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215-228
STATE OF ALASKA ASA OIL AND GAS CONSERVATION COADSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed. Suspend r Perforate r Other Stimulate Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well y-- Other:PROD to WIND Fo7 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rj, Exploratory r 215-228-0 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50-029-21537-63 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25521 KRU 3N-05L1-03 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9657 feet Plugs(measured) None true vertical 6140 feet Junk(measured) None Effective Depth measured N/A feet Packer(measured) 7106 true vertical N/A feet (true vertical) 6041 Casing Length Size MD TVD Burst Collapse L1-03 LINER 2337' 2 3/8 9650' 6140' SCANNED 46442.4atb RECEIVED Perforation depth: Measured depth: Slotted Liner 7322-9649 MAY 1 7 2016 True Vertical Depth: Slotted Liner 6200-6140 ^GCC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7238 MD,6138 TVD Packers&SSSV(type,MD,and TVD) SSSV= None PACKER= BAKER F PACKER @ 7106 MD and 6041 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 201 2691 1100 353 Subsequent to operation 0 _ 0 3714 400 2826 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ Pao WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Darrell Humphrey/Bob Christensen Email: n1139(a)conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature ` Q Phone:659-7535 Date . ............LA !/'TL 5/23/11 , r -,(/‘ Form 10-404 Revised 5/2015 RBDMS Ir1- MAY 1 7 2016 Submit Original Only 3N-05L1-03 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/20/16 Convert well to Seawater Injection-open well return to service 04/30/16 (ISW) : STATE WITNESSED (CHUCK SCHEVE) MIT-IA(PASSED) TO 2000 PSI. e 4i11 KUP SVC • 3N-05L1-03 ConocoPhillips FA Well Attributes Max Angle&MD TD Alaska.Inc, Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(CAB) Act Btm(650) r.,mcocrempc 500292153763 KUPARUK RIVER UNIT SVC 101.09 9,310.17 9,657.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-05L1-03,2/15/201612:34'.42 PM SSSV:NONE 110 12/11/2015 Last WO: 38.49 2/22/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .._. _.._.......Last Tag: Rev Reason:ADD LATERALS lehallf 2/15/2015 HANGER;32.7— .111 Casing Strings Casing Description 100 (in) IID(in) Top(556) Set Depth(ftKB) Set Depth(TVD)...I Wt/Len4060I Grade Top Thread L1-03 LINER 2 3)5 1.992 7,312 6 9,650 0 6,140 6 4.60 L-80 ST-L Liner Details Nominal ID Top(656) Top(TVD)(ftKB) Top Incl(°) Item DesCom (in) 7,312.6 6,193.0 42.16 DEPLOY Shorty Deployment Sleeve 1.920 "21 Perforations&Slots Shot CONDUCTOR;38.0-115.0 .A Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,322.0 9,649.0 6,200.0 6,140.7 A-1.3N-05 2/2/2016 SLOTS GAS LIFT;2,505.7 - yy Notes:General&Safety End Date Annotation NOTE. r SURFACE;37.0-3,764.3---tA, I l GAS LIFT;4,039.6 DT Safety Valve;4,509.6 . r1. GAS LIFT',5 318 6 GAS LIFT;6,353.8 GAS LIFT;7,042.0 XO Enlarging;7,097.8 C' Locator;7,098.3 PACKER;7,106.1— ai SEAL ASSY;7,099.0 SBE;7,108.4 XO Reducing(Tubing);7,128.8 NIPPLE;7,226.4 9 i 00 Enlarging(Tubing);7,238.2 Liner;7,239.2 Liner;7,282.8, RPERF;7,299.0-7,314.0— I (PERF;7,309.0-7,310.0— WHIPSTOCK;7,319.0 PRODUCTION;35.0-7,569.1 L1 LINER;7,845.4-9,633.0 SLOTS;7,322.0-9,649.0— L1-03 LINER:7,312.6-9,6500 • • p4c.. c) , `° O co 0 - o N 9 O E E • co" • aa > IC) - cM O I - • co O ccr) � Z Q O OCO o T NN NNN a T c o) U ml g Z Z co m m w m m w Z Z Z .N O _ >- N 7 7 c c v) c c u) > > 7 — vi ti (I) 9 it it a) it it CO (I) U) Cn T T a, IC) T 0 0 0 CO 0 0 > 0 0 > m Z Z , h H 2 2 H 2 2 E- 0 0 c o a) N W w Z N LO LO N (n LO W W it (1) U) Z co co co co M co co co co co co Y -' O O O O O O O O 9 9 9va I v) aOO > 41 To y = J ET J J J J J J J J J J J J I C co co to co co LC) LO L() LO LO LC) LC) U) LO LO— Z O m O- O Y O O O O O O o. 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Q a o a) O Z• Os_ N a) c o 2 0 I co U V) 'II Z I CO a) CO a5 CO N CO CO d 3 OV 0 0 0 0 0 N E Q N N m TO co co as n) I O Z .c...6 co En m t. m = N C 0 0 0 0 0 J E 0OC) I r co O N > ap co Co CD CO W c > a) CO ID W E o_ 0 a) CD N N CO CO N N N � W O O I W d N Q d re 0 0 C E) 2 N > a) i W N re o c d Z < o o < o o ° I c c v '" °) U 0 0 0 0 0 c 2 .5 .0 o) J a) •a a) co -) 0 , a 7 0 0. a m o E a O E o 0 0 0 °1 D E o ° E °) m E E _ — 0. 2 W W W w W J 3 i 0 a 0 0 0 ° 0 10 RECEliv • STATE OF ALASKA • MAR 0 1 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAGD • WDSPL❑ No. of Completions: Service 0, Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/3/2016 215-228 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1/31/2016 50-029-21537-63 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 1562'FSL,354'FEL, Sec 29,T13N, R9E, UM 2/2/2016 • KRU 3N-05L1-03 Top of Productive Interval: 9. Ref Elevations: KB:67 17. Field/Pool(s): 4104 FNL, 3357 FEL, Sec 29,T13N, R9E, UM GL: 38 BF:38 Kuparuk River Field/Kuparuk Oil Pool Total Depth: 2120 FNL,4139 FEL, Sec 29,T13N, R9E, UM 10. Plug Back Depth MD/TVD: 18. Property Designation: n/a ADL 25521 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Cepth MD/TVD: 19. Land Use Permit: Surface: x- 518046 y- 6013799 Zone- 4 °''`' 96t .16140 ALK 2557 TPI: x- 515046 y- 6013407 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 514253 y- 6015389 Zone- 4 n/a 1727/1727 5. Directional or Inclination Survey: Yes . E (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 7645/6230 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 FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16 62.5 H-40 38 115 115 115 18 232 sx CS II 9 5/8 36 J-55 37 3764 37 3599 11 5/8 1070 sx PF"E"&290 sx (:lass(; 7 26 J-55 35 7569 35 6384 9 300 sx Class G 5 1/2 14 J-55 7239 7327 6138 6204 n/a KO Joint 2 3/8 4.6 L-80 7312 9650 6192 6140 3 Slotted Liner 24. Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7239 7106/6041 Slotted Liner @ 7322-9649 MD,6200-6140 TVD OMpLETION 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes❑ No ❑ 2-/3/1@ Per 20 AAC 25.283(i)(2)attach electronic and printed information VFF1c1Ff1 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED k-- 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 2/15/2016 Flowing Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 2/18/2016 12 hrs Test Period -0. 2 0.148 1481 124/176 n/a Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (torr): Press. 250psiq 1370psig 24-Hour Rate - 5 0.296 2973 n/a L 1I4I6S- Form 10-407 Revised 11/2015 if r� 3!«/ CONTINUED ON PAGE 2 Submit ORIGINIAL onjy t % )/77 RBDMS LIL- MAR 01.2016 -; • • 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No RI If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1727 1727 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 7646 6230 information, including reports, per 20 AAC 25.071. Fault 1 (DT Al/UT Al) 9096 6208 Al 9340 6185 A2 9517 6156 TD(Kuparuk A3) 9657 6140 Formation at total depth: Kuparuk A3 31. List of Attachments: Summary of Daily Operations. Definitive Survey, Schematics Information to be attached includes, but is not limited to: summary of daily operations,wellbore schematic,directional or inclination survey, core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Keith Herring A 263-4321 Email: Keith.E.HerringAcop.com --'." 3 4 Printed Name: J. Burke Title: Sr.CTD Engineer — Signature: Phone: 265-6097 Date: -- INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance, geochemical,or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • 3N-05 Final CTD Schematic Modified by KEH 02-03-16 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Baker Orbit deployment valve at 4509'RKB(4517'PDC) Note:2.89"min ID,no nipple profile 16"62.5#H-40 shoe @ 115'MD 3-1/2"Camco gas lift mandrels: 2505',4039',5318',6353',& 7b42'RKB (2513',4047',5326',6361',&7050'PDC) Packer at 7,106'RKB(7114'PDC) (Note:Must be 7099'or deeper for injector requirements) 9-5/8"36#J-55 3-1/2"X-nipple at 7226'RKB(7234'PDC) (2.812"min ID) shoe @ 3764' I 1 3-1/2"to 5-1/2"crossover: 7238'RKB(7246'PDC) 3-1/2"X 5-1/2"Big Tail Pipe configuration: 7239'-7327'RKB(7247'-7335'PDC) A 0 9> A-sand perfs 7299-7392' a up 77- •TOWS=7317' MD \ — 7"cplgs at 7270', 3N-05L1,TD=10101'MD 7312',7356'MD 2%"slotted liner with anchored billet TOL=7645'MD,BOL=9633'MD IBP(mid-element)=9703'MD Failed IBP(mid-element)=9853'MD 1 L 3N-05L1 PB1,TD=10013'MD Anchored billet at 9000'MD 7"26#J-55 shoe 3N-05L1-03,TD=9657'MD (§7569'MD 2%"slotted liner with deployment sleeve TOL=7312'MD,BOL=9650'MD A KUP POD 3N-05 ConoroPhilhhps Well Attrib Max Angl !Mtn TD AlGskeT_Inc, ;1 Wellbore API/UWI Field Name Wellbore Status 'ncl('1 MD( B) Act (ftKB) -21 500292153700 KUPARUK RIVER UNIT PROD _ 44.90 6,400.00 7,601.0 s1.„ 1 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-05,2/25/2016206:31 PM SSSV: NONE _ 110 12/11/2015 La5t WO: 10/17/2015 38.49 2/22/1986 Vertical schn nabc.(echle9 'Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,452.0 10/25/2015 Rev Reason:ADD LATERALS lehallf 2/15/2016 HANGER',327-. i'r;,411 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 38.0 P ( 115.0 P (116.0 62.50 H-40 WELDED r...,..•.....n.u,�r••,•.,u...•...u..v�.1W.I F�.oat,Corin Description ODIDTopftKB Set Depth ftKB Set Depth TVD...Wt/Len(I...Grade Top Thread 9 P (in) (in) (ftKB) P (ftKB) P I 1 SURFACE 9 5/8 8.765 37.0 3,764.3 3,598 8 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth ftKB Set Depth(TVD)...Wt/Len(I...Grade Top Thread .-_, PRODUCTION 7 6276 35.0 7,569.1 6,383.8 26.00 J-55 BTC Ill Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection CONDUCTOR;38.0.115.0- TUBING-WO 2015 31/2 2.992 32.7 7,120.0 6,050.9 9.30 L-80 EUE 8rd UPPER COMPLETION GAS LIFT;2,505.7 Completion Details Nominal ID I Top(ftKB) Top(TVD)(OKB) Top Incl(') Item Des Com (inl 32.7 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6 4,150.8 42.50 OT Safety Baker Orbit valve 2.890 Valve 4500 SURFACE;37.0-3,764.3 7,097.8 6,034.6 42.84'XO Enlarging 3.5 EUE Box X 4.5 IBT pin 2.960 ti 7,098.3 6,034.9 42.84'Locator 'Locater sub 2.960 GAS LIFT;4,039.6 t- 7,099.0 6,035.5 42.83 SEAL ASSY Baker 80/40 seal assembly 21 ft 2.960 4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2015- LOWER PACKER 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd • COMPLETION OH Safety Valve 45096 Y<si' Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(') Item Des Com (in) 7,106.1 6,040.7 42.81 PACKER Baker F packer 5.380 GAS LIFT;5,318.6 it - 7,109.4 6,043.1 42.79 SBE Seal bore ext.80-40 4.000 gi 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG PULLED 10 25 15 2.812 7,239.2 6,138.7 4235 Liner 5.5 X 148 J-55 W 6"wear soxs 5.000 ilk 7,282.9 6,171.0 42.24 Liner 5.5 X 148 J-55 W 6"wear soxs mule shoe 5.000 GAS LIFT;6,353.6 :' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl 4 Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 7,319.0 6,197.8 42.14 WHIPSTOCK 2 5/8"X 5 1/2"Baker Gen II WHIPSTOCK 2.2 DEG 12/31/2015 LEFT OF HIGHSIDE LOOKING DH WITH SLB GAS LIFT;7,042.0 I WPPT AT 7319'RKB REFERENCING HALLIBURTON JEWELRY LOG DATED 27-OCT-15 8 Perforations&Slots XO Enlarging;7,087.8 !A, Shot Locator;7,098.3 Dens Top(TVD) Ban(TVD) (shots/ 3. