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216-019
RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMAION APR 1 3 2017 REPORT OF SUNDRY WELL OPERATIONS AOGC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate Q Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Q Other: _Acid stim Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska Inc Development Q Exploratory ❑ 216-019 3.Address: Stratigraphic❑ Service ❑ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029-22346-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25639 KRU 1H-10A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk Oil Pool 11.Present Well Condition Summary: Total Depth measured 10518 feet Plugs measured N/A feet true vertical 6463 feet Junk measured N/A feet Effective Depth measured 10518 feet Packer measured 6858 feet true vertical 6463 feet true vertical 6318 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121' Surface 4354' 9-5/8" 4394' 4273' Intermediate Production 7497' 7" 7535' 6871' Liner 3634' 2-3/8" 10518' 6463' Perforation depth Measured depth 7372-10518 n MAY 1: 2017 True Vertical depth 6468-6463 Tubing(size,grade,measured and true vertical depth) 4'x3-1/2",J-55,6894 MD,6348 TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER FB-1 PERMANENT PACKER @ 6858 MD and 6319 TVD SAFETY VLV-CAMCO TRDP-4A-R0 SAFETY VALVE @ 1792 MD and 1792 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7372'-10518' Treatment descriptions including volumes used and final pressure: Treated slotted liner with 420 bbl of 15%HCI with 1000 psi injection pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 106 bbl 123 2 bbl 880 psi 215 psi Subsequent to operation: 48 bbl 2224 0 bbl 850 psi 220 psi 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory❑ Development P ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Jason Burke Email jason.burkeic7i.cop.corn Printed Name Jason Bur,- Title Staff Wells Engineer -' ,, ' � Signature --'"" ""w Phone 265-6097 Date Form 10-404 Revised 5/2015 VII- 3//o!/7- Submit Original Only ,1 -/710 7 RBDMS i.-k, APR 1 3 2017 • 1 H-10 • DTTMSTART JOBTYP SUMMARYOPS 3/25/2017 STIMULATION RU CTU, WAIT 3 HRS FOR LRS TO F/P FLOWLINE, PERFORM FILL TREATMENT CLEANOUT FROM LINER TOP AT 6884/ RKB TO HARD TAG AT 10502 RKB USING SLICK DIESEL WITH DIESEL GEL SWEEPS AT 1.3 BPM, VERY LIGHT SAND CONCENTRATIONS OBSERVED, F/P TBG, JOB IN PROGRESS. 3/26/2017 STIMULATION RIH TO PERFORM ACID STIMULATION, COIL GOES INTO LOCKUP AT TREATMENT 8842' CTMD, TRY COMBINATION OF PUMPING AND RUNNING SPEEDS YET UNABLE TO MAKE IT TO TARGET DEPTH OF 10300' RKB, CALL FOR XRV VIBRATORY TOOL FOR TOMORROW, JOB IN PROGRESS. 3/27/2017 STIMULATION PUMP 420 BBLS OF 15% HCL ACID, LAY IN ACID FROM 10300' CTMD TREATMENT TO 7600' CTMD, F/P TBG TO 2800' CTMD, TURN WELL OVER TO PTS FOR FLOWBACK, JOB COMPLETE. 4/4/2017 STIMULATION FREEZE PROTECT TUBING WITH 30 BBLS DIESEL TREATMENT FREEZE PROTECT FLOWLINE WITH 20 BBLS METH FLUSH PTS SURFACE EQUIPMENT OUT WITH 20 BBLS DSL TO WELL 11 JOB COMPLETE KUP P OD 1H-10A ConocoPhillips 1 Well Attribu Max Angle", TD Alaska,Its:. Wellbore APIIUWI Field Name Wellbore Status ncl(.) MD(ftKB) Act Btm(ftKB) Conoca?hillips 500292234601 KUPARUK RIVER UNIT PROD 98.19 7,285.24 10,518.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date 1H-10A,4/11/20173.38;51 PM SSSV: TRDP 50 7/29/2015 Last WO: 3/4/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERAL lehallf 4/13/2016 HANGER.376— Mi Casing Strings = Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WELen(I...Grade Top Thread pa- - A LATERAL LINER 2 3/8 1.992 6,884.9 10,518.0 6,463.5 4.60 L-80 ST-L ASSY .4 Liner Details J Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(.) Item Des Com (in) 6,884.9 6,340.4 35.74 DEPLOY Seal Bore Deployment sleeve 1.900 CONDUCTOR,40.0-121.0—A Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl • Top(ftKB) (ttKB) (3 Des Com Run Date ID(in) SAFETY ALA,1791.7 6,994.0 6,429.2 35.30 WHIPSTOCK Baker XL Monobore Whipstock 3/27/2016 Perforations&Slots Shot Dene Top(TVD) N)Btm D (shots/ Top IRKS) Btm(ftKB) MB) (ftKB) Zone Date ft) Type Com 7,372.0 10,518.0 6468.3 6,463.5 C-3,1H-10A 4/3/2016 SLOTS alternating solid/slotted GAS LIFT;2,503.9 pipe-.0125 x 2.5"@ 4 circumferential adjacent rows Stimulations&Treatments Proppant Designed(Ib) Proppant In Formation(Ib) Date I 10/26/2006 Cement Squeezes GAS LIFT;3,963.3 Top(11/13) Btm)TVD) Top(ftKB) atm(ftKB) (ftKB) (ftKB) Des Start Date Com 6,970.0 6,990.0 6,409.7 6,426.0 Cement 3/6/2016 Squeezed the perfs from 6970 to 6990 Squeeze Notes:General&Safety End Date Annotation NOTE: SURFACE;39.8-4,394.3 [�� GAS LIFT;4,656.5—� ■ GAS LIFT,5.385.1 GAS LIFT;6.108.5a GAS LIFT;6,487.2 1-1 GAS LIFT,6.809.5 , (,y SEAL ASSY;6,857.0 PACKER;6,857.9 APERF;6,8750-6,977.0— NIPPLE;6,881.4 SOS;6,893.1 CEMENT SOZ;6,916.0 ftKB t' RPERF;6,974.0-6,9840 Cement Squeeze;6,970.0 ftKB FRAC;6,970.0 RPERF,6,970.0-6,990.0 • APERF;6,970.0-7,025.0 I Z. %• PRODUCTION;39.2-6,994.0, • WHIPSTOCK 6s94.0 - SLOTS:7,372.0-10,518.0 A LATERAL LINER ASSY; i I 6034.9-10,518.0 KUP P OD 1H-10 ConocoPhillips 'x Well Attribu 'Max Angle TD a Alaska,Its:. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Conocophi(lips 500292234600 KUPARUK RIVER UNIT PROD 35.94 6,622.90 7,561.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-10.4/12/20172:42:36 PM SSSV:TRDP 50 7/29/2015 Last WO: 6/16/1993 3/4/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,198.0 8/2/2015 Rev Reason:PULL FLOW THRU SLIP-STOP w/ pproven 3/3/2017 g,� SPARTEK GAUGES HANGER,37.6 1111171_ Casing Strings - .. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ` CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED 1.... Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread II SURFACE 95/8 8.921 39.8 4,394.3 4,273.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread CONDUCTOR;40.0-777.0 ""PRODUCTION 7 6.276 39.2 7,535.0 6,870.9 26.00 J-55 AB-MOD Tubing Strings Tubing Description I String Ma,..IID(in) I Top(ftKB) [Set Depth(ft..]Set Depth(TVD)(...I Wt(lb/ft) !Grade I Top Connection TUBING 4"x3.5" 4 3.476 37.6 6,89401 6,347.8 11.00 J-55 DSSHTC sAFErvVLV;,.791.7 Pa i�. Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Corn (in) 37.6 37.6 0.73 HANGER FMC GEN IV HANGER 4.000 GAS LIFT,2,003.9 1,791.7 1,791.7 0.73 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 I H. 3,931.7 3,880.3 27.35 XO Reducing CROSSOVER 4 x 3.5 3.500 6,857.0 6,317.8 35.90 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,857.9 6,318.5 35.90 PACKER BAKER FB-1 PERMANENT PACKER 3.000 6,881.4 6,337.5 35.76 NIPPLE OTIS XN NIPPLE 2.81"POLISHED BORE w/2.75"NO 2.750 GAS LIFT;3,963.3 CE GO 6,893.1 6,347.1 35.69 SOS BAKER SHEAR OUT SUB 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top)TVD) Top Incl Top(kKB) (ftKB) (°) Des Corn Run Date ID(in) 7,210.0 6,605.2 35,50 FISH BHA left in hole,TOL=13.466' 8/8/2015 SURFACE;39.84394.3-•• 7,440.0 6,793.1 35.02 FISH PLUG WEATHERFORD 2.5"IBP-LOST 10/5/2006 DOWNHOLE IN RATHOLE 10/2/2006 GAS LIFT;4,656.5 Perforations&Slots shot GAS LIFT:5,385.1 Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,875.0 6,877.0 6,332.3 6,334.0 A-4,1H-10 2/2/2016 3.0 APERF 2"HSC/120 GAS LIFT;6,108.5 .- 6,970.0 7,025.0 6,409.7 6,454.5 C-4,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg Phasing GAS LIFT;6.487.2 6,970.0 6,990.0 6,409.7 6,426.0 C-4,1H-10 10/18/2006 6.0 RPERF 6 SPF,2506 HYPERJET,PENT= 13.1",EH=0.43" 6,974.0 6,984,0 6,412.9 6,421.1 C-4,1H-10 4/6/2006 6.0 RPERF 2.5"HSD GUN,2506 PJ GAS LIFT,6,809.5 4- HMX,60 deg phase 7,034.0 7,048.0 6,461.9 6,473.3 C-3,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg Phasing 7,098.0 7,124.0 6,514.0 6,535.2 C-1,UNIT B, 9/6/1993 6.0 APERF 1 11/16"Strip Gun;0 SEAL ASSY,6.8570 •=• 1H-10 deg Ph PACKER,5857.9 ' i. 7,310.0 7,345.0 6,686.7 6,715.3 A-4,1H-10 6/16/1993 4.0 IPERF SWS 4.5"Csg Gun; Oriented 68 deg.CCW f/ High Side APERF;6,875.06,877.0-. I Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(Ib) Date NIPPLE;68814 1 10/26/2006 Stimulations&Treatments Vol Clean Pump Stg o Top(ftKB) Btm(kKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 1 6,970.0 6,990.0 10/26/2006 SOS,sass, ,,,11.i. Cement Squeezes Top(TVD) Btm(TVD) Top)ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn it RPERF,6.974.06,984.0 6,916.0 7,230.0 6,365.6 6,621.5 CMT SOZ 10/14/200 Cement Squeeze;6,970.0 kKB * 3 6 FRAC;6,970.0 \ e. 7,025.0 7,245.0 6,454.5 6,633.7 Cement Plug 3/6/2016 pumped cement 6860 to 7245,milled to 7025 RPERF;6,970.06.990.0 N S' Mandrel Inserts WHIPSTOCK;6,9940 St APERF,6,970.0-7,025.01 ` ' ati A LATERAL LINER ASSY.` S. Ton Top(TVD) Valve Latch Port Size TRO Run 6.884.9-10.518.0 y N Top(ftKB) (ftKB) Make Model OD(in) - Sere Type Type (in) (psi) Run Date Com A ` 1 2,503.9 2,503.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,374.0 4/17/2016 Pi 2 3,963.3 3,908.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,380.0 4/17/2016 APERF:7,034.0-7.048.0 .\ 1 - 3- 4,656.5 4,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/29/2016 4 5,385.1 5,099.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,360.0 4/17/2016 CEMENT SW.6,916.0 kKB ,41 APERF;7,0198.0.7,124.0-•* 5 6,108.5 5,698.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 4/17/2016 A s 6 6,487.2 6,013.7 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 6/16/1993 8'30 A s 7 6,809.5 6,279.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 4/17/2016 FISH;7.2/00 * Notes:General&Safety End Date Annotation 9/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 • Cement Plug.7,025.0 kKB IPERF',7,310.0-7.345.0 1 FISH;7,440,0 f-411 PRODUCTION;39.2-7.535.0 4` • • o ✓ O , •-' N 9 N E Y (0 0) • V F O Tr O r-: .CV • • 0 O. • CO 01 A ti (NI z 'll Q a O o U J d •�. 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Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended lb.Well Class: 20AAC 25.105 zoPAc 25.110 Development RI Exploratory ❑ GINJ ❑ WINJ❑ WAGE' WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 4/4/2016 216-019 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 3/28/2016 50-029-22346-01 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 619'FNL, 796'FEL, Sec 33,T12N, R10E, UM 4/2/2016 KRU 1H-10A Top of Productive Interval: 9. Ref Elevations: KB:96 17. Field/Pool(s): 435'FNL,4046'FEL, Sec 34,T12N, R10E, UM GL: 54 BF: 56 Kupurak River Field/Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3559'FNL, 985'FEL, Sec 28,T12N, R10E, UM n/a ADL 25639 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 549551 y- 5980083 Zone- 4 10518/6463 ALK 464 TPI: x- 551579 y- 5980281 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 549342 y- 5982422 Zone- 4 1792/1792 1609/1609 5. Directional or Inclination Survey: Yes RI (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)I 6994/6429 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 CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 40 121 40 121 24 200 sx PF C CMT -9-5/8 36 J-55 40 4394 40 4273 12.25 845 sx Perm E 420 sx ClassG 7 26 J-55 38 7535 38 6871 8.5 210 sx ClassG CMT 2 3/8 4.6 L-80 6884 10518 6340 6463 3 Slotted Liner 24. Open to production or injection? Yes RI 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): 4 x 3.5 6894 6857/6318 Slots 7372-10518 MD,6468-6463 TVD '�IV�F[ _�+�� 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 � /u/ (D Per 20 AAC 25.283(i)(2)attach electronic and printed information I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED LL 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/22/2016 GAS LIFT Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/22/2016 14hrs Test Period ... 