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215-180
P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1C-15550-029-23561-00-00215-18064"35.88"7/31/20251.78/7/2025 • • o O 0 rq O co V) o @ N @ N @ O O 0 O M O ce M z C . 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O co o C I pj • O H III m `- W E a 1 O I 3 N N W C N III d O. ai re O C "2 ! Z N d Lo E E ' p ce o ro o O o c 1 , C V N TA Z H c ~ co c t6 p N V O N V O) a N N •Z E d V` 0. 7 a V E 0 0 LL E 2 aoi 2 E co d 71) 8 E E d a 2 3 I Z 0 a 0 0 0 0 0 • • Guhl, Meredith D (DOA) From: Elgarico, Richard E <Richard.E.Elgarico@conocophillips.com> Sent: Thursday, May 19, 2016 10:59 AM To: Guhl, Meredith D (DOA); Lemke, Sandra D Subject: RE: KRU 1C-155, PTD 215-180, Logs Obtained? Meredith, We just received an update from Schlumberger and verified it with our Geologist. According to Schlumberger,there was no density/porosity tools in the BHA. This is what they ran for LWD on 1C-155: Surface:ARC/TeleScope (ARC provided GR/RES) Intermediate:ARC/Telescope (ARC provided GR/RES) Production: Periscope/IMPulse (Periscope provided GR/RES) Please let us know if you need anything else. Thanks, Ricky From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Friday, May 13, 2016 2:23 PM To: Lemke, Sandra D<Sandra.D.Lemke@conocophillips.com>; Elgarico, Richard E <Richard.E.Elgarico@conocophillips.com> Subject: [EXTERNAL]FW: KRU 1C-155, PTD 215-180, Logs Obtained? The message was returned to me, apparently Steve is no longer at ConocoPhillips. Could you direct me who to contact about the matter below?Or perhaps answer it for me? Thanks! Meredith From: Guhl, Meredith D (DOA) Sent: Friday, May 13, 2016 2:22 PM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 1C-155, PTD 215-180, Logs Obtained? Hi Steve, Could you please get back to me on this matter by May 20, 2016 so I can get the well file into the archive? Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Guhl, Meredith D (DOA) Sent: Monday, May 02, 2016 1:59 PM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Cc: Bettis, Patricia K (DOA) Subject: KRU 1C-155, PTD 215-180, Logs Obtained? Hello Steve, I'm completing the final compliance review for KRU 1C-155, PTD 215-180.On the 10-407 form, in box 22 Logs Obtained, the following is noted: 1.Surface—GR/Res 2. Intermediate—GR/Res/Den/Neu 3. Production—GR/Res/Den/Neu/Periscope However, to date the AOGCC has only received the GR/Res data,from surface to TD. Please advise if the logging program changed, or if data is missing that should be supplied to the AOGCC. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave,Suite 100,Anchorage,AK 99501 meredith.guhlCa@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 PTD 115 - lb'O • I Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, October 29,2015 9:17 AM To: 'Shultz, Steve(Orbis Engineering,Inc.)' Subject: RE: Requesting Change for West Sak 1C-155(PTD 215-180) Follow Up Flag: Follow up Flag Status: Completed Steve, Please submit a revised permit showing the changes in red text. A revised 10-401 form will also need to be signed and submitted. Please mark"Revised" on the top of the permit. Only those sections that change need to be submitted. Thanx, Victoria From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.Shultz©contractor.conocophillips.com] Sent:Thursday, October 29, 2015 8:59 AM To: Loepp, Victoria T(DOA) , Subject: Requesting