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PACKER;7,108.1, - 7,299.0 7,314.0 6,183.0 6,194.1 A-3,3N-05 6/28/1987 8.0 RPERF 21/8"EnerJet;60 deg. SEAL ASSY;7,099.0 '�,+' ph SBE;7,109.4 1.(11,2r.:,, 7,309.0. 7,310.0 6,190.4 6,191.1 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ ll'90 XO Reducing(Tubing);7,128.5 'litdeg.ph 7,324.0 7,342.0 6,201.5 6,214.8 A-2,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJet;60 deg. ph 14 7,334.0 7,335.0 6,208.9 6,209.7 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph Iti 7,337.0 7,342.0 6,211.1 6,214.8 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph NIPPLE;7,226.4 7,364.0 7,392.0 6,231.2 6,252.0 A-1,3N-05 4/21/1986 4.0 IPERF 4"Csg Gun HJ II;90 deg.phase a Mandrel Inserts HO Enlarging(Tubing);7,238.2 / St Liner;7,239.2 ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com Liner;7,282.8N 1 2,505.7 2,502.3 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,348.0 2/9/2016 RPERF;7,299.0-7,3140 2 4,039.6 3,804.8 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,307.0 2/9/2016 IPERF;7,309.0.7,310.0' • 3 5,318.6 4,748.9 Camco MMG 1 1/2 GAS LIFT .GLV RK 0.188 1,284.0 2/9/2016 4 6,353.6 5,499.8 Camco MMG 1 1/2 GAS LIFT 'GLV RK 0.188 1,262.0 2/9/2016 5 7,042.0 5.993.8 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 2/8/2016 _ Notes:General&Safety End Date Annotation 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 sLors;7,3zz.o-s,6as.o - 10/17/2015 NOTE: Orbit Valve is NOT a safety valve,it does not fail to closed position. L7-03 LINER;7,312.6&,650.0 _ 10/17/2015 NOTE: Orbit Valve Control lines/system at Wellhead marked Open/Close. WHIPSTOCK 7,319.0 RPERF;7,324.0.7,342.0 IPERF;7,334.0-7,335.0-,..• C IPERF;7,337.0-7,342.0 IPERF;7,364.0-7,392.9 PRODUCTION;35.0-7,569.1 • • UP PROD 3N-05L1-03 Conoco Phillips II Attributes Max Angle&MD TD Wellbore APIIUWIAlaska Inc. Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) - PS 500292153763 KUPARUK RIVER UNIT PROD 101.09 9,310.17 9,657.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-05L1-03,2/25/2016 2:01.49 PM SSSV: NONE 110 12/11/2015 Last WO: 38.49 2/22/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: ADD LATERALS lehallf 2/15/2015 HANGER;32.7 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L1-03 LINER 2 3/8 1.992 7,312.6 9,650.0 6,140.6 4.60 L-80 ST-L jr.i&� „ Liner Details = Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 7,312.6 6,193.0 42.16 DEPLOY Shorty Deployment Sleeve 1.920 .�Perforations&Slots Shot CONDUCTOR;38.0-115.0 II i Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,322.0 9,649.0 6,200.0 6,140.7 A-1,3N-05 2/2/2016 SLOTS GAS LIFT;2,505.7 Notes: General&Safety End Date Annotation NOTE: SURFACE;37.0-3,764.3 A i. l GAS LIFT:4,039.6 QT Safety Valve;4,509.6 ,zill is • GAS LIFT;5,318.6 ' c.,; GAS LIFT;6,353.6 c_,: GAS LIFT;7,042.0 c v XO Enlarging;7,097.8 Locator;7,098.3al PACKER;7,106.1— SEAL ASSY;7,099.0 ..... = 1 SBE;7,109.4 XO Reducing(Tubing);7,128.8 NIPPLE;7,226.4 XO Enlarging(Tubing);7,238.2 Liner;7,239 2 Dril ; tperations Summary (with Timelog 6epths) _. &Wells 3N-05 Cor►ocoPhitlips fad" 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) 1/21/2016 1/21/2016 3.00 MIRU MOVE RURD P Prep for rig move to 3N-pad.Load and 0.0 0.0 00:00 03:00 secure tree.Check all tree bolts,no studs found loose,45 Minutes. Complete RD checklist,Prep shop for move.Prep for sow arrival. 1/21/2016 1/21/2016 3.50 MIRU MOVE MOB P PJSM,with Peak and rig crew.Pull rig 0.0 0.0 03:00 06:30 modules off of 3Q-13,install jeeps, ready to move. 1/21/2016 1/21/2016 2.50 MIRU MOVE MOB P Move rig modules and shop to 3N-pad 0.0 0.0 06:30 09:00 1/21/2016 1/21/2016 2.00 MIRU MOVE MOB P Remove jeeps,prep well,remove tree 0.0 0.0 09:00 11:00 caps,spot rig modules over well.Send truck back to retrieve shop from pervious location. 1/21/2016 1/21/2016 4.50 MIRU MOVE MOB P RU interconnect,work on post rig 0.0 0.0 11:00 15:30 move checklist, 1/21/2016 1/21/2016 1.00 MIRU MOVE RURD T Manipulate crooked well head 0.0 0.0 15:30 16:30 1/21/2016 1/21/2016 0.50 MIRU MOVE RURD P Complete rig move checklist 0.0 16:30 17:00 1/21/2016 1/21/2016 1.75 MIRU WHDBOP NUND P Nipple up BOPE stack,inspect and 0.0 0.0 17:00 18:45 replace o-rings on riser,and secure cellar,Check all tree bolts,3 bolts on top of swab#1 &2 bolts on top of master valve loose,torqued to spec- ****Note:Check Tree Bolts 0.75 hrs. ****Rig Accept: 17:00 hrs 1/21/2016 1/22/2016 5.25 MIRU WHDBOP BOPE P Begin initial BOPE test 250/4,300 psi, 0.0 0.0 18:45 00:00 annular 2,500 psi.Test witness waived by AOGCC rep.Jonnie Hill. 1/22/2016 1/22/2016 2.25 MIRU WHDBOP BOPE P Continue initial BOPE test 250/4,300 0.0 0.0 00:00 02:15 psi,annular 2,500 psi.Test witness waived by AOGCC rep.Jonnie Hill. Lower 2"Pipe Ram failure. 1/22/2016 1/22/2016 2.00 MIRU WHDBOP RGRP T Replace lower 2"pipe rams.Sim-ops 0.0 0.0 02:15 04:15 start filling Coil 1/22/2016 1/22/2016 1.00 MIRU WHDBOP BOPE P Pressure test inner reel iron and pack 0.0 0.0 04:15 05:15 offs.Shell test BOPE 250/4,300 psi, test lower 2"pipe rams 250/4,300 psi- good. ****Note:No downTime for Nabors, BOPE test was performed within 12 hrs 17:15 to 05:15 1/22/2016 1/22/2016 3.00 MIRU WHDBOP MPSP P PJSM,w/rig and valve crew,load 0.0 0.0 05:15 08:15 lubricator and BPV equipment,and Pull TWC. 1/22/2016 1/22/2016 2.50 MIRU WHDBOP PRTS P P/T PDL's and tiger tank line 0.0 0.0 08:15 10:45 1/22/2016 1/22/2016 0.50 PROD1 WHDBOP SFTY P Pre-spud with rig crews 0.0 0.0 10:45 11:15 Page 1/11 Report Printed: 2/23/2016 II) • DrillingOperations Summary (with Timelog Depths) =y &Welts 3N-05 ConocoPhillips Amt. 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) 1/22/2016 1/22/2016 2.00 PROD1 WHPST PULD T PJSM,for PU/MU BHA#1,attemp to 0.0 0.0 11:15 13:15 function orbit valve,returned fliud not proper upon functioning,attempt to bleed WHP,with no success,attemp to function orbit valve with same results.Confer with town on plan forward.Contacted Baker Hughes Completion they are going to send a Technical engineer(Erin Miller)out for the next time we are out of hole. 1/22/2016 1/22/2016 2.00 PROD1 WHPST PULD P PJSM,PU/MU and deploy milling 0.0 0.0 13:15 15:15 BHA#1, 1/22/2016 1/22/2016 0.75 PROD1 WHPST PULD P Stab INJH and surface test Coiltrak 0.0 74.3 15:15 16:00 tools. 1/22/2016 1/22/2016 3.40 PROD1 WHPST TRIP P RIH with Window Milling BHA#1,with 74.3 7,090.0 16:00 19:24 a 0.6 ako motor,new 2.80 OD window mill,and string reamer.Slow down starting at 6,400 ft to clean out excess bio-degradeable plug left in well bore to 7,240 ft,PUH while circulating bottoms up,RBIH. 1/22/2016 1/22/2016 0.20 PROD1 WHPST DLOG P Tie in at K1 for plus 1.0 ft correction. 7,090.0 7,030.0 19:24 19:36 1/22/2016 1/22/2016 0.25 PROD1 WHPST TRIP P Continue in hole,sat down 2k at 7,317 7,030.0 7,317.0 19:36 19:51 ft with pumps off,top of whipstock, PUH. 1/22/2016 1/22/2016 1.15 PROD1 WHPST DISP P Displace well to 9.5 ppg milling fluid, 7,317.0 7,323.0 19:51 21:00 dry tag pinch point at 7,323 ft 1/22/2016 1/23/2016 3.00 PROD1 WHPST WPST P 7,322.6 ft, Mill window exit per 7,323.0 7,325.5 21:00 00:00 recomended pratice 1.45 bpm at 3,575 psi FS, BHP 3,830 psi,WH 272, IA 617,OA O. NOTE:Bleed IA down from 800 psi 1/23/2016 1/23/2016 6.00 PROD1 WHPST WPST P Continue milling window exit per 7,325.5 7,327.0 00:00 06:00 recomended pratice 1.45 bpm at 3,575 psi FS,BHP 3,830 psi,WH 236, IA 457,OA 0. 1/23/2016 1/23/2016 3.00 PROD1 WHPST WPST P 7,327 ft.milling window exit 1.45 bpm 7,327.0 7,328.2 06:00 09:00 at 3580 psi,BHP 3829,WHP 212, IA 741,OA0 1/23/2016 1/23/2016 3.00 PROD1 WHPST WPST P 7,328.2 ft.Casing exit,conitnue time 7,328.2 7,343.0 09:00 12:00 miling to clean exit area,mill rate hole down to 7,343 ft. ****Note: BOT pumping sechedule is on s:drive. 1/23/2016 1/23/2016 2.00 PROD1 WHPST WPST P 7,343 ft.Perform reaming passes as 7,343.0 7,343.0 12:00 14:00 per RP 1/23/2016 1/23/2016 1.25 PROD1 WHPST TRIP P 7,343 ft.POOH,pumping 1.42 bpm at 7,343.0 74.3 14:00 15:15 3472 psi. 1/23/2016 1/23/2016 1.50 PROD1 WHPST TRIP T OOH,function closed orbit valve, 74.3 74.3 15:15 16:45 attempt to with no success,Baker Technical Engineer Erin Miller confirmed orbit valve to not be working properly,Will contact us after discussing findings with other personnel. 1/23/2016 1/23/2016 0.75 PROD1 WHPST PULD P PJSM,with rig crews,begin undeploy 74.3 74.3 16:45 17:30 window milling BHA#1,secure well for approved training. Page 2/11 Report Printed: 2/23/2016 e0; re Operations Summary (with Timelog Depths) a W 3N-05 conocoPhinips 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) 1/23/2016 1/23/2016 1.50 PROD1 WHPST SFTY P DROPS training with both crews(1 hr) 74.3 74.3 17:30 19:00 change out and Pre Spud with Mike Vancleve's crew. 1/23/2016 1/23/2016 1.50 PROD1 WHPST PULD P PJSM-complete PUD,LD BHA#1 74.3 0.0 19:00 20:30 1/23/2016 1/23/2016 2.00 PROD1 DRILL PULD P PJSM-MU/PD BHA#2,MU to 0.0 72.2 20:30 22:30 CoilTrak,surface test. 1/23/2016 1/24/2016 1.50 PROD1 DRILL TRIP P RIH with BHA#2,2.2°+AKO mototr 72.2 7,000.0 22:30 00:00 and RB HCC Bi-center bit. 1/24/2016 1/24/2016 0.50 PROD1 DRILL DLOG P Tie in to K1 for minus 1.0 ft correction, 7,000.0 7,343.0 00:00 00:30 continue in hole,close EDC, PUW above window 30k, RBIH,clean thru window. 1/24/2016 1/24/2016 5.00 PROD1 DRILL +DRLG P 7,343 ft, OBD 1.5 bpm at 3,570 psi 7,343.0 7,550.0 00:30 05:30 FS,BHP 3,830 psi,WH180,IA 0,OA 0. "Note-New 9.3 ppg FloPro out bit at 7,435 ft. 1/24/2016 1/24/2016 2.00 PROD1 DRILL TRIP P 7,550 ft, Build TD called,pump 5x5 7,550.0 72.2 05:30 07:30 sweep.POOH. 1/24/2016 1/24/2016 0.25 PROD1 DRILL SFTY P At surface,PJSM for PUD 72.2 72.2 07:30 07:45 1/24/2016 1/24/2016 1.25 PROD1 DRILL PULD P PUD build section BHA 72.2 0.0 07:45 09:00 1/24/2016 1/24/2016 1.50 PROD1 DRILL PULD P PD pre-loaded BHA#3 w/RSM 0.0 69.2 09:00 10:30 1/24/2016 1/24/2016 1.25 PROD1 DRILL TRIP P RIH,with Lateral BHA#3 w/RSM 69.2 7,080.0 10:30 11:45 1/24/2016 1/24/2016 0.50 PROD1 DRILL DLOG P Tie into the K1 marker correction of 7,080.0 7,125.0 11:45 12:15 minus 1.5 ft. 1/24/2016 1/24/2016 0.25 PROD1 DRILL DLOG P RIH, log RA marker 7,324 ft.Continue 7,125.0 7,550.0 12:15 12:30 RIH to bottom. 1/24/2016 1/24/2016 6.65 PROD1 DRILL DRLG P 7,550 ft,OBD 1.52 bpm at 3775 psi 7,550.0 7,950.0 12:30 19:09 FS,BHP 3867,WHP 295, IA 153,OA 0 1/24/2016 1/24/2016 0.55 PROD1 DRILL WPRT P 7,950 ft.Wiper up hole to 7,345 ft. 7,950.0 7,345.0 19:09 19:42 PUW 29k 1/24/2016 1/24/2016 0.20 PROD1 DRILL WPRT P 7,345 ft.Wiper back in hole. RIW 11k 7,345.0 7,950.0 19:42 19:54 1/24/2016 1/25/2016 4.10 PROD1 DRILL DRLG P 7,950 ft. OBD 1.46 bpm at 3,675 psi 7,950.0 8,258.0 19:54 00:00 FS,BHP 3,860 psi,WHP 297. IA 332, OA 0, 1/25/2016 1/25/2016 1.55 PROD1 DRILL DRLG P 8,258 ft. OBD 1.45 bpm at 3,974 psi, 8,258.0 8,350.0 00:00 01:33 BHP 3,899 psi,WHP 280,IA 429,OA 0 1/25/2016 1/25/2016 0.50 PROD1 DRILL WPRT P 8,350 ft.Wiper up hole,PUW 31k, 8,350.0 7,255.0 01:33 02:03 Jet/Jog BTP 1/25/2016 1/25/2016 0.25 PROD1 DRILL DLOG P RIH,log RA for plus 1.0 ft correction, 7,255.0 7,360.0 02:03 02:18 continue in hole 1/25/2016 1/25/2016 0.50 PROD1 DRILL WPRT P Wiper back in hole RIW 11.5k 7,360.0 8,350.0 02:18 02:48 1/25/2016 1/25/2016 7.50 PROD1 DRILL DRLG P 8,350 ft. OBD 1.5 bpm at 3,854 psi 8,350.0 8,750.0 02:48 10:18 FS,BHP 3,889 psi,WHP 245, IA 395, OA 0. 