95 557 15 176 bean 6470 scf/stb Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 213 psi 855 psi 24-Hour Rate -b. 163 955 26 23.5 API Form 10-407 Revised 11/2015 VII, 5/.3 d lv, CONTINUED ON PAGE 2 RBDMS LL MAY 0 3 2016Submit ORIGINIAL only • • 28.CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD ND Well tested? Yes ❑ No ❑ Permafrost-Top Surface Surface If yes, list intervals and formations tested,briefly summarizing test results. Permafrost-Base 1609 1609 Attach separate pages to this form, if needed,and submit detailed test Top of Productive Interval 6994 6429 information,including reports,per 20 AAC 25.071. Top C3 7029 6456 Top C2 7169 6490 Top C2/Inverted 7244 6485 Top C3/Inverted 7520 6452 Top C3 10349 6443 TD(Kuparuk C3) 10518 6463 Formation at total depth: Kuparuk C3 31. List of Attachments: Daily Operations Summary,Definitive Survey,Schematics Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclinatio survey,core analysis, oaleontoloaical 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. yi Contact: Keith Herring 263-4321 Email: Keith.E.Herring(rilcop.com l. '%," +-C//(► Printed Name: J. Burke Title: SR.CTD ENGINEER Si natur Phone: 265-6097 Date: 5/20// INSTRUCTIONS General: his form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item lb: 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). Slots 7372-Report measured depth and true vertical thickness of permafrost.Provide MD and ND 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 • a -a a) a) a) a) > > C c (nMMONI- OC I,- I,- r- M co CA co L[) Nr CO • COOMMMMMM Cr) CO X _ O 0) CA000 NCr) Cr) M O' a) • CO v v CO v v v Nr 2I � -• CO CO CD CD CO CD CO CO Q E ▪ 0) CA N O 0) co----- CA U • —• C000N- Ir- OO HO @ O u_ Q� a 0 � o -a a) c a) a) a) 0 2 Cr- Fri o Y 0 N O -Ne M E Q N 0 a Y M N N M M 7 U U U U Uoccs dm � I- I-- F-- II - - H 0 F- O O E i KUP P OD 1 H-10 ConocoPhiD ips Well AttribuMax Angle TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ORB) Act Btm(ftKB) 0.4hgips 500292234600 KUPARUK RIVER UNIT PROD 35.94 6,822.90 7,561.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft( Rig Release Date 1H-10,4/27/20166.45:15AM SSSV:TRDP 50 7/29/2015 Last WO: 6/16/1993 3/4/1993 Vers I.:cherneSE(Actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,198.0 8/2/2015 Rev Reason:GLV C/O pproven 4/19/2016 HANGER;37.6 WI using Strings ■ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread CONDUCTOR I 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED W aaA Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I`V .' SURFACE 95/8 8.921 39.8 4,394.3 4,273.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WE/Len(I...Grade Top Thread PRODUCTION 7 6.276 39.2 7,535.0 6,870.9 26.00 J-55 AB-MOD CONDUCTOR;40.0.121.0 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 4"x3.5" I 4I 3.4761 37.61 6,894.01 6,347.81 11 001J-55 !Top SAFETYVLV;1,791.7 #, Completion Details Nominal ID it Top(ftKB) Top(TVD)(ORB) Top Ind(*) Item Des Com (in) 37.6 37.6 0.73 HANGER FMC GEN IV HANGER 4.000 1,791.7 1,791.7 0.73 SAFETY VLV CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 GAS LIFT;2,503.9 3,931.7 3,880.3 27.35 XO Reducing CROSSOVER 4 x 3.5 3.500 6,857.0 6,317.8 35.90 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,857.9 6,318.5 35.90 PACKER BAKER FB-1 PERMANENT PACKER 3.000 6,881.4 6,337.5 35.76 NIPPLE OTIS XN NIPPLE 2.81"POLISHED BORE w/2.75"NO - 2.750 GO GAS LIFT;3,963.3 6,893.1 6,347.1 35.69 SOS BAKER SHEAR OUT SUB 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) € il. Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,210.0 6,605.2 35.50 FISH BHA left in hole,TOL=13.466' 8/8/2015 7,440.0 6,793.1 35.02 FISH PLUG WEATHERFORD 2.5"IBP-LOST 10/5/2006 DOWNHOLE IN RATHOLE 10/2/2006 SURFACE,39.8-4,394.3- Perforations&Slots GAS LIFT;4,656.5 Shot ■■L Dens I Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com GAS LIFT;5,385.1 6,875.0 6,877.0 6,332.3 6,334.0 A-4,1H-10 2/2/2016 3.0 APERF 2"HSC/120 6,970.0 7,025.0 6,409.7 6,454.5 C-4,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg GAS LIFT;6,108.5 I. Phasing �= 6,970.0 6,990.0 6,409.7 6,426.0 C-4,1H-10 10/18/2006 6.0 RPERF 6 SPF,2506 GAS LIFT,6,4e7.2 HYPERJET,PENT= 13.1",EH=0.43" 6,974.0 6,984.0 6,412.9 6,421.1 C-4,1H-10 4/6/2006 6.0 RPERF 2.5"HSD GUN,2506 PJ pi HMX,60 deg phase � - GAS LIFT;6809.5 : 7034.0 7,048.0 6,461.9 6,473.3 C-3,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg Phasing III 7.098.0 7,124.0 6,514.0 6,535.2 C-1,UNIT B, 9/6/1993 6.0 APERF 1 11/16"Strip Gun;0 1H-10 deg Ph II /,310.0 7,345.0 6,686.7 6,715.3 A-4,1H-10 6/16/1993 4.0 IPERF SWS 4.5"Csg Gun; SEAL ASSY;56520 - Oriented 68 deg.CCW f/ High Side PACKER;8,857.9 Stimulations&Treatments Mm Top Mac Btm APERF;6,675.08,877.0 I Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 6,970.0 6,990.0 6,409.7 6,426.0 FRAC 10/26/200 PUMP C-SAND 6970'-6990'FRAC.W/YF150A GEL NIPPLE,6,881.4 - 6 1084728 16/20 CARBO PROP,PUMPED TOTAL OF 112%OF DESIGN,EXTEND 10 PPA STAGE TO 117 BBLS FROM 60.FLUSH W/10 BBLS WF-20 AND 59 l; DIESEL.FLUSHED TO COMPLETION,FINAL PUMPING PRESSURE 4556 PSI,ISIP=2593 PSI (2260 PSI EST.BOTTOM HOLE PRESSURE). SOS,6,893.1 ;hair I� Cement Squeezes Top(TVD) Btm(TVD) RPERF;8,974.0-6,984.0 i I Top(ftKB) Mtn(ftKB) (ftKB) (ftKB) Des Start Date Com RPERF:6.970.08,990.01 a 6,916.0 7,230.0 6,365.6 6,621.5 CMT SOZ 10/141200 FRAC;8,970.0 ., 6 WHIPSTOCK:8,994.0 I,$ 7,025.0 7,245.0 6,454.5 6,633.7 Cement Plug 3/6/2016 pumped cement 6860 to 7245,milled to 7025 APERF,6,970.0-7,025.0 d Mandrel Inserts A LATERAL LINER ASSY; :7Kyt 6,884.9-70,518.0 Y ii at i on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) MKS) Make Model OD(in) Sero Type Type (in) (psi) Run Date Com APERF;7,034.0-7,046.0 $r4:1021 1 2,503.9 2,503.6 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,374.0 4/17/2016 OKAtiOcInit 2 3,963.3 3,908.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,380.0 4/17/2016 3 4,656.5 4,495.0 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 1/29/2016 APERF;7,098.0-7,124.0-- 4 5,385.1 5,099.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,360.0 4/17/2016 5 6,108.5 5,698.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 4/17/2016 -.viN.A 6 6,487.2 6,013.7 CAMCO 'KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 6/160993 8:30 FISH;7,210.0 x. _ k .k 7 6,809.5 6,279.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 407/2016 Ys,AreAPa Notes:General&Safety End Date Annotation 9/23/2010 NOTE View Schematic w/Alaska Schemat1c9.0 (PERF;7,310.0-7,34.5.0I - FISH;7,440.0 lip PRODUCTION;39.2-7,535.0 ..f KUP P OD 1H-10A conocaphiiiips z Well Attribu Max Angl( D TD Ala. Inc Wellbore APIIUWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) CaocoPhlll ps 500292234601 KUPARUK RIVER UNIT PROD 98.19 7,285.24 10,518.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1H-10A,4/27/20166:45:45 AM SSSV:TRDP 50 7/29/2015 Last WO: 3/4/1993 Vertical achemaho(eo)Uo9... . Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ADD LATERAL lehallf 4/13/2016 HANGER 37 6 "Oil Casing Strings 1Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread !r _ A LATERAL LINER 2 3/8 1.992 6,884.9 10518.0 6,463.5 4.60 L-80 ST-L ASSY a,�`, Liner Details Nominal ID I , y Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (In) 6,884.9 6,340.4 35.74 DEPLOY Seal Bore Deployment sleeve 1.900 CONDUCTOR;40.0-121.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID On) 6,994.0 6,429.2 35.30 WHIPSTOCK Baker XL Monobore Whipstock 3/27/2016 SAFETY VLV;1,791 7 T Perforations&Slots al Shot it Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,372.0 10,518.0 6,468.3 6,463.5 C-3,11-1-10A 4/3/2016 SLOTS alternating solid/slotted GAS LIFT;2,503.9 pipe-.0125x2.5"@4 circumferential adjacent rows Cement Squeezes Top(TVD) Btm(TVD) ITTop(ftKB) 81m(ftKB) (ftKB) (ftKB) Den Start Date Corn 6,970 6,990.0 6,409.7 6.426.0 Cement 3/6/2016 Squeezed the perfs from 6970 to 6990 Squeeze GAS LIFT,3,963.3 Notes:General&Safety End Date Annotation NOTE. • • • SURFACE;39.8-4,394.3-.• GAS LIFT;4,658.5 GAS LIFT;5,385.1 tr GAS LIFT;6,108.5 4'._ I GAS LIFT;6,487.2 ji 11 GAS LIFT,6,509.5 I I SEAL ASSY,6,857.0 PACKER;6,857.9 APERF;6,875.0-6877.0- NIPPLE,6881 4 SOS,6,893.1 RPERF;6,974 0-6,964 FRAC;6,970.0 RPERF;6,970.0-8,9900 APERF;6,97007,025.0 PRODUCTION;39.2-7,535.0, WHIPSTOCK;6,994.0 SLOTS;7,372 0-10518.0 A LATERAL LINER ASSY; J r 6884.9-10,518 0 • • 1H-10 Final CTD Schematic Modified by KEH 4-4-16 4"Camco TRDP-4A-RO SSSV at 1792'RKB(not locked out) �.•-a_ ID=2.812" 4",11#,J-55,DSSHTC tubing to 3932'RKB 16"62.5#H-40 at — _ 3'W'9.3#J-55 EUE 8rd tubing below 3932'RKB 121'MD 4"Camco KBMG mandrel at 2504'RKB 3'W'Camco KBUG gas lift mandrels at 3963',4657,5385', 6109',and 6487'RKB 9-5/8"36#J-55 at 3'W Camco MMG-2 mandrel at 6809'RKB(6805'PDC) 4394'MD Baker GBH-22 locator seal assemly at 6857'RKB Baker FB-1 packer(3.0"ID)at 6858'RKB(6865'PDC) XN nipple at 6881'RKB(6879'PDC) (Milled out to 2.80"I0) 3'Y"tubing tail at 6893'RKB(6891'PDC') 2-3/8"Baker Seal Bore Deployment Sleeve @ 6884'MD for future KB Packer KOP @ 6994'MD Cemtent pilot hole milled \, to 7025'MD C-sand perfs(sgz'd) 6970'-7048'MD 7098'-7124'MD _ k ci • s • • A-sand perfs ? 1H-10A TD=10518'MD 7310'-7345 MD 2-3/8"Solid Liner 6891'-7372'MD 2-3/8"Slotted Liner 7372'-10518'MD Covered by fill up to 7228' y F ;;, MD TOL=6884'MD,BOL=10518'MD t�ti 7535'MD ronamaaaz.anz+zs.a, S • ,. .. Drilling Operations Summary (with Timelog Depths) 6 &Wens 1H-10 ConocoPhillips i Aiaaw Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/23/2016 3/23/2016 3.00 MIRU MOVE MOB P Continue to MOB off 2K-25 to 1H-10 0.0 0.0 10:00 13:00 3/23/2016 3/23/2016 3.00 MIRU MOVE MOB P Northern Energy services trucks on 0.0 0.0 13:00 16:00 location,PJSM load up shop 3/23/2016 3/24/2016 8.00 MIRU MOVE MOB P Leave 2K pad Mob to 1H 0.0 0.0 16:00 00:00 3/24/2016 3/24/2016 4.00 MIRU MOVE MOB P Arrive at 1H-de jeep and spot rig on 0.0 0.0 00:00 04:00 1-R 3/24/2016 3/24/2016 6.00 MIRU MOVE RURD P Rig up on 1R-work post rig move 0.0 0.0 04:00 10:00 checklist, Rig up cellar,swap out in micro motion 3/24/2016 3/24/2016 4.00 MIRU WHDBOP NUND P 10:00 Rig accept, Nipple up stack, 0.0 0.0 10:00 14:00 Swap out apapter flanges,4 1/16"tree 3/24/2016 3/24/2016 1.00 MIRU WHDBOP RURD P Tighten well head bolts,all loose 0.0 0.0 14:00 15:00 3/24/2016 3/24/2016 2.00 MIRU WHDBOP RURD P Grease crew here to repair Tango 0.0 15:00 17:00 valve grease port-broken. Fill stack for shell test repair stem packing on same valve 3/24/2016 3/25/2016 7.00 MIRU WHDBOP BORE P Start BOP test,250 psi low/4200 psi 0.0 0.0 17:00 00:00 high,Witness waived by Bob Noble 3/25/2016 3/25/2016 4.00 MIRU WHDBOP BORE T Continue performing initial BOP test 0.0 0.0 00:00 04:00 3/25/2016 3/25/2016 5.00 SLOT RIGMNT CTOP P PJSM,perform pipe management, 0.0 0.0 04:00 09:00 trim 1425 ft.of coil. 3/25/2016 3/25/2016 2.00 SLOT RIGMNT CTOP P PJSM, Boot e-line,Fill coil, PT inner 0.0 0.0 09:00 11:00 reel iron,pack offs,and new micro motion install 3/25/2016 3/25/2016 1.00 SLOT RIGMNT CTOP P Pump slack mgmt,cut 57'of pipe and 0.0 0.0 11:00 12:00 find wire.Trimmed 75for 1500'total 3/25/2016 3/25/2016 1.50 SLOT RIGMNT CTOP P PJSM,Prep coil for connector instal, 0.0 0.0 12:00 13:30 Instal CTC and pull to 35K, Head up e -line to UQC, PT CTC/UQC to 4K 3/25/2016 3/25/2016 2.00 SLOT WHDBOP PRTS P PJSM, PT PDL's to 1500 PSI,TT to 0.0 0.0 13:30 15:30 1500PSI 3/25/2016 3/25/2016 2.00 SLOT WHDBOP MPSP P PJSM, R/U BPV Lubricator, Pull TWC 0.0 0.0 15:30 17:30 3/25/2016 3/25/2016 1.00 SLOT WHDBOP RURD P Crew change, PJSM, pressure up on 0.0 0.0 17:30 18:30 SSSV from 2000 psi to 4500 psi, install fuseable cap on SSV-log onto safety defeat log in doghouse. 3/25/2016 3/25/2016 1.00 SLOT WHDBOP RURD P Perform valve checklist,inspect Top 0.0 0.0 18:30 19:30 Drive. 3/25/2016 3/25/2016 1.50 PROD1 RPEQPT PULD P PJSM, MU pilot hole milling BHA#1 0.0 62.5 19:30 21:00 3/25/2016 3/25/2016 0.75 PROD1 RPEQPT TRIP P RIH,with BHA#1,0.9°bend motor 62.5 1,795.0 21:00 21:45 and new D331 mill(slick gauge) 3/25/2016 3/25/2016 1.00 PROD1 RPEQPT TRIP P 1795 ft,Tag SSSV 30 fpm at 0.3 bpm, 1,795.0 1,800.0 21:45 22:45 set down 6k,PUW 15k,try different TF,no success,pressure up to 1500 psi on the tubing noticed flapper shift down hole,continue RIH thru SSSV clean, 3/25/2016 3/25/2016 1.00 PROD1 RPEQPT TRIP P Continue RIH to tie in depth. 