Change for West Sak 1C-155 « File: 1C-155 13.375in Surface Summary v410.28.15.pdf» «File: 1C-155wp06 PlanSummary.pdf» Victoria, As you are aware, 1C-154 requested a change for moving the surface casing up due to a thicker silt stone which gave a better LOT when they drilled out. Geology is now requesting the same change for 1C-155. The old TD was 3063'MD and the new one is now 2,636'MD(2400'TVD). I have attached the directional and cement volume calculations for this new surface shoe. Is there anything else you require as far as information or AOGCC forms for this request? Thanks, Steve 1 RECEIVED • STATE OF ALASKA • JAN 12 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN[StaC la.Well Status: Oil Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ❑ WAGE WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp., Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 4.111115 k' ' 215-180/ 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 11/10/2015 50-029-23561-00 ` 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1548.5 FNL,4018.5 FEL,Sec. 12,T11N, R10E, UM 11/26/2015 . KRU 1C-155 - Top of Productive Interval: 9. Ref Elevations: KB: 97y I°`' 17. Field/Pool(s): 4748 FNL, 1535 FEL, Sec. 01,T11N, R10E, UM GL: 57 BF: Kuparuk River Field/West Sak Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 3080 FNL, 3485 FEL, Sec. 36,T12, R10E, UM n/a ADL 25649, 25638 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 562269 y- 5968690 Zone- 4 13435/3876 467,463 TPI: x- 564733 y- 5970791 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 562722 y- 5977722 Zone- 4 none 1844/1792 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary Surface-GR/Res S Intermediate-GR/Res/Den/Neu 5 It" Produlction-GR/Res/Den/NeulPeriscope 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 20 78.67 K-55 40 120 40 120 42 200 cf ArcticCRETE 13 3/8 68 L-80 41 2618 41 2387 16 1563 sxDeepCRETE, 246 sx IeeDCRETE 9 5/8 40 L-80 38 6404 38 3895 12.25 905 SX Class G 4 1/2 11.6 L-80 6188 13395 6188 3877 6.75 screens no cement 24. Open to production or injection? Yes ❑ No RI 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): V„ F„„� 1-V.4\,\Cilet"^'S CL`�� 4 1/2 6231 6187/3877 6726-7857 = MD, 3903-3898 = TVD 8128-8825= MD, 3894-3876 = TVD C,OMPLET ON 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9137-10446MD, 3$93 3$80 TVD DATE Was hydraulic fracturing used during completion? Yes El No 0 alttllt Per 20 AAC 25.283(i)(2)attach electronic and printed information 10717-12021= MD, 3880-3878=TVD VERIFIED DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 12097-12792= MD, 3879-3879 =TVD LA„ 13062-13321= MD, 3883-3$3879 = TVD 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift, etc.): 1/7/2016 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGas-Oil Ratio: 1/10/2016 7 hrs.41 min. Test Period 339 bbl 84 mscf/d 26 bbl/d 'L" I'''. I 250 scf/bbl Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 276 psi 1111 psi 24-Hour Rate -0. 