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215-125
ID • RECEIVED STATE OF ALASKA APR 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN[ ;C 1 a.Well Status: Oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑✓ . Suspended❑ 1 b.Well Class: 20PAC 25.105 2O AC 25.110 Development 0 ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,o�or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/5/2016 215-125/316-029 . 3.Address: 7. Date Spudded: .Z`}1 15.API Number: P.O. Box 100360 Anchorage,AK 99510 8/19/2015 50-029-21008-01 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 327'FSL, 806'FWL, Sec. 29,T12N, R10E, UM 8/25/2015 KRU 1G-11A• Top of Productive Interval: 9. Ref Elevations: KB: 99' 17. Field/Pool(s): 1562' FNL, 1250'FEL, Sec. 32,T12N, R10E, UM GL 63' BF: Kuparuk River Field/Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1911' FSL,2231'FWL, Sec. 32,T12N, R10E, UM 7650'MD/6447'TVD ADL 25640 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 540585 y- 5980976 Zone- 4 10553'MD/6455'TVD 2571 TPI: x- 543826 y- 5979105 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 542043 y- 5977288 Zone- 4 N/A 1652'MD/1624'TVD 5. Directional or Inclination Survey: Yes (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 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 SCOINE10 1UN r Q 2016 none 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 38' 106' 38' 106' 24" 212 sx CS II 10.75" 45.5 J-55 37' 2351' 37' 2206' 13.5" 930 sx ASIII,250 sx ASI 7" 26 J-55 37' 8188' 37' 6901' 8.5" 610 sx Class G,250 sx ASI 2.375" 4.7 L-80 7625' 10030' 6426' 6481' 3" slotted liner 24. Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3-1/2" 7366' 7258'MD/6124'TVD all perfs squeezed off and a CIBP was set at 7650'MD/6447'TVD 7402'MD/6241'TVD and 7813'MD/6583'TVD A NO o>JFD 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. CQMf'LE-to_, Was hydraulic fracturing used during completion? Yes❑ No E DATE Per 20 AAC 25.283(i)(2)attach electronic and printed information 2 iIliI(P DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift,etc.): 9/17/2015 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period --0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 24-Hour Rate -S. Form 10-407 Revised 11/2015 VTC 6` .//c CONT?UEpiQN PAGE 2 RBDMS f.U- APR 1 4 2016 Submit ORIGINIAL onl • 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: ❑ No ❑✓ 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 1652' 1624' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Kuparuk Cl Upper Tf'% 't• 7670' 6464' Top Kuparuk B5 7743' 6507' None Top Kuparuk B5/Base Cl 8592' 6500' Top Kuparuk B5 10457' 6451' Formation at Total Depth: Kuparuk B5 31. List of Attachments: O?maic nob So-to.:144AT/4 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: Cody Pohler @ 265-6 5 Email: Cody.j.pohler(C�Cop.Com OJp Printed Name: Eller Title: CTD Engineering Supervisor Signature: w, Phone: 263-4172 Date: ZVI Mo INSTRUCTIONS General: This form and he equired 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, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection, Shut-in, or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 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 11/2015 Submit ORIGINAL Only • • OE Well Service Summary -410 44,0 441 1G-11 ConocoPehillips A kn Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 3.50 START TICKET OFFLOAD DSL TRAVEL TO CPF-3 TO LOAD SW TRAVEL TO 1G TO LOAD MEOH PJSM Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 0.50 SPOT IN UNIT PJSM RIG UP TO WELL PT TO 3000psi Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 0.50 STANDBY FOR DSO TO ARRIVE TO SHUT IN WELL Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 1.50 {ST DOWN TBG W/SW} BPM BBLS TBG IA OA 1 ST 500 1000 750 1 20 " 1 40 " 1 60 " {SWAP TO DSL} BPM BBLS TBG IA OA 1 ST 450 1000 750 1 10 " 1 20 " {SHUT DOWN} Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 0.50 {ST DOWN FL W/MEOH} BPM BBLS TBG IA OA 1 ST 400 1000 740 1 10 " 1 20 200 980 " {SHUT DOWN} Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 0.50 RIG DOWN PJSM TURN WELL OVER TO DSL Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 05:30 1/24/2016 13:00 0.50 FINISH PAPERWORK TRAVEL TO 2L TO LOAD DSL END TICKET Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 0.50 MEET W/CWG REP @ KOC,P/U WELL FILE AND CPU,TRVL TO 1G Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 3.25 ARRIVE @ 1G.LRS ON WELL,LRS PUMP 60 BBLS DIESEL AND 20 BBLS SEAWATER DOWN TBG,LRS FREEZE PROTECT FLOW LINE W/20 BBLS DIESEL,PJSM,REPACK&REHEAD. LRS COMPLETE FREEZE PROTECT. Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 2.25 SPOT IN EQUIP ON 1G-11,STACK AND LAY DOWN PCE,MAKE UP TOOLS,P/U PCE, REMOVE TREE CAP,INSTALL FUSIBLE&NOTIFY DSO,STAB ON,PT W/GAS. TS(1 7/8")=DIH, 13'STEM,OJS,KJLSS Page 1/4 Report Printed: 4/14/2016 • a Well Service Summary • 1G-11 AI corocda hillips AE#� Time Log Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 1.75 RIH W/3 1/2"GR,SD IN 3 1/2"KB PACKER @ 7585'SLM(7621'RKB),TAP DOWN TO LATCH, JAR UP FOR 30 MIN,GR SHEARS,POOH. Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 1.75 RIH W/ADD'L 5'STEM,3 1/2"GS,SD IN 3 1/2"KB PACKER @ 7585'SLM(7621'RKB),TAP DOWN TO LATCH,PULL PACKER IN 2 OJ LICKS,PUH,GET STUCK @ 7302'SLM,JAR UP 10 TIMES AND COME FREE,GET STUCK @ 7256'SLM,JAR UP 10 TIMES AND COME FREE, POOH. OOH W/3 1/2"KB PACKER;RECOVERED ALL ELEMENTS,SMALL CHUNK MISSING FROM CENTER ELEMENT,SWAP TOOLS. TS=DIH, 10'TUNGSTEN,BMC, DCC,DPG,DCR,S/L XO, 1 1/4"OJS, 1 1/4"KJLSS, 1.75"CENT. Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 1.00 RIH W/1.75"DRIFT.TIE IN W/GLM @ 7171.4'RKB,CONT RIH TAG TOP OF CROSSOVER PUP @ 7739'RKB,POOH. Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 0.75 UNSTAB, INSTALL&PT TREE CAP,REMOVE FUSIBLE&NOTIFY DSO.LDFN. Report Start Date Report End Date Dur(hr) Operation Details 1/24/2016 09:00 1/24/2016 21:00 0.75 TRVL TO KOC,SYNC COMPUTER,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 0.75 MEET W/CWG REP @ KOC,P/U CPU,TRVL TO 1G. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 1.50 ARRIVE @ 1G-11,PJSM,MAKE UP TOOLS,P/U PCE, REMOVE TREE CAP,INSTALL FUSIBLE &NOTIFY DSO. TS=DIH, 10'TUNGSTEN,BMC, DCC,DPC,DCR, D-TRIGII, FIRING HEAD, 11'STRINGSHOT Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 2.50 RIH W/11'STRINGSHOT,TIE IN W/GLM @ 7171'RKB.CCL STOP DEPTH 7641.5'RKB,CCL TO TOP OF STRINGSHOT=13.5',SHOT INTERVAL FROM 7655'-7666'RKB.GOOD INDICATION OF FIRE,POOH. OOH,SWAP TOOLS TS=DIH, 10'TUNGSTEN,BMC,DCC,DPG,DCR,D-TRIGII, FIRING HEAD, 1 11/16"CHC Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 3.00 RIH W/CHEM CUTTER,TIE IN W/GLM @ 7171'RKB,CCL STOP DEPTH 7635'RKB,CCL TO SEVERING HEAD=27',CUT DEPTH 7662'RKB.GOOD INDICATION OF FIRE,POOH. OOH,SWAP TO 1 7/8"S/L TOOLS. TS=DIH, 18'STEM,OJS,KJLSS Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 1.75 RIH W/3 1/2"GS.SD IN 2 3/8"LINER TOP,TAP DOWN TO LATCH,PICK UP AND SEE 200# WIEGHT INCREASE,POOH. OOH W/2 3/8"LINER(37'10"OAL) Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 1.50 UNSTAB, INSTALL&PT TREE CAP,REMOVE FUSIBLE&NOTIFY DSO.LAY DOWN PCE, REMOVE LINER AND TOOLS,RIG DOWN DSL. Report Start Date Report End Date Dur(hr) Operation Details 1/25/2016 05:30 1/25/2016 17:30 1.00 TRAVL TO 1A,SPOT IN EQUIPMENT ON 1A-12,TRVL TO KOC,SYNC COMPUTER,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 00:00 2/3/2016 02:00 0.50 START TICKET TRAVEL TO 1G-PAD AND LOAD MEOH SPOT UNIT Page 2/4 Report Printed: 4/14/2016 Well Service Summary 1G-11 ConocoPhilips A Time Log Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 00:00 2/3/2016 02:00 0.25 PJSM RIG UP TO TBG PT LINES TO 2500 PSI/GOOD PT Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 00:00 2/3/2016 02:00 0.75 DIESEL BBL BPM TBG IA OA SP 1.5 700 S/N 460 20 DOP 0 S/N 460 F/P FLOW LINE 20 BBL MEOH Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 00:00 2/3/2016 02:00 0.25 RIG OFF WELL TURN OVER TO DSO PJSM Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 00:00 2/3/2016 02:00 0.25 FINISH PAPER WORK LEAVE LOCATION END TICKET Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 1.75 CHECK w CWG REP,PU CPU/FILES,TRAVEL TO KIC FOR UNIT,TRAVEL TOY PAD FOR TOOLS,CONTACT DSO, INSPECT AREA,JSSM. Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 1.75 BEGIN RU.108"WIRE&1.875"TS=RS,QC,5',QC,KJ,5',QC,KJ,LSS,QC. RU LRS TROUBLESHOOT LEAKY 0-RING Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 1.25 LRS ONLINE WHILE RIH w/3"GS&2.81"CAT SV LRS 65 BBLS AWAY,SET SV @ 7280'SLM (7311'RKB)PRESSURE UP TBG.TO 1800 PSI,POOH Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 0.75 RIH w/KJ,3"OM-1,7"EXT.&1.625"JD TO STA#1 @ 2697'SLM(2726'RKB)LOCATE,LATCH GLV,POOH w/GLV Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 1.00 RIH w/KJ,3"OM-1 &DV ON RK LATCH TO STA#1 @ 2697'SLM(2726'RKB)LOCATE,SET DV,PRESSURE UP TBG.f/200-1500 PSI,SHEAR OFF,NO CHANGE,POOH. Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 1.00 RIH w/KJ,3"OM-1,7"EXT,&1.625"JD TO STA#2 @4116'SLM(4148'RKB)LOCATE,LATCH OV,POOH w/OV. Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 3.75 LRS RIG UP FOR CIRC OUT,BEGIN CIRCULATING 75 BBLS CRW SEAWATER AND 75 BBLS DIESEL,U TUBE FREEZE FOR FREEZE PROTECT Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 0.25 FINISH RD,REMOVE FUSIBLE,CONTACT DSO, Report Start Date Report End Date Dur(hr) Operation Details 2/3/2016 06:00 2/3/2016 18:00 0.50 TRAVEL TO OFFICE,DOWNLOAD CPU,TURN IN PAPERWORK/FILES,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.00 CHECK w/CWG REP,PU CPU/FILES,TRAVEL TO LOCATION,CONTACT DSO,INSPECT AREA,GET WIND READING 25-30 MPH,JSSM. Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.00 BEGIN RU.108"WIRE&1.875"TS=RS,QC,5',QC,KJ,S',QC,OJ,QC,KJ,LSS,QC. Page 3/4 Report Printed: 4/14/2016 Well Service Summary 1G-11 ConocoPhiffips Time Log Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.00 RIH w/KJ,3"OM-1 &DV ON RK LATCH TO STA#2 @ 4116'SLM(4148'RKB)LOCATE,SET DV,PRESSURE UP TBG.TO 2500 PSI, IA @ 1200,SHEAR OFF,POOH Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.00 RU LRS TO IA AND BEGIN MIT-IA TO 2500 PSI. PRE=1200/1200/323 INITIAL=1350/2500/323 15 MIN=1350/2475/320 30 MIN=1350/2475/320 "'PA5S*** Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.50 RIH w/3"GR,LATCH CAT SV @ 7280'SLM(7311'RKB)TBG.FALLS FROM 1200-50 PSI, POOH w/SV. WIND SPEEDS 35-40 MPH Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 0.75 BEGIN LD,SECURE WELLHEAD,REMOVE FUSIBLE Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 4.75 MONITOR WIND Report Start Date Report End Date Dur(hr) Operation Details 2/4/2016 06:00 2/4/2016 18:00 1.00 TRAVEL TO OFFICE,DOWNLOAD CPU,TURN IN PAPERWORK/FILES,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 5.00 PHASE 2 CONDITIONS,WAIT ON PHASE CONDITIONS TO BE LIFTED Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 0.75 PU CPU/FILES,TRAVEL TO LOCATION,CONTACT DSO, INSPECT AREA,JSSM Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 1.25 SHOVEL AREA, BEGIN RU .108"WIRE&1.875"TS=RS,QC,5',QC,KJ,5',QC,OJ,QC,KJ,LSS,QC. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 1.25 RIH w/2.78"WRP DRIFT,DRIFT FREELY TO 7647'SLM(7677'RKB)POOH. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 1.00 BEGIN RD,REMOVE FUSIBLE,SECURE WELLHEAD,PJSM,CONTACT DSO. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 1.00 TRAVEL TOY PAD FOR TOOLS,TRAVEL TO 3H-20 AND SPOT UP EQUIPTMENT FOR NIGHT. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 0.75 TRAVEL TO OFFICE Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 06:00 2/5/2016 18:00 1.00 DOWNLOAD CPU,TURN IN PAPERWORK/FILES,END TICKET. Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 16:00 2/5/2016 23:00 1.50 ARRIVE ON LOCATION,UNLOAD PCE BASKET,LAYOUT LINES,PREP TOOLSTRING, STATEWIDE ARRIVES,LRS ARRIVES,PJSM,STRAY VOLTAGE TEST Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 16:00 2/5/2016 23:00 1.25 PU LUBE,MU PCE/TOOLSTRING,CHECK FIRE,ARM SETTING TOOL,STAB ONTO WELLHEAD,RIG UP LRS,PT TO 3000 PSI,OPEN SWAB Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 16:00 2/5/2016 23:00 2.25 RIH W/CH,SWIV,WB7,ROLL,WB5,GPST,DBM,FH, 1-11/16 LSST,2.63"TTS CIBP, OAL:31'x2.63",CORRELATED TO HES RCBL LOG DATED 22 JUN 2015,SET CIBP AT 7650', CCL TO MID ELEMENT 13.7',CCL STOP DEPTH 7636.3',POOH Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 16:00 2/5/2016 23:00 1.50 BUMP UP,BLEED PRESSURE,BLOW DOWN LINES,RIG DOWN PCE/TOOLSTRING, LAYDOWN LUBE,LRS STARTING TO RIG UP FOR MITT, LOAD EQUIPMENT,INSPECT LOCATION Report Start Date Report End Date Dur(hr) Operation Details 2/5/2016 16:00 2/5/2016 23:00 0.50 CONVOY BACK TO SHOP,SYNC LAPTOP Page 4/4 Report Printed: 4/14/2016 • KUPD 1G-11A CUn©cc P1"tillip5 Z ,, Well AttributW Max Angle D TD Alaska.Ii1G. �" wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) " Carocov i pa = 500292100801 KUPARUK RIVER UNIT PROD 97.55 8,754.89 10,523.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1G-11A,4/14/20163:12:33 PM SSSV:NONE 200 12/21/2015 Last WO: 3/15/2015 40.99 9/19/1983 Vertcal achemaoc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: SIDETRACK,ADD LATERAL B lehallf 2/26/2016 HANGER 31.2 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top not k uw Top(ftKB) (ftKB) C) Des Corn Run Date ID(In) I E' s [0.. 10,037.0 6,481.1 94.70 IBP IBP ran to isolate heavily water swept zone from 8/27/2015 production. I I1 Perforations&Slots 111 Shot Dens CONDUCTOR;38.0.106.0 Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 8,720.9 8,752.0 6,485.6 6,481.8 A-4,1G-11 8/27/2015 SLOTS Slotted Liner 8,777.2 10,029.6 6,478.7 6,481.7 A-4,1G-11 8/27/2015 SLOTS Slotted Liner SURFACE,37.1-2,351 3-. - Notes:General&Safety End Date Annotation _ . 2/25/2016 NOTE:1G-11A Abandoned-use 10-11B GAS LIFT;2,726.2 GAS LIFT;4,148.1 it GAS LIFT;5320.5 ( GAS LIFT;6,185.3 in it GAS LIFT',6,832.4 1.1 it GAS LIFT;7,171.4 NI it 4 LOCATOR;7,227.5 SEAL ASSY;7,228.5 �f PER,7,235.3 PACKER,7,258.3 ilk I NIPPLE,7,311.1 it kt ::I( it it OVERSHOT,7,359.8 ' l I SBR',7,376.2 1. I PACKER,7,402.3 I PRODUCTION;7,437.7 I PRODUCTION;7,504.8 IPERF;7,540.0-7,590.0 PRODUCTION;37.1-8,18771 B Liner w1SER 82 HES SweIlPackers(water swell); 7,326.6-10,385.0 TUBING PUNCH;7,614.0 CUT LINER;7562.0 I SLOTS;8,720.9-8,752 0 SLOTS,8,777.2-10,029.6 IBP,10,037.0-111 ill . 0 Driithlg Operations Summary(with Timelog Depths) >„I •:. &Wells 1G-11 conocophimps Rig: NABORS CDR2-AC . Job: DRILLING SIDETRACK 1700,-t#g*: ,,,.::- --.. - .................,,,-,::;•::::;:'.,:.-,:.,-:..P. ,::-.;-;::;:; :: :.:4:',•-:*,1.2.---:.-..-•:-::,:-,,,]:,-, ,,::-.--..,::::,,:--: ---;:!:, _• :.:_......:,::7!:;-,::::-•7! $0r1 tiiii0Zi-::: :::Endlime .: 0iir.(*)..:: -::,:n:Plotiki.-::,.]::'.:::T:f:::. 00010fik;:;:::;:::; ::*Aarvily A*:.: jybs p.T,x .,:::.::.:-.r..,::,::,- -!::::::,:::;:,:icoogiaw.ua::-:7-.,;:::::: ;1;ff.i.:;; z.,;.:01(t3y.,:, ,.',eeitt Dipth OM 2/9/2016 2/9/2016 3.50 MIRU MOVE MOB P 'PJSM with Peak and rig crew.Load 0.0' 0.0 03:00 06:30 shop.Pull Sub and Pits off of 3G-04, install jeeps,ready to move. 2/9/2016 21912016 5.00 MIRU MOVE MOB P Mobilize Sub and Pits and shop to 3G- 0.0 0.0 06:30 11:30 pad to 10-11. 2/9/2016 2/9/2016 2.50 MIRU MOVE MOB P Remove jeeps,prep well,remove tree 0.0 0.0 11:30 14:00 . caps,spot Sub and Pits over well. Send truck back to retrieve shop from pervious location. 2/9/2016 2/9/2016 5.00 MIRU MOVE RURD P RU interconnect,work on post rig 0.0 0.0 14:00 19:00 move checklist,communications. 2/9/2016 219/2016 1.75 MIRU WHDBOP NUND 'P Nipple up BOPE stack,change out 0.0 0.0 19:00 20:45 riser,and secure cellar,Check all tree bolts,none found loose,load stack. ****Note:Check Tree Bolts 0.5 hrs. ***•Rig Accept 19:00 hrs 2/9/2016 2/10/2016 3.25 MIRU WHDBOP BOPE P Begin initial BOPE test 250/3,000 0.0 0.0 20:45 00:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Chuck Scheve. 2/10/2016 2/10/2016 3.00 MIRU WHDBOP BOPE P Continue Initial BOPE test 250/3,000 0.0 0.0 00:00 03:00 psi,Annular 2,500 psi.Test witness waived by AOGCC rep.Chuck Sheve. 2/10/2016 2/10/2016 1.50 MIRU WHDBOP PRTS 3, Inspect and service Bowen nuts on 0.0 0.0 03:00 04:30 PDL's,Test TT line and blow down. 2/10/2016 2/10/2016 1.00 MIRU WHDBOP MPSP P PJSM with rig and vatve crew,RU _ 0.0 0.0 04:30 05:30 lubricator and BPV equipment,Pull TWCV.Off load BPV equipment. 2/10/2016 2/10/2016 4.00 MIRU 'WHDBOP PRTS P Pressure test lines and PDL. PT inner 0.0 0.0 05:30 09:30 reel iron. 2/10/2016 2/10/2016 1.50 PROD1 'RPEQPT PULD P PJSM.make up whipstock BHA#1 0.0 74.0 09:30 11:00 and pressure deploy. 