1,800.0 6,740.0 22:45 23:45 3/25/2016 3/26/2016 0.25 PROD1 RPEQPT DLOG P 6740 ft,log HRZ and K1 for baseline 6,740.0 6,785.0 23:45 00:00 corrrection of Page 1/8 Report Printed: 4/5/2016 •Operations Summary (with TimelogDepths) Mining p ,, W+ 1H-10 Conoco lliips s-. RLuks Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 3/26/2016 3/26/2016 0.25 PROD1 RPEQPT DLOG P 6785 ft,continue logging for tie in, 6,785.0 6,862.0 00:00 00:15 correction of plus 1.5 ft. 3/26/2016 3/26/2016 6.00 PROD1 RPEQPT MILL P Tag TOC at 6862 ft,PUW 30k,bring 6,862.0 6,900.0 00:15 06:15 pump up to 1.6 bpm at 2500 psi,swap to vis SW,BHP 3168, IA 808,OA 434 Mill pilot hole. 3/26/2016 3/26/2016 3.20 PROD1 RPEQPT MILL P Stall 3 times here,-7'below TT,most 6,900.0 6,925.0 06:15 09:27 likely 7"casing contact. mill 1'at 180° out 3/26/2016 3/26/2016 4.60 PROD1 RPEQPT MILL P 6925,Stall multiple times,Correletes 6,925.0 6,986.0 09:27 14:03 to 7"collar 3/26/2016 3/26/2016 0.40 PROD1 RPEQPT WPRT P 6986,Stall, Pump sweeps and chase 6,986.0 6,986.0 14:03 14:27 to TOC, PUW=35K, Motor work at transition area and TOO 3/26/2016 3/26/2016 4.00 PROD1 RPEQPT MILL P 6986', Mill, 1.6 BPM @ 2280 PSI FS, 6,986.0 7,025.0 14:27 18:27 BHP=3189,ROP=-15 FPH, DHWOB=1.9K 3/26/2016 3/26/2016 1.50 PROD1 RPEQPT REAM P 7025 ft.TD cement pilot hole,pump 7,025.0 6,862.0 18:27 19:57 5x5 sweep, PUW 32k, PUH,ream transition area,pumping 1.6 bpm at 2230 psi, BHP 3185,WHP 0, IA 566, OA 740 3/26/2016 3/26/2016 0.50 PROD1 RPEQPT OWFF P Check well for flow 6,862.0 6,862.0 19:57 20:27 3/26/2016 3/26/2016 1.50 PROD1 RPEQPT TRIP P POOH,pumping 1.5 bpm at 2130 psi, 6,862.0 62.5 20:27 21:57 EDC closed. pumping 5x5 sweep at 3931 ft. 3/26/2016 3/26/2016 0.50 PROD1 RPEQPT OWFF P Check well for flow, PJSM 62.5 62.5 21:57 22:27 3/26/2016 3/26/2016 0.75 PROD1 RPEQPT PULD P LD milling BHA#1,gauge mill 2.78 62.5 0.0 22:27 23:12 OD no-go. 3/26/2016 3/27/2016 0.80 PROD1 RPEQPT PULD P MU nozzle,stab INJH,jet stack. 0.0 0.0 23:12 00:00 3/27/2016 3/27/2016 0.85 PROD1 i RPEQPT PULD P PJSM,PU/MU Haliburton caliper 0.0 21.8 00:00 00:51 tools,and Coiltrak tools. 3/27/2016 3/27/2016 0.25 PROD1 RPEQPT PULD P Test Haliburton caliper,looks good, 21.8 21.8 00:51 01:06 tag up and reset counters, RIH, pumping 3/27/2016 3/27/2016 1.50 PROD1 RPEQPT TRIP P RIH, pumping min rate 0.32 bpm, 100 21.8 7,015.0 01:06 02:36 fpm,slowing down for jewelry. Drive by K1 no correction. 3/27/2016 3/27/2016 1.24 PROD1 RPEQPT DLOG P 7015 ft,First pass log up at 40 fpm up 7,015.0 5,980.0 02:36 03:50 to 5980 ft, RBIH to 7015 ft.Second pass log up at 40 fpm up to 5980 ft. 3/27/2016 3/27/2016 1.20 PROD1 RPEQPT TRIP P 5980 ft, POOH pumping 0.8 bpm at 5,980.0 21.0 03:50 05:02 800 psi, IA 317,OA 507 3/27/2016 3/27/2016 1.00 PROD1 RPEQPT PULD P At surface,perform 30 min no flow- 21.0 0.0 05:02 06:02 lay down BHA#2 caliper running BHA 3/27/2016 3/27/2016 2.40 PROD1 WHPST PULD P P/U and M/U BHA#3 whipstock 0.0 73.0 06:02 08:26 setting BHA, M/U to coil track and surface test.Open EDC circ freshwater to in Micro motion and set zero 3/27/2016 3/27/2016 2.10 PROD1 WHPST TRIP P Trip in hole with whipstock 73.0 6,795.0 08:26 10:32 3/27/2016 3/27/2016 0.10 PROD1 WHPST DLOG P Log K1 for+1',PUW=32K 6,795.0 6,810.0 10:32 10:38 Page 2/8 Report Printed: 4/5/2016 • • Divining Operations Summary (with Timelog Depths) CA &wens 1H-10 C onocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 3/27/2016 3/27/2016 0.40 PROD1 WHPST TRIP P Continue in hole,Get to set depth of 6,810.0 7,005.5 10:38 11:02 7005.5,TOWS @ 6995.Orient to 10° LOHS. Bring on pumps see tool shift @ 3500 PSI,Set down 4K 3/27/2016 3/27/2016 1.50 PROD1 WHPST TRIP P Trip out after setting whipstock 7,005.5 79.0 11:02 12:32 3/27/2016 3/27/2016 1.00 PROD1 WHPST PULD P At surface,30 min flow check.PJSM, 79.0 0.0 12:32 13:32 Lay down BHA#3 whipstock setting. 3/27/2016 3/27/2016 0.50 PROD1 WHPST PULD 'P M/U BHA#4,window milling BHA 0.0 74.3 13:32 14:02 with.6°motor,2.80 window mill and string reamer,M/U to coil and surface test 3/27/2016 3/27/2016 1.90 PROD1 WHPST TRIP P 'Trip in 74.3 6,795.0 14:02 15:56 3/27/2016 3/27/2016 0.10 PROD1 WHPST DLOG P Log K1 for+.5, 6,795.0 6,814.0 15:56 16:02 3/27/2016 3/27/2016 0.70 PROD1 'WHPST CIRC P Open EDC and displace to 8.45 PPG 6,814.0 6,850.0 16:02 16:44 floPro 3/27/2016 3/27/2016 0.20 PROD1 WHPST TRIP P Close EDC,trip in to dry tag whipstock 6,850.0 6,994.3 16:44 16:56 3/27/2016 3/28/2016 7.06 PROD1 WHPST WPST P Call pinch point @ 6693.8, 1.5 BPM @ 6,994.3 6,995.7 16:56 00:00 2610 PSI FS 3/28/2016 3/28/2016 4.00 PROD1 WHPST WPST P OBM,window 1.51 bpm at 2700 psi 6,995.7 6,997.9 00:00 04:00 on bottom,BHP 3214,open choke, IA 499,OA 694 3/28/2016 3/28/2016 1.30'PROD1 WHPST WPST P 6997.9 ft, Midpoint,time milling 1.52 6,997.9 6,998.8 04:00 05:18 bpm at 2800 psi, BHP 3219,Open choke, IA 231,OA 360 3/28/2016 3/28/2016 2.70 PROD1 WHPST WPST P 6998.8',call window exit,Start drilling 6,998.8 7,016.0 05:18 08:00 rathole 3/28/2016 3/28/2016 1.20 PROD1 WHPST REAM P Make reaming pass per procedure,as 7,016.0 7,016.0 08:00 09:12 drilled,Dry drift looks good 3/28/2016 3/28/2016 1.50 PROD1 WHPST TRIP P Trip out of well,PUW=29K,stop and 7,016.0 74.0 09:12 10:42 open EDC @ 6753 3/28/2016 3/28/2016 1.30 PROD1 WHPST PULD P At surface,30 Min flow check-good, 74.0 0.0 10:42 12:00 Lay down window milling BHA#4 3/28/2016 3/28/2016 0.90 PROD1 DRILL PULD P PJSM, P/U BHA#5 Build section BHA 0.0 72.2 12:00 12:54 w 2.35°AKO motor and RR HCC bi center, M/U to coil and surface test 3/28/2016 3/28/2016 1.30 PROD1 DRILL TRIP P Trip in hole,EDC open 72.2 6,780.0 12:54 14:12 3/28/2016 3/28/2016 0.10 PROD1 DRILL DLOG P Log K1 for+3', PUW=+3' 6,780.0 6,800.0 14:12 14:18 3/28/2016 3/28/2016 0.20 PROD1 DRILL TRIP P Continue in well,clean pass through 6,800.0 7,016.0 14:18 14:30 window,tag up at 7016 3/28/2016 3/28/2016 0.30 PROD1 DRILL DRLG P 7016',Drill, 1.51 BPM @ 2647 PSI 7,016.0 7,024.0 14:30 14:48 FS,BHP=3253 3/28/2016 3/28/2016 0.20 PROD1 DRILL WPRT P 7024 high diff pressure-unable to 7,024.0 6,850.0 14:48 15:00 pump,PUH above TOC 3/28/2016 3/28/2016 0.20 PROD1 DRILL WPRT P Above TOC,open EDC, 1.5 BPM with 6,850.0 6,850.0 15:00 15:12 2200PS1 pump pressure 10 PSI diff pressure,Close EDC to test pressures.Still unable to circulate,.4 BPM @ 1537 PSI Pump,700PSI Diff. 3/28/2016 3/28/2016 1.50 PROD1 DRILL TRIP T Trip out to inspect BHA 6,850.0 72.2 15:12 16:42 Page 3/8 Report Printed: 4/5/2016 Operations Summary (with Timelog Depths) &Mils 1H-10 C:onocoPhiffi ps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/28/2016 3/28/2016 0.75 PROD1 DRILL PULD T Check well for flow, Inspect BHA, 72.2 0.0 16:42 17:27 found X-Treme motor to be locked up 3/28/2016 3/28/2016 1.25 PROD1 DRILL PULD T MU new 2-3/8"X-Treme motor and 0.0 72.2 17:27 18:42 RR HHC bi-center bit.Surface test coiltrak tools,tag up,reset counters. 3/28/2016 3/28/2016 1.25 PROD1 DRILL TRIP T RIH,build section BHA#6,2.35°bend 72.2 6,780.0 18:42 19:57 motor,and RR bit. 3/28/2016 3/28/2016 0.25 PROD1 DRILL DLOG T 6780 ft,Log K1 correction of plus 1.0 6,780.0 6,800.0 19:57 20:12 ft.PUW 30k 3/28/2016 3/28/2016 0.25 PROD1 DRILL TRIP T 6800 ft,continue IRIH thru window. 6,800.0 7,026.0 20:12 20:27 3/28/2016 3/28/2016 1.50 PROD1 DRILL DRLG T 7026 ft,OBD 1.5 bpm at 2790 psi FS, 7,026.0 7,075.0 20:27 21:57 BHP 3020,Open Choke, IA 284,OA 423 ****Note:5 hrs BHI DT 3/28/2016 3/28/2016 0.25 PROD1 DRILL WPRT P 7075 ft, PUH for corrected WS 7,075.0 6,780.0 21:57 22:12 numbers. PUW 30k 3/28/2016 3/28/2016 0.25 PROD1 DRILL DLOG P 6780 ft, log K1 correction of plus 0.5 ft. 6,780.0 6,800.0 22:12 22:27 3/28/2016 3/28/2016 0.15 PROD1 DRILL DLOG P 6800 ft, RIH log RA marker, 6,800.0 7,075.0 22:27 22:36 TOW-6994' BOW-6999' RA -7001.5' 3/28/2016 3/29/2016 1.40 PROD1 DRILL DRLG 'P 7075 ft, BOBD 1.55 bpm at 2700 psi 7,075.0 7,097.0 22:36 00:00 FS, BHP 3280,open choke, IA 300, OA 426 ****Note:control drilling due to high dgls>47° 3/29/2016 3/29/2016 5.00'PROD1 DRILL DRLG P OBD 1.55 bpm at 2775 psi,BHP 7,097.0 7,168.0 00:00 05:00 3304,open choke, IA 400,OA 485 3/29/2016 3/29/2016 1.00 PROD1 DRILL DRLG P 7168 ft,OBD 1.54 bpm at 2751 psi, 7,168.0 7,182.0 05:00 06:00 BHP 3317,open choke, IA 446,OA 510 3/29/2016 3/29/2016 3.30 PROD1 DRILL DRLG P OBD,on harder formation,ROP 7,182.0' 7,215.0 06:00 09:18 <15FPH, 1.5 BPM @ 2712 PSI FS 3/29/2016 3/29/2016 0.20 PROD1 DRILL WPRT P 'Mini wiper to 708()ft,PUW=34K,clean 7,215.0 7,215.0 09:18 09:30 trip 3/29/2016 3/29/2016 3.70 PROD1 DRILL DRLG P 7215', Drill, 1.55 E3PM @ 2721 PSI 7,215.0 7,260.0 09:30 13:12 FS,At 7221'Pumped 15 BBI pill of screen clean to clear possible bit balling. No real change in ROP. 3/29/2016 3/29/2016 3.00 PROD1 DRILL DRLG P 7260 Pump rest of screen clean pill, 7,260.0 7,305.0 13:12 16:12 no indication of help,Continue to drill, 1.6 BPM @ 2741 PSI FS, BHP=3340 3/29/2016 3/29/2016 1.80 PROD1 DRILL TRIP P 7305 call End of Build-Pump 5 X 5 7,305.0 72.0 16:12 18:00 Sweeps,trip out,PUW-31K 3/29/2016 3/29/2016 0.50 PROD1 DRILL OWFF P No flow at surface. 72.0 72.0 18:00 18:30 3/29/2016 3/29/2016 1.15 PROD1 DRILL PULD P PJSM.LD BHA#6,inspect BHA, LD 72.0 0.0 18:30 19:39 motor&bit,no indication of poor performance,pictures of bit on S:drive. Replace Floats and test CC& UQC,good test to 4,000 psi. 3/29/2016 3/29/2016 0.90 PROD1 DRILL PULD P PJSM. MU BHA#7, new motor&RB 0.0 72.5 19:39 20:33 HYC bit Page 4/8 Report Printed: 4/5/2016 • • [aril - Operations Summary (with Timelog Depths) .,, &Wells 1H-10 ConocoPhitl ps Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 3/29/2016 3/29/2016 2.00 PROD1 DRILL TRIP P RIH w/A lateral drilling assembly, 72.5 7,305.0 20:33 22:33 shallow test at surface, DP 550 psi,a little high.Continue in hole,log K1 for +1'correction,PUW=31 K.RIH to 7,305'. 3/29/2016 3/30/2016 1.45 PROD1 DRILL DRLG P BOBD: 1.52 BPM @ 3,150 psi, 7,305.0 7,365.0 22:33 00:00 BHP=3,320 psi,CTW=11.3K, WOB=2K,ROP=45. 3/30/2016 3/30/2016 4.75 PROD1 DRILL DRLG P BOBD: 1.52 BPM @ 3,120 psi, 7,365.0 7,710.0 00:00 04:45 BHP=3,360 psi,CTW=10.5K, WOB=1.6K, ROP=85. 3/30/2016 3/30/2016 0.70 PROD1 DRILL WPRT P Wiper trip#1 to 7050 7,710.0 7,710.0 04:45 05:27 3/30/2016 3/30/2016 3.90 PROD1 DRILL DRLG P 7710',Drill ahead, 1.52 BPM @2930 7,710.0 7,940.0 05:27 09:21 PSI FS,BHP=3447 3/30/2016 3/30/2016 2.70 PROD1 DRILL WPRT T Pull to cased hole,open EDC, Circ 7,940.0 6,830.0 09:21 12:03 bottoms up,Swap out in micro motion and test 3/30/2016 3/30/2016 0.20 PROD1 DRILL WPRT T Trip back in hole to drill,Close EDC 6,830.0 7,015.0 12:03 12:15 3/30/2016 3/30/2016 0.10 PROD1 DRILL DLOG T Log RA for+1' 7,015.0 7,029.0 12:15 12:21 3/30/2016 3/30/2016 0.40 PROD1 DRILL WPRT T Continue trip in to drill 7,029.0 7,940.0 12:21 12:45 3/30/2016 3/30/2016 9.50 PROD1 DRILL DRLG P 7940', Drill, 1.45 BPM @ 2813 PSI 7,940.0 8,340.0 12:45 22:15 FS, BHP=3413.Diffculty steering,try to head up. 3/30/2016 3/30/2016 0.85 PROD1 DRILL WPRT P Wiper trip, PUW=31 K,RBIH. 8,340.0 8,340.0 22:15 23:06 3/30/2016 3/31/2016 0.90 PROD1 DRILL DRLG P BOBD: 1.55 BPM @ 3,485 psi, 8,340.0 8,406.0 23:06 00:00 BHP=3,520 psi,CTW-6.5K, WOB=2.5K, ROP=75. 3/31/2016 3/31/2016 6.20 PROD1 DRILL DRLG P Drill ahead: 1.55 BPM @ 3,415 psi, 8,406.0 8,740.0 00:00 06:12 BHP=3,545 psi,CTW-5.5K, WOB=2.2K, ROP=90.BHA wipers @ 8,485'&8,565'.Start pumping new mud system. 3/31/2016 3/31/2016 0.80 PROD1 DRILL WPRT P Wiper#2 to 7740',PUW=34K 8,740.0 8,740.0 06:12 07:00 3/31/2016 3/31/2016 5.20 PROD1 DRILL DRLG P 8740', Drill, 1.6 BPM @ 2850 PSI FS, 8,740.0 9,140.0 07:00 12:12 BHP=3384 3/31/2016 3/31/2016 1.80 PROD1 DRILL WPRT P 9140 Wiper trip#3 to window with tie 9,140.0 9,143.0 12:12 14:00 in for+3.5' 3/31/2016 3/31/2016 1.10 PROD1 DRILL DRLG P 9143',Drill 1.6 BPM @ 3043 PSI FS, 9,143.0 9,221.0 14:00 15:06 BHP=3502 3/31/2016 3/31/2016 0.20 PROD1 DRILL WPRT P Mini Wiper, PUW=32K,Swap pumps 9,221.0 9,221.0 15:06 15:18 3/31/2016 3/31/2016 5.50 PROD1 DRILL DRLG P 9221', Drill, 1.6 BPM @ 3043 PSI FS, 9,221.0 9,540.0 15:18 20:48 BHP=3539 3/31/2016 3/31/2016 1.00 PROD1 DRILL WPRT P Wiper trip, PUW=32K, RBIH. 9,540.0 9,540.0 20:48 21:48 3/31/2016 4/1/2016 2.20 PROD1 DRILL DRLG P BOBD: 1.65 BPM @ 3,315 psi, 9,540.0 9,676.0 21:48 00:00 BHP=3,580 psi,CTW=9K,WOB=1K, ROP=65.Mini wiper @ 9,625'. Page 5/8 Report Printed: 4/5/2016 , Milling Iterations Summary (with Timelog Depths) _a 1 H-10 ConocoPhitlips Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/1/2016 4/1/2016 3.90 PROD1 DRILL DRLG P Continue drillling 1.65 BPM @ 3,315 9,676.0 9,914.0 00:00 03:54 psi,BHP=3,580 psi,CTW=9K, WOB=1 K, ROP=65.Lost gamma @ 01:50,called town,continue drilling without.When we lose push,cross cut down to upper C3 zone and call)TD. Weight trnasfer,stacking.,early wiper. 