1058 bbl 264 mscf/d 80 bbl/d 17 API Form 10-407 Revised 11/2015 vn_ 4/2,q//(.. ` ��NT�UED ON PASG����y RBDMS L.1- JAN 2 2 'it ORIGINIAL oryly 1 /� jrJ \� • • 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑I Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1844 1792 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 6189 3877 information, including reports, per 20 AAC 25.071. Top Ugnu C 4258 3259 Top Ugnu B 4711 Top Ugnu A 5030 3615 West Sak D 6210 Formation at total depth: West Sak D 31. List of Attachments: Definitive Survey,Operations Summary, Schematics, Cement Report Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontolooical 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: Steve ShultzA263-4297 Email: Steve.ShultzAcontractor.cop.com Printed Name: G.L.Alvord // Title: Alaska Drilling Manager Signature: -L. 6_L Phone: 265-6120 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 KUP P 00 1C-155 COnocoPhillips Well Attribu Max AnglTD 7ia$i(a_Inc, Wellbore API/UWI Field Name Wellbore Status ncl(1 MD(ft Act Btm(ftKB) Garroc8/Phillips 500292356100 WEST SAK PROD 94.00 8,281.43 11435.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-1C-155,1/12/20162:05:32 PM SSSV: NONE Last WO: 39.97 12/12/2015 Vertical.schematic.(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date HANGER,330 1111ff Last Tag: Rev Reason: NEW WELL,GLV C/O lehallf 1/6/2016 1 . . Casing Strings i Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... W11Len(I...Grade Top Thread CONDUCTOR 20 19.500 39.7 119.7 119.7 78.67 B Welded _,,,,..„60140,0664..;w w w �,�Casing Description OD(in) ID(in) Top(RKB) Set Depth(ROB) -Set Depth(TVD)...'Wt/Len(l...-Grade 'Top Thread 39.7-179.7 SURFACE 13 3/8 12.415 41.4 2,617.7 2,386.6 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 38.5 6,403.9 3,895.1 40.00 L-80 Hyd 563 SURFACE;41.4-2617.7 ' Casing Description SOD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len g...Grade Top Thread GAS LIFT;2,783.7 LINER 41/2 4.000 6,187.6 13,395.0 3,877.2 11.60 L-80 Hyd 563 Liner Details Nominal ID GAS LIFT;5,065.7 Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) 6,187.6 3,876.8 83.52 PACKER Baker HRD-E ZXP W/HD's 7"X 9 5/8",7"17#Hydril 6.180 563 pin do SLEEVE;5,120.3 SBE;5,124.9 6,206.3 3,878.9 83.42 NIPPLE RS Nipple 7"26#L-80 7"26#HYD 563 box x box 6.180 6,209.2 3,879.2 83.40 HANGER Baker Flex-Lock 7"X 9 5/8"L-80,7"26#Hydril 563 6.180 GAS LIFT;5,717.0 pin x pin 6,219.0 3,880.3 83.34 XO XO 7"26#Hydril 563 box X 5 1/2"15.5#Hydril 563 4.870 REDUCING pin GAUGE;6,788.9- 6,220.4 3,880.5 83.34 SBE Baker 4.75"ID Seal Bore Extension,5 1/2"Hyd 563 4.740 box x pin 6,241.4 3,883.0 83.22 VALVE Baker Fluid Loss Control valve,7"29#,Hyd 563 box 4.560 x pin LOCATOR;5,210.5 6,248.3 3,883.8 83.18 XO Crossover,7"29#Hyd 563 box x 5-1/2"15.5#Hyd 4.890 SEAL ASSY;6,271.5 6,331.4 3,891.5 86.68 )<OREDUCING 563 pin Crossover,5-1/2"15.5#Hyd 563 box x 4-1/2"12.6# 4.000 REDUCING Hyd 563 pin 6,665.7 3,902.8 88.93 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated)"J"S/N-49168-001-40 6,696.4 3,903.4 88.88 TRACER Tracerco Tracer Cartridge,5-1/2"15.5 ppf Hyd 511 4.000 Pin x Pin,ser#02 6,725.5 3,903.9 88.82 SCREEN Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 INTERMEDIATE;38.5-6,403.9 L-80 Hyd 563 99-124 7,912.9 3,897.9 90.63 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated)"I"S/N-49168-001-23 8,068.4 3,895.6 90.81 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 1958 PACKER (Water activated)"H"S/N-49168-001-27 8,098.9 3,895.2 90.80 TRACER Tracerco Tracer Cartridge,5-1/2"15.5 ppf Hyd 511 4.000 FINE MESH SCREENS;8,728.0 Ig Pin x Pin,ser#04 -7,857.0 8,128.4 3,894.7 91.10 SCREEN Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 Q L-80 Hyd 563 83-98 8,881.0 3,878.3 87.69 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 • PACKER (Water