! GR RTNR CNTC 6500 0000 TENS 2 9759 SP -999 2500 HHOB '999 2500 TENS -999 2500 RCf'T -999 2500 GR 5880 0000 SFbU -56 5000 GR -999 2500 DRHO -999 2500 NPMI -999 2500 RCNT -999 2500 DEPT DPHI GR RTNR CNTC 6400 OOOO TENS 3 1544 SP -999 2500 RMOB -999 2500 TENS -999 2500 RCFT -999 2500 GR 5832 0000 8FbU -62 5333 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DpHI GR RTNR CNTC 6300,0000 TENS 2,3281 SP -999,2500 RHOB -999,2500 TENS -999.2500 RCFT -999,2500 GR 5720 0000 SFbU -62 0000 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DpHI GR RTNR CNTC 6200,0000 TENS 2,8260 -999.2500 RHOB -999,2500 TENS -999,2500 RCFT -999,2500 GR 5644 0000 SFGU -62 0000 GR -999 2500 DRHO -999 2500 NPNI -999 2500 RCNT -999 2500 DEPT DPHI GR RTNR CNTC i 100,0000 TENS 3,1079 8P 999,2500 RHOB 999,2500 TENS 999,2500 RCFT 999,2500 GR 5504 0000 SFLU -68 0000 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DpH! GR RTNR 6000 0000 TE~$ 2 9742 SP -999 2500 R~iOb -999 2500 TEb~S -999 2500 RCFT 7 1 0625 GR -'999 2500 DRHO -999 2500 NPHI -999 2500 ~CNT 2 7103 ILO 96 6250 TENS -999 2500 CALI -999 2500 TNRA -999 2500 CFTC 128,2500 TENS -999' 2500 CA[~I -999,,2,500 TNRA -999,2500 CFTC 2,7090 ! 93~'1250 TENS "9 ,2500 CAhI -999 22500 -99 : 5oo C 'TC 3,2294 ihO 126,8125 TENS '999,2500 CAhI "999,2500 TNRA "999,2500 CFTC 2,2114 ILD -9 ,2500 C~hI ,,,999,2500 TNRA '999,2500 CF~[C 2,6513 113,1250 TE~S '999,2500 CA~I '999,2500 TNRA '999,2500 CFTC 3,2401 ILD 110,7500 TENS -999,2500 CAbI -999,2500 TNRA -999,2500 CFTC 2,7851 104,~875 TENS '999,2500 CALl '999,2500 TN~A '999,2500 CFIC 2 -999 2500 -999 2500 -999 2500 -999 2500 3 2152 · ,999 25O0 · ,999 2500 -999 2500 ,,999 2500 2 9198 -999 25OO -999 2500 -999 2500 -999 2500 ~ 0989 -999 2500 -999 2500 -999 2500 -999 2500 2 2654 -999 2500 -999 2500 -999 2500 -999 2500 2,7990 '999,2500 -999,2500 '999,2500 -999,2500 -999,2500 -999,2500 '999,2500 -999,2500 2 9223 '999 250O '999 2500 '999 2500 -999 2500 bVP OlO,H02 VERIFICATIO!~ !,ISTING PAGE 8 CNTC EPT [)PHI GR RTNR CNTC DEPT DPHI GR RTN~ CNTC DEPT IbM DPHI RTNR CNTC DEPT DpM! GR CNTC DEPT DPHI GR RTNR CNTC DEPT IbM DPHI GR RTNR CNTC DEPT IbM OPPI GR CNTC OEPT DPMI -999.2500 5900 2 '999 '999 '999 '999 0000 TENS 9954 250O RHOB 2500 2500 RCFT 2500 580 ,.99 -99 -99 -99 0 o0o0 2 7041 9 2500 9 2500 9 2500 9 2500 TENS RHOB TE~S ~CFT 57OO 2 -999 -999 -999 -999 000 555 250 250 250 250 TENS R~00 TENS RCFT G~ 56O -99 -99 -99 -99 0 000 2 998 9 250 9 250 9 250 9 250 TENS TENS GR 55OO 2 -999 -999 -999 -999 000 918 250 250 250 250 TENS SP RHOB TENS RCFT GB 5400 2 -999 -999 -999 -999 000 i'15b 250 ,250 .250 ,250 TE~S 8P TENS RCFT GR 530 -99 -99 -99 -99 0 0000 3 1773 9 2500 9 25O0 9 2500 9 2500 TEbS RHOB TE~$ RCFT GR 52O -99 0,0000 2,1448 9,2500 5P RHt)B -999 5360 -74 -999 -999 -999 -999 5!48 ~75 -999 -999 -999 -999 4968, :999, ~999, 999~ -999, 4944. -999 -999, -999. -999, 4900 -999 -999 -999 -999 4868 -27 -999 -999 -999 -999 4568 -30 -999 -999 -999 -999 4500, '28, -999. ,25OO 000o 5000 2500 2500 2500 2500 000o 7500 2500 25OO 2500 2500 0000 250O 2500 250O 2500 2500 0000 7500 2500 2500 250O 2500 0o00 2344 250O 2500 2500 2500 0000 8594 2500 2500 2500 25O0 0000 7031 2500 2500 2500 2500 0000 6406 250(:) GR NPHi RCNT SFLU DRMO NPHi RCNT GR DRHO NPHI RCNT SFbU GR DRHO NPH! RCNT SFLU GR DRHO NPHI RCNT SFLU GR DRHO NPH! RCNT SFLU OR DRHO NPHI RCNT 5FLU GR 2,8968 101 , 0625 '999.2500 '999.2500 '999,2500 2.6346 113,2500 '999,2500 '999.2500 '999,2500 2,4752 97,1250 -999.2500 '999,2500 '999,2500 3,0039 11~,3125 -999.2500 -999,2500 -999,2500 92.8628 3750 -999.2500 -999'2500 2.7395 104.5875 -999,2500 -999.2500 -999.2500 3,2134 107,0625 -999.2500 -999'2500 -999,2500 2.1744 81,6250 -999.2500 TENS CALl CFTC TENS CAbI TNRA CFTC TENS TNRA CFTC TENS CAbI TNRA CFTC TENS CAbI TNRA CFTC TENS CAbI TNRA CFTC TENS CALl TNRA CFTC lhD TENS CALl 2 9526 -999 2500 -999 2500 -999 2500 -999 2500 2 6686 -999 2500 -999 2500 -999 2500 -999 2500 2,4981 -999,2500 -999,2500 '999,2500 '999,2500 2,9758 '999,2500 '999,2500 -999.2500 '999,2500 2 9169 '999 2500 -999 2500 '999 2500 '999 2500 2 702~ -99~ 2500 -999 2500 -999 2500 -99~ 2500 3 1538 -999:2500 -999,2500 '999,2500 '999,2500 2,1450 999,~500 Z99~3,2500 bVP OlO,H02 VERIFICATION LISTING PAGE 9 GR 999.2500 TENS -999.2500 NPMI RTNR ~999.2500 RCFT -999.2500 ~CNT CNTC -999.2500 GR -999.2500 DEPT GR RTNR CNTC 5100 0000 TEaS 3 3173 SP -999 2500 RI{OB -999 2500 TENS -999 2500 RCFT '999 2500 GR 4440 000o 6FLU -33:2500 GR -999,2500 DRHO -999.2500 ~PHi -999,2500 RCNT -999.2500 DEPT DPHI GR RTNR CNTC 5000 0000 TENS 3 0361 SP -999 2500 -999 2500 TENS -999 2500 RCFT '999 2500 4220 0000 8FLU -37 7500 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DPMI RTNR CNTC 4900,0000 TENS 2.5267 SP -999.2500 RMOB -999,2500 TENS -999.2500 RCFT '999,2500 GR 4292 O000 6FLU '45 3750 GR '999 2500 D~HO '999 2500 NPHI '999 2500 RCNT '999 2500 DEPT OPM! RTNR C~TC 4800.0000 TENS 3.2801 SP -999.2500 RHOB -999,2500 TENS -999,2500 NCFT -999.2500 GR 4184 O000 8FLU -45 1875 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DPHI GR RTNR CNTC 4700,0000 TENS 2.8576 SP -999.2500 RHOB -999,2500 TENS -999,2500 RCFT -999.2500 GR 3994 0000 MFbU '44 6875 GR -999 2500 ORHO -999 2500 NPH! -999 2500 RCNT -999 2500 DEPT DPH! GR RT~R CNTC 4600.0000 TENS 3.4665 SP -999,2500 RDO8 -999.2500 TENS -999 2500 RCFT -999:2500 G~ 4268 0000 SFLU -50 9062 GR -999 2500 DRHO -999 2500 NPHI -999 2500 RCNT -999 2500 DEPT DPMI GR RTNR CNTC 4596 5000 TENS -999 2500 RHOD -999 2500 TENS -999.2500 RCF9 '999,250{; GN 3~74i0000 Sf'LU 47 8750 GR -999 2500 DRHO -999'2500 ~Ph! -999.2500 RCNI -999.2500 '999.2500 TN~A -999.2500 CFTC ].049] ibD 97,0000 TENS '999,2500 CALI '999.2500 TNRA "999.2500 CFTC 2.8726 AND 86.9375 TENS '999,2500 CAbI '999,22500 TNRA -999. 