2/10/2016 2/10/2016 3.00 PROD1 RPEQPT TRIP P RIH with whipstock BHA#1.Tie in to 74.0 7,624.8 11:00 14:00 the K1 for a-8 ft correction.Weight check at 7405ft=32klbs PUW.RIH to • • set depth. 2/10/2016 2/10/2016 025 PROD1 RPEOPT WPST P Close EDC.Bring pumps up to set 7,624.8 7,624.8 14:00 14:15 anchor.Whipstock set at 0°HS. TOWS at 7614'. 2/10/2016 '2/10/2016 1.75 PROM RPEQPT 'TRIP P POOH.Swap hole to seawater. 7,624.8 74.0 14:15 16:00 Continue pulling out of the hole. 2/10/2016 2/10/2016 0.50 PROD1 RPEQPT OWFF P 'Flow check. PJSM 74.0 74.0 16:00 16:30 2/10/2016 2/1012016 0.50 PROD1 RPEQPT PULD P LD BHA#1,Check pack offs. 74.0 0.0 16:30 17:00 2/10/2016 2/10/2016 0.85 PROD1 'WHPST PULD P PJSM-MU BHA#2 0.60 motor,string 0.0 74.3 17:00 17:51 mill and HCC DSM,MU to CoiTrak, surface test. 2/10/2016 2/10/2016 2.50 PROD1 WHPST TRIP P 'RIH with BHA#2,Tie in to K1 for 74.3 7,613.4 17:51 20:21 minus 8.5 ft correction.RIH.PUW at 7,552 ft is 35k.Dry tag TOWS at 7,613.6 ft.PU.RIW 11.7k 2/10/2016 2/11/2016 3.65 PROD1 WHPST WPST P Mill 3-1/2"window exit 1.67 born at 7,613.4 7,615.8 20:21 00:00 2,730 psi,BHP 3,212 psi,LA 834,OA 279 Page 118 Report Printed: 5/4/2016 1 S 411 Drill" Operations Summary (with Timelog Depths) :. &Wells 1G-11 Cono<ol'hdIsfits Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time ; sl6[rti:►i? .. • 7pna iiiiiit*l . .. Ph,...,.,.... . . ...Gil:' -.AVI t�code:.. tim+A-T4s .. •pith.n ftaa >. Eridt f l 2/11/2016 2/11/2016 3.95 PROD1 A - - wn.s 41 - 7,615.8 7,849.4 00:00 3:57 2,760 psi,BHP 3,197 psi,IA 605,OA 288.Drill off 3-1/2"at 7,619.1 ft. • Contact 7"at 7,619.4 ft. 2/11/2016 2(11/2016 0.20 PROD1 HPST REAM P Back ream 3-1(2'window 7,619.4 7,605.0 03:57 04:09 2/11/2016 2/11/2016 1.35 PROD1 INHPST 'TRIP 'P POOH for 7"window milling assembly. 7,605.0 74.3 04:09 05:30 2/11/2016 2/11/2016 0.70 PROD! WHPST OWFF P Monitor well for flow.crew change. 74.3 74.3 05:30 06:12 2/11/2016 2/11/2016 2.50 PROD1 WHPST PULD P PJSM-LD BHA#2,PU Weatherford 74.3 75.7 06:12 08:42 BHA#3,with 2°fixed bend motor and 2.80"no-go fat radius mill. Note:Primary mill was 2.79"no-go. Changed out and ran back up mil. SIMOPS:change out gripper blocks on Injector. 2/11/2018 2/11/2016 2.30 PROD1 WHPST TRIP P MU injector,Tag up and reset depth. 75.7 7,620.0 08:42 11:00 RIH with milling BHA#3.Tie in to Kl for a-8.5 ft correction.Continue In the hole.Weight check at 7418 ft.PUW= 36klbs.Dry tag 7"at 7620 ft. 2/11/2016 2/11/2016 6.2 PROD1 WHPST WPST P Begin milling 7'per program 150 7,620.0 7,625.6 11:00 17:15 ROHS.SOW=12.5klbs,purnping1.61 BPM at 2800 psi FS.Bottom of window called at 7622.6 ft. 2/11/2016 2/11/2016- 15') •'•ir. 1 r' DRLG P Continue milling rathole highside at 1 7,625.8 7,638.6 17:15 18:15 6 1 v fph,pumping 1.6 BPM at 2800psi FS. ` 200 lbs WOB,CTW 8.4kibs. 2/11/2016 2/11/20 11_94 k�P DWHPST REAM P Back ream dual string exit 45°R/L, 7,638.8 7,638.6 18:15 20:15F\ PUW 35k,dry drift clean,pump 5x5 sweep.Open EDC. 2/11/2016 2/11/2016 1.45 PROD1 WHPST TRIP P POOH for drilling assembly 7,638.6 75.7 20:15 21:42 ---__------ 2/11/2016 2/11/2016 0.50 PROD1 WHPST OWFF P Monitor well for flow.PJSM 75.7 75.7 21:42 22:12 2/11/2016 2/11/2016 0.65 PROD1 WHPST PULD P LD BHA#3,string mill and FRDSM 75.7 0.0 22:12 22:51 both 2.79"no-go.Minor chipping on outside of mill. 2/11/2016 2/11/2016 0.50 PROD1 DRILL SVRG P Flush choke,service injector and 0.0 0.0 22:51 23:21 check pack offs. 2/11/2016 -2/12/2016 0.65 PROD1 DRILL PULD 1P PJSM-MU drilling BHA#4,2.25°AKO 0.0 72.2 23:21 00:00 motor and HCC Bi-center bit,had to work down through tree. 2/12/2016 2/12/2016 0.75 PROD1 DRILL PULD P Crew change ouL MU drilling BHA#4, 72.2 72.2 00:00 00:45 2.25°AKO motor and RB HCC Bi- center bit to CoilTrak.Surface test. 2112/2016 2/12/2016 1.75 PROD1 'DRILL TRIP P RIH with BHA#4.Stack 10k at 7,367 72.2 7,367.0 00:45 02:30 ft(Otis SBR)several attepmts to pass with different TF and speed,pass through with TF 30'ROHS,pump off at 10 fpm. 2(12/2016 2/12/2016 - 0-20 PROD1 DRILL DLOG P Tie in to K1 for minus 9 ft correction. 7,367.0 7,395.0 02:30 02:42 2/12/2016 2/12/2016 0.80 PROD1 DRILL CIRC P RIH to 7,600 ft. Curculate around 9.0 7,395.0 7,639.0 02:42 03:30 ppg FbPro drilling mud.PUW 33k. Close EDC.RBIH,clean thru window. Page 218 Report Printed: 5/4/2018 • • ''' Milling Operations Summary(with Timelog Depths) _, &wells 1G-11 C otiot_oPhillips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log :S(ett Depth; 5I rt Time #nal Time Our .thrrWmle QPM. Ac rnty Ccde" . a P-7-)( Qpem ii ice) Ertl tom): 2/12/2016 2/12/2016 5.50 PROD1 DRILL DRLG P 7,639 ft. OBD 1.65 bpm at 3,450 psi 7,639.0' 7,837.0 03:30 09:00 FS,BHP 3,585 psi,CWT 10.0k,WOB 1.5k,WHP 22,IAO,OA 292 • 2/12/2016 2(12/2016 0.15 PROD1 DRILL WPRT P Mini Wiper from 7837 ft to 7789 ft. 7,837.0 7,837.0 09:00 09:09 PUW 33 klbs,SOW=12 klbs. 2/12/2016 2/12/2016 1.45 PROD1 DRILL DRLG P OBD 1.69 bpm at 3,755 psi FS,BHP 7,837.0 7,915.0 09:09 10:36 3,585 psi,CWT 11.5k,WOB 1.0k. ROP 40-70 FPH.Send sweep ahead • of reaching TD. TD build section at 7915 ft.Average DLS=45°/100'. 2/12/2016 2/12/2016 1.75 PROD1 DRILL TRIP P POOH with build BHA#4. 7,915.0 - 0.0- 10:36 12:21 2/12/2016 2/12/2016 0.50 PROD1 DRILL OWFF P Flow check well.Static.PJSM for LD 72.2 72.2 12:21 12:51 BHA. 2/12/2016 2/12/2016 0.65 PROD1 DRILL PULD 'P LD BHA#4,Bit condition 1-1-PN-N-X-I 72.2 0.0 , 12:51 13:30 -NO-BHA.check pack offs. 2/12/2016 2/12/2016 1.10 PROD1 DRILL 'PULD P PJSM-MU drilling BHA#5,0.5°AKO 0.0 72.2 13:30 14:36 motor and New HYC Bi-center bit.MU to CoilTrak.Surface test. 2/12/2016 2/12/2016 1.45 PROD1 DRILL TRIP P RIH with BI-IA#5 72.2 7,380.0 14:36 16:03 2/12/2016 2/12/2016 0.15 PROD1 DRILL DLOG P Tie in to K1 for minus 9 ft.correction. 7,380.0 7,397.0 16:03 16:12 2/12/2016 2/12/2016 0.50 PROD1 DRILL TRIP P RIH.PUW at 7,600 ft 31k.RBIH. 7,397.0 7,915.0 16:12 16:42 Close EDC.slight bobble at 7,619 ft. 2/12/2016 2/13/2016 7.30 PROD1 DRILL DRLG P '7,915 ft. OBD 1.89 bpm at 3,760 psi 7,915.0 8,166.0 16:42 00:00 FS,BHP 3,698 psi,CWT 10.4k,WOB 1.0k,ROP 25.60 fph. • 2/13/2016 2/13/2016 2.75 PROD1 DRILL DRLG P 8,166 ft. OBD 1.69 bpm at 3,772 psi 8,166.0 8,315.0 00:00 02:45 FS,BHP 3,729 psi,CWT 10.0k,WOB 2.0k,ROP 60-80 fph.Losses seen at 10 bph at 8,295 ft 2/13/2016 2/13/2016 0.40 PROD1 DRILL WPRT P -Wiper trip up hole to 7,650 ft.PUW 8,315.0 7,650.0 02:45 03:09 34k. 2/13/2016 2/13/2016 - 0.30 PROD1 DRILL 'WPRT P Wiper back In hole.MIA/12.0k 7,650.0 8,315.0 03:09 03:27 . 2/13/2016 2/13/2016 5.25'PROM DRILL DRLG P 8,315 ft. OBD 1.69 bpm at 3,868 psi 8,315.0 8,532.0 03:27 08:42 FS,BHP 3,690 psi,CWT 10.0k,WOB 2.0k,ROP 60-80 fph.Losses 5-10 bph.Crossed fault at 8410 ft.No change in loss rate. 2/13/2016 2/13/2016 0.15 PROD1 DRILL WPRT P BHA wiper.PUW=37klbs,SOW=13 8,532.0 8,532.0 08:42 08:51 klbs. 2/13/2016 2/13/2016 4.50 PROD1 DRILL DRLG P 8,532 ft. OBD 1.67 bpm at 3,871 psi 8,532.0 8,715.0 08:51 13:21 FS,BHP 3,777 psi,CWT 10.3k,WOB 2.0k,ROP 35-50 fph. 2/13/2016 2/1312016 0.65 PROD1 DRILL WPRT P Wiper trip up hole,PUW 39k,RBIH, 8,715.0 8,715.0 13:21 14:00 RIW 9.5k 2/13/2016 2/13/2016 2.00 PROD1 DRILL DRLG P 8,715 ft. OBD 11.67 bpm at 3,850 psi 8,715.0 8,775.0 14:00 16:00 FS,BHP 3,771 psi,CWT 10.0k,WOB 1.4k,ROP 40-50 fph. 2/13/2016 2/14/2016 8.00 PROD1 DRILL WPRT T 8.775 ft.Entire field in Phase III,pump 8,775.0 7,600.0 16:00 00:00 sweep,pick up into 3-1/2'tubing, open EDC,circulate around until • Phase III weather breaks. 2/14/2016 2/14/2016 3.70 PROD1 DRILL CIRC T Continue to circulate around until 7,600.0 7,600.0 00:00 03:42 Phase III weather breaks.PUH and tie in to K1 for a plus 2 ft correction. Page 318 Report Printed: 5/4/2016 REGEIvEcio • 21 51 25 MAR 2 9 2016 2 6 9 8 3 WELL LOG TRANSMITTAL# AOGGC To: Alaska Oil and Gas Conservation Comm. March 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED /1 /2010, Anchorage, Alaska 99501 M K BENDER RE: Plug Setting Record: 1G-11A Run Date: 2/5/2016 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 1G-11A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21008-01 Plug Setting Record(Field Print) ������� 1 color log 50-029-21008-01 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: MALL4z4t117) o_eiteeet 215125 16 760 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. January 29, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED e, Anchora Alaska 99501 I Z/1-1/201Gg K.BENDER FEB 02 2015 AOGCC RE: Multi Finger Caliper: 1G-11A Run Date: 12/25/2015 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 1G-11A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21008-01 Multi Finger Caliper(Field Log) SCANNED i' 8 i i i 1 color log 50-029-21008-01 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: 6-eiteget • PTD 2 /5- -/ 2- Loepp, Loepp, Victoria T (DOA) From: Eller,J Gary <J.Gary.Eller@conocophillips.com> Sent: Monday, August 17, 2015 9:52 AM To: Bettis, Patricia K (DOA) Cc: Loepp, Victoria T (DOA);Venhaus, Dan E;Phillips, Ron L; Burke,Jason Subject: RE: KRU 2E-15L1 & 1G-12L1 Follow Up Flag: Follow up Flag Status: Flagged SCANNED MAR 15 2016 Good morning, Patricia! The exclusion of information on emergency KWF in the KRU 2E-15 (184-189) and 1G-12 (183-132) CTD applications was intentional. ConocoPhillips' sent an e-mail to Victoria Loepp on July 21, 2015 stating our intention to no longer include information on the emergency KWF in Kuparuk CTD drilling applications . At Victoria's request, Dan Venhaus (ConocoPhillips CTD Supervisor), Kai Starck, and myself met with Jim Regg,Guy Schwartz, and Victoria on August 4, 2015 to discuss this. The discussion concluded in less than an hour to the satisfaction of the AOGCC representatives present. Subsequently, the CTD applications for KRU 1G-11A and AL1 (215-125>&215-126)were approved by the Commission without reference to emergency KWF. I hope that gives you sufficient information to proceed, and I would be glad to discuss this some more with you if that would be beneficial. -Gary Eller From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, August 14, 2015 2:35 PM To: Eller, J Gary Subject: [EXTERNAL]KRU 2E-15L1 Good afternoon Gary, What weight of KWF and volume of KWF will be available for emergency purposes while drilling this lateral? 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. 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C a . v p E I co o 5CO is 0 03 m re ao c ° F E Y "'ell w 3 � .0+ y .— .,_ 2 0 1 N C / a3 n U N C Q ❑ C C O To s- a) C •011:C m To n o Q o E _ OT Z ° O N a) £ U m 5 M ❑ (a U z (f) as a) (0 @ N (a O O OO a) ❑ ❑ ❑ ❑ (a ❑ E Q N N v m To m 2 0o Z ao CO N co io co ❑ ❑ ❑ ❑ J ❑ E iatto D . > COCO010, 01 0 m F C dNNNNN CO CO CO CO CO NN a) W E � O N . ON a)N NNNNN N - F- B. d C° = a)E m (6 E Z ° `° W co a' -co Z C O 'U U U U U Q O �. Q O O a JNN C C U w£ 0 0U H a V 0 a ' o Oo C) ° O LL 2 0 O N 0 0❑ ❑ ❑ ❑ ❑ p 0 N a. 2 w w w L1i J w 3 z 0 d 0 c)) 0 CC 0 0 III ®F TRj 0 �w\�\���j� s� THE STATE Alaska Oil and Gas • mw =kr of L /AsKA. Conservation Commission tlt- 2 =4y-_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®FALAS3- Fax: 907.276.7542 www.aogcc.alaska.gov Cody Pohler a '5^ g-s' CTD Engineer f ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-11A Permit to Drill Number: 215-125 Sundry Number: 316-029 Dear Mr. Pohler: 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, , - ":21- 4.t4,\ Cathy P. oerster Chair DATED this Ay day of January, 2016. RBDMS i JAN L 1 2016 • • RECEIVED • STATE OF ALASKA JAN 14 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION O ' / APPLICATION FOR SUNDRY APPROVALS AO CC 20 AAC 25.280 AOGCC Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repa r Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑✓ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. '74& 3. Inc. Exploratory EI Development 0 183 SIS'' 12S 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. PO Box 100360,Anchorage AK 99510 50-029-21008-01 7. If perforating: 8.Well Nane and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ❑Q ✓ KRU 1G-11A 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25640 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10533 6455 10030 6481 2267 Casing Length Size MD TVD Burst Collapse - Conductor 68 16 106' 106' - Surface 2314 10.75 2351' 2206' Production 8151 7 8188' 6901' Liner 2355 2.375 10030 6481 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7540-7590,7676-7722,7945- 6355-6397,6469-6507,6694- 3.5 L-80 7366 7950,7960-7982 6698,6706-6725 Packers and SSSV Type: Packer-Baker FHL Retrievable Packer Packers and SSSV MD(ft)and TVD(ft): MD=7258 TVD=6124 Packer-Otis RRH Packer MD=7402 TVD=6241 Packer-Otis WD Packer MD=7813 TVD=6583 Packer-Baker KB Packer MD=7621 TVD=6422 Packer-Halliburton Swell Packer ' MD=7744 TVD=6408 Safety VLV-Camco TRDP-1A Safety VLV MD=1930 ND=1848 12.Attachments: Proposal Summary Q Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15.Well Status after proposed work: �-�( Commencing Operations: 1/20/2016 OIL 0 WINJ ❑ WDSPL 0 Suspended LYJ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned t 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Cody Pohler @ 265-6435 Email Cody.J.Pohler@conocophillips.com Printed Name Title CTD Engineer Phone 265-6435 Cody Pohler Signature ,,, Date n COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. / l L-C— 0 29 Plug Integrity 0 BOP Test L_.I Mechanical Integrity Test 0 Location Clearance 0 Other:50p / r5 f ii_0 306or51g rsfi 0M P-,-0S-7 1 5 ZZG7"p5'd ) r ,p r'L /InrnvlciVey,fir r „25U0p5-r9 / Aiternafc ,plvq plaC 1.1-1evsf Lppro✓rtt /�cr c���C �5 . 11 Z l� � Post Initial Injection MIT Req'd? Ye/'0 No E Spacing Exception Required? Yes ❑ No C/ Subsequent Form Required: /d-- 4 APPROVED BY / Approved by: / j COMMISSIONER THE COMMISSION Date: `!�— (/� Q i Sub d III i m and Form 10-403 Rev ed 11/2 5 frn/ /q roved application is valid for 12 months from the date of approval. Attachments in Duplicate ORI I N A L ixaIli i ,,,f ll, RBDMS JAN L 1 2016 • • KRU 1G-11B CTD Summary for Plugging Sundry (10-403) Summary of Operations: KRU 1G-11B will be a single lateral producer. The 1G-11A CTD sidetrack was drilled in the summer 2015 but production has been disappointing. The objective is to abandon the 1G-11A sidetrack and drill one lateral north of a major E-W fault to develop the C3/4 sand in the area. 1G-11A sidetrack will be abandoned via a cast iron bridge plug(CIBP)set at 7650' MD in the 3'h"completion above the window exit depth of 7660' MD. There is insufficient room to place cement as required by regulation,so ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to abandon the 1G-11A sidetrack in this manner. 1G-11B will kick off in the C2 sand via a 2 string cemented window exit. The well bore will drop into the Cl before turning up to acquire the C3/4 interval. The well will be geo-steered in pay until TD at 10,303' MD. The lateral will be completed with 2%" slotted liner with the liner top set inside the window at 7,609' MD. Using the maximum formation pressure in the area of 2898 psi in 1 H-08,the maximum potential surface pressure,assuming a gas gradient of 0.1 psi/ft, would be 2267 psi. In the northern fault block the maximum formation pressure in the area of 2890 in 1H-03,the maximum potential p faceCU re woul�d/be 2250 1004 C 2O /5ol, iv/ 2,7� '5 t /.v F, IVO /(� r a w�( �r / �^,`ll �liivv�� g//o�✓ /Ur i i�i1/'" Ply ��- s�3 LL Q ;h49 CTD Drill and Complete 1G-11B: March 2016 /QCT✓Q'2 '4 /4i / Dry e2' Pre-CTD Work /obi /// • Slickline: Dummy all GLMs. Pull the 3'/2"KB liner-top packer at 7625 MD • E-line:Chemical cut the 2%"liner at 7662' MD • Slickline:Pull and lay down the 37' of 2%"liner fish • E-line: Set CIBP for 3'/2"liner at 7650' MD. Pressure test CIBP. • E-line: Set a 3'/2"monobore whip-stock at 7,614' MD at high-side orientation CTD Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1G-11B Sidetrack(C3/4 sand-North) i. Mill 2.80"window at 7,614' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10,303' MD iii. Run 2%"slotted liner with deployment sleeve from TD up to 7,609' MD 1. Optionally a liner top packer and a swell packer pending geology 3. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-CTD Work 1. Pull BPV 2. Obtain static BHP. 3. Put back on production Page 1 of 1 January 13, 2016 • • M L. 0 o o 2 a V p o F 0 H c 0 a - a — p N w m II nZ 2 a 2 m m raa n otl c. cN . 3 F N a .'. N II a N E 2° N E 2 G z "'Oo; `-a0Q N N EON E OCO m N N S E Ocom � EW nn °00 O . 00 w 0 0 ' tg iii n ^ b m . NU phN o no d h Or NOh IINoh.m RN C L.-w' Li-FT).Q O (n !IIN h 2E N mcyvnN N � o 0 n m �_O 0 � hm a aN h h. 