4/1/2016 4/1/2016 0.85 PROD1 DRILL WPRT P Wiper trip,PUW=32K, RBIH. 9,914.0 9,914.0 03:54 04:45 4/1/2016 4/1/2016 3.10 PROD1 DRILL DRLG P 9914',Drill 1.65 BPM @ 3300 PSI FS, 9,914.0 10,045.0 04:45 07:51 BHP=3662, Hard to get started drilling 4/1/2016 4/1/2016 0.10 PROD1 DRILL WPRT P 10045',stacking,BHA wiper, 10,045.0 10,045.0 07:51 07:57 PUW=35K 4/1/2016 4/1/2016 2.60 PROD1 DRILL DRLG P Drill, 1.5 BPM @ 2841 PSI FS, 10,045.0 10,099.0 07:57 10:33 BHP=3548,Hard getting going, CTW=2.2K, DHWOB=1.3 4/1/2016 4/1/2016 1.20 PROD1 DRILL WPRT P Wiper trip to 9730, Prep beaded pill, 10,099.0 10,099.0 10:33 11:45 PUW=31 K 4/1/2016 4/1/2016 2.70 PROD1 DRILL DRLG P Drilling,pump beaded pill, 1.51 BPM 10,099.0 10,109.0 11:45 14:27 @ 2902 PSI FS,BHP=3572, CTW=4K,DHWOB=1.9K 4/1/2016 4/1/2016 0.10 PROD1 DRILL WPRT P Been struggleing trying to go down 10,109.0 10,109.0 14:27 14:33 through zone we had to fight coming up,Turn TF up then turn dow to get through zone at steeper angle 4/1/2016 4/1/2016 2.20 PROD1 DRILL DRLG P Drill 10109 to 10125 then turn down 10,109.0 10,174.0 14:33 16:45 to 701 then 180 LOHS. 4/1/2016 4/1/2016 0.20 PROD1 DRILL WPRT P Pull BHA wiper to 10100, PUW=34K 10,174.0 10,174.0 16:45 16:57 4/1/2016 4/1/2016 1.05 PROD1 DRILL DRLG P 10174',Drill, 1.51 BPM @ 2902 PSI 10,174.0 10,243.0 16:57 18:00 FS,BHP=3603,RIW=7.5K, DHWOB=1.67K with CTW=2.95, stacking,losing weight transfer. 4/1/2016 4/1/2016 0.95 PROD1 DRILL WPRT P 1,000'wiper trip, PUW=33K,RBIH. 10,243.0 10,243.0 18:00 18:57 4/1/2016 4/1/2016 4.80 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,285 psi, 10,243.0 10,408.0 18:57 23:45 BHP=3,660 psi,CTW=-3K,WOB=1 K, ROP=25.Stacking right away,pump two beaded pill for total of 23 bbls.Still stacking,pump 20 bbl lube pill,helped initially. Losing weight transfer again. 4/1/2016 4/2/2016 0.25 PROD1 DRILL WPRT P Try another 1,000 wiper,PUW=36K. 10,408.0 10,408.0 23:45 00:00 4/2/2016 4/2/2016 0.65 PROD1 DRILL WPRT P Continue wiper trip, RBIH. 10,408.0 10,408.0 00:00 00:39 4/2/2016 4/2/2016 3.35 PROD1 DRILL DRLG P BOBD: 1.50 BPM @ 3,395 psi, 10,408.0 10,515.0 00:39 04:00 BHP=3,780 psi,CTW=-5K, WOB=.5K, ROP=15.Stacking right away,pump another beaded pill, pump remaining lube pill.Several beaded pills and lube pills required to make called TD @ 10,515'. Pump sweeps. 4/2/2016 4/2/2016 3.10 PROD1 DRILL WPRT P Long wiper to swab, Perform Jog at 10,515.0 72.0 04:00 07:06 surface,Tag up and reset depth 4/2/2016 4/2/2016 1.30 PROD1 DRILL WPRT P Run back in hole 72.0 6,830.0 07:06 08:24 Page 6/8 Report Printed: 4/5/2016 410 operations Summary (with Timelog Depths) �,, Wells 1 H-10 ConocoPhillips ,, Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 4/2/2016 4/2/2016 0.40 PROD1 DRILL DLOG P Run CCL log for depth control. No 6,830.0 6,965.0 08:24 08:48 correction. PUW=32K 4/2/2016 4/2/2016 1.90 PROD1 DRILL WPRT P Continue in hole,stacking 9395 to 6,965.0 10,518.0 08:48 10:42 9421 no DHWOB,Stack @ 9830, 10013,and 10359'.Tag corrected TD @ 10518 4/2/2016 4/2/2016 0.90 PROD1 DRILL CIRC P Pump beaded liner running pill in new 10,518.0 10,518.0 - 10:42 11:36 8.45PPG FloPro 4/2/2016 4/2/2016 2.00 PROD1 DRILL TRIP P Trip out pumping beaded liner 10,518.0 74.0 11:36 13:36 runnong pill followed by new 8.45 PPG mud. Paint EOP flags©6830 and 3200' 4/2/2016 4/2/2016 0.20 PROD1 DRILL PULD P At surface,30 minute flow check, Lay 74.0 0.0 13:36 13:48 down BHA#7, Lateral drilling bha. 4/2/2016 4/2/2016 3.00 PROD1 DRILL CTOP P Stab injector back on well,Pump fresh 0.0 0.0 13:48 16:48 water to in micormotion and calibrate. Chage-out floats&UQC. 4/2/2016 4/2/2016 0.50 PROD1 DRILL BOPE P PJSM. Function test BOP. 0.0 0.0 16:48 17:18 4/2/2016 4/2/2016 1.00 COMPZ1 CASING PUTB P Prep floor to run liner 0.0 0.0 17:18 18:18 4/2/2016 4/2/2016 5.55 COMPZ1 CASING PUTB P PJSM.PU/MU Liner assembly: Bull 0.0 3,633.0 18:18 23:51 nose, 105 jts slotted, 16 jts solid,and seal bore.deployment sleeve. 4/2/2016 4/3/2016 0.15 COMPZ1 CASING PUTB P Start MU BHA#8 3,633.0 3,633.0 23:51 00:00 4/3/2016 4/3/2016 1.00 COMPZ1 CASING PUTB P Finish MU of BHA#8. 3,633.0 3,677.5 00:00 01:00 4/3/2016 4/3/2016 2.80 COMPZ1 CASING RUNL P RIH w/liner assembly,tie-in EOP flag 3,677.5 10,517.0 01:00 03:48 for-4'correction,continue in hole. Weight check @ 6,877 37K.Sat down @ 8,556', 10,235',and 10,322'. Worked liner to 10,517',bring pump online @ 1.3 bpm,release from liner, TOL @ 6,884'. PUH,reset depth. 4/3/2016 4/3/2016 1.15 DEMOB WHDBOP CIRC P Circulate hole to seawater.POOH to 10,517.0 2,500.0 03:48 04:57 2,500' 4/3/2016 4/3/2016 2.00 DEMOB WHDBOP CIRC P Freeze protect with diesel from 2,500' 2,500.0 42.0 04:57 06:57 4/3/2016 4/3/2016 1.00 DEMOB WHDBOP PULD P At surface, Flow check well-Pass, 42.0 0.0 06:57 07:57 Lay down BHA#8 4/3/2016 4/3/2016 1.30 DEMOB WHDBOP PULD P R/U to set BPV, PJSM Set BPV, R/D 0.0 0.0 07:57 09:15 and load out equipment 4/3/2016 4/3/2016 0.20 DEMOB WHDBOP CTOP P Remove floats from UQC, Install 0.0 0.0 09:15 09:27 nozzle and stab injector back on well 4/3/2016 4/3/2016 0.50 DEMOB WHDBOP CTOP P PJSM with SLB N2 pumpers, PT N2 to 0.0 0.0 09:27 09:57 2500PS1, Blow down reel 4/3/2016 4/3/2016 0.90 DEMOB WHDBOP CTOP P Rig down N2 pumpers, Bleed off CT 0.0 0.0 09:57 10:51 string 4/3/2016 4/3/2016 1.30 DEMOB WHDBOP CTOP P PJSM, Unstab injector, R/U cable to 0.0 0.0 10:51 12:09 CTC,Unstab coil from injector and secure to spool 4/3/2016 4/3/2016 4.00 DEMOB WHDBOP CTOP P PJSM, R/D reel in prep for CT string 0.0 0.0 12:09 16:09 swap, PJSM disconnect injector in prep for swap 4/3/2016 4/3/2016 0.30 DEMOB WHDBOP CTOP P PJSM with crane-lift injector off rig 0.0 0.0 16:09 16:27 Page 7/8 Report Printed: 4/5/2016 • • ,, Drilling Operations Summary (with Timelog Depths) &Wens 1H-10 c i tft Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKB) 4/3/2016 4/3/2016 1.50 DEMOB WHDBOP CTOP P PJSM, Lower used string to empty 0.0 0.0 16:27 17:57 sow bed truck 4/3/2016 4/3/2016 2.05 DEMOB WHDBOP CTOP P PJSM. Lift new injector/gooseneck, 0.0 0.0 17:57 20:00 install on cart. 4/3/2016 4/3/2016 3.50 DEMOB WHDBOP CTOP P PJSM. Install new reel/shim/hubs. 0.0 0.0 20:00 23:30 Hook up hydraulic lines on injector. Flush and blow down surface lines. Weld bracket on new injector. 4/3/2016 4/4/2016 0.50 DEMOB WHDBOP CTOP P PJSM. Roll coil reel for inner reel iron 0.0 0.0 23:30 00:00 install. 4/4/2016 4/4/2016 3.00 DEMOB WHDBOP CTOP P Continue inner reel iron install. 0.0 0.0 00:00 03:00 4/4/2016 4/4/2016 4.00 DEMOB WHDBOP CTOP P Prep coil and install grapple,P/U new 0.0 0.0 03:00 07:00 stripper,Swap out brass, Install packoffs 4/4/2016 4/4/2016 1.00 DEMOB WHDBOP CTOP P Vac out tree, Freeze protect tree with 0.0 0.0 07:00 08:00 9 Gals methonol 4/4/2016 4/4/2016 3.50 DEMOB WHDBOP CTOP P Start R/D Checklist,Nipple down 0.0 08:00 11:30 Stack 4/4/2016 4/4/2016 0.50 DEMOB WHDBOP CTOP P Check stack bolts, 12 loose,master 11:30 12:00 flange and swab. RIG RELEASE 12:00 Page 8/8 Report Printed: 4/5/2016 • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-10A 50-029-22346-01 Baker Hughes INTEQ / 1 Definitive Survey Report HUGHES 04 April,2016 • • ConocoPhillips Kill ConocoPhillips Definitive Survey Report BAKERt ES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Coordinate Reference: Well 1H-10 Project Kuparuk River Unit ND Reference: 1H-10 @ 96.00usft(1H-10) Site: '.Kuparuk 1H Pad MD Reference: 1H-10 @ 96.00usft(1H-10) Well: >1H-10 North Reference: True Wellbore: 1H-10A Survey Calculation Method: Minimum Curvature Design: 1H-10A Database: EDM Alaska NSK Sandbox „tee. 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 I Well 1H-10 Well Position +N/-S 0.00 usft Northing: 5,980,084 49 usft Latitude: 70°21'22.946 N a +El-W 0.00 usft Easting: 549,550.97usft Longitude: 149°35'51.309 W t Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore.... 1H-10A _. ...... � .�� .... { Magnetics Model Name . Sample Date. Declination Dip Angle Reid Strength B BGGM2015 5/1/2016 18.55 81.00 57,497 Design 1H-10A 1 Audit Notes: jI Version: 1.0 Phase: ACTUAL Tie On Depth: 6671.70 Vertical Section: Depth From(TVD) +Ni-S +E/-W Direction:' (usft) {usft) : (usft) (°) s. 96 00 0.00 0.00 300.00 Survey Program Date 4/4/2016 From To<,. Survey Survey (usft) (usft) Survey(Wellbore) Teat Matte -',.::: $184 Date End Date 97.40 6,971.70 1H-10(1H-10) GCT-MS Schlumberger GCT multishot 1/8/2001 6,994 00 10,487.13 1H-10A(1H-10A) MWD MWD-Standard 3/24/2016 4/3/2016 4/4/2016 1:32:4 1PM Page 2 COMPASS 500.1 Build 74 i • ConocoPhillips Mall ConocoPhillips Definitive Survey Report BAKER 5 Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1H-10 €. Project: Kuparuk River Unit TVD Reference: ''1H-10 @ 96.00usft(1H-10) , Site: - Kuparuk 1H Pad MD Reference: 1H-10 @ 96.00usft(1H-10) Well: 1H-10 North Reference: True Wellbore: 1H-10A Survey Calculation Method: Minimum Curvature Design: 1H-10A Database: EDM Alaska NSK Sandbox Survey . Map Map Vertical MD. Inc Azi .TVD TVDSS +Nl-S +E/-W OLS Northing Fasting Section Survey Tool Name Annotation (usft)' . (°) r). (usft) (usft) (usft) (usft) (ft) (ft) 11100'1. (ft) 6,971.70 35.31 81.41 6,411 04 6,315.04 181.35 2,016.83 5,980 279 16 551,566.36 0.37 -1,655.95 MWD(2) TIP S 6,994.00 35.30 81.28 6,429.24 6,333.24 183.29 2,029.58 5,980,281 18 551,579.09 0.34 -1,666.02 MWD(2) KOP ;. 7,016.29 40.18 78.96 6,446.86 6,350.86 185.65 2,043.01 5,980,283.63 551,592.51 22.80 -1,676.47 MWD(2) 7,045.22 55.33 76.90 6,466.25 6,370.25 190.16 2,063.88 5,980,288.27 551,613.34 52.63 -1,692.29 MWD(2) II 7,075.15 70.60 75.31 6,479.82 6,383.82 196.56 2,089.67 5,980,294.85 551,639.09 51.24 -1,711.43 MWD(2) 7,105.05 83.97 68.65 6,486.39 6,390.39 205.60 2117.32 5,980,304.07 551,666.67 49.69 -1,730.85 MWD(2) 7,135.09 86.56 53.55 6,488.88 6,392.89 220.03 2,143.44 5,980,318.67 551,692.70 50.83 -1,746.26 MWD(2) 7,165.09 89.82 41.61 6,489.84 6,393.84 240.22 2,165.53 5,980,339.01 551,714.66 41.23 -1,755.29 MWD(2) , 7,195.11 92.83 26.14 6,489.14 6,393.14 265.06 2182.21 5,980,363.95 551,731.17 52.48 -1,757.32 MWD(2) 7,225.19 95.44 11.36 6,486.96 6,390.96 293.39 2,191.83 5,980,392.34 551,740.60 49.76 -1,751.49 MWD(2) 7,255.17 97.70 356.71 6,483.51 6,387.51 323.01 2,193.93 5,980,421.97 551,742.50 49.12 -1,738.49 MWD(2) 7,285.22 98.19 338.70 6,479.32 6,383.32 351.97 2,187.62 5,980,450.88 551,736.00 59.38 -1,718.55 MWD(2) i 7,315.27 97.60 329.15 6,475.18 6,379.18 378.67 2174.55 5,980,477.50 551,722.76 31.54 -1,693.88 MWD(2) 7,345.37 96.89 327.62 6,471.39 6,375.39 404.10 2158.90 5,980,502.82 551,706.94 5.57 -1,667.62 MWD(2) 1 ( 7,375.20 96.55 326.13 6,467.90 6,371.90 428.91 2142.71 5,980,527.52 551,690.59 5.09 -1,641.19 MWD(2) 5 ) 7,405.60 96.22 324.35 6,464.52 6,368.52 453.72 2125.49 5,980,552.M 551,673.20 5.92 -1,613.86 MWD(2) 7,441.29 96.28 322.87 6,460.63 6,364.63 482.28 2104.44 5,980,580.63 551,651.97 4.13 -1,581.36 MWD(2) 7,465.36 95.94 321.81 6,458.07 6,362.07 501.23 2089.82 5,980,599.48 551,637.22 4.60 -1,559.22 MWD(2) 7,495.27 96.52 319.86 6,454.82 6,358.82 524.28 2,071.04 5,980,622.41 551,618.30 6.76 -1,531.43 MWD(2) 7,525.60 96.65 320.01 6,451.34 6,355.34 547.34 2051.65 5,980,645.33 551,598.75 0.65 -1,503,11 MWD(2) s 7,555.51 94.49 318.80 6,448.44 6,352.44 569.94 2,032.28 5,980,667.81 551,579.24 8.27 -1,475.03 MWD(2) 7,585.60 91.90 317.68 6,446.76 6,350.76 592.35 2012.27 5,980,690.08 551,559 08 9.38 -1,446.50 MWD(2) 4 7,615.60 91.41 316.34 6,445.90 6,349.90 614.28 1,991.82 5,980,711.88 551,538.49 4.75 -1,417.83 MWD(2) 7,645.71 91.72 315.43 6,445.07 6,349.07 