500 CFTC 2,3738 98,7500 TENS -999,2500 CALl -999,2500 '999,2500 CFTC 2.9809 90.7500 TENS -999,2500 CALI -999,2500 TNRA -999"2500 CFTC 2 6622 ILD 86 7500 TENS -999 2500 CAb! -999 2500 TNRA -999 2500 CFTC 4,1740 ILO 85.9]75 TENS -999.2500 CA I -999.2500 TNRA -999.2500 CFTC 2.8160 ILO 83.5625 TENS -999.2500 CAbI -999,2500 TNRA -999.2500 CFTC -999.2500 3 3881 -999 2500 -999 2500 -99~ 2500 -999 250O 3 0548 -999 2500 -999 25O0 -999 2500 -99T/ 2500 2 5845 -999 2500 -999 2500 -999 2500 -999 2500 3 4205 '999:2500 -999,2500 -999.2500 '999,2500 2,9410 '999,2500 -999,2500 -999,2500 -999,2500 3.4391 -999,2500 -999.2500 -999.2500 -999.~500 3 1406 -999 2500 -999 2500 -99N 2500 -999 2500 ~VP O!O,M02 VERIFICATION LISTING PAGE 10 ** FILE TRAILER FiLE NAME IE[)IT ,001 SERVICE NAME VERSION ~ DATE : PAXI~UM LENGTH ~ !024 FILE TYPE ~EXT FILE NA~E EOF ** FILE HEADER ** FiLE NA~E JEDIT ,002 8ERVIC~ NAME ~ DA?~ ~ MAXIMU~ LENGTH : 1024 PRevzous ei£~; : ** CO,ME,TS ** ******************************************************************************* ***** THIS DATA HAS NO~ BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ******************************************************************************* * SCHLUMBERGER LOGS I.,'~CLUDED ~lTR THIS FiLE (EDIT 02 * (SEE FILE EDIT,001 FOR 6" SAMPLED DIL/FDC/CNL/GR AT * FORMATION [)ENMITY COMPENSATED LOG C,FDH) LVP 010,H02 VERIFICATION LISTING PAGE 11 FIRST TO LAST READING: 831!' TO 7549' CO~PENSATED b]~UTRi,)N LOG F:I~.ST TO :hAST READI ~ " 8296' TO 75i9' ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE REPR COOE ENTRY 2 1 66 0 4 I 6b 1 9 4 65 ,lin 16 1 66 0 ! 66 0 DATUM SPECIFICATION MLDC~.S MNE~ SERVICE SERVICE UNiT .AP1 AP1 AP1 APl FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS ~OD DEPT f'T O0 000 O0 0 0 4 TENS FDH LB O0 635 21 0 0 4 DPHI FDM PU O0 890 O0 0 0 4 RHOB FDH G/C3 O0 350 02 0 0 4 DRHO FDH G/C3 O0 356 O1 0 0 4 CALl FDH IN O0 280 Ol 0 0 4 GR FD~ GAPI O0 310 O1 0 0 4 TENS CNH LB O0 635 21 0 0 4 ~PHI CNH PU O0 890 O0 0 0 4 ~'NRA CNH O0 420 O1 0 O 4 ~TNR CNH 00 000 O0 0 0 RCFT CNH CPS O0 000 O0 0 0 RCNT CNH CPS O0 000 O0 0 0 4 CFTC CaM CPS O0 O00 OO 0 0 4 CNTC CN[~ CPS O0 OOO O0 0 0 4 GR CNM GAPI O0 310 Ol 0 0 4 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 O000000OO00000 6~ O000000OO00000 68 00000000000000 68 OOO00000000000 68 O000000OO00000 68 00000000000000 68 O0000OO0000000 68 