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NW N— to Eo (00 V' h l� Y aU N� ak 1 n M U U U — 44 6 C r _-_t cO S Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the atricia or teve 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 atricia r Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. RECEIVED , • STATE OF ALASKA • qFP 2 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANE DQG la.Well Status: Oil❑✓ f Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development a ✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL❑ No. of Completions: // Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Dat( omp)Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: ,8/28/2015 - ,215-125 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360,Anchorage,AK 99501 .8/19/2015. • 50-029-21008-01 ,- 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 327' FSL,806'FWL, Sec. 29,T12N, R10E, UM - •8/25/2015- • KRU 1G-11A • Top of Productive Interval: 9. KB(ft above MSL): 99' - 17. Field/Pool(s): 1562'FNL, 1250'FEL, Sec.32,T12N, R10E, UM GL(ft above MSL): 63' ' Kuparuk River Field/Kuparuk River Oil Poo Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1911'FSL, 2231'FWL,Sec. 32,T12N, R10E, UM •10553'MD/6455'TVD • • ADL 25640 ' 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 540585.5 - y- 5980976 - Zone- 4 10553'MD/6455'TVD- 2571 TPI: x- 543826 y- 5979105 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 542043 • y- 5977288- Zone- 4 no SSSV 1652'MD/1624'TVD 5. Directional or Inclination Survey: Yes ❑✓ (attached) No ❑ 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) - 7658'MD/6454'TVD f 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 GR/Res • 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASINGGRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 65# H-40 38' 106' 38' 106' 24" 212 sx CS II 10.75" 45.5# J-55 37' 2351' 37' 2206' 13.5" 930 sx ASII I,250 sx ASI 7" 26# J-55 37' 8188' 37' 6901' 8.5" 610 sx Class G,250 sx ASI 2.375" 4.7# L-80 7625' 10030' 6426' 6481' 3" slotted liner 24.Open to production or injection? Yes a No ❑ 25.TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 7366' 7258'MD/6124'TVD, slotted liner from 7625'-10030'MD and 6426'-6481'TVD 7402'MD/6241'TVD and 7813'MD/6583'TVD r 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. YMPLET10ft ; Was hydraulic fracturing used during completion? Yes❑ No ❑. •55141Per 20 AAC 25.283(i)(2)attach electronic and printed information MI 4 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 9/17/2015 Gas Lift Oil Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 9/18/2015 4 hours Test Period -2 94 254 176 Bean Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1C)8 1357 24-Hour Rate -► 11 557 2672 not av liable Form 10-407 Revised 5/2015 /01-7--//5-- CONTINUED ON PAGE 2 121 I0�'J Amit ORIGINIAL only P71201----- RBDMS SEP 3 0 201 28:CORE DATA Conventional Coo): Yes ❑ No E Sidewall Cores:•es ❑ No ❑ 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 1652' • 1624' - Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Top Kuparuk Cl upper 7670' 6464' Top Kuparuk B5 - • Top Kuparuk B5/Base Cl 8592' 6500' Fop Kuparuk B5 • Formation at total depth: Kuparuk B5 31. List of Attachments: Summary of Daily Operations,schematic,directional survey 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: Mike Winfree @ 263-4404 Email: Mike.Winfreecop.com 04.%Al 4644 IS-- Printed Name: Dan Venhaus Title: CTD Engineering Supervisor i Signature: Phone: 263-4372 Date: ?-z 44--(3 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP PROD 1G-11A � ConocoPhillips 4 �I Well Attributes 0 Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl(^I MD(ftKB) Act Btm(ftKB) conocasrarpc 500292100801 KUPARUK RIVER UNIT PROD 97.55 8,754.89 10,523.0 •• ,f,":, Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1G-11A,9/18/20152:08.45 PM SSSV:NONE 100 12/16/2013 Last WO: 40.99 9/19/1983 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -'-- -- Last Tag: Rev Reason:ADD SIDETRACK smsmilh 9/18/2015 HANGER;31.2 elf 1/ail Casing Strings Casing Descriptionam. OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I t�l CONDUCTOR 16 15.250 38.0 106.0 106.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WALen(I...Grade Top Thread ab°/SURFACE 10 3/4 9.950 37.0 2,351.3 2,206.1 45.50 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Ml) ,PRODUCTION 7 6.276 37.1 8,187.7 6,521.5 26.00 J-55 BUTT CONDUCTOR;38.0-1060 / Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread 11 A LINER 2 3/8 1.992 7,625.8 10,030.0 6,481.7 4.60 L-80 ST-L V Liner Details SURFACE;37.1-2,351.3-/.• Top(ftKB)KB) Top(TVD)(ftKB) Top Incl(°) Item Des CoNominal ID Pnl - 7,625.8 6,426.7 33.59 SBR BAKER SBR DEPLOYMENT SLEEVE 2.250 GAS LIFT;2,728,2 r 't 7,739.2. 6,504.4 63.02 XO Reducing Crossover Pup 2 3/8",4.6 ppf,L-80 X 2 1/6",3.35 ppf, 1.751' L-80 Hyd511 bxp 7,744.5 6,506.7 64.16'SWELL HALLIBURTON SWELL PACKER,WATER MEDIUM 1.751 GAS LIFT;4,148.1_ '. PACKER 7,759.7- 6,512.7 69.93"XO Enlarging Crossover Pup 2 1/6",3.25 ppf,L-80 X 2 3/8",4.6 ppf, 1.751 L-80,Hyd511 beg GAS LIFT;5,320.5 ":; 8,752.4 6,481.8 97.47 OPEN HOLE OPEN HOLE 3.000 8,776.4 6,478.8 96.69 DEPLOY BAKER SHORTY DEPLOYMENT SLEEVE 1.920 -- Tubing Strings GAS LIFT;8,185.3 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;6,185.3-E TUBING-WO 2015 31/2 2.992 31.2 7,366.3 6,211.7 9.30 L-80 EUE8rd mod Completion Details Nominal ID GAS LIFT;6,832.4 ( Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) 31.2 31.2 0.00 HANGER CIW TUBING HANGER 2.992 7,227.5 6,098.8 35.87 LOCATOR LOCATOR SUB 2.990 GAS LIFT;7,171.4 7,228.5 6,099.6 35.87 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,235.8 6,105.5 35.85 PBR BAKER 80-40 PBR 4.000 7,258.3 6,123.8 35.81 PACKER BAKER FHL RETRIEVALBE PACKER 2.910 LOCATOR;7,227.5 7,311.1 6,166.7 35.63 NIPPLE CAMCO DS NIPPLE(PULLED RHC AND BALL AND 2.812 SEAL ASSY;7,228.5 ROD,4 15 15) FOR;7,235.8 - 7,359.8 6,206.3 35.23 OVERSHOT POOR SOY TUBING OVERSHOT 3.750 PACKER;7,258.3 N,2.'4; Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..f Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-ORIGINAL 41/2 2.992 7,361.3 7,841.21 6,523.3 9.20 J-55 FL4S Completion Details NIPPLE,],311.1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,376.2 6,219.7 35.10 SBR OTIS SBR(2.81"X NIPPLE PROFILE) 2.8(3 II�� 7,402.3 6,241.2 34.87 PACKER OTIS RRH PACKER 2.970 OVERSHOT;7,359.8 I � 7,541.7 6,356.6 33.56 BLAST RINGS BLAST RINGS(3) 2.992 U. SBR;7,378.2 7,657.2 6,452.9 33.75 BLAST RINGS BLAST RINGS(3) 2.992 PACKER;7,402.3 7,812.7 6,522.3 86.98 LOCATOR OTIS LOCATOR 2.992 PRODUCTION;7,437.71( 7,813.1 6,522.3 87.01 PACKER OTIS WD PACKER 4.000 PRODUCTION;7504.8 - 7516.5 6522.5 87.25 MILLOUT OTIS MILL OUT EXTENSION 4.410 7,830.8 6,523.0, 88.25 NIPPLE CAMCO D NIPPLE NO GO 2.750 IPERF;7.540.0-7,590.0- if 7,840.4 6,523.3 88.57 WLEG OTIS WIRLINE RE-ENTRY GUIDE,ELMD TTL @ 7822 3.015 during PPROF on 9/27/2007 TUBING PUNCH;7,814.0 "i. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ( Top(TVD) Top Incl Top((NCB) (RKB) (°) Des Com Run Date ID(in) 0 10,037.0 6,481.1 94.70 IBP IBP ran to Isolate heavily water swept zone from 8/27/2015 production. Perforations&Slots 1 WINDOW;7,858.0-7,888.0 i Shot Dens Top(TVD) Btm(TVD) (shots/( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com I 8,720.9 8,752.0 6,485.6 6,481.8 A-4,1G-11 8/27/2015 ' SLOTS Slotted Liner ' 8,777.2 10,029.6 6,478.7 6,481.7 A-4,1G-11 8/27/2015 SLOTS Slotted Liner I f Mandrel Inserts St ati PRODUCTION;7,775.2 . °, on Top(TVD) Valve Latch Port Sloe TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LOCATOR;7,8127- 1 1 2,726.2 2,522.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 111 PACKER;7,813.1 ' ... 2 4,148.1 3,673.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 MILLOUT;7,816.5 e1 2s 3 5,320.5 4,582.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 4 6,165.3 5,260.1 CAMCO MMG 1 1/2'GAS LIFT DMY RK 0.000 0.0 4/15/2015 NIPPLE;7,830.8 5 6,832.4' 5,780.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 WLEG;7,e40.4 6 7,171.4 6,053.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 7 7,437.7 6,270.2 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/21/2015 8 7,504.8 6,325.9 OTIS SPM i PROD DMY BK 0.000 0.0 6/22/2015 0.000 0.0 4/23/2015 9 7,775.2 6,517.2 OTIS SPM 1 PROD OPEN BEK PRODUCTION;37.1-8.187.7-- I Notes:General&Safety End Date Annotation SLOTS;8,720.9-8,752.0 NOTE'. SLOTS;8,777.2-10,029.6- A LINER;7,825.8-10,030.0 IBP;10,037.0M • • • ❑ M 0 F- d a m p 0 m M n g o m o m ac L. v co E N ❑ m E2 LJ v2b 3 .o y�o 0 lry N _.. n N C e-I O C N Lo m N-f^O ❑ ❑ r t.7..5°' N ,_ b m 2 iiNro 111 Cr) nO od n J ^2 0 n 73 > Y R -- O I5 n co N - N•- N N p N J mPlillN ryry O C• ,- O. n Y N O C C- p N h N tO 2 <0 , , N- � c E v a a a E t F rnda10 .0 0 . °' S W m cn d o`on to„ m m E _ m 6 co E p n c c n c'v = 2 �- co o N o O 4 'C U V O C 0 V N N c0 UQ . a, O O O m co–Mr F N M N OC M L co U (n N S U N — • u) N Ui., r G 0 r N a A ❑ (/)�- o I E o��E J 3 LI r! IIF— (....) ❑ g N mto0 H Q 0 n 'CN h �`V rnN 2Npo . I c n nCO y r h (7 cn 'to ib ❑ aci o Ec, crdi U v rn • m a a # Lri 0 UUU n 0 w o v c es, • _-• E ` m y ioo mN oU 7 b c a °' u o E D_c o ` U 0 Y Q 1--. J LL 1G-11 WELL WORK SUMAMRY DATE SUMMARY PRE-RIG WELL WORK 4/15/2015 GAUGED TBG TO 2.72"TO 7250' SLM; SET BAITED P/T ON BALL n' ROD @ 7311' RKB. REPLACED SOV @ 6185' RKB WITH DV. TESTED TBG 2500 PSI, GOOD. PULLED BAITED P/T AND BALL n' ROD; PULLED RHC. DRIFTED TO 7900' RKB WITH 2-5/8" DUMMY WHIPSTOCK. IN PROGRESS. 4/16/2015 DRIFTED WITH 2.75"CA-2 DUMMY PLUG TO 7831' RKB. SET 2.75" CA-2 PLUG AND DUAL SPARTEK GAUGES @ SAME. RETURN IN 5 DAYS FOR C-SAND BHP. 4/22/2015 MEASURED C SAND BHP @ 7635' RKB: 2796 PSI. PULLED 2.75" CA-2 PLUG w/ GAUGES. FINAL A SAND BHP: 2699 PSI. IN PROGRESS. 4/23/2015 BRUSH TBG TO 2.75" D NIPPLE @ 7831' RKB. SET 2.75"CA-2 PLUG @ 7831' RKB. SET CATCHER @ 7795' SLM. PULLED CVs @ 7775', 7505', 7438', RKB, SET DV @ 7505' RKB. PULLED CATCHER. IN PROGRESS. 4/24/2015 DUMP BAILED 12' SAND ON CA-2 PLUG @ 7831' RKB. COMPLETE. 6/20/2015 SET CATCHER ON SAND @ 7793'SLM. MAKE MULTIPLE ATTEMPTS TO SET 1" DV @ 7438' RKB. BRUSH N' FLUSH MANDREL @ SAME. IN PROGRESS 6/21/2015 SET 1" DV @ 7438' RKB. RAN D&D HOLE FINDER, FOUND LEAK TO BE AT STA. 8 © 7505'RKB. PULLED 1" DV @ 7505' RKB. IN PROGRESS 6/22/2015 SET 1" DV @ 7505' RKB. RAN LEAK DETECT DETERMINED LEAK IN STA. 8 @ SAME. PULLED AVA CATCHER @ 7793' SLM. JOB COMPLETE 7/5/2015 RE-ENERGIZE OC PO (COMPLETE) 7/6/2015 PERFORATE ZONE 7710'TO 7720'. LOG CORRELATED TO DRESSER ATLAS CEMENT BOND LOG DATED 4-OCT-1983. CCL STOP DEPTH AT 7702.4'. CCL TO TOP SHOT 7.4°. READY FOR COIL. POST PERF INJECTIVITY TEST; .75 BPM 500 PSI 1.0 BPM 525 PSI 1.25 BPM 525 PSI. 7/8/2015 OC POT(PASS)OC PPPOT(PASS) 7/11/2015 WEEKLY BOP TEST, RIH LOG FROM 7750' CTMD UP TO 7700' PAINT FLAG, CONTINUE LOGGING UP TO 7100'. POOH, ****JOB IN PROGRESS**** 7/12/2015 RIH TO FLAG, CORRECT TO 7723.71' MID ELEMENT. PICK UP TO 7700', DROP .5" BALL, SET RETAINER. PUMP 35BBLS 15.8 PPG CEMENT. FINAL CTP WAS 1638, WHP 590, IA 0, OA 0, FREEZE PROTECT WELL TO 2000' ***WAIT 24HRS BEFORE SLICKLINE DRIFT***** 7/19/2015 PUMPED 20 BBL DSL DOWN TBG ATTEMPTING TEST. TBG @ 350 PSI. TAGGED 2.812" DS NIP @ 7311' RKB. DRIFTED TBG WITH DUMMY WHIPSTOCK TO 7697' SLM. READY FOR CTU? 7/22/2015 LOG RCBL FROM CEMENT RETAINER AT 7702'TO 7000'. TOP OF CEMENT FOUND AT 7620'. WEAK CEMENT STRINGER FOUND ALL THE WAY UP TO 7480'. LOG CORRELATED TO DRESSER CEMENT BOND LOG DATED 04 OCT 1983. JOB COMPLETE. 7/24/2015 (PRE CTD) : DDT-MV, SSV, SV(PASSED), PPT-MV, SSV, SV(PASSED). 7/29/2015 PERFORATE TUBING FROM 7614'-7619'WITH 2", 3 SPF, 120 DEG PHASING HSC LOADED WITH 6.7 GRAM BH CHARGES. CCL TO TOP SHOT OFFSET: 7.5', CCL STOP DEPTH: 7606.5'. LOG CORRELATED TO DRESSER ATLAS CBL DATED 4- OCT-1983. READY FOR CT. 7/31/2015 Pump 35 bbls of 15.8 ppg cement with middle 25 bbls containing 1.5 ppb of CemNet fiber. Obtained squeeze pressure with approx. 25 bbls behind pipe. Washed down to mandrel @ 7,488'. Started snubbing in soft cement @ 6,580' RKB. POOH washing tubing jewerly while maintaining over balanced on well. 500 psi left on tubing. Tubing left full of diesel down to 6,800' and ready for a slickline tag and pressure test in 48 hrs. *****Job in Progress***** 8/1/2015 Rig down coil, stand back while slick line tags TOC and performs MIT with LRS. Rig back up on well and read milling in the morning. ***Job in Progres 8/1/2015 TAG DS NIPPLE @ 7273' M (7311' RKB FROM TBG TALLY& HAN VER/7290' RKB FROM JEWELRY LOG ON 7/6/15); TAG CEMENT @ 7476' SLM/7493' RKB (CORRECTED TO JEWELRY LOG ON 7/6/15). P.T. CEMENT TO 950 PSI W/NO LOSS IN 10 MIN. READY FOR CTU. IN PROGRESS. 8/2/2015 Mill cement from 7,491' down to retainer @ 7,702.7' RKB. Chase last gel pill to surface @ 80%washing jewelry along the way. Well freeze protected and ready for slickline. *****Job in Progress***** 8/3/2015 TAG CEMENT @ 7684'SLM/7701' RKB; DRIFT DUMMY BAKER WHIPSTOCK DRIFT TO SAME. READY FOR E-LINE (whip stock). IN PROGRESS. 8/4/2015 SET TOP OF BAKER HUGHES WHIPSTOCK 3 DEGREES ROHS AT 7660'. CCL TO TOW OFFSET: 20.6', CCL STOP DEPTH: 7639.4'. RA TAG SET DEPTH: 7667'. BOTTOM OF WHIPSTOCK AT 7670.5' LOG CORRELATED TO DRESSER ATLAS CBL DATED 4-OCT-1983. JOB COMPLETE. • • • ConocoPhiIIips Time Log & Summary We(hale.,Web Reporting Report Well Name: 1G-11 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 8/17/2015 9:00:00 AM Rig Release: 8/28/2015 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/09/2015 24 hrSummary 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. Conducting housekeeping and painting operations. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Standby for for completion of 9ES rig move. R/U ODS PDL, re-spool DS PDL. Conducting housekeeping, painting, and maintenance operations 08/10/2015 00:00 06:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. Checked all connections on stack and secured for rig move. Cleaned rig cellar. 06:00 12:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. Painting and cleaning pit lining. Re-install mouse holes and housekeeping operations. Install new counter support bar and CTES counter. TOTCO inspected and calibrated all rig gauges. 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. Change HPU oil and 0-ring on koomey unit connection. Power up koomey unit to check for leaks. Held 1G-11 pre-spud with rig crew. Cleaned in pipe shed. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Stanby for Completion of 9ES rig move. Prep and paint pits, unload freight, install flag pole, and hang door on hot well. Work on LAD safe system and clean up rig floor. 38/11/2015 00:00 06:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. General housekeeping, seal roof of hot well, and worked on LAD safe system. 06:00 12:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. General housekeeping, preventative maintenance, and prep cuttings pit to paint. Install riser on injector,clean all connections,and replaced 0-rings. Swap hoses on BOP stack on upper blinds and upper 2"pipe rams. Page 1 of 11 Time Logs • - Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Standby for completion of 9ES rig move. Unlock and pressure up koomey to test BOP ram functions. Re-rig slings to BOP's. General housekeeping and preventative maintenance. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Stand by for completion of 9ES Rig move. Continue Ospho and painting in pits. Complete Ladsafe derrick climbing system. Prep and paint DS Mast ram 08/12/2015 00:00 06:00 6.00 0 0 MIRU MOVE WAIT T Continue painting/projects on rig 06:00 12:00 6.00 0 0 MIRU MOVE WAIT T Continue with housekeeping and preventative maintenance around rig. Changed out R7 valve and cleaned shop 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Continue with housekeeping and preventative maintenance around rig. Installed blankets on ODS PDL, worked on air compressor, and started Nabors inventory system 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Perform rig condition audit, Sling log, DOMS, General housekeeping 08/13/2015 00:00 06:00 6.00 0 0 MIRU MOVE WAIT T Hook up flow line, Clean mast legs. Measure out new BOPE stack, paint PUTZ, motor man room,and Hot well, Inventory cabinets 06:00 12:00 6.00 0 0 MIRU MOVE WAIT T Change out R6, grease manual valves on stack, pulled all rams out of old stack, PM and test agitators. Work on Nabors inventory system and housekeeping. 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Good catch powerpoint, greased drag chain and shaker jacks, check and charge nitrogen koomey bottles, and work on mud lift. Work on Nabors inventory system and procedures to transfer fluid. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Complete paiting motor man room& Hot well, Continue painting in pits, Inventory sling locker and rig floor consumables 08/14/2015 00:00 06:00 6.00 0 0 MIRU MOVE WAIT T Paint mast cylinder on rig floor, Service valves R-6&R-7, Install mouse holes, Prep under for centrifuges for paint, Replace worn/ illegible signage 06:00 12:00 6.00 0 0 MIRU MOVE WAIT T Label lines for 1 line drawings for fluid tansfers, prep under centrifuges for paint, and general housekeeping. Page 2 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 0 0 MIRU MOVE WAIT T Change out damaged hydraulic line on wind wall hydraulic motor, boiler maintenance, paint mast raise cylinder,and disconnect flow line. 18:00 00:00 6.00 0 0 MIRU MOVE WAIT T Confirm new BOPE measurments, Prime pit floor, Pre spud with Kaleo's crew. Rig move checklist, Load out 2 loads to 1G 38/15/2015 Moved from 30 to OliktokY, Perform rig mat shuffle 00:00 06:00 6.00 0 0 MIRU MOVE MOB T Continue with rig move checklist, Paint mast tilt cylinders, 06:00 12:00 6.00 0 0 MIRU MOVE MOB T Paint in pit module and motorman room. Work on hot well level alarms, load out trucks for rig move, and inventory parts cabinets. 12:00 16:00 4.00 0 0 MIRU MOVE MOB T Complete rig move checklist and prep rig to move to 1G-11. Peak Oilfield trucks on location at 14:00 hrs. PJSM. Load shop, hookup jeeps and sows to rig. 16:00 21:00 5.00 0 0 MIRU MOVE MOB T Finish laying mats on 30 Pad access road. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Move CDR2 from 30 Pad to 1G-11. 38/16/2015 MOB 30 to 1G-11 00:00 23:30 23.50 0 0 MIRU MOVE MOB P Move CDR2 from 30 Pad to 1G-11. Stopped at 3K access road, 1 Q, and Oliktok"Y"to shuffle rig mats around the rig. 23:30 00:00 0.50 0 0 MIRU MOVE MOB P Matting finished into 1G, Move from Oliktok Y 08/17/2015 Complete MIRU, Rig Accept 09:00, nipple up, complete full BOPE test,Witness waived by Jeff Jones, AOGCC 00:00 01:30 1.50 0 0 MIRU MOVE MOB P Move Oliktok Y to 1G 01:30 03:00 1.50 0 0 MIRU MOVE MOB P On 1G pad, De jeep and spot units on 1G-11 03:00 09:00 6.00 0 0 MIRU MOVE RURD P Start rig up, Start working post move check list. 09:00 10:30 1.50 0 0 MIRU WHDBO NUND P Nipple up BOP,spot and hook up Kill tank to rig,fix scaffolding in cellar to be able to access tree valves. RIG ****Note:ACCEPT 09:00 10:30 12:30 2.00 0 0 MIRU WHDBO NUND P Prep for BOP test,function test BOP's, installed 4ft riser,shell test, secure stack,grease HCR valves, set up test pump, 12:30 22:00 9.50 0 0 MIRU WHDBO BOPE P Start BOP test, Call mechanic out to investigate leak on lower shear seal rams. Could not find leak. 1 Hr NPT for NAD 22:00 23:30 1.50 0 MIRU WHDBO BOPE P Fill coil and PT inner reel iron and packoff 23:30 00:00 0.50 SLOT WELLPF CIRC P Perform slack mgmt Page 3 of 11 ' Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/18/2015 24 hr Summary omplete slack mgmt,cut 75'of coil to find wire, PT PDL&TT Line, Pull BPV, Head up E-lie, M/U BHA#1, RIH and mill3.5"exit 7557.6 to 7663.6 00:00 00:12 0.20 0 0 SLOT WELLPF CIRC P Continue slack mgmt ops 00:12 00:42 0.50 0 0 SLOT WELLPF PRTS P Pressure test PDL&TT line 00:42 02:42 2.00 0 0 SLOT WELLPF CTOP P Cut 75'of pipe to find wire,test wire- Good, Prep coil for CTC Install, Move injector back for BPV removal 02:42 03:54 1.20 0 0 SLOT WHDBO OTHR P PJSM, Rig up FMC and pull BPV, Load out lubricator 03:54 04:24 0.50 0 0 SLOT WELLPF CTOP P PJSM, Install CTC and pull to 35K 04:24 06:51 2.45 0 0 SLOT WELLPF CTOP P Head up E-Line to UQC, PT CC, valve checklist,top drive inspection, test gas alarms. 06:51 08:27 1.60 0 73 PROD1 WHPST PULD P PJSM. PU/MU BHA#1, change-out little jerk dies,test MWD, stab on wellhead,tag-up,set depth. 08:27 12:27 4.00 73 7,659 PROD1 WHPST TRIP P RIH w/BHA#1 window milling assembly,tie-in to K1 for+2' correction, relogged K1 several times, logs not matching up, decide to dry tag WS to verify correction. Dry tag whipstock @ 7,659'. PUW=34K. 12:27 21:45 9.30 7,658 7,664 PROD1 WHPST WPST P Start milling window exit: 1.52 @ BPM @ 2,697 PSI, BHP=3340 PSI, CTW=13.5K,WOB=2.5K, 1 FPH. Mill off 3 1/2 @ 7662, Contact 7" @ 7663.2 21:45 22:03 0.30 7,664 7,664 PROD1 WHPST REAM P Back ream 3.5"window 22:03 23:15 1.20 7,664 7,646 PROD1 WHPST TRIP P POOH 23:15 00:00 0.75 7,646 71 PROD1 WHPST PULD P At surface, 30 min flow check, lay down BHA#1 08/19/2015 Complete Dual string exit window with rathole down to 7684, Drill Build 7684 to 7883' 00:00 00:30 0.50 71 0 PROD1 WHPST PULD P Continue to lay down BHA#1, Mill out©2.80 No-Go 00:30 01:18 0.80 0 75 PROD1 WHPST PULD P PJSM, P/U BHA#2 with 2°fixed bend WFT motor with bit box turned down and wear pad removed. Make up to coil and surface test 01:18 02:48 1.50 75 7,220 PROD1 WHPST TRIP P RIH EDC closed pumping min rate 02:48 03:18 0.50 7,220 7,411 PROD1 WHPST DLOG P log for tie in 7220 to 7260 then run down 7380 to log K1,set down at 7365, PUH change TF from 20R to 90R, PUW=30K, clean pass @ 90R start logging @ 7380'to 7411.-5' correction 03:18 03:42 0.40 7,411 7,665 PROD1 WHPST TRIP P RIH to dry tag 7"@ 7665, PUW=32K 03:42 08:45 5.05 7,665 7,667 PROD1 WHPST WPST P 7655', Bring pumps on, 1.6 BPM @ 2930 PSI FS, BHP=3345,see motor work©7664.5, exit casing @ 7,667.4. Page 4 of 11 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 10:15 1.50 7,667 7,684 PROD1 WHPST DRLG P Start drilling rathole: 1.65 BPM @ 3,185 PSI, BHP=3,380 PSI, CTW=10K,WOB=.5K, ROP=6. 10:15 11:30 1.25 7,684 7,684 PROD1 WHPST REAM P Make back reaming passes through window exit per well plan, dry drift, clean. Increased ECD at window from 10.3 to 11.4, minimal losses occured. 11:30 13:27 1.95 7,684 76 PROD1 WHPST TRIP P POOH for drilling assembly 13:27 13:57 0.50 76 76 PROD1 WHPST OWFF P Flow check 30 mins, no flow. PJSM. 13:57 15:03 1.10 76 0 PROD1 WHPST PULD P LD BHA#2 15:03 16:15 1.20 0 73 PROD1 DRILL PULD P PJSM. PU/MU BHA#3 16:15 17:45 1.50 73 7,370 PROD1 DRILL TRIP P RIH w/build drilling assembly,2.1 AKO motor and RR Hycalog bit. Stack out @ 7363 15R. Orient to 90R and run right through 17:45 17:57 0.20 7,370 7,400 PROD1 DRILL DLOG P Log K-1 for-5'correction. 17:57 18:45 0.80 7,400 7,684 PROD1 DRILL TRIP P Continue in well, Swap to 9.1 PPG FloPro, Close EDC and run through window. Clean through window 18:45 19:51 1.10 7,684 7,719 PROD1 DRILL DRLG P 7684', Drill, 1.54 BPM @ 2670PSI • FS, BHP=3502 19:51 20:03 0.20 7,719 7,719 PROD1 DRILL WPRT P Ratty drilling with stalls, Had to restart MWD computer orienter not turning. PUH to just below window, PUW=34K 20:03 00:00 3.95 7,719 7,883 PROD1 DRILL DRLG P 7719' Drill, 1.54BPM @ 3040, BHP=3850, New mud at surface @ 7720' 08/20/2015 Complete build to 7915, Trip out for lateral BHA, Drill lateral 7915 to 8378 00:00 00:48 0.80 7,883 7,915 PROD1 DRILL DRLG P Drilling ahead, 1.53 BPM @3350 PSI FS, BHP=3870,WHP=280PSI 00:48 02:24 1.60 7,915 66 PROD1 DRILL TRIP P Call End of Build @ 7915,Trip out 02:24 06:00 3.60 66 0 PROD1 DRILL PULD P At surface, PJSM PUD BHA#3, Unable to pump in managed pressure. Cycle T-1 and T-2. Good @ 18 1/2 turns. Put pressure on MP line and observe hose pressureing up. No communication to well. Pump down kill line and build well pressure. Consult with town, Remove tools from well, load PDL with MWD. 06:00 12:30 6.50 0 0 PROD1 DRILL OTHR T Trouble shoot MP line blockage, remove MP hose and T1 &T2 valve, found metal screw-in plug in tree, pictures on S-drive, remove plug. Install tango valve, MP line. Retest swabs,tangos, and BL1 valve to 3,500 psi. Perform valve checklist, reinstall QTS. Establish MP. 12:30 13:24 0.90 0 73 PROD1 DRILL PULD P PJSM. PD BHA#4,skid, MU QC, test MWD, strip on wellhead,tag up, set depth. ___2age Page 5 of 11 'rime Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:24 16:06 2.70 73 7,915 PROD1 DRILL TRIP P RIH w/drilling assembly, 0.5 AKO motor, new Hycalog bit. Tie-in to K1 For-4'correction, continue in hole, unable to log RA,verify correction with B/C1 interface. 16:06 21:42 5.60 7,915 8,265 PROD1 DRILL DRLG P DOBD: 1.40 BPM @ 3,150 PSI, BHP=3,810 PSI, CTW=11.5K, WOB=1.5K, ROP=65. 21:42 22:24 0.70 8,265 8,265 PROD1 DRILL WPRT P Wiper to 7700', PUW=29K, Small spikes in DHWOB.9 @ 7851 &.3 @ 7805. 22:24 00:00 1.60 8,265 8,378 PROD1 DRILL DRLG P 8265', Drill, 1.42 BPM @ 3120 PSI FS, BHP=3880,WHP=186, Losses @ 7-10BPH 08/21/2015 Drill 8378 to 8995, Lost all returns @ Cl interface, Healed to 1 BPM Losses, Lost 996BBIs/24 Hrs 00:00 04:12 4.20 8,378 8,615 PROD1 DRILL DRLG P 8378', Drill ahead, 1.42 BPM @ 3120PS1 FS, BHP=3897 04:12 05:00 0.80 8,615 8,615 PROD1 DRILL WPRT P Wiper to 7800', PUW=29 05:00 06:00 1.00 8,615 8,626 PROD1 DRILL DRLG P 8615', Drill ahead, 1.4 BPM @ 3160, BHP=3938,WHP=200PSI, RIW=12K,started experiencing total losses, PUH. 06:00 12:00 6.00 8,626 8,708 PROD1 DRILL DRLG P Open choke fully, continue drilling, minimal returns. Pump 38 bbl hi vis pill. Drill ahead 1.44 BPM @ 2,950 PSI, BHP=3,550 PSI, CTW=12K, WOB=2K. ROP=8-20. Ankerite! Lost decreasing, MM in 1.42, MM out.78. 12:00 12:30 0.50 8,708 8,708 PROD1 DRILL WPRT P On ankerite stringer, pull BHA wiper 250', pump heavy thru thief zone at 8,626'. 12:30 15:30 3.00 8,708 8,808 PROD1 DRILL DRLG P Drill ahead: 1.46 BPM @ 2,993 PSI, BHP=3,510 PSI, CTW=10K, WOB=1.8K, ROP=30-50. 15:30 15:45 0.25 8,808 8,808 PROD1 DRILL CIRC P Pump additional hi vis pill(40 bbls). MM out rate decreased to.40 BPM. 15:45 18:27 2.70 8,808 8,925 PROD1 DRILL DRLG P Drill ahead: 1.46 BPM @ 2,915 PSI, BHP=3,505 PSI, CTW=9.5K, WOB=@K, ROP=30-50. MM in 1.46; MM out.40. Continue drilling. 18:27 20:09 1.70 8,925 8,965 PROD1 DRILL DRLG P P/U and reset, lost diff, PUW=33K, 1.48 BPM @2730 PSI FS, BHP=3470,WHP=0, Losses=1BPM 20:09 20:45 0.60 8,965 7,750 PROD1 DRILL WPRT P Wiper trip to 7500 with tie in, PUW=30K, 20:45 21:21 0.60 7,750 7,782 PROD1 DRILL DLOG P log base of Cl, missed marker, PUH to 7730, Correction+25, inspected counter looks good. Lube counter chain. 21:21 22:00 0.65 7,782 8,989 PROD1 DRILL WPRT P RBIH,stack out at 8515 with stall, Attemp to log 8520 to 8658,Stack out @ 20 FPM, stack out @ 8666 with stall. 3K stack @ 8550,Stack @ 8670. Clear running below 8700 Page 6 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 23:36 1.60 8,989 8,989 PROD1 DRILL WPRT P 8995 PUH to sort depth issues with MAD pass up 7990 to 7867, RIH taking check shots 23:36 00:00 0.40 8,998 8,995 PROD1 DRILL DRLG P 8998', Drill, 1.47 BPM @ 2730 PSI FS, BHP=3500,WHP=0 38/22/2015 Drilled 8995 to 9250, None to minimal returns, lost 1579 BBIs/24 Hrs 00:00 03:36 3.60 8,995 9,011 PROD1 DRILL DRLG P 8995', Drill, 1.47 BPM @ 2730 PSI FS, BHP=3500,WHP=0, Good weight transfer, Low ROP 03:36 06:36 3.00 9,011 9,016 PROD1 DRILL DRLG P Stall, PUW=29K, Drilling 1.46 BPM @ 2930 PSI FS, BHP=3520, WHP=0, Low ROP, Returns=.45BPM. Hard ankerite, stalled, PUW=32K. Continue drilling,stalled again. 06:36 12:51 6.25 9,016 9,038 PROD1 DRILL DRLG P Drill ahead: 1.43 BPM @ 3010 PSI, BHP=3495 PSI, CTW=11.5K, WOB=2.5K, ROP less than 10. PUH, another stall @ 9,016', back ream. 12:51 15:12 2.35 9,038 9,085 PROD1 DRILL DRLG P Continue drilling: 1.43 BPM @ 3040 PSI, BHP=3520 PSI, CTW=9.5K, WOB=2.4K. Still slow going, lost returns again temporarily, pumped another 20 bbl high vis pill, returns coming back slowly, rate out.40 BPM. 15:12 17:48 2.60 9,085 9,140 PROD1 DRILL DRLG P Continue drilling: 1.45 BPM @ 3125 PSI, BHP=3485 PSI, CTW=8.5K, WOB=2.3K, ROP=25, lost returns again to.25 BPM @ 9,095',slowly increasing. 17:48 19:48 2.00 9,140 9,165 PROD1 DRILL DRLG P Drilling, Lost all returns, annular pressure drop, 1.45 BPM @ 2680 PSI FS, BHP=3299 19:48 20:36 0.80 9,165 9,165 PROD1 DRILL WPRT P 9165',Wiper to 8100', PUW=32K, B-C!transition area 8560 to 9800' looked good,small stack @ 9115 20:36 00:00 3.40 9,165 9,250 PROD1 DRILL DRLG P 9165', Drill 1.45 BPM @ 2840 PSI FS, BHP=3375, No to very little returns 08/23/2015 Drill 9250 to 9938, Minimal returns, Lost 1838 BBLs/24 Hr 00:00 04:12 4.20 9,250 9,365 PROD1 DRILL DRLG P 9250', Drill 1,45 BPM @ 2840 PSI FS, BHP=3430low, <.2BPM returns 04:12 05:12 1.00 9,365 9,365 PROD1 DRILL WPRT P Wiper to 8300', PUW=32K 05:12 10:12 5.00 9,365 9,565 PROD1 DRILL DRLG P Drill ahead. 1.45 bpm, Rtns@0.20. BHP=3467. ROP all over. 10:12 12:12 2.00 9,565 9,565 PROD1 DRILL WPRT P Wiper trip 7760'. PUW=32K Tie in to GR @ 7742'. +7'correction. 12:12 16:48 4.60 9,565 9,765 PROD1 DRILL DRLG P Drill ahead. 1.43 bpm, Rtns@0.21, ROP=all over', BHP=3469 psi. 16:48 17:30 0.70 9,765 9,765 PROD1 DRILL WPRT P Perform wiper to 8850', PUW=31K 17:30 20:06 2.60 9,765 9,864 PROD1 DRILL DRLG P 9765', Drilling, 1.45 BPM @ 2850 PSI FS, BHP=3478 Page 7 of 11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:06 20:18 0.20 9,864 9,864 PROD1 DRILL WPRT P Pull 100'wiper, stacking, low surface weight, PUW=36K 20:18 00:00 3.70 9,864 9,938 PROD1 DRILL DRLG P 9864', Drill, 1.45 BPM @ 2850 PSI FS, BHP=3450 38/24/2015 Drill 9938 to 10082, POOH to check BHA and P/U agitater, Lost 1527BBIs/24 Hrs 00:00 02:24 2.40 9,938 9,965 PROD1 DRILL DRLG P 9938, Drilling, 1.45 BPM @ 2850 PSI FS, BHP=3465 02:24 03:42 1.30 9,965 9,965 PROD1 DRILL WPRT P Wiper trip to 8400', PUW=31K, Small weight bobble @ 8645 RIH. Clean trip PUH 03:42 08:36 4.90 9,965 10,038 PROD1 DRILL DRLG P 9965', Drill 1.45 BPM @ 2850 PSI FS, BHP=3500,WHP=0 08:36 08:42 0.10 10,038 10,038 PROD1 DRILL WPRT P Wgt check/wiper to 9938'. PUW=30k. 08:42 09:12 0.50 10,038 10,038 PROD1 DRILL DRLG P Drill ahead; pumping 1.43 bpm, rtns .12. ROP=4'/hr. Pump 5/5 low/hi sweep.Sweep on bottom. 09:12 12:18 3.10 10,038 10,082 PROD1 DRILL DRLG P Drill ahead. Pump 20 bbls with full lubes. See no significant change. 1.43 in, 0.06 out, BHP=3634. ROP=9'/hr. 12:18 15:30 3.20 10,082 0 PROD1 DRILL TRIP P Begin POOH for bit check and to add agitator. PUW=30k. Rate=1.44, out=0.13, BHP=3425, Pump=2735. Attempt to follow managed press schedule. BHP=3425 psi. Overpull @ 8700'and 7893'. 15:30 17:00 1.50 0 0 PROD1 DRILL BHAH P Pressure undeploy drilling BHA, pumping down manged pressure line. 17:00 18:00 1.00 0 0 PROD1 DRILL BOPE P Perform Bi weekly BOPE function test, 18:00 19:00 1.00 0 0 PROD1 DRILL RGRP P Replace valve P7 in HP discharge line in pits 19:00 21:54 2.90 0 78 PROD1 DRILL BHAH P PJSM, M/U BHA#5 with.5°motor, new bi center bit with Helios cutters, and agitator. Pressure deploy and surface test 21:54 23:12 1.30 78 7,380 PROD1 DRILL TRIP P RIH, EDC Open 23:12 23:30 0.30 7,380 7,404 PROD1 DRILL DLOG P Tie into K1 for-7'correction, Close EDC 23:30 00:00 0.50 7,404 8,825 PROD1 DRILL TRIP P Continue in hole,clean trip through window 08/25/2015 Drill ahead from 10,082'. Attempt to drill ahead with KCL/Clay Guard from 10,220'to 10,371',trouble getting back down.Swap back to 9.1 ppg drilling mud. Continue drilling ahead with minimal returns to called TD at 10,553'. POOH. RIH with Weatherford IBP. 00:00 00:30 0.50 8,825 10,085 PROD1 DRILL TRIP P Continue in hole, EDC closed 00:30 03:30 3.00 10,085 10,285 PROD1 DRILL DRLG P 10085', Drill, 1.45 BPM @ 3300 PSI FS, BHP=3395, Swapped to KCL and clay guard, Got to bit @10,220', Lost-100PSI circ pressure off bottom. ROP coming and going like previous BHA _._ _ Page 8 of 11] Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 10,285 10,285 PROD1 DRILL WPRT P Wiper trip to 9285, PUW @ 38K, dragging 34K. Clean trip up, Set down @ 10110 picked up and went right through, Pumped 20 BBI sweep 04:30 05:42 1.20 10,285 10,371 PROD1 DRILL DRLG P 10220', Drill, 1.45 BPM @ 2770 PSI FS, BHP=3290, RIW=BK 05:42 05:57 0.25 10,371 10,371 PROD1 DRILL WPRT P BHA Wiper, 38k PUW. Close choke to bring up BHP. 05:57 07:15 1.30 10,371 10,371 PROD1 DRILL DRLG P Pull 200'wiper, having problems getting down. 07:15 10:09 2.90 10,371 10,485 PROD1 DRILL DRLG P Swap back to FloPro. Drilling. 10:09 11:09 1.00 10,485 10,485 PROD1 DRILL WPRT P Pull 44k off btm.wiper up to 9485', RBIH. 11:09 14:09 3.00 10,485 10,553 PROD1 DRILL DRLG P Drill ahead 1.45 BPM 3163 psi. .27 ./ on returns,38 ROP. Call TD @ 10553'. 14:09 15:15 1.10 10,553 7,640 PROD1 DRILL TRIP P PUH into window,stop @ 7640. 15:15 16:00 0.75 7,640 7,640 PROD1 DRILL LOT P @ 7640', Shut in choke,shut down pumps.Annular @ 3260 psi.watch for 15 minutes.Annular pretty flat @ 2845 psi. Pumps back on, leave choke closed, pump 20 bbls to get slight returns. 16:00 17:24 1.40 7,640 82 PROD1 DRILL TRIP P Pooh to surface. 17:24 18:15 0.85 82 82 PROD1 DRILL OWFF P On surface, monitor well for flow, crew change out, PJSM-lay down BHA. 18:15 19:45 1.50 82 0 PROD1 DRILL PULD P Lay down BHA#5,drop HOT and USR from BHA, configue BHA for IBP per plan forward. 