635.89 1,970.87 5,980,733.34 551,517.40 3.19 -1,388.88 MWD(2) 7,675.60 92.24 314.52 6,444.04 6,348.04 657.01 1,949.74 5,980,754.31 551,496.13 3.50 -1,360.02 MWD(2) 7,705.51 92.46 312.10 6,442.82 6,346.82 677.51 1,928.00 5,980,774.67 551,474.26 8.12 -1,330.94 MWD(2) e, 7,735.17 92.21 308.97 6,441.61 6,345.61 696.76 1,905.48 5,980,793.77 551,451.61 10.58 -1,301.81 MWD(2) 7,765.27 92.43 307.45 6,440.39 6,344.39 715.37 1,881.84 5,980,812.22 551,427.86 5.10 -1,272.04 MWD(2) 7,795.49 92.27 305.50 6,439.15 6,343.15 733.31 1,857.57 5,980,830.00 551,403.46 6.47 -1,242.04 MWD(2) 7,825.60 93.19 303.46 6,437.71 6,341.71 750.34 1,832.78 5,980,846.86 551,378.56 7.43 -1,212.06 MWD(2) 38 4/4/2016 1:32:41PM Page 3 COMPASS 5000.1 Build 74 i i ConocoPhillips Niall ConocoPhillips Definitive Survey Report HER Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Coordinate Reference: Well 1H-10 Project: Kuparuk River Unit TVD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad MD Reference: 1H-10 @ 96.00usft(1H-10) Well: I1H-10 North Reference: True Wellbore: '1H-10A Survey Calculation Method: Minimum Curvature I Design: 1H-10A Database: EDM Alaska NSK Sandbox Survey Map Map 1811 MD Inc Azi TVD TVDSS +Nf-S +Ef-W Northing Easting OLS -septian survey Tool manic Annotation lash) l1 a (°) (usft) (usft) (usft) (usft) (ft) (ft) (11001 ..: 7,855 53 92.95 301.67 6,436.11 6,340.11 766.43 1,807 59 5,980,862 78 551,353 27 6.03 -1,182.20 MWD(2) 7,885.68 92.83 300.72 6,434.59 6,338.59 78202 1,781 83 5,980,878.20 551,327.42 3.17 -1,152.10 MWD(2) 4 7,915.95 92.61 299.90 6,433.15 6,337.16 797.28 1,755.73 5,980,893.29 551,301.22 280 -1,121.86 MWD(2) 7,945.37 92.30 297.38 6,431.89 6,335.89 811.37 1,729.93 5,980,907.20 551,275.33 862 -1,092.48 MWD(2) 7,975.31 92.27 295.74 6,430.70 6,334.70 824.74 1,703.18 5,980,920.40 551,248.49 5.47 -1,062.62 MWD(2) a I 8,005.33 90.28 291.29 6,430.03 6,334.03 836.72 1,675.66 5,980,932.19 551,220.90 16.23 -1,032.81 MWD(2) 8,035.21 90.25 288.82 6,429.89 6,333.89 846.96 1,647.60 5,980,942.25 551,192.77 827 -1,003.38 MWD(2) 8,065.14 90.52 286.61 6,429.69 6,333.69 856.07 1,618.08 5,980,951.16 551,164.20 7.44 -974.14 MWD(2) 8,095.12 90.28 284.20 6,429.48 6,333.48 864.03 1,590.19 5,980,958.93 551,135.26 8.08 -945.13 MWD(2) 8,125.27 89.51 280.57 6,429.54 6,333.54 870.50 1,560.75 5,980,965.20 551,105.77 1231 -916.40 MWD(2) "...1 8,155.29 90.28 278.98 6,429.59 6,333.59 875.59 1,531.16 5,980,970.11 551,076.16 5.88 -888.23 MWD(2) 8,185.36 88.97 276.35 6,429.53 6,333.53 879.60 1,501.36 5,980,973.92 551,046.34 8.81 -860.42 MWD(2) 8,215.09 89.88 275.70 6,429.57 6,333.57 882.72 1,471.80 5,980,976.84 551,01676 221 -833.25 MWD(2) 8,245.43 89.11 275.26 6,429.83 6,333.83 885.62 1,441.60 5,980,979.51 550,986.54 2.92 -805.65 MWD(2) 8,27570 87.45 276.84 6,43074 6,334.74 888.81 1,411.51 5,980,982.53 550,956.44 7.57 -778.00 MWD(2) ?. 8,305.79 88.00 276.64 6,431.94 6,335.94 892.34 1,381.65 5,980,985.86 550,926.56 1.94 -750.38 MWD(2) 1 8,335.80 90.09 277.63 6,43244 6,336.44 896.06 1,35188 5,980,989.39 550,896.77 7.71 -722.73 MWD(2) 8,365.37 92.03 278.09 6,431.89 6,335.89 900.11 1,322.60 5,980,993.24 550,867.46 6.74 -695.35 MWD(2) r • 8,395.66 93.50 278.07 6,430.43 6,334.43 904.36 1,292.64 5,980,99729 550,837.48 4.85 -667.28 MWD(2) 8,425.78 95.50 280.02 6,428.07 6,332.07 909.08 1,262.99 5,981,001.81 550,807.80 9.26 -639.24 MWD(2) a 8,455.53 94.40 282.91 6,425.50 6,329.50 914.97 1,233.95 5,981,007.51 550,778.72 10.36 -611.15 MWD(2) r 8,485.67 93.93 285.13 6,423.31 6,327.31 922.25 1,204.79 5,981,014.60 550,749.51 7.51 -582.25 MWD(2) 1 8,515.03 93.90 287.71 6,421.30 6,325.30 930.53 1,176.69 5,981,022.69 550,721.37 8.77 -553.78 MWD(2) 8,545.33 93.20 288.86 6,419.43 6,323.43 940.02 1,147.98 5,981,031.99 550,692.59 4.44 524.17 MWD(2) 8,575.72 92.82 290.85 6,417.83 6,32183 950.33 1,119.44 5,981,042.11 550,663.99 6.66 494.30 MWD(2) 8,605.59 92.58 292.81 6,416.43 6,320.43 961.42 1,091.74 5,981,053.02 550,636.22 6.60 -464.76 MWD(2) 8,635.85 92.92 295.37 6,414.97 6,318.97 973.76 1,064.15 5,981,065.17 550,608.55 8.52 434.70 MWD(2) 8,665.91 91.41 298.06 6,413.84 6,317.84 987.26 1,037.32 5,961,078.49 550,581,64 10.26 -404.72 MWD(2) t. 1 8,695.67 90.18 299.96 6,413.42 6,317.42 1,001.69 1,011.30 5,981,092.75 550,555.52 7.60 -374.97 MWD(2) 1 8,725 66 89.29 302.25 6,413 56 6,317.56 1,017.18 985.62 5,981,108.07 550 529.75 8.19 -344.98 MWD(2) 8,750.77 89.29 303.59 6,413 87 6,317 87 1,030.83 964 55 5,981,121.57 550 508.58 5.34 -319 91 MWD(2) 4/4/2016 1:32:41 PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips En ConocoPhillips Definitive Survey Report HUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p1 Local Co-ordinate Reference: Well 1H-10 Project: Kuparuk River Unit ND Reference: 1H-10(oj 96.00usft(1H-10) Site: Kuparuk 1H Pad MD Reference: 1H-10©96.00usft(1H-10) Well: 1H-10 North Reference: True Wellbore: 11H-10A Survey Calculation Method: Minimum Curvature Design: « 1H-10A Database: EDM Alaska NSK Sandbox Survey i t Map Map Vertical i 8 MD Inc Azi TVD TVDSS +NIS +E)-W Northing EastingDLS Seetloh l Survey Tool Name AtlnotattOn (Lista (°) (°) (usft) (usft) (usft) (usft) (h) on (°/1001 8,78077 89.69 305.59 6,414.14 6,318.14 1,047.86 939.85 5,981,138.44 550,483.78 6.80 -290.01 MWD(2) 8,810.63 90.06 308.23 6,414.21 6,318.21 1,065.79 915.98 5,981,156.21 550,459.79 8.93 -260.37 MWD(2) 8,840.65 90.25 309.82 6,414.13 6,318.13 1,084.69 892.66 5,981,174.95 550,436.35 5.33 -230.72 MWD(2) 8,870.53 90.37 312.42 6,413.96 6,317.96 1,104.34 870.15 5,981,194.45 550,413.71 8.71 -201.40 MWD(2) 8,900.63 89.35 314.50 6,414.04 6,318.04 1,125.04 848.30 5,981,215.01 550,391.73 7.70 -172.13 MWD(2) 8,930.58 89.42 316.11 6,414.36 6,318.36 1,146.33 827.24 5,981,236.15 550,370.53 5.38 -143.25 MWD(2) 8,960.45 88.77 318.27 6,414.83 6,318.83 1,168.24 806.95 5,981,257.92 550,350.09 7.55 -114.72 MWD(2) gSa 8,990.55 88.89 320.56 6,415.45 6,319.45 1,191.09 787.37 5,981,280.65 550,330.37 7.62 -86.34 MWD(2) g 9,020.52 88.59 322.74 6,416.10 6,320.10 1,214.59 768.78 5,981,304.02 550,311.62 7.34 -58.49 MWD(2) ii 9,050.49 88.49 324.79 6,416.87 6,320.87 1,238.75 751.07 5,981,328.06 550,293.76 6.85 -31.07 MWD(2) 9,080.45 88.68 326.86 6,417.61 6,321.61 1,263.53 734.25 5,981,352.72 550,276.77 6.94 -4.11 MWD(2) 1 9,110.49 89.05 328.77 6,418.20 6,322.20 1,288.95 718.25 5,981,378.03 550,260.61 6.48 22.45 MWD(2) ;. 9,140.43 89.45 330.11 6,418.60 6,322.60 1,314.72 703.03 5,981,403.71 550,245.22 467 48.52 MWD(2) I & 9,170.56 89.88 331.92 6,418.77 6,322.77 1,341.08 688.43 5,981,429.96 550,230.45 6.17 74.34 MWD(2) ) 9,200.51 90.06 333.37 6,418.79 6,322.79 1,367.68 674.67 5,981,456.47 550,216.51 488 99.56 MWD(2) 9,230.53 90.00 333.72 6,418.77 6,322.77 1,394.56 661.29 5,981,483.25 550,202.96 1.18 124.58 MWD(2) 'i ) 9,260.61 90.34 332.33 6,418.68 6,322.68 1,421.36 647.65 5,981,509.97 550,189.14 476 149.80 MWD(2) 9,290.63 90.12 330.36 6,418.56 6,322.56 1,447.70 633.26 5,981,536.21 550,174.58 6.60 175.44 MWD(2) i 9,320.57 90.43 328.64 6,418.42 6,322.42 1,473.50 618.06 5,981,561.90 550,159.21 5.84 201.49 MWD(2) 9,350.44 90.37 326.85 6,418.21 6,322.21 1,498.76 602.12 5,981,587.05 550,143.11 6.00 227.93 MWD(2) 9,380.71 90.12 324.90 6,418.08 6,322.08 1,523.82 585.14 5,981,611,99 550,125.96 6.49 255.16 MWD(2) 9,410.43 90.06 322.20 6,418.03 6,322.03 1,54772 567.48 5,981,635.78 550,108.15 9.09 282.40 MWD(2) I 9,440.42 90.28 320.09 6,417.94 6,321.94 1,571.07 548.67 5,981,659.00 550,089.18 7.07 310.37 MWD(2) 9,470.33 90.12 318.32 6,417.84 6,321.84 1,593.71 529.13 5,981,681.51 550,069.50 5.94 338.62 MWD(2) 9,500.45 90.03 315.90 6,417.80 6,321.80 1,61578 508.63 5,981,703.44 550,048.86 8.04 367.40 MWD(2) 9,530.35 89.88 313.96 6,417.82 6,321.82 1,636.90 487.47 5,981,724.42 550,027.55 6.51 396.29 MWD(2) II 9,560.56 90.46 312.93 6,417.73 6,321.73 1,657.67 465.53 5,981,745.04 550,005.48 3.91 425.67 MWD(2) ( 9,590.59 91.20 311.49 6,417.30 6,321.30 1,677.84 443.29 5,981,765.06 549,983.11 5.39 455.02 MWD(2) 9,620.38 91.72 310.24 6,416.54 6,320.54 1,697.33 420.77 5,981,784.40 549,960.47 4.54 484.26 MWD(2) 9,650.41 89.79 307.31 6,416.14 6,320.14 1,716.13 397.37 5,981,803.04 549,936.94 11.68 513.94 MWD(2) 9,680.62 90.28 305.62 6,41613 6,320.13 1,734.08 373.07 5,981,820.83 549,91253 5.82 543.95 MWD(2) 4!4/1016 1:32:41PM Page 5 COMPASS 5000.1 Build 74 v • • ConocoPhillips EMI ConocoPhillips Definitive Survey Report BAKKER Company: ConocoPhillips(Alaska)Inc-Kupl Local Co-ordinate Reference: Well 1H-10 Project: Kuparuk River Unit TVD Reference: 1 H-10 @ 96.00usft(1H-10) oast Site Kuparuk 1H Pad MO Reference: 1H-10 c 96.00usft(1H-10) Well: 1H-10 North Reference: True Wellbore`. 1H-10A Survey Calculation Method: Minimum Curvature Design: 1H-10A Database: EDM Alaska NSK Sandbox Survey Map '.'.Map Vertical '. MO Inc Azi ND TVDSS +NIS +61-W DLS Northing Casting Section Survey Tool Name Annotation (usft). (°) ' (°.) (usft) (usft) (usft) {usft) ,. (ft). (ft) s(°M00') tft1 ' 9,712 07 90 00 303.69 6.416.05 6,320.05 1,751.97 347.20 5,981,838 54 549,886.54 6.20 57530 MWD(2) ) '. 9,740.66 89.63 305.20 6,416.14 6,320.14 1,7W.14 323.63 5,981,854.56 549,862.86 5.44 603.80 MWD(2) 1 9,770.59 89.23 307.47 6,416.44 6,320.44 1,785.87 299.52 5,981,872.13 549,838.64 7.70 633.54 MWD(2) 9,800.53 88.40 309.31 6,417.06 6,321.06 1,804.46 276.06 5,981,890.56 549,815.06 6.74 663.16 MWD(2) 9,830.35 87.48 311.52 6,418.13 6,322.13 1,823.77 253.37 5,981,909.72 549,792.25 8.02 692.46 MWD(2) 9,860.67 87.36 313.96 6,419.50 6,323.50 1,844.33 231.12 5,981,930.13 549,769.87 8.05 722.00 MWD(2) 9,890.23 86.87 315.78 6,420.98 6,324.98 1,865.16 210.20 5,981,950.81 549,748.81 6.37 750.54 MWD(2) 9,920.51 87.08 317.41 6,422.58 6,326.58 1,887.12 189.43 5,981,972.64 549,727.89 5.42 779.51 MWD(2) • 9,950.35 87.30 319.65 6,424.04 6,328.04 1,909.46 169.69 5,981,994.84 549,708.01 7.53 807.77 MWD(2) 9,982.78 87.26 322,10 6,425.58 6,329.58 1,934.58 149.25 5,982,019.83 549,687.41 7.55 838.04 MWD(2) 10,010.51 87.17 323.39 6,426.93 6,330.93 1,956.63 132.48 5,982,041.76 549,670.50 4.66 863.58 MD(2) l Wi 10,040.37 89.48 325.08 6,427.80 6,331.80 1,980.84 11E04 5,982,06686 549,652.90 9.58 89679 MWD(2) i. 10,070.32 90.98 326.25 6,427.68 6,331.68 2,005.57 98.15 5,982,090.47 549,635.84 6.35 917.79 MWD(2) 10,100.36 89.75 327.32 6,427.49 6,331.49 2030.71 81.70 5,982,115.49 549,619.22 5.43 944.60 MWD(2) 10,130.28 89.23 325.92 6,427.76 6,331.76 2,055.69 65.23 5,982,140.36 549,602.60 4.99 97135 MWD(2) 10,160.55 89.60 325.38 6,428.07 6,332.07 2080.68 48.16 5,982,165.24 549,585.36 2.16 998.63 MWD(2) f i 10,190.73 86.50 324.54 6,429.09 6,333.09 2105.37 30.84 5,982,189.81 549,567.88 10.64 1,025.98 MWD(2) 10,220.18 85.82 322.60 6,431.07 6,335.07 2,129.01 13.39 5,982,213.34 549,550.28 6.97 1,052.91 MWD(2) S 10,250.54 85.33 322.70 6,433.41 6,337.41 2,153,07 -4.97 5,982,237.27 549,531,76 1.65 1,080.84 MWD(2) 10,280.62 83.78 321.33 6,436.26 6,340.26 2,176.67 -23.40 5,982,260.75 549,513,18 6.86 1,108.60 MWD(2) 10,310.45 84.74 319.15 6,439.25 6,343.25 2199.49 -42.38 5,982,283.44 549,494.05 7,95 1,136.45 MWD(2) I 10,340.31 84.77 317.38 6,441.98 6,345.98 2221.68 -62.17 5,982,305.49 549,474.11 5.90 1,164.68 MWD(2) i 10,370.33 83.91 316.12 6,444.94 6,348.94 2,243.43 -82.64 5,982,327.11 549,453.50 5.06 1,193.29 MWD(2) 10,400.91 82.89 313.80 6,448.45 6352.45 2,264.90 -104.14 5,982,348.43 549,431.87 8.24 1,222.63 MWD(2) I 10,430.29 82.46 311.42 6,452.20 6,356.20 2,284.63 -125.58 5,982,368.01 549,410.29 8.17 1,251.07 MWD(2) i 10,460.39 82.58 309.78 6,456.12 6,360.12 2,304.05 -148.24 5,982,387.28 549,387.51 5.42 1,280.40 MWD(2) 10,467.13 82.67 307.79 6,459.55 6,36355 232066 168.91 5,982,403.75 549366.73 7.39 1,306.61 MWD 12) s 10,518.00 82.67 307.78 6,463 49 6367 49 2,339.42 193 71 5 982,422.35 549 342.41 0.00 1,336.94 PROJECTED to TD 4/4/2016 1:32:41PM Page 6 COMPASS 5000.1 Build 74 21 601iFtECEIV 0 2 7 0 4 4y BAKER APR 18 PRINT DISTRIBUTION LIST HUGHES AtOG Please sign and return one copy of this transmittal form to: COMPANY onocoPhillips Alaska,Inc. ConocoPhillips Alaska,Inc. Tom Osterkamp DATA LOGGED WELL NAME 1H-10A 700 G Street. 