1/25/2016 1/25/2016 0.50 PROD1 DRILL WPRT P 8,750 ft.Wiper up hole to 7,752 ft. 8,750.0 7,752.0 10:18 10:48 PUW 27k 1/25/2016 1/25/2016 0.50 PROD1 DRILL WPRT P 7,752 ft,Wiper back in hole RIW 11k 7,752.0 8,750.0 10:48 11:18 Page 3/11 Report Printed: 2/23/2016 • • Operations Summary (with Timelog Depths) Wing it 3N-05 °moc Phillips Masi. 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) 1/25/2016 1/25/2016 6.10 PROD1 DRILL DRLG P 8,750 ft.BOBD 1.5 bpm at 3730 psi 8,750.0 9,150.0 11:18 17:24 FS,BHP 3983,WHP 217, IA 636,OA 0 1/25/2016 1/25/2016 1.25 PROD1 DRILL WPRT P 9,150 ft.Wiper up hole,PUW 28k, 9,150.0 7,260.0 17:24 18:39 Jet/Jog BTP. 1/25/2016 1/25/2016 0.20 PROD1 DRILL DLOG P Log RA for plus 1.5 ft correction. 7,260.0 7,360.0 18:39 18:51 1/25/2016 1/25/2016 0.65 PROD1 DRILL WPRT P Wiper trip back inhole,RIW 11k 7,360.0 9,150,0 18:51 19:30 1/25/2016 1/25/2016 2.30 PROD1 DRILL DRLG P 9,150 ft. OBD 1.45 bpm at 4,052 psi 9,150.0 9,278.0 19:30 21:48 FS,BHP 3,933 psi,WHP 225, IA 550, OA 0 ""NOTE: New 9.3 ppg FloPro out bit at 9,220 ft. 1/25/2016 1/26/2016 2.20 PROD1 DRILL EQRP T 9,278 ft. ft. PUH slowly while 9,278.0 9,000.0 21:48 00:00 troubleshooting failed/corrupt LWD survey data base,had to up load new data base,RBIH from 8,730 ft. *NOTE:2 hours down time BHI. 1/26/2016 1/26/2016 0.20 PROD1 DRILL TRIP T Continue RIH from 9,000 ft. 9,000.0 9,278.0 00:00 00:12 1/26/2016 1/26/2016 6.00 PROD1 DRILL DRLG P 9,278 ft. OBD 1.45 bpm at 3,745 psi 9,278.0 9,550.0 00:12 06:12 FS,BHP 3,950 psi,WHP 287, IA 593, OA 0 1/26/2016 1/26/2016 0.40 PROD1 DRILL WPRT P 9,550 ft.Wiper up hole to 9,000 ft. 9,550.0 9,000.0 06:12 06:36 PUW 27k 1/26/2016 1/26/2016 0.25 PROD1 DRILL WPRT P 9,000 ft.Wiper back in hole RIW 10k 9,000.0 9,550.0 06:36 06:51 1/26/2016 1/26/2016 5.50 PROD1 DRILL DRLG P 9,550 ft. BOBD 1.5 bpm at 3950 psi 9,550.0 9,880.0 06:51 12:21 FS,BHP 4050,WHP 157, IA 229,OA 0 1/26/2016 1/26/2016 2.00 PROD1 DRILL WPRT P 9,886 ft.pump 10x10 sweep,wiper up 9,886.0 7,260.0 12:21 14:21 hole to jet the BTP, PUW 27k,Jet 5.5 2 times,RBIH to 7340 for tie in 1/26/2016 1/26/2016 0.10 PROD1 DRILL DLOG P Log RA for+2.5' 7,340.0 7,357.0 14:21 14:27 1/26/2016 1/26/2016 1.20 PROD1 DRILL WPRT P 7,260 ft.Wiper back in hole.RIW 9k, 7,260.0 9,886.0 14:27 15:39 tag up several times down to 7725 then clear '*"Note:9,320 ft.Having to lower pump rate to get to bottom 1/26/2016 1/26/2016 2.50 PROD1 DRILL DRLG P 9,886 ft,BOBD 1.5 bpm at 3950 psi 9,886.0 10,013.0 15:39 18:09 FS,BHP 3677,WHP 235, IA 230,OA 0 1/26/2016 1/26/2016 2.60 PROD1 DRILL TRIP T 10013 call TD for poor hole conditions 10,013.0 7,250.0 18:09 20:45 -out of target. Pump sweeps PUH slowly waiting on sweeps, PUW:---27.5K.Had to work through 9810.PUH through window,Jog through 5.5"tail pipe.Packing off- work pipe to clear up.Pump more sweeps. Page 4/11 Report Printed: 2/23/2016 S • n Wffing Operations Summary (with Timelog Depths) el op, 3N-05 ConocoPhiilips li Mast. Rig: NABORS CDR2-AC Job: DRILLING SIDETRACK Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/26/2016 1/26/2016 1.80 PROD1 DRILL TRIP T RBIH to ensure build section clean. 7,250.0 5,000.0 20:45 22:33 Clean pass through window.Stacked out @ 7370.Work pipe multiple times to get to 7400 then clear to end of build @ 7550.Jet moving uphole.Jog below window.Observed increased cuttings from bottoms up. 1/26/2016 1/27/2016 1.45 PROD1 DRILL TRIP T Stop @ 5000'.Open EDC continue 5,000.0 602.0 22:33 00:00 out.Jog/Jet orbit valve. 1/27/2016 1/27/2016 0.60 PROD1 DRILL TRIP T Continue out of well.Attempt to close 602.0 80.0 00:00 00:36 Orbit,Not closing 1/27/2016 1/27/2016 2.00 PROD1 DRILL PULD T PJSM for PUD.Tag and space out. 80.0 0.0 00:36 02:36 PUD BHA#3 RSM 1/27/2016 1/27/2016 1.00 PROD1 STK PULD T PJSM,PD BHA#4 Aluminum 0.0 72.9 02:36 03:36 anchored billet, M/U coil to BHA and surface test 1/27/2016 1/27/2016 1.75 PROD1 STK TRIP T RIH BHA#4 Anchor billet 72.9 7,100.0 03:36 05:21 1/27/2016 1/27/2016 0.50 PROD1 STK DLOG T Log K1 for minus 1.0 ft. 7,100.0 7,125.0 05:21 05:51 1/27/2016 1/27/2016 0.50 PROD1 STK TRIP T 7,125 ft.Continue RIH 7,125.0 9,011.8 05:51 06:21 1/27/2016 1/27/2016 0.25 PROD1 STK WPST T 9,011.75 ft.Set Billet,bring pump up, 9,011.8 9,011.8 06:21 06:36 pressure sheared at 4600 psi,set down 2.5 k, 1/27/2016 1/27/2016 2.00 PROD1 STK TRIP T 9,011 ft.POOH,pumping 1.4 bpm at 9,011.8 61.1 06:36 08:36 3356 psi 1/27/2016 1/27/2016 0.25 PROD1 'STK PULD T Tag up space out,PJSM for PUD 61.1 61.1 08:36 08:51 1/27/2016 1/27/2016 1.25 PROD1 STK PULD T PUD BOT setting tools. 61.1 0.0 08:51 10:06 1/27/2016 1/27/2016 0.50 PROD1 STK PULD P Function test BOPE 0.0 0.0 10:06 10:36 1/27/2016 1/27/2016 1.00 PROD1 STK PULD T PD kickoff/drilling BHA#5 0.0 72.2 10:36 11:36 1/27/2016 1/27/2016 0.50 PROD1 STK PULD T Check pac-offs and upper check 72.2 72.2 11:36 12:06 valves,Stab INJH,surface test Coiltrak tools. 1/27/2016 1/27/2016 1.25 PROD1 STK TRIP - T RIH,with kickoff/drilling BHA#5 w/ 72.2 7,100.0 12:06 13:21 0.68°bend motor and re-run bi center bit. 1/27/2016 1/27/2016 0.25 PROD1 'STK DLOG T 7,100 ft.Tie into the K1 marker with 7,100.0 7,128.0 13:21 13:36 no correction. 1/27/2016 1/27/2016 0.75 PROD1 STK TRIP T 7,128 ft.Continue RIH 7,128.0 9,000.0 13:36 14:21 1/27/2016 1/27/2016 0.25 PROD1 STK TRIP T 9,002.3 ft.Dry tag TOB,PUH,PUW, 9,000.0 9,000.0 14:21 14:36 bring pump online. 1/27/2016 1/27/2016 2.40 PROD1 STK KOST T 9,001 ft.Time mill off billet, 1.46 bpm 9,000.0 9,003.5 14:36 17:00 at 3839 psi FS, BHP 3970,WHP 240, IA 0,OA 0, Hard to get going,Stick- slipping with stalls, Pump lube pill and get on billet 1/27/2016 1/27/2016 0.30 PROD1 DRILL DRLG T Drilling ahead, 1.46 BPM @ 3900 PSI 9,003.5 9,030.0 17:00 17:18 FS,BHP=3990 1/27/2016 1/27/2016 0.20 PROD1 DRILL WPRT T Dry drift billet area,Looks good, 9,030.0 9,030.0 17:18 17:30 PUW=29K 1/27/2016 1/27/2016 5.90 PROD1 DRILL DRLG T 9030', Drill, 1.47 BPM @ 3925 PSI 9,030.0 9,410.0 17:30 23:24 FS,BHP=3998 Page 5/11 Report Printed: 2/23/2016 Operations Summary (with Timelog Depths) 3N-05 Coa,ocoPhiilips 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) 1/27/2016 1/28/2016 0.60 PROD1 DRILL WPRT T 9410',Wiper to 8500'with 5 X 5 9,410.0 9,410.0 23:24 00:00 Sweep 1/28/2016 1/28/2016 0.60 PROD1 DRILL WPRT T Continue wiper trip,Clean trip up and 9,410.0 9,410.0 00:00 00:36 down 1/28/2016 1/28/2016 6.00 PROD1 DRILL DRLG T 9410',Drill,1.4 BPM @ 3960 PSI FS, 9,410.0 9,810.0 00:36 06:36 BHP=4020,RIW=11.22K,WHP=134 1/28/2016 1/28/2016 1.25-PROD1 DRILL WPRT T 9,810 ft.Wiper up hole to 7,260 ft, 9,810.0 7,260.0 06:36 07:51 jetting 5.5",PUW 29.5k 1/28/2016 1/28/2016 0.25 PROD1 DRILL DLOG T 7,345 ft.tie into the RA marker 7,260.0 7,345.0 07:51 08:06 correction plus 1.0 ft. 1/28/2016 1/28/2016 0.75 PROD1 DRILL WPRT T Continue wiper in hole,RIW 10k 7,345.0 9,810.0 08:06 08:51 *""*Note:Stacked out 5k SW,PUW 28k,7,744 ft.no DHWOB,pack-off, annular increased,turn around,and continued RIH. 1/28/2016 1/28/2016 8.30 PROD1 DRILL DRLG T 9,810 ft.BOBD 1.5 bpm at 3,900 psi 9,810.0 10,101.2 08:51 17:09 FS,BHP 4005,WHP 79, IA 207,OA 4, 10028'Out rate increasing, Increase well head 1/28/2016 1/28/2016 1.40 PROD1 DRILL WPRT P 10102 ft,Call TD,Wiper up hole, 10,101.2 7,335.0 17:09 18:33 pump 5x5 sweep,PUW 28k 1/28/2016 1/28/2016 0.90 PROD1 DRILL WPRT P Clean out big tail pipe and circulate 7,335.0 7,297.0 18:33 19:27 bottoms up 1/28/2016 1/28/2016 1.30 PROD1 DRILL PRTS P Perform static pressure test, Start @ 7,297.0 7,279.0 19:27 20:45 Annular 4289,WHP=1168,End of 30 min Annular=4452,WHP=1352.Bleed Whp to 670 and retest.Annular down to 4011.After 30 min Annular=4461 WHP=1366,EMW=13.61 PPG 1/28/2016 1/28/2016 0.90 PROD1 DRILL WPRT P Trip in to inflatable set depth,Stack 7,279.0 9,810.0 20:45 21:39 out @ 7333,PUH then run right through,Tie into RA for+1', 1/28/2016 1/29/2016 2.35 PROD1 DRILL TRIP P Pump sweeps and trip out 9,810.0 7,394.0 21:39 00:00 1/29/2016 1/29/2016 2.00 PROD1 DRILL TRIP P Continue out of well 7,394.0 68.0 00:00 02:00 1/29/2016 1/29/2016 2.00 PROD1 DRILL PULD P PJSM,at surface,Tag up and space 68.0 0.0 02:00 04:00 out,PUD BHA#5 1/29/2016 1/29/2016 2.50 PROD1 DRILL PULD T PJSM,M/U WFT Inflatable packer and 0.0 0.0 04:00 06:30 PD,M/U to coil and surface test 1/29/2016 1/29/2016 1.75 PROD1 DRILL TRIP T RIH,with WIBP and Coilrack tools. 0.0 7,070.0 06:30 08:15 1/29/2016 1/29/2016 0.25 PROD1 DRILL DLOG T 7,070 ft,Tie into the K1 marker 7,070.0 7,097.0 08:15 08:30 correction of minus 1.0 ft.PUW 27k 1/29/2016 1/29/2016 1.50 PROD1 DRILL TRIP T 7,097 ft.Continue RIH to setting 7,097.0 9,853.2 08:30 10:00 depth. 1/29/2016 1/29/2016 0.75 PROD1 DRILL TRIP T 9853.15 ft.Park coil for 20mins,DHT 9,853.2 9,853.2 10:00 10:45 is 152°F,pressure up DP in stages, 275 psi/2000 psi CP, 687 psi/2400 psi CP, 1000 psi/2800 psi CP 1350 psi/3600 psi CP,setting tool shifted 640 psi/1850 psi CP,PUH,pulled free 5k over. Page 6/11 Report Printed: 2/23/2016 i • DrilreIIs Operations Summary (with Timelog Depths) 3N-05 ConocoPhillips ,i` Al ka 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) 1/29/2016 1/29/2016 0.25 PROD1 DRILL TRIP T POOH,pumping thru setting tools,at 9,100.0 9,100.0 10:45 11:00 0.20 bpm at 2420 WHP, BHP 4643, WHP 1397, IA 0,OA 0 1/29/2016 1/29/2016 0.25 PROD1 DRILL TRIP T 9,100 ft. Bleed WHP down to 3743 9,100.0 9,100.0 11:00 11:15 psi,shut in,WHP pressured up to 1366 psi, IBP failed to hole pressure. 1/29/2016 1/29/2016 4.75 PROD1 DRILL TRIP T 9,100 ft,RBIH hole is clear to 9,840 ft, 9,100.0 43.3 11:15 16:00 POOH to surface. 1/29/2016 1/29/2016 2.00 PROD1 DRILL PULD T PJSM, PUD Weatherford setting tools 43.3 0.0 16:00 18:00 and Coiltrak tools 1/29/2016 1/29/2016 2.40 PROD1 DRILL PULD T PJSM,Crew change,Valve check list, 0.0 48.8 18:00 20:24 PD BHA#7,Second inflatable pulg 1/29/2016 1/29/2016 1.70 PROD1 DRILL TRIP T RIH BHA#7 Inflatable packer 48.8 7,070.0 20:24 22:06 1/29/2016 1/29/2016 0.40 PROD1 DRILL DLOG T Log K1,During logging pass tool 7,070.0 7,077.0 22:06 22:30 turned off,Check surface euipment 1/29/2016 1/30/2016 1.50 PROD1 DRILL TRIP T Unable to get tool readings,POOH.At 7,077.0 2,392.0 22:30 00:00 4892 Choke B failed.Trouble shoot, POOH using manual operation. BHI 1.5 Hrs NPT 1/30/2016 1/30/2016 0.50 PROD1 DRILL TRIP T Continue out of well 2,392.0 53.0 00:00 00:30 1/30/2016 1/30/2016 2.30 PROD1 DRILL 'PULD T At surface,tag up and space out, 53.0 0.0 00:30 02:48 PJSM PUD BHA#7,Packer good 1/30/2016 1/30/2016 1.30 PROD1 DRILL PULD ' T PJSM, PD BHA#8 Inflaitable packer 0.0 48.8 02:48 04:06 1/30/2016 1/30/2016 4.00 PROD1 DRILL RGRP T Trouble shoot choke B,re-calibrate, 48.8 48.8 04:06 08:06 inspect choke,blowdown choke line, check settings in software 1/30/2016 1/30/2016 1.00 PROD1 DRILL TRIP T RIH,Weatherford IBP and Coiltrak 48.8 7,070.0 08:06 09:06 tools 1/30/2016 1/30/2016 0.75 PROD1 DRILL DLOG T 7,070 ft.tie into the K1 marker 7,070.0 7,128.0 09:06 09:51 correction of minus 10.0 ft. 5 Hours BHI NPT for today 1/30/2016 1/30/2016 1.50 PROD1 DRILL TRIP T 7,128ft,Continue RIH to setting depth. 