activated)"G"S/N-49168-001-22 Q 9,076.9 3,890.3 86.49 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated)"F"S/N-49168-001-29 9,107.4 3,892.0 86.98 TRACER 'Tracerco Tracer Cartridge,5-1/2"15.5 ppf Hyd 511 4.000 Pin x Pin,ser#06 9,137.0 3,893.5 87.48 SCREEN Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 FINE MESH SCREENS;8,128.0 L-80 Hyd 563 53-82 8825.0 10,501.1 3,878.1 91.69 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated)"E"S/N-49168-001-4 10,656.6 3,878.9 88.77 SWELL Baker swell packer 4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated)"D"S/N-49168-001-39 4 10,686.9 3,879.5 88.92 TRACER Tracerco Tracer Cartridge,5-1/2"15.5 ppf Hyd 511 4.000 Pin x Pin,ser#08 10,716.5 3,880.1 89.06 SCREEN +Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 L-80 Hyd 563 23-52 12,036.8 3,878.7 89.52 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 FINE MESH SCREENS;9,137.0 PACKER (Water activated)"C"S/N-49168-001-9 -10,448.0 IS - 12,067.2 3,879.0 89.28 TRACER Tracerco Tracer Cartridge,5-1/2"15.5 ppf Hyd 511 4.000 Pin x Pin,ser#10 iir 12,096.8 3,879.5 88.93 SCREEN Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 L-80 Hyd 563 7-22 Q 12,847.2 3,880.1 88.89 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 PACKER (Water activated) "B"S/N-49168-001-30 13,041.9 3,883.7 89.68 SWELL Baker swell packer,4-1/2"x 6.38",920 medium 3.958 113 PACKER (Water activated)"A"S/N-49168-001-12 0 13,061.7 3,883.8 89.87 SCREEN Baker 4-1/2"Excluder 2000 Screen,4-1/2",11.6 ppf 4.000 L-80 Hyd 563 1-6 FINE MESH SCREENS; - 10,717.0-12,021.0 13,371.5 3,878.0 91.89 PACKOFF Baker Pack-off Bushing,4-1/2"12.6 ppf Hyd 563 box 2.390 xpin 1 Tubing Strings 0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 33.8 6,230.8 3,881.7 12.60 L-80 IBT-M Completion Details FINE MESH SCREENS; Nominal ID 12,OW.0.12,702.0 Top(ftKB) Top(ND)(kKB) Top Incl(3 Item Des Com (in) 33.8 33.8 0.12 HANGER Vetco Gray M822 4-1/2"Tubing hanger 3.958 1E15,120.3 3,653.7 68.32 SLEEVE Baker 4-1/2"CMU Sliding Sleeve(CLOSED)w/3.813" 3.813 DB profile 5,124.9 3,655.4 68.51 SBE Baker 3.812"Seal Bore Extension 3.812 Q 6,169.9 3,874.8 83.62 GAUGE Baker Gauge Carrier,Dual Guardian,Ported(w/ 3.958 SurSENS gauges) FINE MESH SCREENS; 6,210.5 3,879.4 83.39 LOCATOR Baker No go Locator,above located,4-1/2",12.6 ppf L- 3.870 13,052.0.13,321.0 80,IBT-m box top 6,211.5 3,879.5 83.39 SEAL ASSY Baker"PBR"Seal assembly 3.850 LINER;6,187.6-13,395.0---.----il KUP 4OD 1C-155 Conoco Phillipslak • Alaska Inc, Conooi*dips HORIZONTAL-10-155,1112120162'.05'.33 PM Vertical schematic(actual) HANGER,33.8 . Perforations&Slots .............. I I'" Shot Dens I Top(TVD) Btm(TVD) (shots/ 'AT/'^ Top(RKB) Btm(RKB) (MB) (ttKB) Zone Date tt TypeCom CONDUCTOR;39.7-119.7 ) 6,726.0 7,857.0 3,903.9 3,898.3 WS D,1C- 12/3/2015 FINE EXCLUDER 2K 155 MESH SCREENS#99THRU SURFACE;41.4-2,617.7 • ) SCREE #124 I NS GAS LIFT;2,793.1 al 8,128.0 8,825.0 3,894.7 3,876.5 WS D,1C- 12/3/2015 -FINE EXCLUDER 2K ! 155 MESH SCREENS#83THRU GAS LIFT,5,085.7 ISCREE #98 i se 9,137.0 10,446.0 3,893.5 3,880.6 WS D,1C- 12/3/2015 FINE EXCLUDER 2K SLEEVE;5,120.3 ,. 155 MESH SCREENS#53 THRU SBE;5,124.9 SCREE #82 al NS a ■ 10,717.0 12,021.0 3,880.1 3,878.6 WS D,1C- 12/3/2015 FINE EXCLUDER 2K GAS LIFT;5,747.0 mit 155 MESH SCREENS#23 THRU ® SCREE #52 II® NS GAUGE;6,168.8 I. 12,097.0 12,792.0 3,879.5 3,879.2 WS D,1C- 12/3/2015 FINE EXCLUDER 2K 155 MESH SCREENS#7THRU SCREE #22 I NS LOCATOR;6,210.5 lal 13,062.0 13,321.0 3,883.8 3,879.7 WS D,1C- '12/3/2015 FINE EXCLUDER 2K 1=. 