1.! /t4/2014, Anchorage,Alaska 99510 M.K.BENDER FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska LOG DATE April 2,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider@bakerhughes.com TODAYS DATE April 14,2016 Revision STATUS Final Replacement: No Details: Requested by: COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #OF PRINTS #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 0 Attn:Ricky Elgaricio ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska I 0 0 0 Attn:Lynda M.Yaskell and/or Leonardo Elias 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC I 1 I 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** I 0 I 1 1 Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 1 1 1 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: 0 2 3 3 0 0 TOTALS FOR ALL PAGES: 0 2 3 3 0 0 • • • it H MI i.�_ `Wo , ,I. gZo c.D r- N :V CZi cv sain ao ILI -4 c' 0 C WI s IOC T''' 0. 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L11 (0 ,1- 010)NM .- 0O D U) N 01 CDCO U) NN N CO NIrON ..._ io NOO00O0NONOO O OO O O O OOoOO oO 06 0 i 0 q n r r 8m 0D O) 0 O O O N NNNN R V U 'r0 C g v P O O D 0 a Q a a o J O O O O O O O O O O O 6 O 6 O O O coC1C U •= 21 6019 SRECEIVED M 2 6994 APR 0 5 2016 Letter of Transmittal VU AOGCC BAKER Date: DATA LOGGED i April 4, pri14, 2016 4/5/2o1 HUGHES I K BENDER To: From: Makana Bender Yosha Ragbirsingh/Michael Soper AOGCC Baker Hughes INTEQ 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): 1H-10A (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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W m m r r O (o CO 8 0 m N V V' CO CO O M N 7 V a) 0) N6(0 a) co r N. 0) M V; 4 m CO 0 O- O- S I I �' �� O a) W CO r r (O r r r n W O mW W am N N M V V 2 N N mN N Nm U 'l • . N e, 'rd n.4 r m W M (0 r M N m N m W (0 M m V N (0 7 OmM MWN (0 Mc (0MM MN (01- d (0WV7 M dWMW �M O oo0 oOMOO 1-4 M >5C d O r 8N2NU ) .. G V . Nm 0) ai ai ai a) 0) 0) a) O 0) O O O O O O O O O O O O O O O (J O Ov coU 0 u U• ain ) A,u, a OF Tit • gwI17 est THE STATE Alaska Oil and Gas of LAsKA Conservation Commission •• S 4 333 West Seventh Avenue Anchorage,GOVERNOR BILL WALKER e, Alaska 99501-3572 g Main: 907.279.1433 S Fax: 907.276.7542 www.aogcc.alaska.gov J. Burke CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1H-10A ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-019 Surface Location: 619' FNL, 796' FEL, Sec. 33, T12N,R10E, UM Bottomhole Location: 3576' FNL, 1095' FEL, Sec. 28, T12N,R10E,UM Dear Mr. Burke: 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, 19)44-t-7 Cathy 17. Foerster Chair DATED this no day of February,2016. STATE OF ALASKA RECEIVED *KA OIL AND GAS CONSERVATION COMI ON JAN 2 7 2016 PERMIT TO DRILL 20 AAC 25.005 i p 1 a.Type of Work: 1 h.Proposed Well Class: Exploratory-Gas ❑ Service- WAG ❑ Service-Disp ❑ lc.Spe i i e p p ed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Oil Q- Service- Winj ❑ Single Zone Q • Coalbed Gas ❑ Gas Hydrates ❑ Redril Q- Reentry ❑ Exploratory-Oil ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone El Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket ❑. Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc. Bond No. 5952180 • KRU 1H-10A • 3.Address: 6. Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10600' " TVD: 6359' ' Kuparuk River Field/ 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Kuparuk River Oil Pool ' Surface: 619'FNL,796'FEL,Sec 33,T12N,R10E, UM + ADL 25639• Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 435'FNL,4043'FEL,Sec 34,T12N,R10E,UM ALK 464 4/1/2016 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3576'FNL, 1095'FEL,Sec 28,T12N,R10E, UM 2560 • 8910' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL(ft): . 96' 15.Distance to Nearest Well Open Surface:x- 549551 y- 5980083 Zone- 4 • GL Elevation above MSL(ft): 54' to Same Pool: 1H-07A_WP05, 250' 16. Deviated wells: Kickoff depth: .7000' feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 96° degrees Downhole: 4408 • Surface: 3765 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 3/8" 4.6# L-80 STL 3717' 6883' 6339' 10600' 6359' 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): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 7561' 6892' 7440'/7226' 7226' 6618' 7210' Casing Length Size Cement Volume MD TVD Conductor 80' 16" 200 SX PF C Cement 121' 121' Surface 4354' 9 5/8" 845 SX PERM E,420 SX Class G 4394' 4273' Production 7496' 7" 210 SX Class G Cement 7535' 6870' Perforation Depth MD(ft): 6970'-6990' / 7310'-7345' Perforation Depth TVD(ft): 6410'-6426' / 6687'-6715' 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirementsE1 21. Verbal Approval: Commission Representative: Date //2 //( 22. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Keith Herring @ 263-4321 Email Keith.E.Herring@cop.com Printed Name 3.R- ty_ Title CTD Engineering Supervisor Signat - J / Phone --(0,04IN Date Zt'p III Commission Use Only Permit to Drill API Number: Permit ApprovalSee cover letter for other Number: t)/(.701 50-029-oz2..3% -oI--OC-� Date: a �1,,,`1W requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: d Other: /30P feS f fp 4 zoQ ps-A9 Samples req'd: Yes[=INo[� Mud log req'd:Yes No /9h v l et r pr--e ye of tr!r 71-e- i- fo Z 5 1Q j751l2 easures: Yes 17 Noll] Directional svy req'd:Yes ge No❑ Spacing exception req'd: Yes❑ Noll Inclination-only svy req'd:Yes❑ Nog Post initial injection MIT req'd:Yes❑ No❑ APPROVED BY / Approved by: Cilef, / ;'t- t/11^— COMMISSIONER THE COMMISSION Date:2 l(p_/G VTL 2/�,�/6 1 -2112.91 Submit Form and Form 10-401(Revised 11/2015) ORM INA4apths from the date of approval(20 AAC 25.005(g)) Attachmentss in Duplicate 111v- • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 26, 2016 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for permit to drill a single lateral out of the Kuparuk Well 1H-10 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin as early as April 1, 2016. The CTD objective will be to drill one lateral (1H-10A), targeting the C3 and C4 sand intervals. Attached to this application are the following documents: - Permit to Drill Application Form (10-401) for 1H-10A - Detailed Summary of Operations - Directional Plans for 1H-10A - Current Wellbore Schematic - Proposed Wellbore Schematic The application for sundry approval (10-403) for 1H-10 was approved on 1/21/2016. If you have any questions or require additional information please contact me at 907-263-4321. Sincerely, c Keith Herring Coiled Tubing Drilling Engineer • • Kuparuk CTD Lateral NABORS ALASKA 1 H-1 OA 1J; °c°Phi"iPs Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)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 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AA C 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 17. Attachments 7 Attachment 1: Directional Plans for 1H-10A 7 Attachment 2: Current Well Schematic for 1H-10 7 Attachment 3: Proposed Well Schematic for 1H-10A 7 Page 1 of 7 January 26, 2016 PTD Application: 1H-10A 1. Well Name and Classification (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b)) The proposed lateral described in this document is 1H-10A. The lateral will be classified as"Development— Oil" well. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) The lateral will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 1H-10A. 3. Blowout Prevention Equipment Information (Requirements of 20 AA C 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 4200 psi. Using the maximum formation pressure in the area of 4408 psi in 1H-07 (i.e. 12.8 ppg EMW), the maximum potential surface pressure in 1H-10, assuming a gas gradient of 0.1 psi/ft, would be 3765 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)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) The formation pressure in KRU 1H-10 was measured to be 2391 psi (7.2 ppg EMW) on 11/2/2015. The maximum downhole pressure in the vicinity 1H-10 is to the north in well 1 H-07. The 1H-10 sidetrack will be drilled northwest towards 1 H-16 which is a lower pressure well. The higher pressure from the 1 H-07 well is not expected to be encountered while drilling the 1H-10 sidetrack due to an east west fault between the two wells. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No gas injection has been performed at 1H pad however, if significant gas is detected in the returns, the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) The major expected risk of hole problems is the potential for excessive losses to the formation. Managed pressure drilling (MPD) target pressure will be reduced in order to manage losses to the formation. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1H-10 lateral will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 January 26, 2016 PTD Application: 1H-10A 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 1H-10A 6883' 10600' 6243' 6359' 2%", 4.7#, L 80, ST-L slotted liner, deployment sleeve in 3 '/" tubing tail Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.5 H-40 Welded 40' 121' 0' 121' 1640 670 Surface 9-5/8" 36.0 J-55 BTC 40' 4394' 0' 4273' 3520 2220 Production 7" 26.0 J-55 AB-MOD 39' 7535' 0' 6871' 4980 4320 Tubing 4" 11.0 J-55 DSSHTC 38' 3932' 0' 3880' 6300 6590 Tubing 3-1/2" 9.3 J-55 8rd EUE 3932' 6894' 3880' 6348' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 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 A diagram of the Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based PowerVis muds.5 ppg) — Drilling operations: Chloride-based PowerVis mud (8.5 ppg). This mud weight will hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with 8.5 ppg PowerVis completion fluid in order to provide formation over-balance and maintain wellbore stability while running completion. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole 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 5000 psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". In the 1H-10 lateral we will target a constant BHP of 8.5 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 January 26, 2016 • PTD Application: 1H-10A Pressure at the 1H-10 Window (7000' MD, 6434' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off C-sand Formation Pressure (7.2 ppg) 2391 psi 2391 psi Mud Hydrostatic (8.5 ppg) 2844 psi 2844 psi Annular friction (i.e. ECD, 0.060 psi/ft) 420 psi 0 psi Mud + ECD Combined 3264 psi 2844 psi (no choke pressure) (overbalanced (overbalanced —873 psi) —453 psi) Target BHP at Window(8.5 ppg) 2844 psi 2844 psi Choke Pressure Required to Maintain 0 psi 0 psi Target BH; 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. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 1H-10 is a Kuparuk A-sand and C-sand producer well equipped with 4" x 3W tubing and 7" production casing. The CTD sidetrack will utilize a single lateral to target the C3 and C4 sands to accelerate production near 1H-10 and 1H-16. This lateral will be supported by vertical producers 1H-03 and 1H-22. Prior to CTD operations, E-line will punch 2' of holes in the 3W tubing tail and the XN nipple at 6881' MD will be milled out to a 2.80" ID. The existing A-sand perforations have been covered with a sand plug_A cement plug will be placed on the sand plug and the C-sand perforations will be squeezed with cem ent. The 3W Lubin taii wiirt5e cemented in place and will provide a means to kick out of the 7" casing. ConocoPhillips requests a variance from the requirements of 20 ACC 25.11(c)(1) to plug the A-sand ✓ and C-sand perforations in this manner. Following the cement squeeze Nabors CDR2-AC will drill a pilot hole to 7030' MD and set a mechanical whipstock in the 2.80" pilot hole to kick off at 7000' MD. 1H-10A sidetrack will exit through 7" production casing at 7000' MD and TD at 10,600' MD, targeting the C3 and C4 sands.11t will be completed with 2%" slotted liner from TD up to 6883' MD with a deployment sleeve back into the 3W tubing tail. Page 4 of 7 January 26, 2016 • PTD Application: 1H-10A Pre-CTD Work 1. RU slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test. 2. RU E-line: Punch 2' of holes in the 3%" tubing tail at 6878' MD. 3. RU Pumping Unit: Perform injectivity test down the tubing. 