7,128.0 9,703.2 09:51 11:21 1/30/2016 1/30/2016 0.75 PROD1 DRILL TRIP T 9,703.2 ft mid element,shut pump 9,703.2 9,703.2 11:21 12:06 down,close EDC,set and let packer temp stablize for 30 min,soft set IBP, CP 2000/DP 375 CP 2400/DP 743 CP 2800/DP 1159 CP 3200//DP1535 CP 3600/DP 1843 Setting Sleeve Shifted 1/30/2016 1/30/2016 1.00 PROD1 DRILL TRIP T 9,703.2 ft.PUH to 9,100 ft,PUW 30k, 9,703.2 9,100.0 12:06 13:06 broke back to 25k,Top of fishing neck 9696 ft.Bleed WHP down to 3640 psi annular, 11.6 EDC at the window. Page 7/11 Report Printed: 2/23/2016 i • Operations Summary (with Timelog Depths) -y &Drilling i 3N-05 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) 1/30/2016 1/30/2016 3.00 PROD1 DRILL TRIP P 9100 ft,RBIH to 9600 ft.Weight up 9,100.0 9,600.0 13:06 16:06 with 26 sacks-11.8 ppg completion fluid and MU 11.8 ppg liner running pill with beads. 1/30/2016 1/30/2016 2.40 PROD1 DRILL TRIP P POOH,laying in 11.8 ppg beaded liner 9,600.0 46.6 16:06 18:30 running pill. Paint EOP flags @ 7500 &5200' 1/30/2016 1/30/2016 1.50 PROD1 DRILL PULD P At surface,perform 30 min No flo, 46.6 0.0 18:30 20:00 Good test,Lay down BHA#8 Packer running 1/30/2016 1/31/2016 4.00 COMPZ1 CASING PUTB P R/U floor and run BHA#9, Non ported 0.0 1,500.0 20:00 00:00 bullnose,68 Jts slptted liner,Shorty deployment sleeve 1/31/2016 1/31/2016 0.70 COMPZ1 CASING PUTB P Continue making up BHA#9,L1 liner 1,500.0 1,976.0 00:00 00:42 with non ported bullnose,68 Jts slotted liner and shorty deployment sleeve 1/31/2016 1/31/2016 0.80 COMPZI CASING PULD P PJSM,M/U coil trac to liner,M/U coil 1,976.0 2,020.1 00:42 01:30 and surface test 1/31/2016 1/31/2016 1.50 COMPZI CASING TRIP P RIH BHA#9 2,020.1 7,220.0 01:30 03:00 1/31/2016 1/31/2016 0.10 COMPZI CASING DLOG , P Tie into flag for-5',PUW=30K, 7,220.0 7,215.0 03:00 03:06 continue in 1/31/2016 1/31/2016 0.60 COMPZ1 CASING TRIP P Continue in well,Set down in bottom 7,215.0 9,040.0 03:06 03:42 window, P/U and then clean through 1/31/2016 1/31/2016 0.40 COMPZI CASING DLOG P Tie into K1 for+4,total correction-1' 9,040.0 9,055.0 03:42 04:06 1/31/2016 1/31/2016 0.20 COMPZI CASING TRIP P RIH to set depth 9633,Pump off liner, 9,055.0 7,657.1 04:06 04:18 Top of deployment sleeve 7657, Remove liner lenght left in hole, 1/31/2016 1/31/2016 1.25 COMPZ1 CASING TRIP P POOH after releaseing from liner 7,657.1 44.2 04:18 05:33 1/31/2016 1/31/2016 0.50 COMPZ1 CASING OWFF P Check well for flow,Crew change, 44.2 44.2 05:33 06:03 PJSM 1/31/2016 1/31/2016 0.50 COMPZ1 CASING PULD P LD liner setting tools 44.2 0.0 06:03 06:33 1/31/2016 1/31/2016 2.00 COMPZI CASING PULD P MU Open Hole Anchored billet,check 0.0 72.9 06:33 08:33 upper quick check valves.Surface test Coiltrak,EDC alignment error,swap upper section of Coiltrak 1/31/2016 1/31/2016 2.00 COMPZ1 CASING RUNL P RIH,with Open Hole Anchored Billet, 72.9 7,095.0 08:33 10:33 EDC open,pumping 0.25 bpm at 561 psi.IA 0,OA 0 1/31/2016 1/31/2016 0.25 COMPZI CASING RUNL P 7095 ft.Tie into the K1 marker 7,095.0 7,124.0 10:33 10:48 correction of minus 1.0 ft. PUW 31k 1/31/2016 1/31/2016 0.25 COMPZ1 CASING RUNL P 7124 ft.Continue RIH w/Open Hole 7,124.0 7,657.6 10:48 11:03Anchored Billet. 1/31/2016 1/31/2016 0.50 COMPZ1 CASING RUNL P 7657.6 ft,Set down on liner,2k 7,657.6 7,645.4 11:03 11:33 DHWOB,PUW 32k,bring pump up to shear 3500 psi,Set down 2k DHWOB, PUH PUW 31k. 1/31/2016 1/31/2016 1.25 COMPZ1 CASING RUNL P PUH above window,7300 ft.check 7,645.4 72.2 11:33 12:48 well for flow,POOH to surface. 1/31/2016 1/31/2016 0.50 COMPZ1 CASING PULD P At surface,check well for flow, PJSM 72.2 72.2 12:48 13:18 1/31/2016 1/31/2016 1.70 COMPZ1 CASING PULD P LD OH anchor setting tools.Change 72.2 0.0 13:18 15:00 out UQC-Check valves Page 8/11 Report Printed: 2/23/2016 Operations Summary (with Timelog Depths) Well4-tor" s 3N-05 ConocoPhiliips "hlaqkay 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) 1/31/2016 1/31/2016 0.70 PROD4 STK PULD P PU/MU L1-03 lateral drilling assembly 0.0 72.2 15:00 15:42 with 0.T motor bend and RB HCC bi- center bit. 1/31/2016 1/31/2016 1.50 PROD4 STK TRIP P RIH,L1-03 drilling assembly. 72.2 7,100.0 15:42 17:12 1/31/2016 1/31/2016 0.10 PROD4 STK DLOG P Log K1 for no correction 7,100.0 7,123.0 17:12 17:18 1/31/2016 1/31/2016 2.40 PROD4 STK CIRC P Roll hole back to used 9.3 PPG FloPro 7,123.0 7,647.0 17:18 19:42 1/31/2016 1/31/2016 2.50 PROD4 STK KOST P 7647', Dry tag top of billet,Bring on 7,647.0 7,650.6 19:42 22:12 pumps and start milling kick off,Get on billet 7646'1.45 BPM @ 3819 PSI FS,BHP=3837.Start pushin more @ 7648.5 1/31/2016 1/31/2016 0.50 PROD4 DRILL DRLG P Drilling ahead, 1.44 BPM @ 3725 PSI 7,650.6 7,682.0 22:12 22:42 FS,Start new mud down coil 1/31/2016 1/31/2016 0.10 PROD4 DRILL WPRT P Dry drift billet area, PUW=27K,Clean 7,682.0 7,682.0 22:42 22:48 past billet 1/31/2016 2/1/2016 1.20 PROD4 DRILL DRLG P 7682',Drill, 1.45 BPM @ 3779 PSI 7,682.0 7,782.0 22:48 00:00 FS,BHP=3863,WHP=220,New mud @ bit 7696'@ 23:01 2/1/2016 2/1/2016 2.30 PROD4 DRILL DRLG P 7782',Drill, 1.45 BPM @ 3779 PSI 7,782.0 8,060.0 00:00 02:18 FS,BHP=3863,WHP=220, 2/1/2016 2/1/2016 0.60 PROD4 DRILL WPRT P 8060',Wiper to 7350, PUW=28K, 8,060.0 8,060.0 02:18 02:54 Clean trip up and down 2/1/2016 2/1/2016 4.00 PROD4 DRILL DRLG P 8060',Drill ahead, 1.46 BPM @ 3775 8,060.0 8,460.0 02:54 06:54 PSI FS, BHP=3905,WHP=185 2/1/2016 2/1/2016 0.50 PROD4 DRILL WPRT P 8,460 ft.Wiper up hole to 7,725 ft. 8,460.0 7,725.0 06:54 07:24 PUW 27k. 2/1/2016 2/1/2016 0.50 PROD4 DRILL WPRT P 7,725 ft,Wiper back in hole.RIW 13k 7,725.0 8,460.0 07:24 07:54 2/1/2016 2/1/2016 4.61 PROD4 DRILL DRLG P 8,460 ft.BOBD 1.4 bpm at 3564 psi, 8,460.0 8,860.0 07:54 12:30 BHP 3897,WHP 148,IA 0,OA 0 2/1/2016 2/1/2016 1.50 PROD4 DRILL WPRT P 8,860 ft.Wiper up hole to 7,260 ft. 8,860.0 7,350.0 12:30 14:00 Jetting the BTP, 2/1/2016 2/1/2016 0.25 PROD4 DRILL DLOG P 7,350 ft.Tie into the RA marker zero 7,350.0 7,400.0 14:00 14:15 correction 2/1/2016 2/1/2016 0.75 PROD4 DRILL WPRT P 7,400 ft.Continue wiper in hole RIW 7,400.0 8,860.0 14:15 15:00 13k 2/1/2016 2/1/2016 5.60 PROD4 DRILL DRLG P 8,860 ft.,BOBD 1.45 bpm at 3780 psi, 8,860.0 9,248.0 15:00 20:36 BHP 3981,WHP 143,IA 77,OA 0 2/1/2016 2/1/2016 1.10 PROD4 DRILL WPRT P Pull wiper to 8253,PUW=28K 9,248.0 9,248.0 20:36 21:42 2/1/2016 2/2/2016 2.29 PROD4 DRILL DRLG P 9169',Drill, 1.45 BPM @ 3850 PSI 9,248.0 9,338.0 21:42 00:00 FS,BHP=4016 2/2/2016 2/2/2016 3.60 PROD4 DRILL DRLG P Drill, 1.42 BPM @ 3861 PSI FS, 9,338.0 9,538.0 00:00 03:36 BHP=3948,WHP=138 2/2/2016 2/2/2016 0.20 PROD4 DRILL WPRT P Mini Wiper to 9437,PUW=27K 9,538.0 9,538.0 03:36 03:48 2/2/2016 2/2/2016 2.20 PROD4 DRILL DRLG P Drill, 1.42 BPM @ 3861 PSI FS, 9,538.0 9,655.0 03:48 06:00 BHP=4045 2/2/2016 2/2/2016 3.50 PROD4 DRILL WPRT P 9,655 ft.TD L1-03 lateral,pump 10x10 9,655.0 72.2 06:00 09:30 sweeps,perform wiper to the window, pump another 5x5 sweep at the window,jetting 5.5"BTP 2/2/2016 2/2/2016 0.25 PROD4 DRILL WPRT P At surface,re-zero counters,RBIH to 72.2 72.2 09:30 09:45 confirm depth. Page 9/11 Report Printed: 2/23/2016 • 6 Operations Summary (with Timelog Depths) 0a 3N-05 fillips Alaska 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) 2/2/2016 2/2/2016 3.00 PROD4 DRILL WPRT P RBIH.Tied into K1 for a-1 ft 72.2 9,657.0 09:45 12:45 correction.Stacked weight at 9347 ft. Slowed pumps to 0.75 BPM,run back through with no issues. Confirm TD at 9657 ft. 2/2/2016 2/2/2016 3.25 PROD4 DRILL DISP P POOH laying in 43 bbls 11.8 ppg NaBr 9,657.0 72.2 12:45 16:00 liner running pill with Alpine beads follwed by 11.8 ppg NaBr completion fluid. Paint EOP flags @ 7200&4800 • 2/2/2016 2/2/2016 0.50 PROD4 DRILL OWFF P Flow check. 72.2 72.0 16:00 16:30 2/2/2016 2/2/2016 1.50 PROD4 DRILL PULD P PJSM,Flow check good, Lay down 72.0 0.0 16:30 18:00 drilling BHA#11,R/U floor to run liner 2/2/2016 2/2/2016 4.00 COMPZ4 CASING PUTB P PJSM,M/U BHA#12 with non ported 0.0' 2,337.4 18:00 22:00 bullnose,80 Jts slotted liner,2 PUPS, Shorty deployment sleeve 2/2/2016 2/2/2016 0.50 COMPZ4 CASING PULD P M/U coil trak to liner, M/U coil to BHA 2,337.4 2,381.6 22:00 22:30 and surface test 2/2/2016 2/2/2016 1.00 COMPZ4 CASING RUNL P RIH BHA#12 2,381.6 7,185.0 22:30 23:30 2/2/2016 2/2/2016 0.10 COMPZ4 CASING DLOG P Correct to 4800'EOP flag for-4', 7,185.0 7,181.0 23:30 23:36 PUW=30K,DHWOB=-10.8K 2/2/2016 2/3/2016 0.40 COMPZ4 CASING RUNL P Continue in well,Clean pass through 7,181.0 8,294.0 23:36 00:00 window 2/3/2016 2/3/2016 0.40 COMPZ4 CASING RUNL P Continue in hole with BHA#12,L1-03 8,294.0 9,400.0 00:00 00:24 completion 2/3/2016 2/3/2016 0.20 COMPZ4 CASING DLOG P Log K1 for+1.5'correction 9,400.0 9,441.0 00:24 00:36 2/3/2016 2/3/2016 0.10 COMPZ4 CASING RUNL P Continue in to set depth 9,441.0 9,650.0 00:36 00:42 2/3/2016 2/3/2016 0.10 COMPZ4 CASING RUNL P At 9650, PUW=35K,DHWOB=-7.6K, 9,650.0 7,306.0 00:42 00:48 Get back on depth and bring pumps on 1.4 BPM @ 4477, Release from liner, PUW=28K,DHWOB=-2K,Reset counters,TOL=7312, BOL=9650 2/3/2016 2/3/2016 1.00 COMPZ4 CASING DISP P Roll well to seawater 7,306.0 7,306.0 00:48 01:48 2/3/2016 2/3/2016 2.20 DEMOB WHDBOP FRZP P POOH,FP from 2500' 7,306.0 43.3 01:48 04:00 2/3/2016 2/3/2016 2.00 DEMOB WHDBOP RURD P At surface, PJSM,PUD BHA#12 43.3 0.0 04:00 06:00 Liner running BHA 2/3/2016 2/3/2016 2.00 DEMOB WHDBOP RURD P Clean and clear rig floor.Begin 0.0 0.0 06:00 08:00 offloading pits.Stage equipment on 3G pad in preparation for the next well. 2/3/2016 2/3/2016 1.00 DEMOB WHDBOP MPSP P Bring lubricator and rod to the rig floor. 0.0 0.0 08:00 09:00 RU lubricator,pressure test to 250/1500psi.Goot test.Equalize lubricator to SIWHP of 1020 psi.Open well, RIH and set BPV. 2/3/2016 2/3/2016 3.00 DEMOB WHDBOP RURD P Blow down and flush surface 0.0 0.0 09:00 12:00 lines/stack.Continue offloading fluids from the rig.Start rig move checklist. Continue staging equipment at 3G pad. Page 10/11 Report Printed: 2/23/2016 • S 0.:, i Operations Summary (with Timelog Depths) ifire 3N-05 ConocoPhilliips Alaska 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) 2/3/2016 2/3/2016 2.50 DEMOB WHDBOP RURD P Trucks on location at 13:00 hrs. 0.0 12:00 14:30 RIG RELEASE 14:30 Page 11/11 Report Printed: 2/23/2016 • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-05L1-03 50-029-21537-63 Baker Hughes INTEQ En Definitive Survey Report HUGHES 10 February,2016 , • • IIIII/ ConocoPhillips ISRIIII ConocoPhillips Definitive Survey Report HUBAKER GHES Company: ConocoPhillips(Alaska)Inc-Kup2 Local Co-ordinate Reference: Well 3N-05 Project: Kuparuk River Unit TVD Reference: 3N-05 t 67.00usft(3N-05) Site: Kuparuk 3N Pad MD Reference: 3N-05(q)67.00usft(3N-05) Well: 3N-05 North Reference: True Wellbore: 3N-05L1 Survey Calculation Method: Minimum Curvature Design: 3N-05L1 Database: EDM Alaska NSK Sandbox Project Kuparuk River Unit,North Slope Alaska,United States $Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level ,. t. [ UsinGeo Datum: NAD 1927(NADCON CONUS) g Well Reference Point Map Zone: ..,,. Alaska Zone 04 Using geodetic scale factor Well 3N-05 Well Position .NI-S 0.00 usft Northing: 6,013,799.48 usft Latitude: 70°26'55 957 N +E/-W 0.00 usft Easting: 518,046.18usft Longitude: 149°51'10 002 W ii Position Uncertainty 0ft0 usft Wellhead Elevation: usft Ground Level: 33 70 usft Wellbore 3N-05L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (*) r) (nT) BGGM2015 3/1/2016 1052 81 03 57493 Design 3N-05L1-03 Audit Notes. Version: 1 0 Phase: ACTUAL Tie On Depth: 7,640 27 1 Vertical Section: Depth Front(TVD) *NI-S tE/-W DirectIon (usft) (usft) (usft) 33 30 000 000 345.00 Survey Program Date 2/9/2016 From To .. ".... '.... ."'