19:45 21:00 1.25 0 49 COMPZ CASING PULD P PJSM-Bring in and MU 2.125" Weatherford IBP to BHA#6. 21:00 22:51 1.85 49 7,360 COMPZ CASING TRIP P RIH with BHA#6, EDC open, pump 7 bbl before catching fluid. 22:51 23:03 0.20 7,360 7,390 COMPZ CASING DLOG P Tie in at K1 for minus 8.5-ft correction, 23:03 00:00 0.95 7,390 7,636 COMPZ CASING TRIP P RIH to right above window,wait on IBP to climatize while keeping hole full. 08/26/2015 IBP pre-set above window at 7,645-ft. POOH. Retrieve IBP#1. Set Weatherford 2.125"IBP at 10,040-ft mid element. Pump beaded liner pill in 9.1 ppg mud. RIH with lower"A"liner segment-bull nose,40 jts slotted, shorty deployment sleeve. Lost 288 bbl/24 hrs. 00:00 01:30 1.50 7,636 7,645 COMPZ CASING TRIP T Continue to climatize IBP, BHT 106° to 118°,shut down pumps, close EDC, PUW above window 31k, RBIH pumps off,stack out 4k at 7,645-ft, PUW 31k,stack out at same depth 2 more times, no joy, open EDC. 01:30 04:00 2.50 7,645 49 COMPZ CASING TRIP T POOH,tie in at K1 0-ft correction, no over pull at DS nipple at 7,290-ft, getting good returns, IBP left at 7,645-ft,top of IBP at 7,638-ft. 04:00 04:30 0.50 49 49 COMPZ CASING OWFF T On surface, monitor well for flow. PJSM Page 9of11 ' Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:15 1.75 49 44 COMPZ CASING PULD T LD IBP running tool, setting sleeve not sheared. MU IBP retrieving tool to BHA. 06:15 08:00 1.75 44 7,630 COMPZ CASING TRIP T RIH w/IBP retrieving tool. Tie in for a -8 corr. Pick up wt of 29k @ 7630'. 08:00 08:30 0.50 7,638 7,638 COMPZ CASING FISH T Pumps up, EDC closed, flowing fluid out of the pulling tool.Wash on to the fishing neck,tag @ 7638'. Shut down the pump allow to equilize& dogs on catch to retract on the F/N. Pull 4k over pulled free. PUH 30', RBIH past 7638', appears fish is on, 08:30 10:15 1.75 7,638 44 COMPZ CASING TRIP T POOH. open EDC to alow fluid in the coil to fall out above pulling tool. Pump over the top to keep hole full. 10:15 10:45 0.50 44 44 COMPZ CASING OWFF T Good no flow test, 30 minutes. PJSM for lay down. 10:45 11:15 0.50 44 0 COMPZ CASING PULD T Lay down BHA#7. Have IBP fish. Nothing apparent on IBP why it set early. 11:15 12:00 0.75 0 49 COMPZ CASING PULD T PJSM-Pick-up BHA#8, Weatherford IBP. 12:00 15:00 3.00 49 10,060 COMPZ CASING TRIP T RIH W/Weatherford IBP(with EDC open)tie in for-8 corr. RIH to 10,060° NOTE:Trouble time stops at 14:00 when window passed. 15:00 15:45 0.75 10,060 10,040 COMPZ CASING PACK P Pull up hole, 31k stop @ 10040'mid element. Close EDC, DP bore/annular increasing again.Watch for 15 minutes&allow plug to climatize. Pressure up down coil in stages, plug set @ 1300 psi. Pick off plug clean. 15:45 19:00 3.25 10,040 48 COMPZ CASING CIRC P Open EDC, line up pumps down coil thru EDC. Line up for 9.1 beaded pill, displace down to EDC. POOH. 19:00 19:30 0.50 48 48 COMPZ CASING OWFF P On surface, monitor well for flow. PJSM for BHA lay down. 19:30 20:00 0.50 48 0 COMPZ CASING PULD P LD BHA#8. 20:00 20:45 0.75 0 0 COMPZ CASING PUTB P Prep floors for running liner. 20:45 00:00 3.25 0 1,254 COMPZ CASING PUTB P PJSM-MU bull nose,40jts slotted, shorty deployment sleeve. 38/27/2015 Run"A"liner in 2 segments, lower-bull nose,40 jts slotted,shorty deployment sleeve from 10,030-ft to 8,776-ft. Upper-ported bull nose, 1 jt slotted,XO, 32 jt solids, Halliburton SwellPacker,3 jts solids,XO,2 solid pup jts, SBR deployment sieve, unable to get to bottom,top of SBR at 7,625-ft, est 24-ft open hole between liner segments. Swap well over to seawater. Freeze protect from 2,500-ft. PUD BHA#10. Begin flushing stack. 00:00 01:00 1.00 1,254 1,298 COMPZ CASING PUTB P MU bull nose,40 jts slotted,shorty deployment sleeve to BHA#9 01:00 03:42 2.70 1,298 10,030 COMPZ CASING RUNL P RIH with BHA#9.Tie in to flag for minus 13.5-ft correction. PUW 30k. RBIH. on depth, PUW 35k, RBIH. release off liner at 10.030-ft, PUW 29k. reset depth counters. � __ „Pa,ge 10 of 11 ' • ' Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:42 06:33 2.85 8,776 44 COMPZ CASING DISP P Open EDC, line up pumps down coil thru EDC. Line up for 10.0 ppg NaCl/NaBr beaded pill,displace down to EDC. POOH. 06:33 07:00 0.45 44 44 COMPZ CASING OWFF P Tag up.Watch well for flow for 30 minutes. No flow,top off well. 07:00 08:30 1.50 44 0 COMPZ CASING PUTB P PJSM. Lay down BHA#9. 08:30 12:45 4.25 0 1,171 COMPZ CASING PUTB P PJSM. PU liner run#2.jt of slotted, solid 33,jts, Halliburton swell PKR (measured @ 2.68"at the element)3 jts of solid,&deployment sleeve. 12:45 17:24 4.65 1,171 8,747 COMPZ CASING RUNL P RIH w/liner run#2. See flag @ -48.64 on BHi counter???Run by K-1 on the fly, see+6'corr. Had to work&cycle pipe @ 8695',8721, (4), 8747(18)times. Hard tag @ 8747'. Pumped off&subtracted liner from counter. Re-log K-1 for a+7' correction. RBIH,tag top of upper liner©7625'. Top should be 7649'. 24'high. Confer with town. 17:24 19:45 2.35 7,625 2,500 DEMOB WHDBO DISP P Swap well over to seawater, POOH. MI-PJSM, RU LRS. P/T lines and equipment, pump 30 bbl diesel down tubing, RDMO LRS. 19:45 20:45 1.00 2,500 44 DEMOB WHDBO FRZP P Freeze protect from 2,500-ft, POOH. 20:45 22:45 2.00 44 0 DEMOB WHDBO PULD P PJSM-Undeploy and LD BHA#9 22:45 00:00 1.25 0 0 DEMOB WHDBO RURD P Flush stack&surface line with inhibited FW, clean pits. 08/28/2015 Flush and inhibit coil,surface lines and stack. Set BPV. ND BOPE. RDMO Rig release @ 08:00. 00:00 02:00 2.00 0 0 DEMOB WHDBO RURD P Flush stack&surface line with inhibited FW, clean pits. 02:00 05:30 3.50 0 0 DEMOB WHDBO MPSP P PJSM-Bring in FMC equipment. Attempt to set BPV, running tool not working right. FMC hand hotshot for another running tool and backup BPV. Set BPV. Test from below. Off load FMC equipment. 05:30 07:00 1.50 0 0 DEMOB WHDBO RURD P Nipple down BOPE. Check tree bolts(40 minutes, 11 loose bolts) Note: Final SITP 90 psi 07:00 08:00 1.00 0 0 DEMOB WHDBO RURD P Complete rig move checklist Note: ** Rig released at 0800 hrs �_.._ . Page 11 of 11 1G-11 WELL WORK SUMAMRY 'DATE ' SUMMARY • • POST-RIG WELL EVENTS 9/1/2015 TAGGED LINER TOP @ 7625' RKB W/2.75" BAR BELL ASSY&2.46" LIB. SET 35 KB PACKER W/AVA SEAL ASSY IN LINER TOP @ 7625' RKB. IN PROGRESS. 9/2/2015 MEASURED BHP @ 7615' RKB: 2775 PSI. SET 2.75"AVA CATCHER ON KB PACKER @ 7620' RKB. PULLED DV's FROM 6164', 5299', 4127', &2705' RKB. SET 1/4" OV @ 6164' RKB. SET 3/16"GLV's @ 5299', 4127', &2705' RKB. PULLED CATCHER. IN PROGRESS. 9/3/2015 RAN TEST TOOL TO KB PACKER @ 7620' RKB. MITT 2500 PSI, PASSED. COMPLETE. • • • W at_ MAIO Nil ma Q= NIA V" 0. 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O O Ni m ro ro a o , 0*' Cri V M N N (N) 0 co N O O O M y 6 V V V 0N CO .V. c T O O O O O O LC) t73 arn d V o U E o ai d m y 0 a o) o CC € Nro _i • 21 5125 2 6 2 3.3 BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY ConocoPhillips Baker Hughes INTEQ DATA LOGGED (mandatory) 795 East 94th Avenue cl/q/zot5 WELL NAME 1G-11A Anchorage,Alaska 99515 iv,. K.BENDER (mandatory) FIELD Kuparuk River Unit to acknowledge receipt of this data. (mandatory) COUNTY North Slope Borough LOG TYPE LWD-Coil (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: August 28,2015 TODAYS DATE: 3-Sep-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Patrick Rider EMAIL: 1trick.rider(a�bakerhughes.co (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD Final CD ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRIN I S #OF COPIES #OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 2 BP Exploration(Alaska)Inc. I 1 I 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson 3 Chevron/KRU Rep 1 1 1 Attn:Glenn Frederick P.O.Box 196247 Anchorage,AK 99519 4 State of Alaska -AOGCC I 1 I 1 I 2 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I I 1 de`� I Attn:Sean Clifton ��" �h • ,550 West 7th Avenue,Suite 802 U �J /► Anchorage,Alaska 995011241 �,.( B ***Stamp"confidential"on all material deliver to DNR C3` PO TOTALS FOR THIS PAGE: 0 3 4 4 4 0 TOTALS FOR ALL PAGES: 0 3 4 4 4 0 Lt') • 0 M N M :-N !n CD iA N • W MI Z `W; iii -i0 gZ 111 o ( leil CC 0- I C t CD O CU o w W a Q i--- >, ki, Z w E IIMINN s O CO D. T ; 0 0 § z Rco & X§ _ _ _ §I 0 a' cc) \ u) 2c' ° ~ / .2J ] » \ U § o0 a , Lo - ^ t( ( I u) / \ —1 CO # 0. j 3 \ \ \ ! 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ICN} } LN2O\ \ S'NI 2 E \ N 2 £ 2 & / / \ ( / © CO CO N . . / 2 c co } LOU)} 0 } \ CO E2 4 •C \ N NNNN un \ \ \: , , ; N ,i- ,r\ \ \ , o-, a) =E \ 0 3 hi /§ [ ¥ £ .. \ 22 � , � \ƒ dkk !2 uk , • • . r 215125 26176 Letter of Transmittal vI BAKEDate: DATA LOGGED HUGHESAugust 27, 2015 q /1/2015 K.BENDER To: From: Makana Bender Yosha Ragbirsingh I Michael Soper AOGCC Baker Hughes TIN 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 1G-11A RECEIVED AUG 282015 AOGCC (1) Total print Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. 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Cri V LO N CO CO CO O (7 oN N O O O M (y N N OM V V V N L() © co 8 >,O 2 v o 0 0 o O N. (0 O. 5S' 5 . U S O CO 141,1,';„!,1 " a3 • • OF` rij 0 • 6.0 1 v tv THE STATE Alaska Oil andGas i�, of Conservation Commission ,_ ul, ,..„...,. ._ _ -,._,:., 333 West Seventh Avenue ;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \ Main: 907.279.1433 ®F ALAS'- Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-11A ConocoPhillips Alaska, Inc. Permit No: 215-125 Surface Location: 327' FSL, 806' FWL, SEC. 29, T12N, R10E, UM Bottomhole Location: 1557' FSL, 2124' FWL, SEC. 32, T12N, R10E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, (---4P--(4 CL— Cathy P. oerster Chair /- DATED this (p day of August, 2015. 0 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 1 2015 PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑✓ - Service-Winj ❑ Single Zone Q 1 c.Specify if well is proposed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill 0- Reentry L Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Lij Blanket L Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. - Bond No. 59-52-180 , KRU 1G-11A • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10976'- TVD: 6436' - Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:327'FSL,806'FWL,Sec.29,T12N, R10E, UM ADL 25640• Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1574'FNL, 1236'FEL,Sec. 32,T12N, R10E, UM 2571 8/20/2015 Total Depth: 9.Acres in Property: 14.Distance to 1557'FSL,2124'FWL,Sec.32,T12N, R10E, UM 2459 • Nearest Property: 20200 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: •99 feet 15.Distance to Nearest Well Open Surface:x- 540586 y- 5980976 Zone- 4 • GL Elevation above MSL: 63 feet to Same Pool: 1G-14,1040 16.Deviated wells: Kickoff depth: . 7660 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: - 97° deg Downhole:2898 psig, Surface:2270 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 3321' 7655' 6451' 10976' 6436' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 8208' 6918' 7831' 7359' 6200' none Casing Length Size Cement Volume MD TVD Conductor/Structural 68' 16" 212 sx CS II 106' 106' Surface 2314' 10.75" 930 sx AS III,250 sx AS I 2351' 2206' Production 8151' 7" 610 sx Class G,250 sx AS I 8188' 6901' Scab Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7540-7590,7676-7722,7945-7950,7960-7982 6355-6397,6469-6507,6694-6698,6706-6725 20.Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mike Win free @ 263-4404 Email Michael.A.Winfree@cop.com Printed Name D. =nha Title CTD Engineering Supervisor � Signature Ii1^- Phone:263-4372 Date 7'!00'i5 Commission Use Only Permit to Drill API Number: `yam Permit Approval See cover letter Number: 62/,,,5-- 12. 50- ©Q� aI0©�"-01 —W Date: x 1( (I 6 1for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m bane,gas hydrates,or gas contained in shales: d Other: 30P test -td j000 Sr. SSA les req'd: Yes ❑ No [J Mud log req'd: Yes❑ No[r. /1}rr e�v/ca r r-c Ircvy r/ -s t `"R measures: Yes t[ No __co Directional svy req'd: Yes" No❑ //� Spacing exception req'd: Yes ❑ No LA Inclination-only svy req'd: Yes❑ No[� (J _ APPROVED BY THE iQ Approved by: �� ` • -4.I N R COMMISSION Date: 7J Form 10-401 (Re Z 1k. 6 p it s - 'd o r tF�from the date of approval(20 AA 05( r�1`LA 7' 2,t, 1 J� • • ConocoPhillips RECEIVED p Alaska JUL 21 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC July 16, 2015 Commissioner-State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the Kuparuk Well 1G-11 using the coiled tubing drilling rig, Nabors CDR2-AC. CTD operations are scheduled to begin at the end of August, 2015. The objective will be to drill laterals KRU 1G-11A, and 1G-11AL1 targeting the Kuparuk Cl and C3/4 sands respectively. Attached to this application are the following documents: — 10-401 Applications for 1G-11A and 1G-11AL1 — Detailed Summary of Operations — Directional Details for 1G-11A and 1 G-11AL1 including anti-collision — Proposed CTD Schematic If you have any questions or require additional information please contact me at 907-263-4404. Sincere, Mike A. Winfre- ConocoPhillips Alaska Coiled Tubing Drilling Engineer • • Kuparuk CTD Laterals NABORS ALASKA 1G-11A & 1G-11AL1 CIJ ConocoPhOnps Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 5 (Requirements of 20 AAC 25.005(c)(13)) 5 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review (for injection wells only) 7 (Requirements of 20 AA C 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1G-11A&AL1 7 Attachment 2: Current Well Schematic for 1G-11 7 Attachment 3: Proposed Well Schematic for 1G-11A&AL1 7 Page 1 of 7 7/20/2015 • • PTD Application: 1G-11A & AL1 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1G-11A & AL1. Laterals will be classified as "Development- Oil' well. v 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the Cl & C3/4 sand packages in the Kuparuk reservoir. See the attached 10-401 form for surface and subsurface coordinates of the 1G-11A &AL1. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the maximum formation pressure in the area of 2898 psi in the 1H-08,the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft, would be 2270 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details. - The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) 1 Reservoir Pressure and Maximum Expected Downhole Pressurela(3 (Requirements of 20 AAC 25.005 (c)(4)(a)) A static bottom hole pressure of 1G-11 C sand in January 2015 indicated a reservoir pressure of 2794 psi or 8.4 ppg equivalent mud weight. The maximum down hole pressure in the 1G-11 pattern is at 1H-08 with 2,898 psi. It is not expected that the 1G-11 reservoir pressure will be as high as 1H-08. The 1G11A &AL1 well bores are planned over 4,000ft from the 1 H-08 well. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled. Gas injection has been performed on 1G pad, so cuttings will be monitored for entrained gas. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) Exposed shale while drilling the 1G-11 laterals, especially at fault crossings, has the potential to cause hole problems. Managed pressure drilling equipment will be used to keep pressure on the well bore to minimum of 11.8ppge, which has historically kept shale sections stabilized at Kuparuk. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. Page 2 of 7 7/20/2015 • PTD Application: 1G-11A & AL1 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS IG-11A 7,655' 10,976' 6,451' 6,436' 23/", 4.7#, L-80, ST-L slotted liner; with a shorty deployment sleeve.. 1G-11AL1 7,609' 10,303' 6,412' 6,389' 2%", 4.7#, L-80, ST-L slotted liner; with a shorty deployment sleeve. Existing Casing/Liner Information Category OD Weight Grade Conn. Top Btm Top Btm Burst Collapse (P130MD MD TVD TVD psi psi Conductor 16" 65 H-40 Welded 38' 106' 0' 106' 1640 630 Surface 10-3/4" 45.5 J-55 BTC 37' 2,351' 0' 2,206' 3580 2090 Casing 7" 26 J-55 BTC 37' 8,188' 0' 6,901' 7240 5410 Tubing 3 1/2" 9.3 L-80 EUE8Rd mod 31' 7,366' 0' 6,212' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride weighted FloVis water based mud (9.1 ppg) r — Drilling operations: Chloride weighted FloVis water based mud (9.1 ppg). This mud weight will hydrostatically overbalance the reservoir pressure. — Completion operations: Liner running operations will be done with 11.8ppg Bromide weighted completion fluid to maintain well bore stability during completion operations. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the coiled tubing stripper and MPD choke which are not part of the BOP equipment but are tested to the same pressure and frequency as the BOPE as detailed in section 3 "Blowout Prevention Equipment Information". The targeted MPD BHP will be 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Page 3 of 7 7/20/2015 • PTD Application: 1G-11A & AL1 Pressure at the 1G-11A Window(7660' MD, 6455' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Pressure (8.4 ppg) 2794 psi 2794 psi Mud Hydrostatic (9.1 ppg) 3055 psi 3055 psi Annular friction (i.e. ECD, 0.090 psi/ft) 690 psi 0 psi Mud + ECD Combined 3745 psi 3055 psi (no choke pressure) (over balanced (over balanced —950 psi) —261 psi) Target BHP at Window(11.8 ppg) 3960 psi 3960 psi Choke Pressure Required to Maintain Target BHP 215 psi 905 psi Pressure at the 1G-11AL1 Window(7614' MD, 6416' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Pressure (8.4 ppg) 2794 psi 2794 psi Mud Hydrostatic (9.1 ppg) 3035 psi 3035 psi Annular friction (i.e. ECD, 0.090 psi/ft) 685 psi 0 psi Mud + ECD Combined 3720 psi 3035 psi (no choke pressure) (over balanced (over balanced —926 psi) —241 psi) Target BHP at Window(11.8 ppg) 3937 psi 3937 psi Choke Pressure Required to Maintain Target BHP 217 psi 902 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A—Application is for a land-based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Page 4 of 7 7/20/2015 • • PTD Application: 1G-11A & ALA 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background KRU 1G-11 will be a dual lateral producer. A recent RWO was performed to replace the tubing to allow for CTD operations. The objective of this well is to drill 2 laterals on either side of a E-W fault to develop the C sand regions in the area. 1G-11A will kick off in the C2 sand at 7,660'MD via a 2 string cemented window exit,then land in the B shale. An evaluation of the Cl resistivity log will be made after landing and the well. The well will continue to be drilled in the B shale for an additional 800 feet to bypass the fully swept Cl near the parent well. Length of B shale footage drilled before turning up to reacquire the Cl sand will be determined once the Cl log near the window has been analyzed. The 1G-11A lateral has two potential faults mapped with variable throw predicted in the 10-25' range. TD is planned at 10,976' MD. The lateral will be completed with 2-3/8"slotted liner with the liner top placed inside the window at 7,655' MD. 1G-11AL1 will kick off the billet at 7,614'MD in the C2 sand via a 2 string cemented window exit. The well bore will drop into the Cl before turning up to acquire the C3/4 interval. The well will be geosteerd in pay until TD at 10,303' MD. The lateral will be completed with 2-3/8" slotted liner with the liner top set inside the window at 7,609' MD. Pre-CTD Work • Coil: Cement 3'/2"x 7"annulus around planned window area to support CTD casing exit • E-line: Set a 31/2'thru-tubing whip-stock at 7,660' MD and 0°HS Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1G-11A Lateral(C1 sand- South) i. Mill 2.80"window at 7,660' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10,976' MD iii. Run 2%"slotted liner with deployment sleeve from TD up to 7,655' MD 3. 1G-11AL1 Lateral(C3/4 sand -North) i. Mill 2.80"window at 7,614' MD ii. Drill 2.70"x 3.00"bi-center lateral to TD of 10303' MD iii. Run 2%" slotted liner with deployment sleeve from TD up to 7,609' MD 4. Freeze protect the well. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. 3. Put back on production Page 5 of 7 7/20/2015 • • PTD Application: 1G-11A & AL1 Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. — The 1G-11 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AA C 25.005(c)(14)) • No annular injection on this well. • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 7 7/20/2015 • • PTD Application: 1G-11A & AL1 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. ✓ — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name, . E ~` 1G-11A 20,200' 1 G-11 AL1 19,950' — Distance to Nearest Well within Pool (measured to offset well) L, f 'al Name ©ls rc ' fi r t- t , 1G-11A 1,040' 1G-14 1 G-11 AL1 990' 1 G-10BL2 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) NA- 1G-11 is a production well. 17. Attachments Attachment 1: Directional Plans for 1G-11A &AL1 Attachment 2: Current Well Schematic for 1G-11 Attachment 3: Proposed Well Schematic for 1G-11A & AL1 Page 7 of 7 7/20/2015 • • it(V .. m 3-0 ro I` m _ n a r n aj w mC -5,- Q O Q) M N N m O V v O O O V p m (V 0 4) N V - r- r E 2 Eo - - 4) = O N _N �1�q�q\\� L g 1`1- c;(13 an 2 m :1 Q! m ° ywmoU 3O U O OI,:pOW m n 1,24; a c : 3p lo O E Of- E , UEN , maES oEW2s y O NUUU - ' rrn Uma Uca VN(V 0(V C4;-. 44NV .7“.v, . N a N "UOrc �NCrN mm MrWm0 o I o F- � A L',:' .,...._ 0 „ „C ...i.,„.„, tt,-. 3 .. .4.,. .„.„,,,,.„,,,,,„ vJ �* . H M M M I o p a '6 (7) 4m op I L00 22 p " p u a eL WU . mN nO M rN W O a N c'u 'Cr w N a0t0 p hf.....@OV a� cvE c �=m b00 nrE Q( cN WV Nc0o OUUU @_=_ Nio @ Uc YQ CO • • ozs u) I I N O M 11 co to Q O 1 1 (0N- CO6) I I C O O I I Q t0 r9 1 I (D- cso u) 11 N 1 1 t` 10 co _ C Q 1 1 O01 M O Q N II C N f— O- 1 I N N_ (6 o N 11 II (6 CO)Pr CD COp Cl) I I 0 0 la U lfC . O I -O y.- w 'cY p c, n C Q ) N C 7 N Q N O- �' C N co V W t ,CO I I O ,...4„..: 35 N f� r-O 0 M 11 Q N I M N 76 CU 06 N I �--zo v + I I -N knit 0 N O_ a O) Q aOQ O -6 0 c Q C r O- H aIEL8pl _ N - I dN •O(MO M� M M �N� I�i C M C^r CO h W Q' Iall ; 8: .52 r w (0 U N :00 U IIVW :or,_ U)t6 7C) NOI IN� ) p7Y Q'� I I [DOU O '' I I OJO. OU cLOO)CUQyU C m HI I Y* J E N o C Q rn f6 Q E .0 M cDai 0 00 c wty 0 i, >Q> Ute" i il0 N N N N y l N 4 > N N NI I r ) N I1 c6 f6 ')C CU r r 1 1 NC') C)I- m m AA W C)O M U O M M I I III / // 8 / i 1. U — 1 e ..1,D,1'Fii V, 1,- ;/3'=m/t/w'aitta)'i.xkv-iil, ,) ''..-.A_o ' 9 3 1 1;;I.I.r A i.; 1,',,���I I�, 11 /'.µ �, ,;.,I I I U Ip p�� o 0 0 p pp Q~ 2a) o� a c Q Lo 22 �U o o ,nQ �_ CV L k In t/) I� 2-O co co N 0 01 *c0 r- o LOM N (1) . , r` 4) EE c a� m� p n o Zo o)5 _ _ m - . N N N N a r g N-0 2 N Zr) �L � UMC) , QIP CO a O m U U U N it II �= m c°Ud d ,,'coo 0 0Qc0c1:-0 I AV KUP PROD • IG-11 ConocoPhilhps Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status ncl I') MD(ftKB) Act Btm(ftKB) Conncdtntrls500292100800 KUPARUK RIVER UNIT PROD 41.68 4,900.00 8,208.0 44. ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 10-11,6/24/2015 4:21:07 PM SSSV:NONE 100 12/16/2013 Last WO: 3/15/2015 40.99 9/19/1983 Vertical schemaoc faaua� Annotation Depth(ftKB) End Date Annotation Last Mod By End Date �� Last Tag:SLM 7,946.0 6/10/2014 Rev Reason:GLV C/O lehallf 6/24/2015 HANGER;31 2 L-h!J` Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND). WtlLen(I Grade Top Thread �� I CONDUCTOR 16 15.250 38.0 106.0 1060 6500 H-40 WELDED 4 ( I' Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth IND)... WtlLen(I...Grade Top Thread SURFACE 103/4 9.950 370 2351.3 22061 45.50 J 55 BTC - tela Casing Descr pt on 0D(0) ID(n) Top(ftKB) Set Depth(ftKB) Set Depth IND).. WtlLen(1...Grade Top Thread 1i PRODUCTION 7 6.276 371 8187.7 69009 26.00 J 55 BUTT 1 fs,Tubing Strings CONDUCTOR,38.0-106.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 1 TUBING-WO 31/21 29921 31 2I 7,366.31 6,211 7I 9.301 L-80 I EUE8rd mod Completion Details ': T Nominal ID SURFACE,37.1-2,351.3--4 : Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 31.2 31.2 0.10 HANGER CIW TUBING HANGER 2.992 GAS LIFT,2,726.2 ,. 7,227.5 6,098.8 35.87 LOCATOR LOCATOR SUB 2.990 7,228.5 6,099.6 35.87 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 2.990 7,235.8 6,105.5- 35.85'PBR BAKER 80-40 PBR 4.000 7,258.3 6,123.8 35.81 PACKER BAKER FHL RETRIEVALBE PACKER 2.910 GAS LIFT,4,148.1 ilt 7,311.1- 6,166.7 35.63 NIPPLE 'CAMCO DS NIPPLE(PULLED RHC AND BALL AND 2.812 ROD,4 15 15) L 7,359.8 6,206.3 35.23 OVERSHOT 'POOR BOY TUBING OVERSHOT 3.750 GAS LIFT,5,320.5 Tubing Description 'String Ma...I ID(in) 'Top(ftKB) 'Set Depth(hi Depth(ND)(...'Wt(Ib/ft) 'Grade 'Top Connection i:. TUBING-ORIGINAL 41/2 2.992 7,361.3 7,841.2 6,606.2 920 J-55 FL4S Completion Details Nominal ID GAS LIFT,6,185.3 I,.'. Top(ftKB) Top(ND)(ftKB) Top not(°) Item Des Com (in) 7,376.2 6,2)9.7 35.10 SBR OTIS SBR(2.81"X NIPPLE PROFILE) 2.813 7,402.3 6,241.2 34.87 PACKER OTIS RRH PACKER 2.970 7,541.7 6,356.6 33.56 BLAST RINGS BLAST RINGS(3) 2.992 GAS LIFT;6,832.4 MI 7,657.2 6,452.9 33.74 BLAST RINGS BLAST RINGS(3) 2.992 7,812.7 6,582.3 33.28 LOCATOR OTIS LOCATOR 2.992 GAS LIFT;7.171 a fiE7,813.1 6,582.6 33.28 PACKER 'OTIS WD PACKER 4.000 1 7,816.5 6,585.4 33.25 MILLOUT 'OTIS MILL OUT EXTENSION 4.410 • rc 7,830.8 6,5974- 33.15 NIPPLE 'CAMCO D NIPPLE NO GO 2.750 LOCATOR;7,2275 7,8404 6,605.5 33.09 WLEG OTIS WIR LINE RE-ENTRY GUIDE,ELMD TTL @ 7822 3.015 SEAL ASSY,7,226 5 during PPROF on 9/27/2007 PER;7,2358 PACKER;7,2583 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) -'-- - Top(ND) TopIncl I F Top(ftKB) (HKB) (e) Des Com Run Date ID(in) '1 7,831.0 6,597.6 33.15 PLUG CA-2 PLUG w 12ft of SAND -4/23/2015 NIPPLE,7,311.1 4^•;' Perforations&Slots I Shot Dens .i Top(ND) Btm(ND) (shotstt Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,540.0 7,590.0 6,3552 6,396.9 C-4,1G-11 12/23/1983 12.0 IPERF 120 deg Phasing;5" OVERSHOT;7,359.8 I Dresser Atlas al 7,676.0 7,7220 6,468.5 6,506.7-C-1,1G-11 12/23/1983 12.0 IPERF 120 deg Phasing;5" SBR,7,376.2 i'.akDresser Atlas PACKER.7,402.3 7,945.0 7,950.0 6,693.5 6,697.7-A-5,1G-11 3/30/1984 4.0 APERF 90 deg Phasing,RigidJet ' IS PRODUCTION,7,437.7 III 7,960.0 7,980.0 6,706.2 6,723.2 A-4,1G-11 11/26/1993 4.0 APERF 180 deg.Phasing;163 CCW orientation;2 5/8" PRODUCTION,7,504.8 :.. Titan HC _ 7,980.0 7,982.0 6,723.2- 6,724.9 A-4,1G-11 3/30/1984 4.0 APERF 90 deg Phasing;RigidJet 1PERF,7,540.G7,590 0-= "' Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run (PERF;7,676.0-7,722.0 - N Top(HKB) (HKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,726.2 2,522.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 2 4,148.1 3,673.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 3 5,320.5 4.582.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 4. 6,185.3 5260.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 4/15/2015 PRODUCTION,7775.2 -: " 5 6,832.4 5,780.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 g. 6 7,171.4 6,053.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 3/23/2015 LOCATOR;7,812.7 7 7,437.7 6,270.2 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/21/2015 PACKER,7,613.1 8 7,504.8 6,325.9 OTIS SPM 1 PROD DMY BK 0.000 0.0 6/22/2015 MILLDUT;7,8165 .P.M4 9 7,775.2 6,551.0 OTIS SPM 1 PROD OPEN BEK 0.000 0.0 4/23/2015 Notes:General&Safety End Date Annotation NIPPLE;7,836e IN 1/20/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION PLUG;7,831.0 9/16/2010 NOTE:View Schematic w/Alaska SChematic9.0 WLEG,7,840.4 .. APERF;7.945.0-7,950.0- ^ APERF;7,960.0-7,980.0- APERF,7,980.0-7,982.0-J _- PRODUCTION',37.1-8,187.7-, • • • N 1��= ktlimo m ' , o 0 .___. _ __ ... . 11 N 1 I II - - ��pn J I �., k TQI 1 1 os I ' I _ it - t - , r _,,.., ,-. r.-,.. 1 ,, . , _,,_ -9,' , ' -+. I ' '°"..- I '' .0 =z�x { I > 1 I 1 zea - , dd w Iaaa! 4 0 -------Thz 1. W m- O —8 ; • 1- g a o v , — - r. 8 W pM h y oco �2 "tCC , o � a 0 9,- �— T N w . y , �' 0� �� °.o �^ O ti,,,, ..,,,,,...,,,6:-.4 ,-,-,.,..: . ._ .....m .WL-',0762 1 + + N.., h + , r O N ,N C r , ✓J G N 141110 ti m . V --. 31 -ate.] ____ -_ ___ O .�I 6 o . a 6t na-�� _.....-- _�_� 1 1 - o va=do 1 $ .....I __ , __- ........ ___ —- - =o n` 7. c -- g t 1 i o e. �A • o�� } ro i I r IA a ./j o CL U c i !OW - - eW • m 0 0 0 :a. o "vc,�.�C,' - 0 0 0 0 0 0 O h o p0 0 0 p0 0 8 0 ((���?Qpp� Y O r.iVO -V N , Oi tz O O O N N r 8 8 r 8 q „ V "" U (u?A3sn ocz)(+)tivoN/(-)gxnos ,_ • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-11 1G-11A Plan: 1 G-11 A_wp02 Standard Planning Report 06 July, 2015 ?dal BAKER HUGHES IP,- rAiii ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site:' Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A Design: 1 G-11A_wp02 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1G Pad Site Position: Northing: 5,981,540 78 usft Latitude: 70°21'37.826 N From: Map Easting: 540,089.12 usft Longitude: 149°40'27.705 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1G-11 Well Position +N/-S 0.00 usft Northing: 5,980,976.13 usft Latitude: 70°21'32.246 N +EI-W 0.00 usft Easting: 540,585.50 usft Longitude: 149°40'13.280 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1G-11A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 10/1/2015 18.85 81.00 57,501 Design 1G-11A_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 Vertical Section: Depth From(TVD) +N/-S', +E/-W Directiop 1'�j)�lq���i,l,r (usft) (usft). (usft) (,)I 0W1'r ,, ;� � 1,oi 0.00 0.00 0.00 225.00 7/6/2015 4:02.42PM Page 2 COMPASS 5000.1 Build 61 • 0 ®- ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A Design: 1 G-11A_wp02 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth r System +NI-S +El-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) :1I4j0y Target 7,600.00 33.47 128.40 6,306.23 -1,880.13 3,219.15 0.00 0.00 0.00 0.00 7,660.00 33.76 128.10 6,356.20 -1,900.69 3,245.24 0.56 0.48 -0.50 -29.92 7,685.00 43.76 128.10 6,375.67 -1,910.34 3,257.54 40.00 40.00 0.00 0.00 7,792.88 86.50 134.93 6,420.03 -1,974.44 3,328.40 40.00 39.62 6.33 10.00 7,955.58 89.43 200.00 6,426.52 -2,124.75 3,361.72 40.00 1.80 39.99 89.00 8,056.08 89.44 207.04 6,427.52 -2,216.84 3,321.64 7.00 0.00 7.00 90.00 8,256.08 89.94 221.03 6,428.62 -2,382.17 3,209.99 7.00 0.25 7.00 88.00 8,406.08 94.52 230.48 6,422.78 -2,486.62 3,102.78 7.00 3.06 6.30 64.00 8,706.08 97.08 251.44 6,392.12 -2,630.77 2,843.41 7.00 0.85 6.98 82.00 8,926.08 93.42 266.46 6,371.89 -2,672.56 2,629.04 7.00 -1.67 6.83 103.00 8,996.08 92.64 271.30 6,368.19 -2,673.92 2,559.17 7.00 -1.11 6.92 99.00 9,286.08 89.37 251.26 6,363.07 -2,717.65 2,274.06 7.00 -1.13 -6.91 261.00 9,636.08 87.35 226.84 6,373.24 -2,896.18 1,976.29 7.00 -0.58 -6.98 265.00 9,816.08 85.89 214.30 6,383.89 -3,032.39 1,859.66 7.00 -0.81 -6.97 263.00 9,966.08 94.99 219.55 6,382.74 -3,152.14 1,769.68 7.00 6.07 3.50 30.00 10,266.08 95.02 198.46 6,356.29 -3,412.01 1,625.59 7.00 0.01 -7.03 271.00 10,536.08 93.45 217.35 6,336.18 -3,648.84 1,500.10 7.00 -0.58 7.00 94.00 10,636.08 93.18 210.35 6,330.38 -3,731.70 1,444.53 7.00 -0.27 -7.01 268.00 10,736.08 89.67 204.29 6,327.89 -3,820.47 1,398.68 7.00 -3.51 -6.06 240.00 10,976.08 85.96 187.89 6,337.11 -4,050.06 1,332.42 7.00 -1.55 -6.83 257.00 7/6/2015 4.02.42PM Page 3 COMPASS 5000.1 Build 61 • ! ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A Design: 1 G-11A_wp02 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NL-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (0/100ft) (°) (usft) (usft) 7,600.00 33.47 128.40 6,306.23 -1,880.13 3,219.15 -946.83 0.00 0.00 5,979,113.66 543,814.48 TIP 7,660.00 33.76 128.10 6,356.20 -1,900.69 3,245.24 -950.74 0.56 -29.92 5,979,093.24 543,840.67 KOP 7,685.00 43.76 128.10 6,375.67 -1,910.34 3,257.54 -952.62 40.00 0.00 5,979,083.66 543,853.02 Start 40 dls 7,700.00 49.68 129.46 6,385.94 -1,917.18 3,266.05 -953.79 40.00 10.00 5,979,076.86 543,861.56 7,792.88 86.50 134.93 6,420.03 -1,974.44 3,328.40 -957.39 40.00 9.06 5,979,019.94 543,924.22 4 7,800.00 86.55 137.79 6,420.46 -1,979.59 3,333.30 -957.22 40.00 89.00 5,979,014.83 543,929.15 7,900.00 88.11 177.80 6,425.31 -2,070.20 3,370.26 -919.29 40.00 88.83 5,978,924.43 543,966.60 7,955.58 89.43 200.00 6,426.52 -2,124.75 3,361.72 -874.67 40.00 86.89 5,978,869.84 543,958.35 End 40 dls,Start 7 dls 8,000.00 89.43 203.11 6,426.96 -2,166.06 3,345.40 -833.92 7.00 90.00 5,978,828.44 543,942.26 8,056.08 89.44 207.04 6,427.52 -2,216.84 3,321.64 -781.21 7.00 89.97 5,978,777.54 543,918.78 6 8,100.00 89.54 210.11 6,427.91 -2,255.41 3,300.64 -739.09 7.00 88.00 5,978,738.86 543,897.99 8,200.00 89.79 217.10 6,428.49 -2,338.64 3,245.33 -641.13 7.00 87.97 5,978,655.34 543,843.13 8,256.08 89.94 221.03 6,428.62 -2,382.17 3,209.99 -585.36 7.00 87.93 5,978,611.62 543,808.04 7 8,300.00 91.28 223.79 6,428.15 -2,414.60 3,180.38 -541.49 7.00 64.00 5,978,579.04 543,778.60 8,400.00 94.33 230.10 6,423.24 -2,482.75 3,107.45 -441.73 7.00 64.03 5,978,510.50 543,706.05 8,406.08 94.52 230.48 6,422.78 -2,486.62 3,102.78 -435.69 7.00 64.34 5,978,506.60 543,701.41 8 8,500.00 95.40 237.02 6,414.65 -2,541.91 3,027.37 -343.27 7.00 82.00 5,978,450.91 543,626.30 8,600.00 96.27 244.01 6,404.47 -2,590.85 2,940.83 -247.47 7.00 82.57 5,978,401.50 543,540.03 8,700.00 97.04 251.01 6,392.87 -2,628.83 2,849.12 -155.77 7.00 83.28 5,978,363.03 543,448.54 8,706.08 97.08 251.44 6,392.12 -2,630.77 2,843.41 -150.35 7.00 84.09 5,978,361.06 543,442.84 9 8,800.00 95.56 257.87 6,381.77 -2,655.46 2,753.43 -69.28 7.00 103.00 5,978,335.89 543,353.01 8,900.00 93.87 264.69 6,373.54 -2,670.55 2,654.98 11.00 7.00 103.71 5,978,320.27 543,254.65 8,926.08 93.42 266.46 6,371.89 -2,672.56 2,629.04 30.77 7.00 104.27 5,978,318.12 543,228.72 10 8,996.08 92.64 271.30 6,368.19 -2,673.92 2,559.17 81.14 7.00 99.00 5,978,316.38 543,158.87 11 9,000.00 92.59 271.03 6,368.01 -2,673.84 2,555.25 83.85 7.00 -99.00 5,978,316.44 543,154.95 9,100.00 91.48 264.12 6,364.45 -2,678.07 2,455.47 157.40 7.00 -99.01 5,978,311.67 543,055.20 9,200 00 90.35 257.21 6,362.85 -2,694.28 2,356.87 238.58 7.00 -99.26 5,978,294.93 542,956.70 9,286.08 89.37 251.26 6,363.07 -2,717.65 2,274.06 313.66 7.00 -99.37 5,978,271.11 542,874.03 12 9,300 00 89.28 250.29 6,363.23 -2,722.23 2,260.92 326.20 7.00 -95.00 5,978,266.45 542,860.91 9,400.00 88.68 243.32 6,365.01 -2,761.59 2,169.07 418.97 7.00 -94.99 5,978,226.61 542,769.29 9,500.00 88.10 236.34 6,367.83 -2,811.79 2,082.71 515.54 7.00 -94.86 5,978,175.94 542,683.21 9,600.00 87.54 229.36 6,371.64 -2,872.10 2,003.11 614.47 7.00 -94.67 5,978,1 1 5.20 542,603.95 9,636.08 87.35 226.84 6,373.24 -2,896.18 1,976.29 650.46 7.00 -94.40 5,978,090.99 542,577.26 13 9,700.00 86.81 222.39 6,376.50 -2,941.61 1,931.47 714.28 7.00 -97.00 5,978,045.32 542,532.69 9,800.00 86.01 215.42 6,382.76 -3,019.23 1,868.83 813.46 7.00 -96.77 5,977,967.37 542,470.47 9,816.08 85.89 214.30 6,383.89 -3,032.39 1,859.66 829.24 7.00 -96.34 5,977,954.16 542,461.38 14 9,900.00 90.98 217.23 6,386 18 -3,100.43 1,810.65 912.01 7.00 30.00 5,977,885.86 542,412.74 9,966.08 94.99 219.55 6,382.74 -3,152.14 1,769.68 977.54 7.00 29.92 5,977,833.94 542,372.06 7/6/2015 4:02:42PM Page 4 COMPASS 5000.1 Build 61 ,,..