155 MESH SCREENS#1 THRU#6 SEAL ASSY;6,211.5 41 SCREE :M1 NS Mil 1 c:a Mandrel Inserts St ati an lop(TVD) Valve Latch Port Size TRO Run N Top(MB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,793.1 2,492.7 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,456.0 1/4/2016 INTERMEDIATE;3e.56,403.8 2 5,065.7 3,632.6 Camco KBMG 1 GAS LIFT OV BK 0.313 0.0 1/4/2016 R 3 5,747.0' 3,810.5 Camco 'KBMG 1 GAS LIFT DMY BK 0.000 0.0 1200/2015 ®1 Notes:General&Safety CJEnd Date Annotation FINE MESH SCREENS;6,726.0 aNOTE -7,857,0 j FINE MESH SCREENS,8,128.0 -8,825.0 Q I ' Q 6 FINE MESH SCREENS-10,;9,137.446.00 FINE MESH SCREENS; 10,717.0-12,021.0 { FINE MESH SCREENS; 12,097.0-12,792.0 1 FINE MESH SCREENS; 13,062.0-13,321.0 I LINER;6,187.6-13,395.0 1 111111 iterations Summary (with Timelog IIepths) 0 1C-155 Conoco`Phiifips Arr.F Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code f Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/8/2015 11/8/2015 4.50 MIRU MOVE MOB P Stomp power,pump and pit 0.0 0.0 06:00 10:30 complexes away from sub.Jack up sub and stomp pipe shed out from under sub. 11/8/2015 11/8/2015 1.50 MIRU MOVE MOB P Stomp sub base off of well,out far 0.0 0.0 10:30 12:00 enough to clear other wells and start towards 1C-155.Trailing with pipe shed. 11/8/2015 11/8/2015 3.00 MIRU MOVE MOB P Continue stomping sub towards 1C- 0.0 0.0 12:00 15:00 155,trailing with pipe shed after moving mats.Stage pits and power modules via stompers.Spotted sub, leveled and shimmed @ 15:00 11/8/2015 11/8/2015 3.25 MIRU MOVE MOB P Continue walking pipe shed under and 0.0 0.0 15:00 18:15 into sub,shim and pin same.Stage casing module @ pipe shed.Begin electrical innerconnects. 11/8/2015 11/8/2015 1.25 MIRU MOVE MOB P PJSM,raise and pin derrick,secure 0.0 0.0 18:15 19:30 mast cylinders while walking casing shed into pipe shed. 11/8/2015 11/8/2015 1.00 MIRU MOVE RURD P PJSM,skid rig floor to drill position. 0.0 0.0 19:30 20:30 Secure cylinders and handrails. 11/8/2015 11/8/2015 1.50 MIRU MOVE MOB P Walk pits into sub,pump into pits, 0.0 0.0 20:30 22:00 lower C-section,raise cattle chute and secure. 11/8/2015 11/8/2015 1.50 MIRU MOVE MOB P Walk power into pump complex,berm 0.0 0.0 22:00 23:30 and lower cellar containment.Un-pin and secure cellar hydraulic cylinders. M/U fluid and electric innerconnects. All modules connected @ 23:00 hrs. 11/8/2015 11/9/2015 0.50 MIRU MOVE RURD P Remove securing straps and chain 0.0 0.0 23:30 00:00 from Topdrive energy track and bails. Plug in cattle chute lights,contunue to make up innerconnects. 11/9/2015 11/9/2015 2.00 MIRU MOVE RURD P Continue plugging in power module, 0.0 0.0 00:00 02:00 continue M/U innerconnects.Hammer up stand pipe and cement line jumper hoses,spool drilling line up on drawworks.Get steam and water running around rig.SIMOPS-work on 5"DP in the casing shed. 11/9/2015 11/9/2015 1.50 MIRU MOVE RURD P Un-pin top drive,bridle up and scope 0.0 0.0 02:00 03:30 derrick.Bridle down and secure cables.Place diverter signage and barricades,install well sign and post permits. Accept rig @ 03:00 11/9/2015 11/9/2015 7.00 MIRU MOVE RURD P Install picking lines on bails,pick 0.0 0.0 03:30 10:30 surface riser to rig floor and lower to cellar and bolt up.Install annular on top of riser,move flow box into place, change out air boots. Install pitcher nipple,center stack,rig up flowline, chink up flow box and tighten bolts. SIMOPS-Install hydraulic block on top drive.Perform Pre-spud derrick inspection,obtain RKB's. Page 1/35 Report Printed: 1/7/2016 operations Summary (with Timelog IIepths) 0; 1C-155 ConocoPhill ps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr); Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/9/2015 11/9/2015 1.50 MIRU MOVE RURD P Install PS-21 slips and 5"inserts. 