-411rVe1i Survey . , (usft) (usft) Survey(Wellbore) . Tool Name OesetiotAn , •- ' Start Date End gate 10000 7,300.00 3N-05(3N-05) GCT-MS Schlumberger OCT multishot 1/15/2001 7,31700 7,640.27 3N-05L1PB1(3N-05L1PB1) MWD MWD-Standard 1/21/2016 1/26/2016 ;'. 7,646.00 9,61756 3N-05L1-03(3N-05L1-03) MWD MWD-Standard 1/29/2016 2/2/2016 2/10/2016 11:27:56AN1 Page 2 COMPASS 5000 I Build 74 . ConocoPhillips Kai COnOcoPhillips Definitive Survey Report R ONES Project: KuparukcoRiverp (Alaska)lt ° TVDc l Reference: 3N-05Well3N-05 @ Company: ConocoPhillips Inc.-Kup2 Local Co-ordinate Reference: 3N-87.00usft(3 pp05 N-05) Site: Kuparuk 3N Pad MD Reference: 3N-05 @ 67.00usft(3N-05) 1. Well: 3N-05 North Reference: True Wellbore: 3N-05L1 Survey Calculation Method: Minimum Curvature Design: 3N-05L1 Database: EDM Alaska NSK Sandbox Survey MD Inc Azi TVD TVDSS *Nr-S Map Map Vertical +E!-W Northing Fasting DLS Section Survey Tool Name Annotation (tisk) (°) (°) (usft) (usft) _(usft) (usft) (ft) (ft) CM 00') (ft) 7,640.27 97.08 327.13 6,230.35 6,16335 -278.86 -3.255.17 6,013,51276 514,79202 1.80 57314 MWD(2) TIP 7,64600 96.92 327.34 6,229.65 6,162.65 -274.08 -3,258.25 6,013,517.54 514,788.93 4.59 578.55 MWD(3) KOP i 7,675.44 94.09 32653 6,22682 6,159.82 -249.53 -3,274.23 6,013,542.05 514,772.89 10.00 606.41 MWD(3) 7,705.61 91.26 325.72 6,225.42 6,158.42 -224.51 -3,291.03 6,013,567.03 514,75603 9.76 634.92 MWD(3) 7,740.81 8721 324.76 6,225.89 6,158.89 -195.60 -3,311.09 6,013,595.88 514,735.90 11.82 668.04 MWD(3) 7,770.03 83.57 323.68 6,228.23 6,161.23 -171.97 -3,328.12 6,013,619.47 514,718.82 1299 695.27 MWD(3) 7,796.12 81.12 324.34 6,231.71 6,164.71 -151.05 -3,343.31 6,013,640.35 514,703.58 9.72 719.41 MWD(3) 7,825.98 81.62 323.85 6,236.19 6,169.19 -127.14 -3,360.63 6,013,664.21 514,68621 233 746.98 MWD(3) d ,, 7,85E70 85.42 323.91 6,239.54 6,172.54 -103.29 -3,378.03 6,013,688.02 514,668.75 1279 774.53 MWD(3) 7,885.02 89.39 324.13 6,240.87 6,173.87 -79.59 -3,395.23 6,013,711.67 514,651.48 13.56 801.87 MWD(3) 7,915.46 93.47 325.48 6,240.11 6,173.11 -54.73 -3,412.77 6,013,736.49 514,633.89 14.12 830.42 MWD(3) 1 7,945.68 90.46 326.62 6,239.08 6,172.08 -29.69 -3,429.63 6,013,761.50 514,616.97 10.65 858.98 MWD(3) 7,975.64 92.15 327.11 6,238.39 6,171.39 -0.60 -3,446.01 6,013,786.54 514,600.54 5.87 887.45 MWD(3) 8,010.58 91.29 331.60 6,237.34 6,170.34 25.44 -3,463.80 6,013,816.53 514,58267 13.08 921.07 MWD(3) 8,039.94 93.23 334.22 6,236.19 6,169.19 51.55 -3,477.16 6,013,842.61 514,569.25 11.10 949.75 MWD(3) 8,075.34 95.69 337.12 6,233.43 6,166.43 83.70 -3,491.70 6,013,874.72 514,554.64 10.72 984.57 MWD(3) 8,105.30 93.13 338.91 6,231.13 6,164.13 111.40 -3,502.88 6,013,90239 514,543.39 10.42 1,01422 MWD(3) € 8,135.36 94.24 341.73 6,229.20 6,162.20 139.64 -3,512.98 6,013,930.60 514,533.22 10.06 1,044.11 MWD(3) 1 I 8,165.33 91.78 345.22 6,227.62 6,160.62 168.33 -3,521.49 6,013,959.26 514,524.64 14.23 1,074.02 MWD(3) 3 8,200.55 93.50 349.11 6,226.00 6,159.00 202.62 -3,529.31 6,013,993.54 514,516.75 12.07 1,109.17 MWD(3) 8,230.53 93.01 352.63 6,224.30 6,157.30 232.17 -3,534.05 6,014,023.07 514,511.93 11.84 1,138.94 MWD(3) a, 8,260.62 9282 355.41 6,222.77 6,155.77 262.06 -3,537.18 6,014,052.94 514,508.72 9.25 1,16862 MWD(3) @I 8,290.63 91.17 357.42 6,221.72 6,154.72 291.99 -3,539.06 6,014,082.87 514,506.78 8.66 1,198.01 MWD(3) $ 8,320.60 90.86 359.43 6,221.19 6,154.19 321.94 -3,539.88 6,014,11281 514,505.88 6.78 1,227.16 MWD(3) t 8,350.44 90.68 359.82 6,220.79 6,153.79 351.77 -3,540.08 6,014,142.65 514,505.61 1.44 1,25603 MWD(3) 6,380.46 9163 3.18 6,220.18 6,153.18 381.77 -3,539.30 6,014,172.65 514,506.32 11.56 1,284.80 MWD(3) 8,410.50 9246 6.57 6,219.11 6,152.11 411.68 -3,536.75 6,014,202.56 514,508.79 11.68 1,313.03 MWD(3) 8,440.20 91.78 9.64 6,218.01 6,151.01 441.06 -3,53257 6,014,231.94 514,51291 10.58 1,340.33 MWD(3) 8,470.31 91.78 11.98 6,217 08 6,150.08 470.62 -3,52692 6,014,261.51 s 514,518.48 7.77 1,367.42 MWD(3) 8,500.16 9230 9.30 6,216.02 6,149.02 499.94 -3,521.42 6,014,290.84 514,523.91 9.14 1,394.31 MWD(3) 21102016 11:27:56AM Pape 3 COMPASS 5000.1 Build 74 le • • ConocoPhillips With ConocoPhillips Definitive Survey Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Coordinate Reference: Well 3N-05 Project: Kuparuk River Unit TVD Reference: 3N-05©67.00usft(3N-05) Site: Kuparuk 3N Pad MD Reference: 3N-05 @ 67.Oousft(3N-05) Well: 3N-05 North Reference: True Wellbore: 3N-05L1 Survey Calculation Method: Minimum Curvature Design: 3N-05L1 Database: EDM Alaska NSK Sandbox Survey ,. Map Map Vertical MD Inc Azi TVD NVDSS +N/-5 +El-W DLS (usft) (°) (°) (usftj ) (usft) Northing Easting (' ) Section Survey Tool Name Annotation ,. _.:,, { tusft 11 In! noo' (ft) ' 8,53024 92.33 545 6,214.80 6,147.80 529.74 -3,517.56 6,014,320.65 514,527.70 1279 1,422.10 MWD(3) I8,56028 92.83 2.31 6,213.45 6,14645 55967 -3,515.53 6,014,350 59 514,529.66 10.57 1,450.49 MWD(3) dg 8,590.63 90.15 357.98 6,212.66 6,14566 590.00 -3,515.45 6,014,380.91 514,529.66 16.77 1,479.77 MWD(3) ) 9 8,620.58 9206 356.40 6,212.08 6,145.08 619.91 -3,516.92 6,014410.81 514,528.12 8.28 1,509.03 MWD(3) ##'# 8,650.26 93.29 355.03 6,210.69 6,143.69 649.47 -3,519.14 6,014,440.37 514,525.83 6.20 1,538.16 MWD(3) q 8,680.14 92.49 350.83 6,209.19 6,14219 679.08 -3,522.81 6,014,469.96 514,522.09 14.29 1,567.71 MWD(3) 8,710.18 91.50 347.07 1208.14 6,141.14 708.54 -3,528.56 6,014,499.41 514,516.26 1294 1,59766 MWD(3) 8,740.13 90.74 343.96 6,207.56 6,140.56 737.53 -3,536.05 6,014,528.37 514,508.71 10.69 1,627.60 MWD(3) 8,770.28 89.54 340.35 6207.48 6,140.48 766.22 -3,545.29 6,014,557.04 514,49940 12.62 1657.70 MWD(3) 8,800.23 89.85 337.70 6,207.64 6,140.64 794.19 -3,556.01 6,014,584.98 51A 488.61 8.91 1687 49 MWD(3) 8,830.34 89.94 335.13 6,207.70 6,140.70 821.78 -3,568.05 6,014,612.54 514,476.50 8.54 1,717.26 MWD(3) 8,860.12 90.25 332.94 6,207.65 6,140.65 848.55 -3,581.09 6,014,639.27 514,463.40 7.43 1,746.49 MWD(3) 8,890.20 88.80 336.19 1207.90 6,140.90 875.71 -3,594.01 6,014,666.40 514,450.42 11.83 1,776.07 MWD(3) I 8,920.21 89.69 339.33 6,208.29 6,14129 903.48 -3,605.36 6,014,694.14 514,439.00 10.87 1,805.83 MWD(3) 8,950.20 89.91 34290 1208.40 6,141.40 931.85 -3,61507 6,014,722.48 514,429.23 11.93 1,835.75 MWD(3) 8,980.32 90.43 34600 1208.31 6,141.31 960.87 -3,623.14 6,014,751.48 514,421.08 10.44 1665.86 MWD(3) 9,010.24 90.80 347.62 6,207.99 6,140.99 989.99 -3,629.97 6,014,780.58 514414.19 5.55 1195.77 MWD(3) 9,040.11 89.17 34929 1207.99 6,140.99 1,019.26 -3,63595 6,014,809.83 514,408.14 7.81 1,925.58 MWD(3) 9,070.34 89.48 35251 1208.35 6,141.35 1,049.10 -3,640.73 6,014,839.66 514,403.29 10.70 1955.64 MWD(3) x 9,100.43 90.00 355.48 6,208.49 6,141.49 1,079.02 -3,643.87 6,014,869.57 514,400.07 10.02 1,985.36 MWD(3) 2 9,130.13 8939 358.09 6,208.65 6,141.65 1,108.67 -3,64554 6,014,899.21 .514,398.33 9.02 2,014.43 MWD(3) ) 9,160.04 89.72 358.93 6,208.88 6,141.88 1,138.57 -3,646.32 6,014929.11 514,397.48 3.02 2043.51 MWD(3) 9,190.15 92.95 358.13 6,208.18 6,141.18 1,168.66 -3,647.09 6,014,959.19 514,396.63 11.05 207277 MWD(3) 9,220.22 96.30 357.80 6,205.75 6,138.75 1,198.61 -3,648.15 6,014,989.13 514,395.50 11.19 2,101.98 MWD(3) 9,250.32 100.24 357.09 6,201.42 6,134.42 1,228.36 -3,649.48 6,015,018.88 514,394.10 13.30 2,131.06 MWD(3) 9,280.31 100.34 354.14 6,196.06 6,129.06 1,257.78 -3,651.74 6,011048.29 514,391.77 968 2160.06 MWD(3) 9,310.18 101.09 351.56 6,190.51 6,123.51 1,286.90 -3,65539 6,011077.39 514,388.05 8.85 2,189.13 MWD(3) , 9,340.27 100.49 349.15 6184.88 6,117.88 1,316.03 -3,660.34 6,015,106.52 514,383.03 8.12 2218.56 MWD(3) 9,370.32 100.56 345.70 1179.39 6,112.39 1,344.86 -3,666.77 6,015,135.33 514376.53 11.29 2248.07 MWD(3) 9,400.29 100.37 343.66 6,173.94 6,106.94 1,373.29 -3,674.56 6,011163.73 514368.67 6.72 2,277.54 MWD(3) 9,430.34 99.41 340.19 6,168.78 1101.78 1,401.42 -3,683.74 6,011191.84 514359.42 11.82 2,307.09 MWD(3) 2/102016 11:27:56AM Page 4 COMPASS 5000.1 Build 74 0 S ConocoPhillips r1iT11 ConocoPhillips Definitive Survey Report B ICEHUGHES Company: ConocoPhillips(Alaska)Inc.-Ku p2 Local Co-ordinate Reference: Well 3N-05 Project:.. Kuparuk River Unit ND Reference: 3N-05 5 67.00usft(3N-05) Site: Kuparuk 3N Pad MD Reference: 3N-051567.O0usft(3N-05) Well: 3N-05 North Reference: True Wellbore: 3N-05L1 Survey Calculation Method: Minimum Curvature Design: 3N-05L1 Database: EDM Alaska NSK Sandbox Survey Map Map - Vertical MD Inc Azi ND TVDSS +N1-S +E/-W DLS Northing Easting Section Survey Tool Name Annotation ( (usft) (°) (°) (usft) {usft) (usftj {usft) lhl 1111 (°1100') (ft) 9,460.33 98.72 338.18 6164 05 6,097.D5 1,429.10 -3,694.27 6,015,219 49 514,348.83 7.01 2,336.56 MWD(3) ?. 9,490.12 97.29 334.66 6,159.90 6,092 90 1,456.14 -3,706.07 6,015,246.49 514,336.97 12.65 2,365.72 MWD(3) 1 9,520.40 9776 332.05 6,155.94 6,088.94 1,482.96 -3,719.53 6,015,273.29 514,323.44 8.69 2,395.12 MWD(3) 9,550.66 97.76 329.82 6,151.85 6,084.85 1,509.17 -3,734.09 6,015,299.45 514,308.82 7.30 2424.20 MWD(3) t 9,580.48 98.13 328.54 6,147.73 6,080.73 1,534.53 -3,749.22 6,015,324.78 514,293.63 4.43 245261 MWD(3) 9,617.56 95.04 327.56 6,143.48 6,076.48 1,565.78 -3,768.71 6,015,355.98 514,274.06 8.74 2,487.85 MWD(3) 9,657.00 95.04 327.56 8,140.01 6,073.01 1,598.94 -3,789.79 6,015,389.08 514,252.91 0.00 2525.33 PROJECTED to TD 2/10/2016 11:27:56AM Page 5 COMPASS 5000.1 Build 74 • 215228 ram �, 26 860 BAKER FEB 2 6 2016 PRINT DISTRIBUTION LIST HUGHES _ sign and return one copy of this transmittal form to: �� COMPANY Cbid'6c lilEl PAlaska,Inc. ConocoPhillips Alaska,Inc. Ricky Elgarico.ATO 3-334. DATA LOGGED /"S/201�g WELL NAME 3N-05L1-03 700 G Street. M.K.BENDER Anchorage,Alaska 99510 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE GR-RES BHI DISTRICT Alaska --- LOG DATE February 2,2016 AUTHORIZED BY Patrick Rider EMAIL Patrick.Rider(c�bakerhuohes.com TODAYS DATE February 25,2016 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 IS #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. I 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 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 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 coCD • • N L0 co (N U7 ‘O N 1111 W Mill N_ `W; g zQ I c CZ 0 Q Cn CU w W X r a N z •_ - Cl) 7 M Cl! > Z r- _ ..Y. 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Z CZ. 0 • N • • RECEIVED • FEB 1 2 2016 Letter of Transmittal AOGCC FARC BAKER Date: DATA LOGGED February 11, 2016 7-f J2014 HUGHES M 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): 3N-05L1PB1 21 5 2 2 5 2 6 8 1 5 3N-05L1 215225 26814 3N-05L1-03 2 1 5 2 2 8 2 6 8 1 6 (3) Total prints 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. Michael Soper, Baker Hughes, Project Engineer Michael.Soper@BakerHughes.com Yosha Ragbirsingh, Baker Hughes, Survey Manager Yosha.Ragbirsingh@BakerHughes.com CO • • N u, Nv... ' L[) CO EdO pi s, cti C%4W Ci ill Z41 II 0 07 Or gmo 4741 4TN O. 