- i •• Mg ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1 G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A Design: 1 G-11 A_wp02 �Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (°1100ft) (°) (usft) (usft) 15 10,000.00 95.03 217.16 6,379.78 -3,178.63 1,748.71 1,011.11 7.00 -89.00 5,977,807.33 542,351.24 10,100.00 95.09 210.14 6,370.96 -3,261.50 1,693.55 1,108.71 7.00 -89.21 5,977,724.17 542,296.53 10,200.00 95.07 203.11 6,362.10 -3,350.49 1,648.95 1,203.17 7.00 -89.83 5,977,634.95 542,252.41 10,266.08 95.02 198.46 6,356.29 -3,412.01 1,625.59 1,263.19 7.00 -90.45 5,977,573.31 542,229.40 16 10,300.00 94.85 200.84 6,353.37 -3,443.84 1,614.23 1,293.73 7.00 94.00 5,977,541.43 542,218.21 10,400.00 94.30 207.84 6,345.39 -3,534.60 1,573.16 1,386.94 7.00 94.20 5,977,450.45 542,177.64 10,500.00 93.69 214.83 6,338.42 -3,619.75 1,521.31 1,483.82 7.00 94.76 5,977,365.03 542,126.25 10,536.08 93.45 217.35 6,336.18 -3,648.84 1,500.10 1,519.39 7.00 95.25 5,977,335.83 542,105.20 17 10,600.00 93.28 212.87 6,332.42 -3,701.03 1,463.41 1,582.24 7.00 -92.00 5,977,283.45 542,068.79 10,636.08 93.18 210.35 6,330.38 -3,731.70 1,444.53 1,617.28 7.00 -92.26 5,977,252.68 542,050.08 18 10,700.00 90.94 206.47 6,328.09 -3,787.88 1,414.15 1,678.48 7.00 -120.00 5,977,196.34 542,020.01 10,736.08 89.67 204.29 6,327.89 -3,820.47 1,398.68 1,712.46 7.00 -120.14 5,977,163.67 542,004.73 19 10,800.00 88.67 199.93 6,328.82 -3,879.67 1,374.64 1,771.33 7.00 -103.00 5,977,104.35 541,981.00 10,900.00 87.11 193.10 6,332.51 -3,975.42 1,346.25 1,859.11 7.00 -102.94 5,977,008.45 541,953.14 10,976.08 85.96 187.89 6,337.11 -4,050.06 1,332.42 1,921.66 7.00 -102.68 5,976,933.74 541,939.72 Planned TD at 10976.08 7/6/2015 4:02:42PM Page 5 COMPASS 5000.1 Build 61 • S Fake ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A Design: 1 0-11 A_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (1 (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1G-11A_Fault1 0.00 0.00 0.00 -9,327.271,142,096.80 5,977,838.00 1,682,604.00 70°5'51.420 N 140°28'55.200 W -plan misses target center by 1138767.79usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Rectangle(sides W295.00 H1.00 D0.00) 1G-11A_T01 0.00 0.00 6,429.00 -8,633.271,143,403.71 5,978,539.00 1,683,907.00 70°5'56.226 N 140°28'14.949 W -plan misses target center by 1140052.34usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11A_T08 0.00 0.00 6,337.00 -10,473.921,141,455.52 5,976,688.00 1,681,969.00 70°5'41.235 N 140°29'18.440 W -plan misses target center by 1138116.28usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11 CTD Polygon Nor 0.00 0.00 0.00 -8,462.311,143,229.62 5,978,709.00 1,683,732.00 70°5'58.143 N 140°28'19.168 W -plan misses target center by 1139895.38usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Polygon Point 1 0.00 0.00 0.00 5,978,709.00 1,683,732.00 Point2 0.00 152.40 114.83 5,978,862.00 1,683,845.99 Point3 0.00 299.01 190.63 5,979,009.01 1,683,920.99 Point4 0.00 491.09 180.66 5,979,201.01 1,683,909.98 Point5 0.00 646.33 137.48 5,979,356.00 1,683,865.96 Point6 0.00 810.71 71.36 5,979,520.01 1,683,798.96 Point7 0.00 1,047.03 16.62 5,979,756.00 1,683,742.95 Point8 0.00 1,306.12 5.01 5,980,015.00 1,683,729.93 Point9 0.00 1,591.94 44.55 5,980,301.00 1,683,767.92 Point 10 0.00 1,806.04 29.70 5,980,515.00 1,683,751.91 Point 11 0.00 2,089.89 -121.80 5,980,797.99 1,683,598.89 Point 12 0.00 2,271.27 -189.83 5,980,978.99 1,683,529.89 Point 13 0.00 2,409.48 -226.09 5,981,116.98 1,683,492.88 Point 14 0.00 2,480.37 169.33 5,981,190.01 1,683,887.87 Point 15 0.00 2,346.20 198.61 5,981,056.01 1,683,917.88 Point 16 0.00 2,240.89 254.06 5,980,951.01 1,683,973.89 Point 17 0.00 1,875.93 424.12 5,980,587.02 1,684,145.91 Point 18 0.00 1,542.79 444.33 5,980,254.02 1,684,167.92 Point 19 0.00 1,289.00 398.96 5,980,000.02 1,684,123.93 Point20 0.00 1,058.87 419.73 5,979,770.02 1,684,145.95 Point21 0.00 875.52 479.75 5,979,587.02 1,684,206.95 Point22 0.00 650.03 567.55 5,979,362.03 1,684,295.96 Point23 0.00 435.86 594.41 5,979,148.03 1,684,323.98 Point24 0.00 83.13 536.51 5,978,795.03 1,684,268.00 Point25 0.00 -84.77 327.58 5,978,626.01 1,684,060.00 Point26 0.00 -83.67 122.56 5,978,626.00 1,683,855.00 Point27 0.00 0.00 0.00 5,978,709.00 1,683,732.00 1G-11A_T05 0.00 0.00 6,386.00 -9,497.291,141,912.86 5,977,667.00 1,682,421.00 70°5'50.041 N 140°29'1.178 W -plan misses target center by 1138566.82usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11A_Fault2 0.00 0.00 0.00 -9,765.601,141,779.39 5,977,398.00 1,682,289.00 70°5'47.634 N 140°29'6.143 W -plan misses target center by 1138453.27usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Rectangle(sides W315.00 H1.00 D0.00) 1G-11A_T03 0.00 0.00 6,363.00 -9,155.391,142,491.78 5,978,012.00 1,682,998.00 70°5'52.505 N 140°28'43.200 W -plan misses target center by 1139143.55usft at 7900.O0usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11A_T02 0.00 0.00 6,407.00 -8,988.531,143,074.75 5,978,182.00 1,683,580.00 70°5'53.264 N 140°28'25.864 W -plan misses target center by 1139725.48usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11A_T04 0.00 0.00 6,372.00 -9,310.301,142,103.89 5,977,855.00 1,682,611.00 70°5'51.574 N 140°28'54.924 W -plan misses target center by 1138756.65usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 7/6/2015 4:02:42PM Page 6 COMPASS 5000.1 Build 61 • ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1G-11 Survey Calculation Method: Minimum Curvature Wellbore: 1G-11A15. Design: 1 G-11A_wp02 1G-11A_T07 0.00 0.00 6,328.00 -10,236.371,141,543.81 5,976,926.00 1,682,056.00 70°5'43.411 N 140°29'14.895 W -plan misses target center by 1138202.85usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11A_T06 0.00 0.00 6,364.00 -9,752.581,141,777.46 5,977,411.00 1,682,287.00 70°5'47.763 N 140°29'6.142 W -plan misses target center by 1138433.12usft at 7900.00usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Point 1G-11 CTD Polygon Sot 0.00 0.00 0.00 -8,468.511,143,266.59 5,978,703.00 1,683,769.00 70°5'58.029 N 140°28'18.141 W -plan misses target center by 1139932.39usft at 7900.O0usft MD(6425.31 TVD,-2070.20 N,3370.26 E) -Polygon Point 1 0.00 0.00 0.00 5,978,703.00 1,683,769.00 Point 2 0.00 286.79 230.57 5,978,991.01 1,683,997.99 Point3 0.00 175.08 361.98 5,978,880.02 1,684,129.99 Point4 0.00 0.73 423.05 5,978,706.02 1,684,192.00 Point5 0.00 -242.03 373.74 5,978,463.02 1,684,144.01 Point 6 0.00 -467.28 229.52 5,978,237.02 1,684,001.03 Point7 0.00 -653.15 13.50 5,978,050.00 1,683,786.04 Point 8 0.00 -797.46 -303.31 5,977,903.99 1,683,470.04 Point9 0.00 -826.66 -640.51 5,977,872.96 1,683,133.04 Point 10 0.00 -867.00 -949.76 5,977,830.95 1,682,824.04 Point 11 0.00 -1,035.86 -1,165.69 5,977,660.94 1,682,609.05 Point 12 0.00 -1,226.13 -1,305.73 5,977,469.93 1,682,470.06 Point 13 0.00 -1,378.75 -1,379.55 5,977,316.93 1,682,397.08 Point 14 0.00 -1,701.12 -1,503.30 5,976,993.93 1,682,275.09 Point 15 0.00 -1,898.75 -1,576.37 5,976,795.92 1,682,203.10 Point 16 0.00 -2,044.58 -1,612.15 5,976,649.92 1,682,168.11 Point 17 0.00 -1,972.43 -2,010.81 5,976,719.90 1,681,769.10 Pointl8 0.00 -1,764.69 -1,957.69 5,976,927.90 1,681,821.09 Point 19 0.00 -1,574.21 -1,856.66 5,977,118.91 1,681,921.08 Point20 0.00 -1,383.83 -1,737.62 5,977,309.91 1,682,039.07 Point21 0.00 -1,012.86 -1,537.61 5,977,681.92 1,682,237.05 Point22 0.00 -847.67 -1,383.71 5,977,847.93 1,682,390.04 Point23 0.00 -723.52 -1,223.02 5,977,972.94 1,682,550.04 Point24 0.00 -592.96 -951.29 5,978,104.95 1,682,821.03 Point25 0.00 -401.15 -353.19 5,978,299.98 1,683,418.02 Point26 0.00 -302.13 -168.64 5,978,399.99 1,683,602.02 Point27 0.00 -173.75 -49.94 5,978,529.00 1,683,720.01 Point28 0.00 -84.04 5.55 5,978,619.00 1,683,775.00 Point29 0.00 0.00 0.00 5,978,703.00 1,683,769.00 Casing Points °. Measured Vertical Casing Hole Depth Depth Diameter Diameter 'till j°G 1" ift it (usft) Name (in) (in) 10,976.08 6,337.11 2 3/8" 2.375 3.000 7/6/2015 4.02.42PM Page 7 COMPASS 5000.1 Build 61 • IIIr `/ ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska Sandbox Local Co-ordinate Reference: Well 1 G-11 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1G-11 @ 99.00usft(1G-11) Site: Kuparuk 1G Pad North Reference: True Well: 1 G-11 Survey Calculation Method: Minimum Curvature Wellbore: 10-11A Design: 1 G-11A_wp02 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +Et-W (usft) (usft) (usft) (usft) Comment 7,600.00 6,306.23 -1,880.13 3,219.15 TIP 7,660.00 6,356.20 -1,900.69 3,245.24 KOP 7,685.00 6,375.67 -1,910.34 3,257.54 Start 40 dls 7,792.88 6,420.03 -1,974.44 3,328.40 4 7,955.58 6,426.52 -2,124.75 3,361.72 End 40 dls,Start 7 dls 8,056.08 6,427.52 -2,216.84 3,321.64 6 8,256.08 6,428.62 -2,382.17 3,209.99 7 8,406.08 6,422.78 -2,486.62 3,102.78 8 8,706.08 6,392.12 -2,630.77 2,843.41 9 8,926.08 6,371.89 -2,672.56 2,629.04 10 8,996.08 6,368.19 -2,673.92 2,559.17 11 9,286.08 6,363.07 -2,717.65 2,274.06 12 9,636 08 6,373.24 -2,896.18 1,976 29 13 9,816 08 6,383.89 -3,032 39 1,859.66 14 9,966.08 6,382.74 -3,152.14 1,769.68 15 10,266.08 6,356.29 -3,412.01 1,625.59 16 10,536.08 6,336.18 -3,648.84 1,500.10 17 10,636.08 6,330.38 -3,731.70 1,444.53 18 10,736.08 6,327.89 -3,820.47 1,398.68 19 10,976.08 6,337.11 -4,050.06 1,332.42 Planned TD at 10976.08 7/6/2015 4.02:42PM Page 8 COMPASS 5000.1 Build 61 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1G Pad 1G-11 1G-11A 1 G-11 A_wp02 Travelling Cylinder Report 22 June, 2015 BAKER HUGHES 41, Baker Hughes INTEQ • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.O0usft North Reference: True Reference Well: 1G-11 Survey Calculation Method:,- ▪ Minimum Curvature Well Error: 0.O0usft Output errors are at ▪ 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1 G-11A_wp02 Offset TVD Reference: Offset Datum Reference 1G-11A_wp02 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,600.00 to 10,976.08usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,287.71 usft Error Surface: Elliptical Conic Survey Tool Program Date 6/22/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,600.00 1G-11 (1G-11) BOSS-GYRO Sperry-Sun BOSS gyro multishot 7,600.00 10,976.08 1 G-11 A_wp02(1G-11A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (..) 10,976.08 6,436.11 2 3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Kuparuk 1G Pad 1G-05-1 G-05-1 G-05 10,976.08 7,550.00 1,188.76 238.07 1,053.19 Pass-Major Risk 1G-09-1G-09-1G-09 Out of range 1G-10-1G-10-1G-10 Out of range 1G-10-1G-10A-1G-10A Out of range 1G-10-1G-10B-1 G-10B Out of range 1G-10-1 G-10BL1-1 G-10BL1 Out of range 1G-10-1G-1 OBL2-1 G-10BL2 Out of range 1G-10-1G-10BPB1-1G-10BPB1 Out of range 1G-11-1G-11-1G-11 7,674.95 7,675.00 0.78 2.99 -1.74 FAIL-Major Risk 1G-11-1G-11AL1-1G-11AL1_wp03 7,600.00 7,600.00 0.00 0.22 -0.22 FAIL-Minor 1/10 1 G-12-1G-12-1G-12 8,865.41 7,625.00 1,243.55 240.78 1,036.34 Pass-Major Risk 1G-14-1G-14-1G-14 10,000.00 7,950.00 1,048.22 196.51 861.90 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 2 of 8 COMPASS 5000.1 Build 65 • • Baker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit ND Reference: 1G-11 @ 99.00usft(1G-11) Reference Site:4 Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference: True Reference Well: 1 G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1 G-11A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1 G-05-1 G-05-1 G-05 offset Site Error: 0.00 usft Survey Program: 100-FINDER-MS Rule Assigned:Major Risk Offset Well Error: 0 00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface'a Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft( (usft) (usft) (usft) (usft) () (usft) (usft(. (usft) (usft) (usft) (usft) 10,924.16 6,432.81 7425.00 5,238.15 48.18 34.28 -147.54 -3,974.61 880.46 2-11/16 1,272.23 234.04 1,139.21 Pass-Major Risk 10,934.03 6,433.38 7,450.00 5,254.08 48.19 34.43 -148.28 -3,993.27 885.27 2-11/16 1,255.36 234.83 1,121.88 Pass-Major Risk 10,950.00 6,434.36 7,475.00 5,270.06 48.20 34.58 -149.41 -4,011.90 890.04 2-11/16 1,238.60 235.89 1,104.36 Pass-Major Risk 10,950.00 6,434.36 7,500.00 5,286.09 48.20 34.72 -149.50 -4,030.49 894.78 2-11/16 1,221.89 236.23 1,087.65 Pass-Major Risk 10,964.41 6,435.31 7,525.00 5,302.17 48.20 34.87 -150.51 -4,049.04 899.50 2-11/16 1,205.27 237.21 1,070.30 Pass-Major Risk 10,976.08 6,436.11 7,550.00 5,318.29 48.21 35.02 -151.33 -4,067.55 904.21 2-11/16 1,188.76 238.07 1,053.19 Pass-Major Risk,CC,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 3 of 8 COMPASS 5000.1 Build 65 aBaker Hughes INTEQ ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference: True Reference Well: 10-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1G-11A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-11-1 G-11-1G-11 offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (use) (usft) (usft) (usft) (") (usft) (usft) (usft) (usft) (usft) (usft) 7,625.00 6,426 07 7,625.00 6,426.07 0.08 0.16 -31.30 -1,888.69 3,229.99 2-11/16 0.00 1.12 -0.83 FAIL-Major Risk,CC 7,650.00 6,446.88 7,650.00 6,446.88 0.16 0.32 -31.37 -1,897.26 3,240.87 2-11/16 0.00 2.02 -1.44 FAIL-Major Risk1I 7,674.95 6,467.17 7675.00 6,467.66 0.19 0.48 -51.45 -1,905.84 3,251.81 2-11/16 0.78 2.99 -1.74 FAIL-Major Risk,ES,SF 7,699.03 6,484.31 7,700.00 6,488.41 0.20 0.64 -49.77 -1,914.41 3,262.80 2-11/16 5.41 4.24 1.39 Pass-Major Risk 7,721.09 6,497.38 7,725.00 6,509.17 0.20 0.80 -46.84 -1,922.95 3,273.81 2-11/16 13.92 5.49 8.57 Pass-Major Risk 7,740.00 6,506.31 7,750.00 6,529.96 0.21 0.96 -44.89 -1,931.43 3,284.80 2-11/16 25.78 6.60 19.35 Pass-Major Risk 7,756.99 6,512.43 7,775.00 6,550.79 0.22 1.12 -43.48 -1,939.84 3,295.78 2-11/16 40.34 7.55 33.01 Pass-Major Risk 7,770.00 6,515.84 7,800.00 6,571.65 0.23 1.28 -42.44 -1,948.19 3,306.74 2-11/16 57.04 8.28 49.04 Pass-Major Risk 7,782.54 6,518.03 7,825.00 6,592.55 0.24 1.44 -41.54 -1,956.46 3,317.68 2-11/16 75.36 8.99 66.78 Pass-Major Risk 7,792.29 6,519.00 7,850.00 6,613.49 0.24 1.60 -40.81 -1,964.65 3,328.61 2-11/16 94.96 9.60 85.95 Pass-Major Risk 7,805.58 6,519.80 7,875.00 6,634.47 0.25 1.76 -35.47 -1,972.75 3,339.53 2-11/16 115.23 10.02 105.94 Pass-Major Risk 7,818.52 6,520.55 7,900.00 6,655.50 0.26 1.91 -29.64 -1,980.76 3,350.43 2-11/16 135.71 10.54 126.14 Pass-Major Risk 7,830.00 6,521.19 7,925.00 6,676.57 0.27 2.07 -24.16 -1,988.70 3,361.28 2-11/16 156.45 11.01 146.59 Pass-Major Risk 7,841.77 6,521.82 7,950.00 6,697.72 0.28 2.22 -18.49 -1,996.57 3,372.05 2-11/16 177.46 11.49 167.32 Pass-Major Risk 7,851.98 6,522.33 7,975.00 6,718.92 0.29 2.37 -13.40 -2,004.38 3,382.74 2-11/16 198.76 11.90 188.35 Pass-Major Risk 7,861.25 6,52277 8,000.00 6,740.19 0.30 2.52 -8.70 -2,012.13 3,393.36 2-11/16 220.36 12.26 20969 Pass-Major Risk 7,870.00 6,523.16 8,025.00 6,761.52 0.31 2.67 -4.24 -2,019.79 3,403.90 2-11/16 242.24 12.56 231.33 Pass-Major Risk 7,877.21 6,523.47 8,050.00 6,782.91 0.32 2.82 -0.43 -2,027.37 3,414.40 2-11/16 264.40 12.82 253.26 Pass-Major Risk 7,884.06 6,523.74 8,075.00 6,804.33 0.33 2.97 3.17 -2,034.89 3,424.87 2-11/16 286.80 13.05 275.44 Pass-Major