4. RU Service Coil: Mill out XN nipple, place cement plug on sand plug, and cement squeeze the C- sand perforations up to the holes in the tubing tail. 5. RU slickline: Tag top of cement and pressure test cement 6. Prep site for Nabors CDR2-AC and set BPV Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1H-10A Sidetrack (C-3/4 sand, Northwest) a. Mill 2.80" high-side pilot hole through cement to 7030' MD b. Caliper pilot hole c. Set top of whipstock at 7000' MD d. Mill 2.80" window at 7000' MD e. Drill 2.74" x 3.00" bi-center lateral to TD of 10600' MD f. Run 2%" slotted liner with a deployment sleeve from TD up to 6883' MD 3. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP 3. Install gas lift design 4. Return to production 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 using 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 slick-line. — 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. Page 5 of 7 January 26, 2016 • • PTD Application: 1H-10A Liner Running — The 1H-10 CTD lateral will be displaced to an overbalance completion fluid (as detailed in Section 8 "Drilling Fluids Program") prior to running liner. — 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 23/8" rams will provide secondary well control while running 23/8" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 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). 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 Narrte - Dietan 1H-10A 8910' - Distance to Nearest Well within Pool Lateran tam+ distance Well q 1 H-07A_WP05 1H-10A 250' (Proposed CTD Lateral) 1H-10A 360' 1H-16 Page 6 of 7 January 26, 2016 PTD Application: 1H-10A 16. Attachments Attachment 1: Directional Plans for 1H-10A Attachment 2: Current Well Schematic for 1H-10 Attachment 3: Proposed Well Schematic for 1H-10A Page 7 of 7 January 26, 2016 • W • • kill z mWo IllibgeO 0 0 _ -� _ __. l �.-_____L I O z =yg813 — z o 0gi8g',0I O ai o f • N.-... z 3mt c� W00 = o t gg I"8 I LL';', m m m w p 0 --_ + - a 0009 ro 0 0 1- n2 do` 3m o N o .a.1- c v9 o , CO 0 J '- - w a - 0 0 I 1114: -a.. o cd ._ _._ _. w o lei,' ‘,: - ' = o kC N lu ^ o oW3a¢ ++_.. -, _, 11101 a 3iN E MEM -"- 0 _. s _.. - ___-_ 000-.._0 o II Z N FAN= o N Q ' o, ,-....t--„,-, • CL - o jo o - 'o 0 0 ! ° 0 0 0 0 0 0 0 o o 0 o a o 0 I I . : C H o 0 0 0 0 0 0 0 0 N o O H O 1� N 0 M M 0 t` .1 N O r N O N N t7p M (u!fusn OSZ) +) o. (-)alnos -- 2 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1H Pad 1H-10 1H-10A Plan: 1 H-10A_wp03 Standard Planning Report 14 January, 2016 BAKER HUGHES `. ConocoPhillips EMIConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-10A_wp03 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 1H Pad Site Position: Northing: 5,979,968.84 usft Latitude: 70°21'21.831 N From: Map Easting: 549,197.16usft Longitude: 149°36'1.675 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38 ° Well 1H-10 Well Position +N/-S 0.00 usft Northing: 5,980,084.49 usft Latitude: 70°21'22.946 N +E/-W 0.00 usft Easting: 549,550.97 usft Longitude: 149°35'51.309 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1H-10A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 5/1/2016 18.55 81.00 57,497 Design 1 H-10A_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 6,971.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 300.00 1/14/2016 12:21:58PM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • VIII ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-10A_wp03 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100ft) (°/100ft) (°/100ft) (°) Target 6,971.70 35.31 81.41 6,315.04 181.35 2,016.83 0.00 0.00 0.00 0.00 7,000.00 35.29 81.25 6,338.13 183.82 2,033.00 0.33 -0.07 -0.57 -102.27 7,025.00 44.04 81.25 6,357.36 186.24 2,048.76 35.00 35.00 0.00 0.00 7,127.13 90.00 81.25 6,396.17 200.17 2,139.22 45.00 45.00 0.00 0.00 7,400.00 95.88 318.26 6,372.25 409.00 2,215.37 45.00 2.15 -45.07 277.00 7,650.00 92.33 301.08 6,354.23 567.49 2,024.14 7.00 -1.42 -6.87 259.00 7,775.00 91.54 309.80 6,350.00 639.86 1,922.46 7.00 -0.63 6.98 95.00 8,100.00 94.51 287.21 6,332.62 793.80 1,639.18 7.00 0.91 -6.95 278.00 8,350.00 91.31 304.44 6,319.83 902.19 1,415.34 7.00 -1.28 6.89 100.00 8,450.00 90.82 297.46 6,317.97 953.57 1,329.64 7.00 -0.50 -6.98 266.00 8,700.00 90.78 314.96 6,314.46 1,100.66 1,128.73 7.00 -0.02 7.00 90.00 8,900.00 89.55 301.01 6,313.89 1,223.45 971.48 7.00 -0.62 -6.97 265.00 9,100.00 85.97 314.56 6,321.74 1,345.57 813.92 7.00 -1.79 6.77 105.00 9,170.00 90.58 316.23 6,323.85 1,395.37 764.80 7.00 6.58 2.39 20.00 9,400.00 90.83 300.13 6,321.01 1,537.08 584.63 7.00 0.11 -7.00 271.00 9,500.00 90.22 307.11 6,320.09 1,592.41 501.41 7.00 -0.61 6.97 95.00 9,700.00 89.97 321.11 6,319.77 1,731.26 358.16 7.00 -0.12 7.00 91.00 9,875.00 89.97 308.86 6,319.87 1,854.73 234.61 7.00 0.00 -7.00 270.00 10,100.00 89.97 324.61 6,319.99 2,018.05 80.88 7.00 0.00 7.00 90.00 10,200.00 85.96 318.86 6,323.54 2,096.47 19.03 7.00 -4.01 -5.74 235.00 10,600.00 84.09 290.82 6,358.94 2,321.92 -304.64 7.00 -0.47 -7.01 265.00 1/14/2016 12:21:58PM Page 3 COMPASS 5000.1 Build 74 • • ConocoPhillips ISM ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-1 OA_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +El-W Section Rate Azimuth Northing Easting (usft) (°) C) (usft) (usft) (usft) (usft) (°/100ft) (°) (usft) (usft) 6,971.70 35.31 81.41 6,315.04 181.35 2,016.83 -1,655.95 0.00 0.00 5,980,279.16 551,566.36 TIP 7,000.00 35.29 81.25 6,338.13 183.82 2,033.00 -1,668.72 0.33 -102.27 5,980,281.73 551,582.51 KOP 7,025.00 44.04 81.25 6,357.36 186.24 2,048.76 -1,681.15 35.00 0.00 5,980,284.26 551,598.25 End 35 dls,Start 45 dls 7,100.00 77.79 81.25 6,393.29 196.07 2,112.60 -1,731.53 45.00 0.00 5,980,294.51 551,662.03 7,127.13 90.00 81.25 6,396.17 200.17 2,139.22 -1,752.54 45.00 0.00 5,980,298.78 551,688.61 4 7,200.00 93.78 48.65 6,393.70 230.56 2,204.31 -1,793.71 45.00 -83.00 5,980,329.60 551,753.49 7,300.00 96.84 • 3.55 6,383.94 317.58 2,247.06 -1,787.22 45.00 -84.11 5,980,416.90 551,795.66 7,400.00 95.88 318.26 6,372.25 409.00 2,215.37 -1,714.07 45.00 -88.51 5,980,508.09 551,763.37 End 45 dls,Start 7 dls 7,500.00 94.51 311.37 6,363.19 479.14 2,144.77 -1,617.85 7.00 -101.00 5,980,577.76 551,692.32 7,600.00 93.07 304.51 6,356.58 540.45 2,066.12 -1,519.09 7.00 -101.62 5,980,638.54 551,613.27 7,650.00 92.33 301.08 6,354.23 567.49 2,024.14 -1,469.21 7.00 -102.08 5,980,665.30 551,571.11 6 7,700.00 92.02 304.57 6,352.33 594.57 1,982.16 -1,419.32 7.00 95.00 5,980,692.10 551,528.96 7,775.00 91.54 309.80 6,350.00 639.86 1,922.46 -1,344.96 7.00 95.13 5,980,736.99 551,468.97 7 7,800.00 91.78 308.07 6,349.27 655.57 1,903.02 -1,320.28 7.00 -82.00 5,980,752.56 551,449.43 7,900.00 92.74 301.13 6,345.32 712.27 1,820.82 -1,220.74 7.00 -82.05 5,980,808.71 551,366.86 8,000.00 93.65 294.17 6,339.74 758.57 1,732.44 -1,121.05 7.00 -82.32 5,980,854.43 551,278.18 8,100.00 94.51 287.21 6,332.62 793.80 1,639.18 -1,022.67 7.00 -82.71 5,980,889.04 551,184.70 8 8,200.00 93.26 294.11 6,325.83 828.99 1,545.89 -924.29 7.00 100.00 5,980,923.60 551,091.19 8,300.00 91.97 301.00 6,321.26 875.17 1,457.38 -824.54 7.00 100.47 5,980,969.20 551,002.39 8,350.00 91.31 304.44 6,319.83 902.19 1,415.34 -774.63 7.00 100.78 5,980,995.93 550,960.17 9 8,400.00 91.07 300.95 6,318.79 929.18 1,373.28 -724.70 7.00 -94.00 5,981,022.65 550,917.94 8,450.00 90.82 297.46 6,317.97 953.57 1,329.64 -674.72 7.00 -94.07 5,981,046.74 550,874.15 10 8,500.00 90.82 300.96 6,317.25 977.96 1,286.02 -624.74 7.00 90.00 5,981,070.84 550,830.36 8,600.00 90.80 307.96 6,315.84 1,034.50 1,203.62 -525.11 7.00 90.05 5,981,126.83 550,747.60 8,700.00 90.78 314.96 6,314.46 1,100.66 1,128.73 -427.17 7.00 90.15 5,981,192.49 550,672.28 11 8,800.00 90.16 307.98 6,313.63 1,166.84 1,053.85 -329.24 7.00 -95.00 5,981,258.16 550,596.98 8,900.00 89.55 301.01 6,313.89 1,223.45 971.48 -229.61 7.00 -95.06 5,981,314.22 550,514.25 12 9,000.00 87.74 307.78 6,316.25 1,279.88 889.04 -129.99 7.00 105.00 5,981,370.10 550,431.44 9,100.00 85.97 314.56 6,321.74 1,345.57 813.92 -32.09 7.00 104.84 5,981,435.28 550,355.89 13 9,170.00 90.58 316.23 6,323.85 1,395.37 764.80 35.34 7.00 20.00 5,981,484.75 550,306.45 14 9,200.00 90.61 314.13 6,323.54 1,416.64 743.66 64.29 7.00 -89.00 5,981,505.88 550,285.18 9,300.00 90.73 307.13 6,322.37 1,481.72 667.83 162.50 7.00 -89.02 5,981,570.45 550,208.92 9,400.00 90.83 300.13 6,321.01 1,537.08 584.63 262.24 7.00 -89.10 5,981,625.25 550,125.36 15 9,500.00 90.22 307.11 6,320.09 1,592.41 501.41 361.97 7.00 95.00 5,981,680.03 550,041.79 16 9,600.00 90.09 314.11 6,319.82 1,657.45 425.54 460.20 7.00 91.00 5,981,744.56 549,965.50 9,700.00 89.97 321.11 6,319.77 1,731.26 358.16 555.46 7.00 91.02 5,981,817.92 549,897.64 1/14/2016 12:21:58PM Page 4 COMPASS 5000.1 Build 74 • • ConocoPhillips /Gild ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-10A_wp03 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) (°/100ft) (°) (usft) (usft) 17 9,800.00 89.97 314.11 6,319.83 1,805.07 290.78 650.71 7.00 -90.00 5,981,891.26 549,829.78 9,875.00 89.97 308.86 6,319.87 1,854.73 234.61 724.19 7.00 -90.00 5,981,940.55 549,773.29 18 9,900.00 89.97 310.61 6,319.88 1,870.71 215.39 748.82 7.00 90.00 5,981,956.40 549,753.96 10,000.00 89.97 317.61 6,319.94 1,940.26 143.63 845.75 7.00 90.00 5,982,025.47 549,681.75 10,100.00 89.97 324.61 6,319.99 2,018.05 80.88 938.98 7.00 90.00 5,982,102.83 549,618.49 19 10,200.00 85.96 318.86 6,323.54 2,096.47 19.03 1,031.76 7.00 -125.00 5,982,180.83 549,556.13 20 10,300.00 85.38 311.87 6,331.10 2,167.38 -50.98 1,127.84 7.00 -95.00 5,982,251.27 549,485.66 10,400.00 84.87 304.86 6,339.60 2,229.18 -129.06 1,226.36 7.00 -94.47 5,982,312.55 549,407.18 10,500.00 84.44 297.84 6,348.93 2,280.95 -214.03 1,325.83 7.00 -93.88 5,982,363.75 549,321.88 10,600.00 84.09 290.82 6,358.94 2,321.92 -304.64 1,424.78 7.00 -93.22 5,982,404.12 549,231.01 Planned TD at 10600.00 1/14/2016 12:21:58PM Page 5 COMPASS 5000.1 Build 74 1 ConocoPhillips • IGilII ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-10A_wp03 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 1H-10A_T08 0.00 0.00 6,359.00 -5,468.01 1,139,811.60 5,982,156.00 1,689,263.00 70°6'23.089 N 140°25'26.121 W -plan misses target center by 1137579.26usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_T06 0.00 0.00 6,324.00 -6,411.31 1,140,897.49 5,981,220.00 1,690,355.00 70°6'12.330 N 140°24'59.252 W -plan misses target center by 1138670.32usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_Faultl 0.00 0.00 0.00 -6,548.381,141,057.60 5,981,084.00 1,690,516.00 70°6'10.763 N 140°24'55.282 W -plan misses target center by 1138849.14usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Rectangle(sides W300.00 H1.00 D0.00) 1H-10A_T01 0.00 0.00 6,396.00 -7,590.431,142,254.85 5,980,050.00 1,691,720.00 70°5'58.880 N 140°24'25.677 W -plan misses target center by 1140035.22usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_T04 0.00 0.00 6,314.00 -6,623.141,141,170.12 5,981,010.00 1,690,629.00 70°6'9.872 N 140°24'52.399 W -plan misses target center by 1138944.22usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_T03 0.00 0.00 6,344.00 -7,063.081,141,910.30 5,980,575.00 1,691,372.00 70°6'4.508 N 140°24'33.210 W -plan misses target center by 1139687.14usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1 H-10A_T02 0.00 0.00 6,369.00 -7,355.751,142,307.41 5,980,285.00 1,691,771.00 70°6'1.081 N 140°24'23.162 W -plan misses target center by 1140086.18usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_Fault1_V 0.00 0.00 6,314.00 -6,548.381,141,057.60 5,981,084.00 1,690,516.00 70°6'10.763 N 140°24'55.282 W -plan misses target center by 1138831.25usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Polygon Point 1 6,314.00 0.00 0.00 5,981,084.00 1,690,516.00 Point2 6,314.00 1.00 1.00 5,981,085.01 1,690,516.99 1H-10 CTD Polygon Nor 0.00 0.00 0.00 -7,709.871,142,169.05 5,979,930.00 1,691,635.00 70°5'57.847 N 140°24'28.640 W -plan misses target center by 1139968.14usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Polygon Point 1 0.00 0.00 0.00 5,979,930.00 1,691,635.00 Point2 0.00 62.66 205.44 5,979,994.01 1,691,840.00 Point3 0.00 215.11 292.45 5,980,147.02 1,691,925.99 Point 4 0.00 378.32 262.51 5,980,310.01 1,691,894.98 Points 0.00 770.86 -269.97 5,980,698.98 1,691,359.96 Point6 0.00 950.42 -656.84 5,980,875.96 1,690,971.95 Point7 0.00 1,454.64 -1,289.61 5,981,375.94 1,690,335.92 Point8 0.00 2,191.94 -2,083.86 5,982,107.90 1,689,536.89 Point9 0.00 2,191.94 -2,083.86 5,982,107.90 1,689,536.89 Point 10 0.00 2,568.38 -2,754.47 5,982,479.86 1,688,863.87 Point 11 0.00 2,336.19 -2,881.01 5,982,246.86 1,688,738.88 Pointl2 0.00 1,970.99 -2,248.33 5,981,885.88 1,689,373.90 Pointl3 0.00 1,586.64 -1,896.81 5,981,503.91 1,689,727.92 Point 14 0.00 1,205.76 -1,465.26 5,981,125.92 1,690,161.94 Point 15 0.00 701.41 -811.49 5,980,625.96 1,690,818.97 Point 16 0.00 496.62 -389.79 5,980,423.98 1,691,241.97 Point 17 0.00 258.30 -40.31 5,980,188.00 1,691,592.99 Point 18 0.00 0.00 0.00 5,979,930.00 1,691,635.00 1H-10A_T07 0.00 0.00 6,320.00 -5,771.601,140,196.64 5,981,855.00 1,689,650,00 70°6'19.575 N 140°25'16.459 W -plan misses target center by 1137965.88usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1H-10A_T05 0.00 0.00 6,314.00 -6,547.381,141,057.61 5,981,085.00 1,690,516.00 70°6'10.773 N 140°24'55.278 W -plan misses target center by 1138831.25usft at 7300.00usft MD(6383.94 TVD,317.58 N,2247.06 E) -Point 1/14/2016 12:21:58PM Page 6 COMPASS 5000.1 Build 74 • �- ConocoPhillips • Frill ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 1H-10 Company: ConocoPhillips(Alaska)Inc.