O00OO0000OO000 68 O000000000000O 68 O000000OO00000 68 OOO00000000000 68 O000000OO00OO0 68 O000000OO00000 DATA EPT 8365,0996 TEN6 4768,0000 DPHI RHO 0,0145 CALl 8,3750 GR NpM! 33,2554 TNRA 2,9461 ~TNR ~CNT 1849,9268 CFTC 658,2180 CNTC 15,8706 RHOB 149,~750 TENS 3,0339 RCFT 1905,4016 GR 4768,0000 502,4897 149,~750 DEPT 8300,2988 TENS 7440,0000 OPHI 11,3194 RHOB 2,4632 LVP 010,H02 VERIFICATION LISTING PAGE 12 DRHO 0.0204 CAbi NPHi 35.0671 T~{RA RCNT !920,0474 CFTC DEPT 8200 2988 T~ES DEHO 0 022! CALl NpH! 35 9679 T~HA RCNT 2071 8'721 CFTC D"EPT 8100 2998 TENS DRHO -0,0045 CALI NPHi 34,3260 TN~A RCNT 2257,2041 CFtC DEPT 8000,2998 TENS DRHO 0,0078 CALI NPBI 41,3633 TNRA ECNT 1898,2998 Cf'lC DEPT 7900 2998 TENS DRHO O' · ,0251 CALI NPHI 32,4606 TNEA ECNT 2254,9580 CFTC DEPT 7800 2998 TENS DRHO -0,10~4 CALl NPHI 29,6768 TN~A R~NT 2313,12]0 CFTC DEPT 7700,2998 TENS DRHO 0,0329 CALl NPHI 29'3979 TNRA RCNT 2128,5137 CFTC DEPT 7600 2998 TENS DRHO -0:0078 CALl NPHI 43,1775 TNEA RCNT 1752,6758 CFTC DEPT 75~9 3994 TENS DRHO 0:0020 CALl ~PHI -999,2500 TNR~ RCNT -999,2500 CFTC 9,2344 GE 643,9769 CNTC 7324,0000 DPHI 9.0234 GR 3.I475 RTNR 691,1814 CNTC 7480,0000 DPMI 8.7266 GR 3,0335 RTNE 781,9574 CNTC 7148,0000 DPHI 8,8906 GR 3.4310 ~T~ 552,6641 CN · 6784,0000 DPHI 8.67~9 GR 2,9~75 ~TNR 8~,6748 CNTC 7088.0000 [)PHI 9,0078 GR 2,7595 RTNR 903,~062 CNIC 6792,0000 DPHI 9,8906 GR 2.8132 RTNR 771,2169 CNTC 6584,0000 [)PHI 8,9922 GR 3,5386 RTNR 547,~853 CNTC 6552 0000 DPHI 912187 GR -999 2500 RTNR -999 2500 'C~TC ** FILE TRAIbER FILE NA~E :EDIT ,002 SERVICE NAHE : DATE : MAXIMU~ LENGTH : 1024 FILE TYPE NEXT F~LE NA~E : 143.8750 TENS 3,4444 1984.0830 OR 11.4584 RaOB 90,0625 TENS 3.2581 RCFT 2138,6i62 OR 8 7596 51 RCFT 2]26 5493 GR 15,4452 104,1250 TENS 1876,7615 GR 14~356~ ~OB 8~,~750 .91~3 ~CFT 2344.5688 GR 2.9309 72,1875 T£NS 245~,7907 RCFT .6318 GR 7,3316 ~HOB 123,5625 TENS 2,7059 RCFT 2165,1152 GE ~1,6806 RHOB 121.5625 TENS 3,46~5 RCFT ~889,3020 GR '999,2500 RHOB 127,8X25 TENS -999,2500 RCFT -999,2500 GR 7~.}0,0000 1,5502 143,8750 2,4609 7324,0000 549,9559 90,0625 2,5055 7480,0000 738,~895 84,1875 2,3952 7~48,0000 52b,17bl 104,1250 2,4131 6784,0000 720,9279 85,3750 2,b0!6 708~,0000 84~,8732 7~,~875 2,5290 679Z,0000 b38,8949 12~,5625 2,4573 6584,0000 583.9220 121,5625 2 3592 -999:2500 '999,2500 '999,2500 L'VP OlO,J,i.)2 V~:RIFICATiO'N bIS:lING PAGE 13 ** TAPE TRAILER SERVICE NAME :EDIT DATE :8B/05/ 6 URIGiN :F$1A IAPE NAME CONTINUATION NEXT TAPE NAME : COMMENTS :LIS TAPE, A~CO ALA6KA, INC. 3 0-16A, API 50-029-21796-0! ** REEL TRAILER D~TE 188/05/ 6 RE~L NAME :72716 CONTINOATION # NEXT REEL NAME : COMMENTS :his TAPE, ARCO ALASKA, INC, 3 (J-16~, API 50-029-21796-01 EOF ********** EOF