0.0 0.0 10:30 12:00 Install Kelly hose,R/U 5"handling equipment.Calibrate blocks on Amphion and Totco system. 11/9/2015 11/9/2015 4.25 MIRU MOVE PULD P M/U 24 stands 5"DP with doubles 2 x 0.0 0.0 12:00 16:15 1.Continue making up stands with singles 1 x 1.Tag up inside conductor @ 79'MD from RKB. 11/9/2015 11/9/2015 1.00 MIRU MOVE BOPE P Perform Diverter test Witnessed by 0.0 0.0 16:15 17:15 AOGCC Jeff Jones.Annular closing time 74 sec,Knife valve open 14 sec, Perform Koomey drawdown. Accumulator system pressure=3000 psi,Manifold=1500 psi,Pressure after functioning=2100 psi,200 psi attained=11 seconds with 2 electric pumps,Full system pressure attained=50 seconds with 2 air and 2 electric pumps.6 bottle N2 average= 1942 psi. 11/9/2015 11/9/2015 1.00 MIRU MOVE PULD P Continue M/U stands drill pipe 1 x 1 0.0 0.0 17:15 18:15 and rack back in derrick. 11/9/2015 11/9/2015 1.25 MIRU MOVE SFTY P Safety Stand Down W/CPAI and DDI 0.0 0.0 18:15 19:30 crew concerning hand injury on rig floor while latching elevators,picking up drill pipe from skate. 11/9/2015 11/9/2015 2.75 MIRU MOVE PULD P Continue M/U stands drill pipe 1 x 1 0.0 0.0 19:30 22:15 for total 62 stands 5"DP in derrick. 11/9/2015 11/9/2015 1.25 MIRU MOVE PULD P Make up 9 stands 5"HWDP including 0.0 0.0 22:15 23:30 jars and rack back. 11/9/2015 11/10/2015 0.50 MIRU MOVE BHAH P Mobilize BHA components to rig floor. 0.0 0.0 23:30 00:00 Load casing shed with 13-3/8"casing. 11/10/2015 11/10/2015 1.25 MIRU MOVE BHAH P Continue to mobilize BHA to rig floor, 0.0 0.0 00:00 01:15 and from casing shed to pipe shed. 11/10/2015 11/10/2015 0.50 MIRU MOVE SFTY P Hold pre-spud meeting with DDI rig 0.0 0.0 01:15 01:45 crew,SLB DD and MWD,MI mud engineer.Discuss using Spud Mud, broaching,hydrates,diverting shallow gas,exclusion zone and muster areas. 11/10/2015 11/10/2015 1.00 MIRU MOVE BHAH P P/U conductor cleanout BHA, 16" 0.0 70.0 01:45 02:45 Smith XR+bit,9-5/8"motor and XO to 5"HWDP. 11/10/2015 11/10/2015 0.25 MIRU MOVE SEQP P Fill high pressure mud lines with 70.0 70.0 02:45 03:00 water.Test mud lines to 3500 psi for 5 minutes.Fill hole with spud mud and confirm no leaks on riser or diverter system. 11/10/2015 11/10/2015 0.50 MIRU MOVE REAM P Clean out conductor from 78'MD, 70.0 120.0 03:00 03:30 where tagged earlier to 120'MD @ 400 gpm,psi=280. 11/10/2015 11/10/2015 2.50 SURFAC DRILL DDRL P Drill 16"surface hole from 120'MD,to 120.0 264.0 03:30 06:00 264'MD,to make rathole for rest of BHA @ 550 gpm,600 psi,77%flow out,40 rpm,2-3k,8k WOB,off bottom=500,P/U=54k,S/O=63k, ROT=55k, 1k Tq. 11/10/2015 11/10/2015 0.50 SURFAC DRILL TRIP P POOH from 264'MD to 45'MD,blow 264.0 45.0 06:00 06:30 down top drive. Page 2/35 Report Printed: 1/7/2016 Operations Summary (with Timelog D pths) 0 II 0 1C-155 ConooriPhillips hkxk Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/10/2015 11/10/2015 3.00 SURFAC DRILL BHAH P P/U remaining surface