Risk 7,890.00 6,523.97 8,100.00 6,825.74 0.33 3.11 6.38 -2,042.42 3,435.34 2-11/18 309.38 13.26 297.83 Pass-Major Risk 7,895.95 6,524.18 8,125.00 6,847.16 0.34 3.26 9.53 -2,049.94 3,445.82 2-11/16 332.15 13.45 320.41 Pass-Major Risk 7,900.00 6,524.31 8,150.00 6,868.58 0.34 3.41 11.89 -2,057.47 3,456.29 2-11/16 355.08 13.64 343.18 Pass-Major Risk 7,905.81 6,524.50 8,175.00 6,890.00 0.35 3.56 14.89 -2,064.99 3,466.76 2-11/16 378.15 13.79 366.10 Pass-Major Risk 7,910.00 6,524.62 8,200.00 6,911.41 0.36 3.70 17.21 -2,072.51 3,477.23 2-11/16 401.37 13.93 389.17 Pass-Major Risk 7,910.00 6,524.62 8,208.00 6,918.27 0.36 3.75 17.42 -2,074.92 3,480.58 2-11/16 408.83 13.99 396.59 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 4 of 8 COMPASS 5000.1 Build 65 • --- Baker Hughes INTEQ • ,e,---- ConocoPhillips Travelling Cylinder Report BAKER • HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River UnitTVD Reference: 1G-11 @ 99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference: True Reference Well: 1G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00usftOutput errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1 G-11 A_wp02 Offset TVD Reference: Offset Datum i. Offset Design Kuparuk 1G Pad- 1G-11-1G-11 AL1-1G-11AL1_wp03 Offset Site Error: 0.00usft Survey Program: 100-BOSS-GYRO,7600-MWD Rule Assigned:Minor 1/10 Offset Well Error: 0 00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N1-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) (usft) 7,600.00 6,40523 7,600.00 6,405.23 0.00 0.00 128.40 -1,880.13 3,219.15 2-11/16 0.00 0.22 -0.22 FAIL-Minor 1/10,CC,ES,SF 7,606.66 6,410.79 8,250.00 6,409.11 0.02 0.62 38.76 -1,54046 3,495.97 2-11/16 438.15 1.62 436.53 Pass-Minor 1/10 7,620.52 6,422.34 8,225.00 6,414.20 0.07 0.55 40.30 -1,564.83 3,498.20 2-11/16 420.65 1.55 419.10 Pass-Minor 1/10 7,624.99 6,426.06 7,625.00 6,425.83 0.08 0.05 128.73 -1,888.91 3,230.25 2-11/16 0.42 0.47 0.00 FAIL-Minor 1/10 7,634.07 6,433.63 8,200.00 6,419.30 0.11 0.48 41.91 -1,589.26 3,499.68 2-11/16 402.94 1.53 401.46 Pass-Minor 1/10 7,647.31 6,444.64 8,175.00 6,424.41 0.15 0.43 43.60 -1,613.72 3,500.39 2-11/16 385.02 1.55 383.59 Pass-Minor 1/10 7,649.62 6,446.57 7,650.00 6,444.07 0.16 0.05 127.64 -1,899.41 3,243.67 2-11/16 4.49 0.65 3.99 Pass-Minor 1/10 7,660.30 6,455.45 8,150.00 6,429.53 0.19 0.37 45.38 -1,638.19 3,500.33 2-11/16 366.93 1.57 365.54 Pass-Minor 1/10 7,674.32 6,466.68 7,675.00 6,458.77 0.19 0.06 124.36 -1,911.24 3,260.01 2-11/16 12.46 0.76 11.90 Pass-Minor 1/10 7,680.29 6,471.21 8,125.00 6,434.64 0.19 0.33 47.14 -1,662.65 3,499.52 2-11/16 348.56 1.52 34725 Pass-Minor 1/10 7,695.63 6,482.07 8,100.00 6,439.76 0.20 0.30 49.04 -1,687.07 3,497.94 2-11/16 329.77 146 328.54 Pass-Minor 1/10 7,700.72 6,485.41 7,700.00 6,469.79 0.20 0.07 117.48 -1,922.52 3,279.36 2-11/16 20.86 0.81 20.26 Pass-Minor 1/10 7,710.31 6,491.33 8,075.00 6,444.86 0.20 0.28 50.96 -1,711.43 3,495.60 2-11/16 310.70 1.40 309.55 Pass-Minor 1/10 7,726.02 6,499.91 8,050.00 6,449.95 0.21 0.27 52.77 -1,735.70 3,492.50 2-11/16 291.28 1.31 290.21 Pass-Minor 1/10 7,727.87 6,500.83 7,725.00 6,477.78 0.21 0.08 106.27 -1,931.27 3,301.33 2-11/16 29.21 0.85 28.57 Pass-Minor 1/10 7,742.39 6,507.29 8,025.00 6,455.03 0.21 0.27 54.46 -1,759.88 3,488.64 2-11/16 271.43 1.22 270.43 Pass-Minor 1/10 7,753.88 6,511.45 7,750.00 6,483.70 0.22 0.09 92.35 -1,936.05 3,325.10 2-11/16 38.67 0.86 37.97 Pass-Minor 1/10 7,758.96 6,513.02 8,000.00 6,460.07 0.22 0.26 55.98 -1,783.92 3,484.03 2-11/16 251.09 1.11 250.15 Pass-Minor 1/10 7,77521 6,516.88 7,975.00 6,465.10 0.23 0.25 57.30 -1,807.82 3,478.68 2-11/16 230.22 0.99 229.34 Pass-Minor 1/10 7,776.24 6,517.06 7,775.00 6,488.27 0.23 0.11 78.89 -1,936.19 3,349.64 2-11/16 51.29 0.86 50.54 Pass-Minor 1/10 7,790.66 6,518.88 7,950.00 6,470.09 0.24 0.25 58.38 -1,831.54 3,472.58 2-11/16 208.81 0.88 207.99 Pass-Minor 1/10 7,792.88 6,519.03 7,800.00 6,491.33 0.24 0.13 68.90 -1,931.68 3,374.00 2-11/16 68.38 0.84 67.60 Pass-Minor 1/10 7,797.14 6,519.29 7,925.00 6,475.10 0.25 0.24 60.35 -1,854.86 3,465.13 2-11/16 186.78 0.83 185.99 Pass-Minor 1/10 7,800.00 6,519.46 7,825.00 6,492.17 0.25 0.15 65.50 -1,922.97 3,397.37 2-11/16 89.76 0.82 88.98 Pass-Minor 1/10 7,800.00 6,519.46 7,900.00 6,480.36 0.25 0.22 61.71 -1,876.35 3,453.58 2-11/16 163.26 0.82 162.48 Pass-Minor 1/10 7,802.68 6,519.63 7,850.00 6,490.25 0.25 0.18 63.85 -1,910.62 3,418.98 2-11/16 113.75 0.81 112.98 Pass-Minor 1/10 7,802.96 6,519.64 7,875.00 6,485.71 0.25 0.20 63.16 -1,895.09 3,437.99 2-11/16 138.64 0.81 137.87 Pass-Minor 1/10 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 5 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ l4kU ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 ©99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference: True i. Reference Well: 1G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1 G-11A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1G-12-1G-12-1G-12 Offset Site Error: 0 00 usft Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth r Azimuth +N/-S +E/-W-. Hole Size Centre Distance Deviation (usft) (usft) (usft) Instil Instil (usft) (°I (usft) (usft) (usft) (usft) (usft) (usft) 8,823.74 6,478.55 7,875.00 5,916.99 44.98 63.03 -164.42 -3,782.99 2,990.12 2-11/16 1,282.09 234.65 1,064.80 Pass-Major Risk 8,827.68 6,478.20 7,850.00 5,898.88 44.99 62.81 -163.13 -3,769.66 2,979.20 2-11/16 1,276.36 235.24 1,059.81 Pass-Major Risk 8,831.65 6,477.85 7,825.00 5,880.82 44.99 62.59 -161.83 -3,756.27 2,968.26 2-11/16 1,270.97 235.84 1,055.23 Pass-Major Risk 8,850.00 6,476.29 7,650.00 5,755.06 45.01 61.03 -153.30 -3,662.41 2,890.82 2-11/16 1,245.31 237.74 1,038.72 Pass-Major Risk 8,850.00 6,476.29 7,675.00 5,773.06 45.01 61.25 -154.34 -3,675.67 2,901.99 2-11/16 1,247.44 238.06 1,038.91 Pass-Major Risk 8,850.00 6,476.29 7,700.00 5,791.02 45.01 61.47 -155.37 -3,689.03 2913.14 2-11/16 1,250.16 238.38 1,039.74 Pass-Major Risk 8,850.00 6,47629 7,725.00 5,808.95 45.01 61.70 -156.40 -3,70245 2,92424 2-11/16 1,253.42 238.69 1,041.15 Pass-Major Risk 8,850.00 6,476.29 7,750.00 5,826.90 45.01 61.92 -157.43 -3,715.89 2,935.31 2-11/16 1,257.18 239.01 1,043.09 Pass-Major Risk 8,850.00 6,47629 7,775.00 5,844.85 45.01 62.14 -158.45 -3,729.34 2,946.33 2-11/16 1,261.42 239.32 1,045.56 Pass-Major Risk 8,850.00 6,476.29 7,800.00 5,862.82 45.01 62.37 -159.46 -3,742.82 2,957.31 2-11/16 1,266.15 239.64 1,048.56 Pass-Major Risk 8,865.41 6,475.05 7,625.00 5,737.01 45.03 60.81 -151.13 -3,649.23 2,879.61 2-11/16 1,243.55 240.78 1,036.34 Pass-Major Risk,ES,SF 8,869.91 6,474.71 7,600.00 5,718.90 45.03 60.59 -149.76 -3,636.15 2,868.38 2-11/16 1,242.47 241.43 1,036.57 Pass-Major Risk 8,874.47 6,474.36 7,575.00 5,700.78 45.04 60.37 -148.39 -3,623.13 2,857.11 2-11/16 1,241.91 242.07 1,037.38 Pass-Major Risk 8,879.09 6,474.02 7,550.00 5,682.64 45.05 60.15 -147.02 -3,610.15 2,845.82 2-11/16 1,241.85 242.72 1,038.73 Pass-Major Risk,CC 8,883.77 6,473.68 7,525.00 5,664.49 45.05 59.93 -145.64 -3,597.21 2,834.50 2-11/16 1,242.27 243.38 1,040.61 Pass-Major Risk 8,900.00 6,472.54 7,425.00 5,592.15 45.07 59.05 -140.36 -3,545.38 2,788.90 2-11/16 1,248.34 245.38 1,053.40 Pass-Major Risk 8,900.00 6,472.54 7,450.00 5,610.15 45.07 59.27 -141.38 -3,558.40 2,800.35 2-11/16 1,246.25 245.73 1,048.98 Pass-Major Risk 8,900.00 6,472.54 7,475.00 5,628.22 45.07 59.49 -142.40 -3,571.37 2,811.77 2-11/16 1,244.57 246.08 1,045.00 Pass-Major Risk 8,900.00 6,472.54 7,500.00 5,646.34 45.07 59.71 -143.43 -3,584.29 2,823.15 2-11/16 1,243.31 246.43 1,041.45 Pass-Major Risk 8,908.07 6,472.01 7,400.00 5,574.20 45.09 58.83 -138.77 -3,532.30 2,777.40 2-11/16 1,250.79 246.68 1,057.09 Pass-Major Risk 8,913.10 6,471.69 7,375.00 5,556.29 45.09 58.60 -137.40 -3,519.18 2,765.91 2-11/16 1,253.64 247.35 1,061.64 Pass-Major Risk 8,918.16 6,471.37 7,350.00 5,538.39 45.10 58.38 -136.03 -3,506.02 2,754.45 2-11/16 1,256.90 248.01 1,066.65 Pass-Major Risk 8,926.08 6,470.89 7,300.00 5,502.62 45.11 57.93 -133.48 -3,479.56 2,731.64 2-11/16 1,264.64 248.87 1,078.14 Pass-Major Risk 8,926.08 6,470.89 7,325.00 5,520.50 45.11 58.15 -134.46 -3,492.81 2,743.03 2-11/16 1260.57 249.24 1,071.76 Pass-Major Risk 8,933.88 6,470.43 7,275.00 5,484.74 45.13 57.70 -131.92 -3,466.31 2,720.26 2-11/16 1,269.14 250.08 1,084.09 Pass-Major Risk 8,939.36 6,470.11 7,250.00 5,466.85 45.14 57.48 -130.55 -3,453.09 2,708.85 2-11/16 1,274.10 250.80 1,090.79 Pass-Major Risk 8,950.00 6,469.52 7,200.00 5,431.02 45.15 57.03 -127.87 -3,426.76 2,685.98 2-11/16 1,285.35 252.15 1,105.63 Pass-Major Risk 8,950.00 6,469.52 7,225.00 5,448.94 45.15 57.25 -128.82 -3,439.91 2,697.42 2-11/16 1,279.52 252.53 1,097.46 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 6 of 8 COMPASS 5000.1 Build 65 • • Baker Hughes INTEQ NM ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: 1G-11 @ 99.00usft(10-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference: True Reference Well: 1G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1 G-11A_wp02 Offset TVD Reference: Offset Datum Offset Design Kuparuk 1G Pad- 1 G-14-1G-14-1G-14 Offset Site Error: 0.00 use Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-5 +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (°) (usft) (usft) (usft) (usft) (usft) (usft) 9,800.00 6,481.76 7,400.00 6,496.77 46.85 33.20 -53.78 -2,267.59 835.66 2-11/16 1,277.77 183.66 1,103.07 Pass-Major Risk 9,800.00 6,481.76 7,425.00 6,514.62 46.85 33.41 -52.99 -2,284.28 840.89 2-11/16 1,264.12 183.97 1,088.86 Pass-Major Risk 9,800.00 6,481.76 7,450.00 6,532.46 46.85 33.62 -52.19 -2,301.00 846.15 2-11/16 1,250.80 184.28 1,074.99 Pass-Major Risk 9,809.16 6,482.40 7,475.00 6,550.27 46.86 33.84 -51.98 -2,317.72 851.43 2-11/16 1,237.72 184.91 1,060.98 Pass-Major Risk 9,816.08 6,482.89 7,500.00 6,568.07 46.87 34.05 -51.59 -2,334.46 856.73 2-11/16 1,224.97 185.48 1,047.40 Pass-Major Risk 9,834.70 6,484.05 7,525.00 6,585.84 46.89 34.27 -50.13 -2,351.22 862.06 2-11/16 1,212.46 18625 1,034.07 Pass-Major Risk 9,863.67 6,485.11 7,550.00 6,603.58 46.92 34.49 -48.27 -2,368.00 867.43 2-11/16 1,200.03 187.29 1,020.58 Pass-Major Risk 9,888.93 6,485.31 7,575.00 6,621.28 46.95 34.71 -46.48 -2,384.80 872.84 2-11/16 1,187.70 18827 1,007.24 Pass-Major Risk 9,911.12 6,484.93 7,600.00 6,638.96 46.97 34.92 -44.75 -2,401.61 878.29 2-11/16 1,175.52 189.19 994.13 Pass-Major Risk 9,930.75 6,484.16 7,625.00 6,656.65 47.00 35.14 -43.06 -2,418.43 883.73 2-11/16 1,163.59 190.05 981.33 Pass-Major Risk 9,948.24 6,483.13 7,650.00 6,674.38 47.02 35.36 -41.40 -2,435.21 889.11 2-11/16 1,152.00 190.83 968.95 Pass-Major Risk 9,963.91 6,481.93 7,675.00 6,692.15 47.05 35.58 -39.77 -2,451.97 894.43 2-11/16 1,140.80 191.58 957.03 Pass-Major Risk 9,966.08 6,481.74 7,700.00 6,709.97 47.05 35.79 -38.62 -2,468.70 899.69 2-11/16 1,130.03 191.94 945.91 Pass-Major Risk 9,966.08 6,481.74 7,725.00 6,727.81 47.05 36.01 -37.54 -2,485.41 904.92 2-11/16 1,119.76 19224 935.38 Pass-Major Risk 9,975.87 6,480.89 7,750.00 6,745.65 47.07 36.22 -37.18 -2,502.12 910.16 2-11/16 1,109.86 192.93 924.82 Pass-Major Risk 9,979.40 6,480.58 7,775.00 6,763.49 47.07 36.44 -36.33 -2,518.84 915.39 2-11/16 1,100.45 193.38 915.06 Pass-Major Risk 9,982.99 6,480.27 7,800.00 6,781.33 47.08 36.66 -35.46 -2,535.55 920.62 2-11/16 1,091.50 193.84 905.81 Pass-Major Risk 9,986.63 6,479.95 7,825.00 6,799.17 47.08 36.87 -34.58 -2,552.26 925.86 2-11/16 1,083.03 194.31 897.07 Pass-Major Risk 9,990.33 6,479.63 7,850.00 6,817.01 47.09 37.09 -33.68 -2,568.98 931.09 2-11/16 1,075.05 194.79 888.86 Pass-Major Risk 10,000.00 6,478.78 7,875.00 6,834.85 47.10 37.30 -33.23 -2,585.69 936.32 2-11/16 1,067.60 195.55 880.93 Pass-Major Risk 10,000.00 6,478.78 7,900.00 6,852.69 47.10 37.52 -32.02 -2,602.40 941.56 2-11/16 1,060.59 195.87 873.98 Pass-Major Risk 10,000.00 6,478.78 7,925.00 6,870.53 47.10 37.74 -30.79 -2,619.11 946.79 2-11/16 1,054.12 196.19 867.63 Pass-Major Risk 10,000.00 6,478.78 7,950.00 6,888.37 47.10 37.95 -29.56 -2,635.83 952.03 2-11/16 1,048.22 196.51 861.90 Pass-Major Risk,CC,ES,SF CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 7 of 8 COMPASS 5000.1 Build 65 • Baker Hughes INTEQ • ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1G-11 Project: Kuparuk River Unit TVD Reference: ' 1G-11 @ 99.00usft(1G-11) Reference Site: Kuparuk 1G Pad MD Reference: 1G-11 @ 99.00usft(1G-11) Site Error: 0.00usft North Reference:k True Reference Well: 1G-11 Survey Calculation Method: Minimum Curvature Well Error: 0.0Ousft Output errors are at 1.00 sigma Reference Wellbore 1G-11A Database: OAKEDMP2 Reference Design: 1G-11A_wp02 Offset TVD Reference: Offset Datum Reference Depths are relative to 1G-11 @ 99.00usft(1G-11) Coordinates are relative to:1G-11 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:0.31° Ladder Plot 1400— 1050 0 0 Q a) co ▪ 700— U 0 a) J —_ 0) 1) 350— J J 0 I I I 0 2000 4000 6000 &000 10000 12000 Meastxed Depth LEGEND —B— 1G-05,1G-05,1G-05V1 — f 1G-11,1G-11AL1,1G-11AL1 wp03V0 -- 1G-14,1G-14,1G-14 V1 —4)— 1G-11,1G-11,1G-11 V1 -- 1G-12,1G-12,1G-12 V1 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 6/22/2015 3:33:37PM Page 8 of 8 COMPASS 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C V CO N t00 V V cn CV 0 V CVO M M 000 N O V 0-(C CO •� Ch M c'i CO Oi Oi Oi V N-M CV CT I�U)V to M M O)to - .O MM Cr 00 CO 03 NO cn cncn O co coca coO co co co _ S /•• O i WO D OOOCO co co CO cO tb 03 00 000000 CO W CO CO Mao \ \ N A + O O O c0 to O O O O O O O O 0 O O O O O O ^0 0 O O g 0 O O S 0 0 OJ' O O O CO CV to CO CO CO CD CO CO CO C)CD CO CO CO CD CO CO O N M C r en O CO CO CD 4)CO CO O O N CD CO M CD O M M M N yt .0 b b .p b so •U •o N CC bON to /4) CO CO CO I-CT O N V i-O)O)NCO CO 0)N to CO N-0) 1-N-1�r N-CO CO 0000 00 CO O O)6)0 O__O O__O O_ Fs 0 . 0 C J N M V V)VD NCO CTO-N M V t 0 co N-co 0)0 O z o A) N (uifljsn 06) gid0a PPoi�an anis, U • • /7TP 2 / 5-1 2 .5— Loepp, Victoria T (DOA) From: Venhaus, Dan E <Dan.Venhaus@conocophillips.com> Sent: Tuesday,July 21,2015 10:21 AM To: Loepp,Victoria T(DOA) Cc: Schwartz, Guy L(DOA); Eller,J Gary;Starck, Kai;Winfree, Mike A Subject: 1G-11 permit changes Follow Up Flag: Follow up Flag Status: Flagged Victoria— You should be receiving the PTD application for 1G-11 CTD sidetrack soon. We are making some verbiage changes to the drilling fluids section and providing more explanation of the MPD equipment/process used in Coiled Tubing Drilling. We hope to clarify items that you and I discussed on the recent 30-08 permit. Some highlights: • Removed emergency kill weight fluid from fluids section in the PTD application since this fluid is not required either by ConocoPhillips drilling policy or Alaska regulation. When MPD drilling was initiated in Kuparuk in 1998 the emergency kill weight fluid was added as a contingency due to the newness of MPD technology. In 17 years of CTD operations we have never used the emergency kill weight fluid for well control purposes. We have always maintained primary well control with CT stripper and the MPD choke, both of which are 5K rated. Secondary well control is provided by the BOPE while drilling.We feel this third level of well control(emergency kill weight fluid)is no longer needed. • Two wellbore volumes of overbalance completion fluid are readily available on the rig to kill the well for liner installation (i.e. becomes primary well control). Completion fluid weight is designed for expected reservoir pressure along well path. PTD applications will continue to include an explanation of how we determined this expected reservoir pressure along the planned well path. • Maximum potential reservoir pressure in the area will continue to be used for calculating BOPE test pressure. Please contact me should have any questions. We are more than happy to meet and show schematics of the rig layout and pressure control systems, if needed. Thanks! Dan Venhaus CTD Engineering Supervisor-Alaska Cell 907-230-0188 Office 907-263-4372 1 • r OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: /K?L ) c - ) I J- 5YPTD: Is _ U5- /Development Development _Service Exploratory Stratigraphic Test Non-Conventional FIELD: 14 �vk(� POOL: . �I / � - Ili 0.1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 II/ 410 00 N , mO a) n O U) N , � c d L To CO > L O a) a a C c0 co OO o C a). c' a , (d' fd. .co y , mc. �. W. , 2 o. a 0_ , U m 3 c, a c' a) o 43, -a, a) Y . N W Q c a) N L N a 0. C9 J, G i C -c 4) OO W p. m O F- O. C aa) aai a n , E. n co, =, w a) OD N, c y. Y, o C7 o E. • r• n p. Ica CT1c. w a coi, cNy a m. a .0 C Ct a) a yr °� 1 U Y .O, a 3 M. U N — a) 0 3' Y m c. 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