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S 0 Y Y co M co °.- o°Ji rn rn rn ca m rn S� Q. to Lo0 U U) v( O CO CO CD o N Q0 0 0 0 Ci r; r; r O cc V O iiii C d V m of of ai a,- of Qi TO Li 7 i `13 m N y 7 .- a 0 • SOF 714, 7,�s THE STATE • • Alaska Oil and Gas ofALASKA Conservation Commission _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O4'ALAS/1°' Fax: 907.276.7542 www.aogcc.alaska.gov D. Venhaus CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 3N-05L1-03 ConocoPhillips Alaska, Inc. Permit to Drill Number: 215-228 Surface Location: 1562' FSL, 354' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 2620' FSL, 4161' FEL, SEC. 29, T13N, R9E, UM Dear Mr. Venhaus: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well Permit No. 186-026, API No. 50-029- 21537-00-00. Production should continue to be reported as a function of the original API number stated above. 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, Cathy '. Foerster Chair DATED this eLday of January, 2016. RECEIVED • STATE OF ALASKA . DEC 2 3 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ®� 20 AAC 25.005 CC 1a.Type of Work: 1h.Proposed Well Class: Exploratory-Gas ❑ Service- WAG E, Service-Dis ❑ 1c.Specify if well is proposed for: Drill ❑ Lateral, 0 Stratigraphic Test ❑ Development-Oil ❑ Service- Winj ❑ Single Zone Q' Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory-Oil ❑ Development-Gas E Service-Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well❑filis11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. #sess-26-E 395,ZI$O KRU 3N-05L1-03 , 3.Address: 6. Proposed Depth: 12.Field/Pool(s): PO Box 100360 Anchorage,AK 99510-0360 MD: 9160' . TVD: 6172' . Kuparuk River Field/• 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Kuparuk Oil Pool • Surface: 1562'FSL,354'FEL,Sec.29,T13N,R9E,UM ` ADL 25521 • Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 1175 FSL,3358'FEL,Sec.29,T13N, R9E,UM ALK 2557 1/14/2016 Total Depth: 9.Acres in Property: / :31,b 14.Distance to Nearest Property: 2620'FSL,4161'FEL,Sec.29,T13N, R9E,UM , 2,5i .2SS-� 12072' 4b. Location of Well(State Base Plane Coordinates-NAD 27). 10. KB Elevation above MSL(ft): • 67' 15.Distance to Nearest Well Open Surface:x- 518046 y- 6013799 Zone- 4. GL Elevation above MSL(ft): ,38' to Same Pool: 3N-04, 1556' 16. Deviated wells: Kickoff depth: . 7600' feet 17.Maximum Potential Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 96° degrees Downhole: 4577 psig • Surface: 3957 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2.375" 4.6# L-80 STL 1846' 7314' 6127' 9160' 6172' 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): 7595' 6402' None 7482' 6318' None Casing Length Size Cement Volume MD TVD Conductor/Structural 115' 16" 232 sx CS II 115' 115' Surface 3764' 9-5/8" 1070 sx PF"E"&290 sx Class G 3764' 3599' Production 7569' 7" 300 sx Class G 7569' 6384' Perforation Depth MD(ft): 7299'-7392' Perforation Depth TVD(ft): 6183'-6231' 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 MC 25.050 requirem s❑✓ 21. Verbal Approval: Commission Representative: Date/L-J,//S" 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 D.Venha j Title CTD Engineering Supervisor Signature c � � 7 Phone 263-4372 Date /2-z/-5- Commission Z/-5- Commission Use Only Permit to DrillAPI Number: Permit Approval See cover letter for other / v { 'O 4' Number: J50-oa9 p2/537—43 Date: 114 1,4) 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:/36 p 1- , - fa 4 3 7 p5 f ci 1Samples req'd: Yes No L ' Mud log req'd:Yes Li] No[' ,41-Irt vl a rC vft-+frr' f S/ n Z,,12c)p 2 measures: Yes No Directional svy req'd:Yes[' No fq ft W 1 frl t 55-rd ✓Vl L ,T- j 4. Spacing exception req'd: Yes❑ Noll Inclination-only svy req'd:Yes❑ No Post initial injection MIT req'd:Yes❑ No❑ IC vl`ced affifr S1-4 b1 iikd l,4,J7c fig -, U47 APPROVED BY _//Approved by: �/ �-r-�� COMMISSIONER THE COMMISSION Date:/ (p LibVT '/T li' i4 0,10/' `Zz/yel& Submit Form and Form 10-401(Revised 11/2015) This permit is valid for 24 mntm the date of approval(20 AAC 25.005(g)) Attachments in Duplicate ORIGINAL • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 22, 2015 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad-lateral out of the KRU 3N-05 using the coiled tubing drilling rig, Nabors CDR2-AC. The work is scheduled to begin mid-January, 2016. The CTD objective will be to drill four laterals (3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03), targeting the Kuparuk A-sand intervals. Note the current A sand perforations will be open below the whipstock. Attached to this application are the following documents: — Permit to Drill Application Forms (10-401)for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 — Detailed Summary of Operations — Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, &3N-05L1-03 — Current wellbore schematic — Proposed wellbore schematic If you have any questions or require additional information please contact me at 907-263-4321. Sincerely, Keith Herring Coiled Tubing Drilling Engineer ! ! Kuparuk CTD Laterals NAflQR xa 0'0 .1 3N-05L1, L1-01, L1-02, & L1-03 Cly eM 2nt CogxwaafIrDiips Application for Permit to Drill Document 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 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 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Attachments 8 Attachment 1: Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, &3N-05L1-03 8 Attachment 2: Current Well Schematic for 3N-05 8 Attachment 3: Proposed Well Schematic for 3N-05L1, 3N-05L1-01, 3N-05L1-02, &3N-05L1-03 8 Page 1 of 8 December 18, 2015 4110 • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 1. Well Name and Classification (Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b)) The proposed laterals described in this document are 3N-05L1, L1-01, L1-02, & L1-03. All laterals will be classified as "Service—WAG"wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the A sand package in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of the 3N-05L1, L1-01, L1-02, & L1-03. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4300 psi. Using the maximum formation pressure in the area of 4577 psi in 3M-13 (i.e. 14.2 ppg EMW), the maximum potential surface pressure in 3N-05, assuming a gas gradient of 0.1 psi/ft, would be 3957 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 3N-05 was measured to be 4041 psi (12.5 ppg EMW) on 11/09/2015. However the pressure is expected to decline to 11.5 ppg by the spud date. The maximum downhole pressure in the 3N- 05 vicinity is to the northwest in the 3M-13 producer at 4577 psi (14.2 ppg EMW) measured in November 2015. The lowest downhole pressure in the 3N-05 vicinity is to the north in the 3Q-22 producer at 2063 psi (6.4 ppg EMW) measure in February 2015. Due to the 3M-13 and 3Q-22 wells' being offset that high pressure is not expected during operations of drilling the 3N-05 laterals. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) None of the offset injection wells to 3N-05 have ever injected gas, so there is a low probability of encountering free gas while drilling the 3N-05 laterals. 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 in the 3N-05 laterals will be shale instability at large fault crossings. Managed pressure drilling (MPD)will be used to reduce the risk of shale instability associated with the fault crossing. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 3N-05 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 8 December 18, 2015 111 PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 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 2%", 4.7#, L-80, ST-L slotted liner; 3N-05L1 10070' 11600' 6180' 6245' openhole anchored aluminum billet on top 2%", 4.7#, L-80, ST-L slotted liner; 3N-05L1-01 9925' 11585' 6174' 6252' openhole anchored aluminum billet on top 23/8", 4.7#, L-80, ST-L slotted liner; 3N-05L1-02 7600' 11095' 6159' 6172' openhole anchored aluminum billet on top 3N-05L1-03 7314' 9160' 6127' 6172' 2%", 4.7#, L-80, ST-L slotted liner; deployment sleeve on top 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 38' 115' 0' 115' 1640 630 Surface 9-5/8" 36.0 J-55 BTC 37' 3764' 0' 3599' 3520 2020 Production 7" 26.0 J-55 BTC 35' 7569' 0' 6384' 4980 4330 Tubing 3-1/2" 9.3 L-80 EUE 8rd 33' 7239' 0' 6138' 10160 _ 10530 Tubing Tail 5-1/2" 14.0 J-55 STC 7239' 7327' 6138' 6204' 4270 3120 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 AA C 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 mud (9.5 ppg) — Drilling operations: Chloride-based FloVis mud (9.3 ppg)! This mud weight will not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: The 3N-05 contains a downhole deployment valve allowing deployment of tool strings and liner without pumping kill weight fluid. If the valve does not hold, BHA's will be deployed using standard pressure deployments and the well will be loaded with 11.8 ppg NaBr completion fluid in order to provide formation over-balance and maintain wellbore stability while running completions. 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 Page 3 of 8 December 18, 2015 ! ! PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 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 3N-05 laterals we will target a constant BHP of 11.8 ppg EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 3N-05 Window(7319' MD, 6198' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A-sand Formation Pressure(11.5ppg) 3706 psi 3706 psi Mud Hydrostatic(9.3 ppg) 2997 psi 2997 psi Annular friction (i.e. ECD, 0.080 psi/ft) 586 psi 0 psi Mud + ECD Combined 3583 psi 2997 psi (no choke pressure) (underbalanced (underbalanced —124 psi) —709 psi) Target BHP at Window(11.8 ppg) 3803 psi 3803 psi Choke Pressure Required to Maintain Target BHP 220 psi 806 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Well KRU 3N-05 is a Kuparuk A-sand injection well equipped with 3'/2"tubing and 5 '/z"big tail pipe completion. Four laterals will be drilled to the northwest of the parent well with the laterals targeting the Al, A2 and A3 sands. A thru-tubing whip-stock will be set pre-rig inside the 5'/2"tail pipe at the planned kickoff point of 7319' MD to drill all four laterals. Page 4 of 8 December 18, 2015 III • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. The 3N-05L1 lateral will exit through the 51/2"tail pipe and 7"casing at 7319' MD and TD at 11600' MD, targeting the A2 sand. It will be completed with 2%"slotted liner from TD up to 10070' MD with an openhole anchored aluminum billet for kicking off the 3N-05L1-01 lateral. The 3N-05L1-01 lateral will drill northwest to a TD of 11585' MD targeting the Al sand. It will be completed with 2%"slotted liner from TD up to 9925' MD with an openhole anchored aluminum billet for kicking off the 3N-05L1-02 lateral. The 3N-05L1-02 lateral will drill northwest to a TD of 11095' MD targeting the A3 sand. It will be completed with 2%"slotted liner from TD up to 7600' MD with an openhole anchored aluminum billet for kicking off the 3N-05L1-03 lateral. The 3N-05L1-03 lateral will drill northwest to a TD of 9160' MD targeting the Al sand. It will be completed with 2%"slotted liner from TD up to 7314' MD with a deployment sleeve back into the 5 1/2"tail pipe. Pre-CTD Work 1. RU Slickline: Dummy all gas lift valves and obtain an A-sand SBHP, drift a dummy whip-stock to TD. 2. RU E-line: Set Baker Hughes 31/2"x 51/2"thru-tubing whip-stock at 7319' MD 3. Perform injection test 4. Pump degradable plug for temporary parent bore isolation 5. Prep site for Nabors CDR2-AC, including setting BPV. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3N-05L1 Lateral(A2 sand northwest) a. Mill 2.80"window at 7319' MD. b. Drill 3"bi-center lateral to TD of 11600' MD. c. Run 2%"slotted liner with an openhole anchored aluminum billet from TD up to 10070' MD. 3. 3N-05L1-01 Lateral(Al sand northwest) a. Kick off of the openhole anchored aluminum billet at 10070' MD. b. Drill 3"bi-center lateral to TD of 11585' MD. c. Run 2%"slotted liner from TD up to 9925' MD. 4. 3N-05L1-02 Lateral(A3 sand northwest) a. Kick off of the openhole anchored aluminum billet at 9925' MD. b. Drill 3"bi-center lateral to TD of 11095' MD. c. Run 2%"slotted liner from TD up to 7600' MD. 5. 3N-05L1-03 Lateral(Al sand northwest) a. Kick off of the openhole anchored aluminum billet at 7600' MD. b. Drill 3"bi-center lateral to TD of 9160' MD. c. Run 2%"slotted liner from TD back into the 5 1/2"tail pipe at 7314' MD. 6. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Page 5 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. Post-Rig Work 1. Pull BPV. 2. Pre-produce for less than 30 days 3. Return to injection. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this well is a deployment valve. This valve, when closed using hydraulic control lines from surface, isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well. If the deployment valve fails, operations will continue using the standard pressure deployment process. A system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slick-line lubricator can be used. This pressure control equipment listed ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse Liner Running — The 3N-05 well has a deployment valve installed. It will serve to deploy liners into the newly drilled laterals. If the valve fails the laterals 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 2%" rams will provide secondary well control while running 2%" 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 (1 R-18 or 1B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). Page 6 of 8 December 18, 2015 • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. — Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name' Distance 3N-05L1 9863' 3N-05L1-01 9870' 3N-05L1-02 10355' 3N-05L1-03 12072' — Distance to Nearest Well within Pool Lateral Name DistanceWell 3N-05L1 3N-04 932' 3N-05L1-01 3N-04 1000' 3N-05L1-02 3N-04 993' 3N-05L1-03 3N-04 1556' 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) There is one well within %4-mile of the 3N-05L1, L1-01, L1-02, and L1-03 laterals 3N-05 (mother bore) Injector • Classified as a"Normal Well" • The well is completed with 3.5" 9.3#L-80 tubing and 7" 26#J-55 production casing. • Packer located at 7106' MD which is located less than 200'from the top of the perforations. • A-sand perforations: A3: 7299' -7314' MD, A2: 7309' -7342' MD, and Al: 7364' -7392' MD • Well was recently worked over on 10-18-15, new tubing was run and a down hole deployment valve was installed. • Production casing was cemented with 300 sx of Class"G" cement. The proposed kick off point for the CTD sidetrack is in the A-sand perforations and should not compromise existing conformance. 3N-04(Injector), —932' away from 3N-05L1, L1-01, L1-02, & L1-03 lateral to the east • 3N-04 is currently injecting water into the Kuparuk A, C, and Unit B sand intervals. • Classified as a"Normal Well" • Well is completed with 2.875"6.5#L-80 tubing and 7"26#J-55 production casing. • Packers located at 7383' and 7439' MD the lowest most which is located less than 200' from the top of the perforations. • A, C, Unit B perforations: C4/Unit B: 7574' -7584' MD, A3: 7612' -7622' MD, A2: 7625' -7632' MD, and Al: 7639' -7645' MD • Production casing was cemented with 350 sx Class `G' and 175 sx PF 'C' Page 7 of 8 December 18, 2015 • • PTD Application: 3N-05L1, L1-01, L1-02 & L1-03. 17. Attachments Attachment 1: Directional Plans for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Attachment 2: Current Well Schematic for 3N-05 Attachment 3: Proposed Well Schematic for 3N-05L1, 3N-05L1-01, 3N-05L1-02, & 3N-05L1-03 Page 8 of 8 December 18, 2015 410 S MI W Ill Z G h111011771,171trirm,11 I � amu n -0 _ -- II V R� - T . 1-' j �- :: '-1.-,, it o d ','L;;,-1 -3 _ r - a �r A z L tc mon2 :Q ':aw : � IO w 3 vi .``� ;v:_ T . , - __ ,±-4-i-,-S-„- _./l _.. �a V-1 =,ids pi, '�'�s 7 o ,,••.'. cr LL reaza.g` �-- .moo � LcV m � o To - a,,° ) z z, T A> i ,.. _ o l �, 04 -0 -1/ G.r.. Z'-r.T'yY � zzQ7z _ z y f z o0 0 6 '�'ar. _ z o m �o } 1, _- M r z J `r '' I o W _C _ T, z �,� moo` c s ,- r. )0 z �,-. 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W , N , , v q , ,O 1� Qr • • ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-05 3N-05L1-03 Plan: 3N-05L1-03_wp01 Standard Planning Report 10 December, 2015 BAKER HUGHES • • ConocoPhillips .S`, ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3N-05 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-05 @ 67.00usft(3N-05) Site: Kuparuk 3N Pad North Reference: True Well: 3N-05 Survey Calculation Method: Minimum Curvature Wellbore: 3N-05L1-03 Design: 3N-05L1-03_wp01 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 3N Pad Site Position: Northing: 6,013,799.17 usft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19usft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.14 ° Well 3N-05 Well Position +N/-S 0.00 usft Northing: 6,013,799.48 usft Latitude: 70°26'55.957 N +E/-W 0.00 usft Easting: 518,046.18 usft Longitude: 149°51'10.002 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 33.70 usft Wellbore 3N-05L1-03 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 3/1/2016 18.52 81.03 57,493 Design 3N-05L1-03_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,600.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) -33.70 0.00 0.00 345.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (usft) (0) (0) (usft) (usft) (usft) (°/100ft) (°/100ft) (°/100ft) (°) Target 7,600.00 93.92 315.07 6,159.23 -336.39 -3,248.58 0.00 0.00 0.00 0.00 7,765.00 82.37 315.07 6,164.56 -219.84 -3,364.86 7.00 -7.00 0.00 180.00 7,865.00 89.37 315.07 6,171.76 -149.27 -3,435.25 7.00 7.00 0.00 0.00 8,065.00 89.15 329.07 6,174.37 8.08 -3,557.88 7.00 -0.11 7.00 91.00 8,265.00 90.62 342.99 6,174.78 190.37 -3,638.93 7.00 0.74 6.96 84.00 8,545.00 95.57 1.99 6,159.54 466.19 -3,675.39 7.00 1.77 6.79 75.00 8,745.00 88.49 349.89 6,152.43 665.07 -3,689.55 7.00 -3.54 -6.05 240.00 8,945.00 87.33 335.93 6,159.75 855.64 -3,748.12 7.00 -0.58 -6.98 265.00 9,160.00 86.13 350.96 6,172.09 1,060.79 -3,809.12 7.00 -0.56 6.99 95.00 12/10/2015 10:51:33AM Page 2 COMPASS 5000.1 Build 74 • ConocoPhillips • FIRS ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3N-05 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-05 @ 67.00usft(3N-05) Site: Kuparuk 3N Pad North Reference: True Well: 3N-05 Survey Calculation Method: Minimum Curvature Wellbore: 3N-05L1-03 Design: 3 N-05L 1-03_wp01 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (usft) (0) (0) (usft) (usft) (usft) (usft) (°/100ft) (0) (usft) (usft) 7,600.00 93.92 315.07 6,159.23 -336.39 -3,248.58 515.87 0.00 0.00 6,013,455.26 514,798.75 TIP/KOP 7,700.00 86.92 315.07 6,158.50 -265.64 -3,319.16 602.47 7.00 -180.00 6,013,525.83 514,728.00 7,765.00 82.37 315.07 6,164.56 -219.84 -3,364.86 658.54 7.00 -180.00 6,013,571.52 514,682.20 Start 7 dls 7,800.00 84.82 315.07 6,168.47 -195.21 -3,389.42 688.68 7.00 0.00 6,013,596.08 514,657.58 7,865.00 89.37 315.07 6,171.76 -149.27 -3,435.25 744.93 7.00 0.00 6,013,641.91 514,611.64 3 7,900.00 89.33 317.52 6,172.16 -123.97 -3,459.43 775.62 7.00 91.00 6,013,667.15 514,587.40 8,000.00 89.21 324.52 6,173.44 -46.29 -3,522.30 866.93 7.00 90.97 6,013,744.67 514,524.36 8,065.00 89.15 329.07 6,174.37 8.08 -3,557.88 928.65 7.00 90.88 6,013,798.94 514,488.65 4 8,100.00 89.40 331.51 6,174.81 38.47 -3,575.23 962.50 7.00 84.00 6,013,829.29 514,471.23 8,200.00 90.14 338.47 6,175.21 129.03 -3,617.48 1,060.91 7.00 83.97 6,013,919.74 514,428.76 8,265.00 90.62 342.99 6,174.78 190.37 -3,638.93 1,125.71 7.00 83.94 6,013,981.02 514,407.16 5 8,300.00 91.25 345.36 6,174.21 224.04 -3,648.47 1,160.70 7.00 75.00 6,014,014.66 514,397.54 8,400.00 93.05 352.13 6,170.45 321.99 -3,667.97 1,260.36 7.00 75.04 6,014,112.55 514,377.81 8,500.00 94.80 358.92 6,163.60 421.39 -3,675.75 1,358.38 7.00 75.29 6,014,211.92 514,369.79 8,545.00 95.57 1.99 6,159.54 466.19 -3,675.39 1,401.57 7.00 75.76 6,014,256.73 514,370.03 6 8,600.00 93.63 358.65 6,155.13 521.01 -3,675.09 1,454.44 7.00 -120.00 6,014,311.53 514,370.21 8,700.00 90.09 352.61 6,151.87 620.60 -3,682.71 1,552.61 7.00 -120.27 6,014,411.10 514,362.35 8,745.00 88.49 349.89 6,152.43 665.07 -3,689.55 1,597.33 7.00 -120.46 6,014,455.55 514,355.40 7 8,800.00 88.16 346.06 6,154.03 718.83 -3,701.00 1,652.22 7.00 -95.00 6,014,509.27 514,343.82 8,900.00 87.58 339.07 6,157.75 814.11 -3,730.92 1,752.00 7.00 -94.89 6,014,604.47 514,313.67 8,945.00 87.33 335.93 6,159.75 855.64 -3,748.12 1,796.57 7.00 -94.63 6,014,645.95 514,296.37 8 9,000.00 87.00 339.77 6,162.47 906.51 -3,768.83 1,851.06 7.00 95.00 6,014,696.77 514,275.54 9,100.00 86.44 346.76 6,168.20 1,002.05 -3,797.56 1,950.79 7.00 94.81 6,014,792.24 514,246.59 9,160.00 86.13 350.96 6,172.09 1,060.79 -3,809.12 2,010.52 7.00 94.41 6,014,850.94 514,234.88 Planned TD at 9160.00 12/10/2015 10:51:33AM Page 3 COMPASS 5000.1 Build 74 ,�- • ConocoPhillips • FAIN ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3N-05 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-05 @ 67.00usft(3N-05) Site: Kuparuk 3N Pad North Reference: True Well: 3N-05 Survey Calculation Method: Minimum Curvature Wellbore: 3N-05L1-03 Design: 3 N-05 L1-03_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +El-W Northing Easting -Shape (0) (0) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 3N-05L1-03_T03 0.00 0.00 6,152.00 620.85 -3,682.83 6,014,411.34 514,362.23 70°27'2.054 N 149°52'58.161 W -plan misses target center by 0.16usft at 8700.26usft MD(6151.87 TVD,620.86 N,-3682.74 E) -Point 3N-05L1-03_T04 0.00 0.00 6,172.00 -1,947.921,136,332.65 6,014,603.00 1,654,267.00 70°12'31.106 N 140°39'40.449 W -plan misses target center by 1139582.37usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05 CTD Polygon 0.00 0.00 0.00 -3,381.501,137,338.28 6,013,172.00 1,655,276.00 70°12'15.702 N 140°39'17.896 W -plan misses target center by 1140607.56usft at 7600.O0usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Polygon Point 1 0.00 0.00 0.00 6,013,172.00 1,655,276.00 Point2 0.00 -185.28 -310.47 6,012,985.99 1,654,966.01 Point 3 0.00 64.37 -995.95 6,013,233.95 1,654,280.00 Point4 0.00 2,197.04 -1,608.96 6,015,364.92 1,653,661.89 Points 0.00 2,986.05 -2,848.22 6,016,150.85 1,652,420.84 Point6 0.00 3,958.12 -2,411.87 