-Kup1 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1H-10 @ 96.00usft(1H-10) Site: Kuparuk 1H Pad North Reference: True Well: 1H-10 Survey Calculation Method: Minimum Curvature Wellbore: 1H-10A Design: 1 H-10A_wp03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 10,600.00 6,358.93 2 3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 6,971.70 6,315.04 181.35 2,016.83 TIP 7,000.00 6,338.13 183.82 2,033.00 KOP 7,025.00 6,357.36 186.24 2,048.76 End 35 dls,Start 45 dls 7,127.13 6,396.17 200.17 2,139.22 4 7,400.00 6,372.25 409.00 2,215.37 End 45 dls,Start 7 dls 7,650.00 6,354.23 567.49 2,024.14 6 7,775.00 6,350.00 639.86 1,922.46 7 8,100.00 6,332.62 793.80 1,639.18 8 8,350.00 6,319.83 902.19 1,415.34 9 8,450.00 6,317.97 953.57 1,329.64 10 8,700.00 6,314.46 1,100.66 1,128.73 11 8,900.00 6,313.89 1,223.45 971.48 12 9,100.00 6,321.74 1,345.57 813.92 13 9,170.00 6,323.85 1,395.37 764.80 14 9,400.00 6,321.01 1,537.08 584.63 15 9,500.00 6,320.09 1,592.41 501.41 16 9,700.00 6,319.77 1,731.26 358.16 17 9,875.00 6,319.87 1,854.73 234.61 18 10,100.00 6,319.99 2,018.05 80.88 19 10,200.00 6,323.54 2,096.47 19.03 20 10,600.00 6,358.94 2,321.92 -304.64 Planned TD at 10600.00 1/14/2016 12:21:58PM Page 7 COMPASS 5000.1 Build 74 Baker Hughes INTEQ EhII ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1H-10 Project: Kuparuk River Unit TVD Reference: 1H-10 @ 96.00usft(1H-10) Reference Site: Kuparuk 1H Pad MD Reference: 1H-10 @ 96.00usft(1H-10) Site Error: 0.00 usft North Reference: True Reference Well: 1H-10 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 1H-10A Database: OAKEDMP2 Reference Design: 1 H-10A_wp03 Offset TVD Reference: Offset Datum Reference 1 H-10A_wp03 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 6,971.70 to 10,600.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,250.40 usft Error Surface: Elliptical Conic Survey Tool Program Date 1/14/2016 From To (usft) (usft) Survey(Wellbore) Tool Name Description 97.40 6,971.70 1H-10(1H-10) GCT-MS Schlumberger GCT multishot 6,971.70 10,600.00 1 H-10A_wp03(1H-10A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") C') 10,600.00 6,454.93 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 1H Pad 1 H-02-1 H-02-1 H-02 Out of range 1H-05-1H-05-1 H-05 Out of range 1 H-05-1H-105-1 H-105 Out of range 1H-06-1 H-06-1 H-06 Out of range 1 H-07-1 H-07-1H-07 Out of range 1 H-07-1H-07A-1 H-07A_wp05 9,225.52 10,450.00 274.44 219.46 112.60 Pass-Major Risk 1H-07-1 H-07AL1-1 H-07AL1_wp04 Out of range 1 H-08-1H-08-1H-08 Out of range 1H-09-1 H-09-1 H-09 Out of range 1H-10-1H-10-1H-10 7,000.00 7,000.00 0.00 1.16 -1.08 FAIL-Major Risk 1H-11-1H-11-1H-11 Out of range 1H-12-1H-12-1H-12 Out of range 1H-13-1H-13-1H-13 Out of range 1H-14-1H-14-1H-14 Out of range 1H-i5-1H-l5-1H-i5 Out of range 1H-16-1H-16-1H-16 10,472.50 7,125.00 371.63 297.80 81.41 Pass-Major Risk 1H-17-1H-17-1H-17 Out of range 1H-18-1H-18-1H-18 Out of range 1H-21-1H-21-1H-21 7,260.00 6,875.00 1,183.43 211.41 976.23 Pass-Major Risk 1 H-22-1 H-22-1 H-22 Out of range 1 H-401(UGNU)-1H-401-1H-401 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-104(formerly 101 and 27)-Plan:1 H-104 Out of range Plan:1H-106(formerly 107 and 28D)-Plan:1H-10 Out of range Plan:1H-107(formerly 108 and 30E)-Plan:1H-10 Out of range Plan:1H-112(formerly 106 and 28E)-Plan:1H-11 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/14/2016 10:21:39AM Page 2 COMPASS 5000.1 Build 74 ■ y • o aill 1 A ill M' N o $ :on',1 III 8 Sc a= o •a V _ a g o O •N l\ C Y M O W• _ .o ci Pm v- x ` w ^ -` F o m. aiIiI!i i . 7. . c N p±: . 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N v .c n m n-O N N O I n n-O LCD I n 0 0 0 N-0 0 0 N-0 0 0 U U )O •O LO U U b CP co co V CD n- M,r n-0) a In t-00 NCO p7 V CO n-n-n-N-n-n-CO 0000 c0 c0 CP C)CP O CP CA OCD- O_ C O -LCD _O UNM V In CO n-00 COCP CD V'In CO n-COW CPOr- O Z O N N N u., (uygsn S6)tgdau feopian amus U r-' KUP PROD • 1H-10 IC0nocoPhilli 5 y Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB/ G..-a.hil" 500292234600 KUPARUK RIVER UNIT PROD 35.94 6,822.90 7,561.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date 1H-10,8/13/2015332:34 PM SSSV:TRDP 50 11/5/2014 Last WO: 6/16/1993 3/4/1993 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,198.0 8/2/2015 Rev Reason:FISH LEFT IN WELL lehallf 8/13/2015 I h HANGER;37.6� � Casing Strings Ile Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth IND)...Wt/Len(I...Grade Top Thread ((( CONDUCTOR 16 15.062 40.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 39.8 4,394.3 4,273.2 36.00 J-55 BTC Casing Description OD(in) 'ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread g: _ PRODUCTION 7 6.276 39.2 7,535.0 6,870.9 26.00 J-55 AB-MOD .w..../1,Tubing Strings CONDUCTOR 40.0.121.0-4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 4"x3.5" 4 3.476 37.6 6,894.0 6,347.8 11.00 J-55 DSSHTC Completion Details SAFETY VLV;1,791.7 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(7 Item Des Com (in) 37.6 37.6 0.73 HANGER FMC GEN IV HANGER 4.000 i. 1,791.7 1,791.7 0.73 SAFETY VLV 'CAMCO TRDP-4A-R0 SAFETY VALVE 2.812 3,931.7' 3,880.3 27.35'XO Reducing CROSSOVER 4 x 3.5 3.500 GAS LIFT;2,503.9 6,857.0' 6,317.8 35.90 SEAL ASSY 'BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.000 6,857.9 6,318.5 35.90 PACKER BAKER FB-1 PERMANENT PACKER 3.000 -- 6,881.4' 6,337.5 35.76 NIPPLE OTIS XN NIPPLE 2.81"POLISHED BORE w/2.75"NO 2.750 ,_____,,I GO P 6,893.1 6,347.1 35.69 SOS 'BAKER SHEAR OUT SUB 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT,3,963.3Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,210.0 6,605.2 35.50 FISH BHA left in hole,TOL=13.466' 8/8/2015 7,440.0 6,793.1 35.02 FISH PLUG WEATHERFORD 2.5"IBP-LOST 10/5/2006 DOWNHOLE IN RATHOLE 10/2/2006 Perforations&Slots Shot Dens SURFACE;39.6-4,394.3-. .- Top(TVD) Bite(ND) (shotsk Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,970.0 6,990.0 6,409.7 6,426.0 C-4,1H-10 10/182006 6.0 RPERF 6 SPF,2506 GAS LIFT;4,656.5 HYPERJET,PENT= 13.1",EH=0.43" 0 6,970.0 7,025.0 6,409.7 6,454.5 C-4,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg GAS LIFT;5,385.1 Phasing 6,974.0 6,984.0 6,412.9 6,421.1 C-4,1H-10 4/6/2006 6.0'RPERF 2.5"HSD GUN,2506 PJ HMX,60 deg phase GAS LIFT;6,108.5 7,034.0 7,048.0 6,461.9 6,473.3 C-3,1H-10 10/7/1993 6.0 APERF EnerJet III;90 deg Phasing GAS LIFT,6.187.2FE 7,098.0 7,124.0 6,514.0 6,535.2 C-1,UNIT B, 9/6/1993 6.0'APERF 1 11/16"Strip Gun;0 1H-10 deg Ph --I - 7,310.0' 7,345.0 6,686.7 6,7153 A-4,1H-10 6/16/1993 4.0 IPERF SWS 4.5"Csg Gun; Oriented 68 deg.CCW f/ GAS LIFT;6,809.5 l'. I High Side Stimulations&Treatments Min Top Max Btm I Depth Depth Top(TVD) Btm(TVD) (ftKB) (MB) (ftKB) (ftKB) Type Date Com 6,970.0 6,990.0 6,409.7 6,426.0 FRAC 10/26/200 PUMP C-SAND 6970'-6990'FRAC.W/YF150#GEL 6 1084726 16/20 CARBO PROP,PUMPED TOTAL OF SEAL ASSY;6.867.0 - 112%OF DESIGN,EXTEND 10 PPA STAGE TO 117 PACKER;8,857.9 . BBLS FROM 60.FLUSH W/10 BELS WF-20 AND 59 DIESEL.FLUSHED TO COMPLETION,FINAL PUMPING PRESSURE 4556 PSI,ISIP=2593 PSI (2260 PSI EST.BOTTOM HOLE PRESSURE). NIPPLE;6.881.4 illCement Squeezes SOS;6,893.1 Top(TVD) Btm(TVD) Top(ftKB) Btm(MB) (ftKB) (MB) Des Start Date Corn 6,916.0 7,230.0 6,365.6 6,621.5 CMT SQZ 10/14/200 6 RPERF;6.974.0-89848 _ Mandrel Inserts FRAC;6,970.0 t RPERF;6970.0.5990.0 - St ati Ii., on Top(TVD) Valve Latch Port Side TRO Run APERF;6.970.0.7,026.0 iv N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn ,�5, 1 2,503.9 2,503.6 CAMCO KBMG t GAS LIFT GLV 'BK 0.156 1,345.0 2/6/2007 ,f.1 2 3,963.3' 3,908.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/6/2007 stl 3 4,656.5 4,495.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,332.0 2/6/2007 APERF;7,034.0-7,048.0-% he 4 5,385.1 5,099.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 2/5/2007 oZ•ot or, ole ooe 5 6,108.5 5,698.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,318.0 2/5/2007 APERF;7,098.0.7,124.0-b6 6,487.2 6,013.7 CAMCO KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 6/16/1993 ✓ 7 6,809.5 6,279.2 CAMCO MMG-2 1 1/2 GAS LIFT OV RK 0.250 0.0 2/5/2007 Notes:General&Safety FISH;7,210.0 ' End Date Annotation V v r, 9/23/2010 NOTE.View Schematic w/Alaska Schematic9.0 IPERF;7,310.0-7345.0- FISH;7,440.0 ti PRODUCTION;39.2-7,535.0 - 4 • • 1 H-10 Proposed CTD Schematic Modified by 1GE 1-12-16 4"Camco TRDP-4A-RO SSSV at 1792'MD ...-•. ID=2.812" 4", 11#,J-55, DSSHTC tubing to 3932'MD 3'A"9.3#J-55 EUE 8rd tubing below 3932'MD 16"62.5#H-40 at 121'MD 4"Camco KBMG mandrel at 2504'MD 3'/z'Camco KBUG gas lift mandrels at 3963',4657',5385', 6109',and 6487'MD 9-5/8"36#J-55 at 31/x'Cameo MMG-2 mandrel at 6810'MD 4394'MD Baker GBH-22 locator seal assemly at 6857'MD Baker FB-1 packer at 6858'MD(3.0"ID) XN nipple at 6881"MD (2.75"min ID) 31/2' tubing tail at 6893'MD t L 'r';', :', \ ' KOP @ 7000'MD C-sand perfs(sgz'd) 6970'-7048'MD ;, 7098'-7124'MD — . rJSJJssassssJJu; - JJJ iy;rJJ;r r JJ C+J..;.;.JJ;.i J i r A-sand perfs POPES' 7310'-7345 M D J.rJ"",, +JJJ 1H-10A wp03 JUJJJt+J'JJ f J :f;+'+J'!:+:riti JSJJ TD @ 10,600'MD 44,1J.+1J�J JS 1 Covered b fill upto cu;+sJ'+'s' JJs Top of Liner @ 6883 MD Y ;rJUJ<x":russ ssss ruglsggi s 7228'MD rJ1s11ssss ss At Ag SSJSSS rg gr11111J11J.fg1 ',rJ1JJJJJIJJJJ;r 'rJ11J1J1J1g 1 gJg r;r;444,4 J1J ".1111d111.rgggjr 7"26#J-55 at .'suxrusu:+gag 7535'MD %<wJSJsss±•,�`f`<u. 'J'rJJ;tJ,,y,r*N. ':fir•.r.r.(:�:L�•'{:is r:�: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: KA .k /)4— )t/)- PTD: d/Co - 017 /Development Service Exploratory Stratigraphic Test Non-Conventional FIELD: kU+E,f POOL: gLA.,3CAJjL /`�VE� XtAlick4 AWL) ) 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 0 • C'' J , , , , , , p) Q , N0- , o '- o. c a. U 3. U a ?3' v), IU , , Z ca c. W' co a c'. a c' m L' C a OO o a`� , , , , ; ta' �' E O° ' 3' Z. a) ° w a2 7 L m 3 a�. >, 5. aY .CO• ° c . vi - 9 _ � a , N 3; a`�i. ' v' , w '3 , °a) w a '8' ° 3, , aNr , o �. 3, a a: �, w. o �, 4 , 1- O. i0 0 E av). 3 n E co 0 2. <-. 0' Z �. ;� O , C. �, a p � N. 43 < , Gx 0. va . v. Y' v' co. p. v. N _. -o, m a) N �• O. "FE, 0. L. '3. , �. �. '� . O• CO• @ M - N 2' N •Op. E 0 D, U. 0' o p y ri •_. N� °. c p Z O'. S' cc. (NA N9 °. , 7, U. C.) 7, m'. m' o, O'. a_ E. �'. N, o, a) p w. �. a 2, 'a' `2a L. o. X. 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