6,017,123.87 1,652,854.79 Point7 0.00 2,837.64 -989.38 6,016,006.95 1,654,279.85 Point 8 0.00 1,615.78 -679.24 6,014,785.97 1,654,592.92 Point9 0.00 0.00 0.00 6,013,172.00 1,655,276.00 3N-05L1_Fault3 0.00 0.00 0.00 -1,379.61 1,136,232.01 6,015,171.00 1,654,165.00 70°12'36.772 N 140°39'40.853 W -plan misses target center by 1139497.72usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05L1_Fault4 0.00 0.00 0.00 -305.961,135,592.55 6,016,243.00 1,653,523.00 70°12'48.141 N 140°39'54.493 W -plan misses target center by 1138857.79usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point • 3N-05L1_FaultlN 0.00 0.00 0.00 -3,163.071,136,756.75 6,013,389.00 1,654,694.00 70°12'18.682 N 140°39'33.600 W -plan misses target center by 1140025.47usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05L1_Fault1S 0.00 0.00 0.00 -3,400.861,137,074.21 6,013,152.00 1,655,012.00 70°12'15.904 N 140°39'25.544 W -plan misses target center by 1140343.54usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05L1-03_T02 0.00 0.00 6,174.00 -2,794.401,136,495.61 6,013,757.00 1,654,432.00 70°12'22.647 N 140°39'39.472 W -plan misses target center by 1139746.85usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05L1_Fault2 0.00 0.00 0.00 -1,933.921,136,332.68 6,014,617.00 1,654,267.00 70°12'31.242 N 140°39'40.387 W -plan misses target center by 1139599.03usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point 3N-05L1-03_T01 0.00 0.00 6,170.00 -3,186.021,136,734.69 6,013,366.00 1,654,672.00 70°12'18.492 N 140°39'34.332 W -plan misses target center by 1139986.84usft at 7600.00usft MD(6159.23 TVD,-336.39 N,-3248.58 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,160.00 6,172.09 2 3/8" 2.375 3.000 12/10/2015 10:51:33AM Page 4 COMPASS 5000.1 Build 74 • ConocoPhillips • Ira.. ConocoPhillips Planning Report BAKER HUGHES Database: EDM Alaska NSK Sandbox Local Co-ordinate Reference: Well 3N-05 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 3N-05 @ 67.00usft(3N-05) Site: Kuparuk 3N Pad North Reference: True Well: 3N-05 Survey Calculation Method: Minimum Curvature Wellbore: 3N-05L1-03 Design: 3N-05L1-03_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 7,600.00 6,159.23 -336.39 -3,248.58 TIP/KOP 7,765.00 6,164.56 -219.84 -3,364.86 Start 7 dls 7,865.00 6,171.76 -149.27 -3,435.25 3 8,065.00 6,174.37 8.08 -3,557.88 4 8,265.00 6,174.78 190.37 -3,638.93 5 8,545.00 6,159.54 466.19 -3,675.39 6 8,745.00 6,152.43 665.07 -3,689.55 7 8,945.00 6,159.75 855.64 -3,748.12 8 9,160.00 6,172.09 1,060.79 -3,809.12 Planned TD at 9160.00 • 12/10/2015 10:51:33AM Page 5 COMPASS 5000.1 Build 74 • ConocoPhillips • l I � rll ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 3N-05 Project: Kuparuk River Unit TVD Reference: 3N-05 @ 67.00usft(3N-05) Reference Site: Kuparuk 3N Pad MD Reference: 3N-05 @ 67.00usft(3N-05) Site Error: 0.00 usft North Reference: True Reference Well: 3N-05 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 3N-05L1-03 Database: EDM Alaska ANC Prod Reference Design: 3N-05L1-03_wp01 Offset TVD Reference: Offset Datum Reference 3N-05L1-03_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 7,600.00 to 9,160.00usft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,112.67 usft Error Surface: Elliptical Conic Survey Tool Program Date 12/10/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 100.00 7,310.00 3N-05(3N-05) GCT-MS Schlumberger GCT multishot 7,310.00 7,600.00 3N-05L1_wp02(3N-05L1) MWD MWD-Standard 7,600.00 9,160.00 3N-05L1-03_wp01 (3N-05L1-03) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 9,160 00 6,239.09 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 3N Pad 3N-04-3N-04-3N-04 Out of range 3N-05-3N-05L1-3N-05L1_wp03 7,651.47 7,650.00 13.09 1.24 12.02 Pass-Minor 1/10 3N-05-3N-05L1-01-3N-05L1-01_wp01 7,600.00 7,600.00 0.00 0.29 -0.22 FAIL-Minor 1/10 3N-05-3N-05L1-02-3N-05L1-02_wp01 7,600.00 7,600.00 0.00 0.29 -0.22 FAIL-Minor 1/10 3N-07-3N-07-3N-07 Out of range 3N-07-3N-07A-3N-07A Out of range 3N-07-3N-07AL1-3N-07AL1 Out of range 3N-07-3N-07AL1-01-3N-07AL1-01 Out of range 3N-07-3N-07AL1-02-3N-07AL1-02 Out of range 3N-07-3N-07AL1-03-3N-07AL1-03 Out of range 3N-07-3N-07AL2-3N-07AL2 Out of range 3N-07-3N-07AL2-01-3N-07AL2-01 Out of range 3N-07-3N-07AL2-02-3N-07AL2-02 Out of range 3N-07-3N-07AL2-03-3N-07AL2-03 Out of range 3N-09-3N-09-3N-09 Out of range 3N-11-3N-11-3N-11 Out of range 3N-11-3N-11A-3N-11A Out of range 3N-11-3N-11AL1-3N-11AL1 Out of range 3N-11-3N-11AL2-3N-11AL2 Out of range 3N-11-3N-11AL2-01-3N-11AL2-01 Out of range 3N-11-3N-11AL3-3N-11AL3 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 12/10/2015 10:03:10AM Page 2 COMPASS 5000.1 Build 74 • • 1o III N o s 1r�= § ;g _8 g_ s „ g o -K pa• V b , _ r. Q `� -$' K F 11 4 i`I z err'' :A4., :M 5 M 9 .8 z _$ 4 2 °• 4 e Com. X .Z, 8 4 I 4 Q °22 F 6 z .Zn . h / K e Z h 2E d z , / 3/," 1 .8 o g i 6 g x ,m 5 ai I -v �R] Z K H t-z. 'Ti iiiii v JI G., I r C r y Y Y °� ��10 j r 1� �' Y l'''' 2\ -g 7.1 , ,-5'r i Fi 4 4 - 3 z o, Hr jq r a VI' ZO7 m q F 7, m 8 a .73 z oa 8 0 w ~ o$ I ` 8 8 8 S h 8 0 g t o M M M m M z !1 0 v (uyusn OS£)(+)9uoN/(-)tonos m m 8a M 8 _R w - ' ,a• r O ppr U eN o M 0 $ c `. u V `Faa m x` 1I 8 0. U '22 �a a -No .4 0-a 1,01 LO-V1,0-NL--- .I1 8 't li m -c.0 a O d Z F. • J O� C0_ C, F; r r- MLO r-rM rN 2... £O7.£0-['I!0-N£--- 07tO I"CJ M u,In .. 01 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 'O Q O J tf] Ll 0 0 0.-0 rn O u)2 _ N .. z ' I-- O m N N 0 z0� £0->-s0-N£--- -. a M io C M Q 2 N 0000000000 0 N 0 0 0 0 O O O O O 2 2 q - 0o �r-I-N-N-N-r- - nng4Z Q Z 2AA,a7" �_gmN ao OM1 C+01 f3"" q cd Vui t: T au ai 0. Y o,� 0100 T V CO CO co M r...co V o v [� y 3 a i ."=".. - M 0M•1 M M c0,M M M M WI CO-MO-NE I _ 4 Gni E =q &i m g$ z 4 ' 3J J W 0 �rn v Ism r-rn r-zgrn .i y�., .'. , b Q co M OC?N Cr!M O 0 o ai ai es o<ri ui uio _ 'z W M N 7 ,-C c00 000 O ,, 0100 Og V.--V V ggg CV '� c �ul co r`�rul u'l ul r` of Ca,..c,m m m<n Q... -- rn Z C,"1 •r,,r f•N.N.01 07 01 M e0 ¢ 23 O OO rnrnm rnrn ,__._. o p -r-u'i 0)N O�00SO 0 O r mom 8O OMi aa1 52 a00 2`m m W _-y-__.._..._-__i.__._- 8 N V-r-u)N t`CO CO CO O l CO CO CO L 0 R M 1 O c,0 0 0 0 O O O O O M �O*1 LB 4 4 4 po .1 h h h h b b b O I S cO CO CO LB V,- .N 0^a00N rn 1O 01 vj to) � I�CO fO COCOaD Q1 0 CD o C O0 N CO V LO CO r�CO 0) o (uy$sn 0SI)tndoU ieoploA orui, V fix KUP INJ • 3N-05 Conor PI tiliips 'r ^ Weil Attributes Max Angle&MD TD A48ska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(MKB) crnocowJal� 500292153700 KUPARUK RIVER UNIT INJ 44.90 6,400.00 7,601.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 39-05,11/22/2015 3:36:27 PM SSSV:NONE Last WO: 10/17/2015 39.49 2/22/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ._. Last Tag SLM 7,452.0 10/25/2015 Rev Reason:GLV CIO pproven 11/22/2015 HANGER;32.7- x-., Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread orf1. 111•14 SURFACE 9 5/8 8.765 37.0 3,764.3 3,598.8 36.00 J-55 BTC ,1 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND) Wt/Len(L..Grade Top Thread PRODUCTION 7 6.276 35.0 7,569.1 6,383.8 26.00 J-55 BTC AiL.A./ J.,Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Iblft) Grade Top Connection TUBING-WO 2015 31/2 2.992 32.7 7,120.0 6,050.9 9.30 L-80 EUE 8rd CONDUCTOR;38.0-1150 .� UPPER COMPLETION Completion Details GAS LIFT',2.505 7 TNominal ID Top(ftKB) Top(ND)(ftKB) Top Ind(°) Item Des Com (in) 32.7 32.7 0.06 HANGER Tubing hanger 3.500 4,509.6- 4,150.8 42.50 QT Safety Baker Orbit valve 2.890 Valve 4500 7,097,8- 6,034.6' 42.84 XO Enlarging 3.5 EUE Box X 4.5 IBT pin 2.960 7,098.3 6,034.9 42.84 Locator Locater sub 2.960 SURFACE,37.0-3,764.3-.. ( 7,099.0 6,035.5 42.83 SEAL ASSY i Baker 80/40 seal assembly 21 ft 2.960 ii Tubing Description String Ma...ID(in) Top(ftKB) -Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2015- 31/2 2.992 7,106.1 7,327.2 6,203.9 9.30 L-80 EUE 8rd GAS LIFT;4,039.6 LOWER PACKER COMPLETION Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) OT Safety Valve;4,509 6 7,106.1 6,040.7 42.81 PACKER Baker F packer 5.380 7,109.4 6,043.1 42.79 SBE Seal bore ext.80-40 4.000 7,226.4 6,129.3 42.38 NIPPLE 3.5 X 2.812 X nipple,PXX PLUG PULLED 1025 15 2.812 7,239.2 6,138.7 42.35 Liner 5.5 X 14#J-55 W 6"wear soxs 5.000 GAS LIFT;5,318 6 - 7,282.9 6,171.0 42.24 Liner 5.5 X 14#J-55 W 6"wear soxs mule shoe 5.000 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f GAS LIFT;6 353 6 Top(ftKB) Bim(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,299.0 7,314.0 6,183.0 6,194.1 A-3,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJel;60 deg. ph 7,309.0 7,310.0 6,190.4 6,191.1 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph GAS LIFT 7,042.0 7,324.0 7,342.0 6,201.5 6,214.8 A-2,3N-05 6/28/1987 8.0 RPERF 2 1/8"EnerJel;60 deg. ph 7,334.0 7,335.0 6,208.9 6,209.7 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 deg.ph 7,337.0 7,342.0 6,211.1 6,214.8 A-2,3N-05 4/21/1986 1.0 IPERF 4"Csg Gun HJ II'90 00 Enlarging 17,097.9 deg.ph Locator',7,098. 7,364.0 7,392.0 6,231.2 6,252.0 A-1,3N-05 4/21/1986 4.0 IPERF 4"Csg Gun HJ II;90 deg.phase PACKER;7,106.1 ' ' Mandrel Inserts SEAL ASSY;7,099 0 Z. - St It ni SBE;7,109.4 a o N` Top(TVD) Valve Latch Port Size TRO Run XO Reducing(Tubi111 Top(ftKB) (ftKB) Make Madel OD(in) Sery Type Type (in) (psi) Run Date Com ng)7,12E.9 - 1 2,505.7 2,502.3 Cameo MMG 11/2 GAS LIFT GLV RK 0.188 1,348.0 10/10/2015 111 r: 2 4,039.6 3,804.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,307.0 10/10/2015 3 5,318.6 4,748.9 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,284.0 10/10/2015 4 6,353.6 5,499.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,264.0 10/10/2015 NIPPLE;7,226.4 1 i 5 7,042.0 5,993.8 Camco MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 10/25/2015 Notes:General&Safety X0 Enlarging(Tubing);7238.2 End Date Annotation 11/5/2010 NOTE:View Schematic w/Alaska Schematic9.0 Liner,7239.2 10/17/2015 NOTE:Orbit Valve is NOT a safety valve,it does not fail to closed position. 10/17/2015 NOTE:Orbit Valve Control lines/system at Wellhead marked Open/Close. Liner;7,282 8-, RPERF',7,299.0-7,314.0 IPERF,7,309.0-7,310.0- I I RPERF;7,324.0-7342 0 (PERF;7334.0-7,3350 IPERF',7,337.0-7342.0- (PERF;7,364.0-7392 0- PRODUCTION;35 0-7,569.1 • • Lrl ,5 �� 22 0 N _ o LOo LO� a) 0 N O O co N O N C� r O O co O r %i co p O co E O co m �� r� o0 = <p ` E rn o II m II m -- Y CD N Cr N U II a o0 m �, c'`) N 0 O N I-; ~s = 6 � cr) co W ami-a ami II .o O r is m� c3 c3 O- N a) ' U _ d' _ c._ mL- E m L U CN CO 't U h O U m �' c II O N <) O 0 m EiW �i•� oami oro m= O a) O LI) � p)if) o -J o \\\\ a O_ N 0 N co w co : o h o y \ , oa) O Co un- o \ \ C Vi O N N CO 0N. O Z\ Zm \\`\ o N .Q- �O m cv U Z M N CO N \\\\ \\ Z 0 as I— C "O Y N MN \�\ MN a E O C 0 - ' N 6- � III\ co w a0 = Yo N C Hm Ali Y / I .. c 2 a)� W cn � o -2 E a) cfl ' N 0 m r i 1 � 0 - Ov) O N ' N ..,,/ a) O 7 a co ' / / —/ O � U ti � a N- // 4t - N ECO 'E � 1.6 ai mai 0 X o X rn //. 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(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(0, 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 • • U To , Cl) 0) 0 O a , U) Cl) a) 0 U) c a: a) Q c a): Q 0 __: 3. 0 . 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