BHA,obtain 45.0 117.0 06:30 09:30 Gyro survey in conductor @ 117'MD. 11/10/2015 11/10/2015 0.50 SURFAC DRILL SRVY P Obtain Gyro survey @ 212'MD,wash 117.0 255.0 09:30 10:00 stand down to bottom,tagged up @ 255'MD,9'fill. 11/10/2015 11/10/2015 2.00 SURFAC DRILL DDRL P Continue drilling 16"surface hole from 255.0 380.0 10:00 12:00 264'MD to 380'MD,380'TVD,650 gpm,930 psi,48%flow out,40 rpm, Tq on/off=3k/2k, 13k WOB,P/U=56k, S/O=63k,ROT=55k,ADT=1.22, ART=0.57,AST=0.65.Total bit hrs=2.72,Total jar hrs=151.69. 11/10/2015 11/10/2015 6.00 SURFAC DRILL DDRL P Continue drilling 16"surface hole from 380.0 964.0 12:00 18:00 380'MD to 964'MD,957'TVD with 650 gpm, 1420psi,45%flow out,60 rpm,Tq on/off=5k/2k,20k WOB, P/U=89k,S/O=97k,ROT=98k, ADT=3.72,ART=2.47,AST=1.25 11/10/2015 11/11/2015 6.00 SURFAC DRILL DDRL P Continue drilling 16"surface hole from 964.0 1,490.0 18:00 00:00 964'MD to 1490'MD, 1472'TVD with 701 gpm,1925psi,45%flow out,60 rpm,Tq on/off=7k/3k,25k WOB, P/U=110k,S/0=109k,ROT=106k, ADT=3.72,ART=2.47,AST=1.25. Total bit hrs=8.66,Total Jar hrs=159.13 11/11/2015 11/11/2015 5.50 SURFAC DRILL DDRL P Drilling 16"surface hole from 1490' 1,490.0 1,911.0 00:00 05:30 MD to 1911'MD, 1847'TVD with 750 gpm,2170 psi,60%flow out,60 rpm, Tq on/off=5k/3k, 10k WOB, P/U=118k,S/0=113k,ROT=115k, ADT=3.72,ART=2.47,AST=1.25. Total bit hrs=8.66,Total Jar hrs=159.13 11/11/2015 11/11/2015 1.75 SURFAC DRILL CIRC T Circulate hole clean while 1,911.0 1,911.0 05:30 07:15 troubleshooting MWD tool,not responding.Rackstand back and continue to trouble shoot MWD. MU stand and attempt to drill 10'to see if MWD regains communication.(Tool Functioning) 11/11/2015 11/11/2015 4.75 SURFAC DRILL DDRL P Continue to drill 16"surface hole from 1,911.0 2,213.0 07:15 12:00 1911'MD to 2213'MD,2104'TVD with 600 gpm, 1670psi,52%flow out, 60 rpm,Tq on/off=5k/3k, 18k WOB, P/U=122k,S/0=116k,ROT=115k. ADT=6.03,ART=1.97,AST=4.06. Total bit hrs=16.19.Total Jar hrs= 165.16. 11/11/2015 11/11/2015 5.00 SURFAC DRILL DDRL P Continue to drill 16"surface hole from 2,213.0 2,629.0 12:00 17:00 2213'MD to 2629'MD,2393'TVD with 601 gpm, 1820psi,49%flow out,60 rpm,Tq on/off=9k/4k,25k WOB, P/U=122k,S/0=116k,ROT=115k. ADT=3.59,ART=1.62,AST=1.97. Total bit hrs=18.28.Total Jar hrs= 168.75. Page 3/35 Report Printed: 1/7/2016 .Operations Summary (with Timelogepths) 1C-155 C:or oa 0 hilhps AWL: Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)', 11/11/2015 11/11/2015 0.75 SURFAC CASING CIRC P Obtain survey,CBU while rotating and 2,629.0 2,567.0 17:00 17:45 reciprocating from 2629'MD to 2567' MD with 750 gpm, 1900psi,60%flow out,60 rpm,Tq=4k for 6400stks. Reduce pump rate while pumping nut plug sweep to surface. 632 gpm, 680psi,48%flow out,60 rpm,4k TQ Concurrently, Change out swab,piston,and sub rod on MP#1 11/11/2015 11/11/2015 2.25 SURFAC CASING CIRC P Continue to CBU while rotating and 2,567.0 2,475.0 17:45 20:00 reciprocating from 2629'MD to 2567' MD with 750 gpm, 1900psi,60%flow out,60 rpm,Tq=4k for 6400stks. Rack stand and continue to CBU at same parameters from 2572'to 2475' MD for additional 6522stks.P/U=124k, S/0=120k,ROT=118k,4k TQ 11/11/2015 11/11/2015 0.25 SURFAC CASING OWFF P Montior well for 10min noting a 2,475.0 2,475.0 20:00 20:15 reduction in hydrates breaking out at surface. 11/11/2015 11/11/2015 3.00 SURFAC CASING BKRM P Attempt to POOH on elevators from 2,475.0 1,814.0 20:15 23:15 2475'MD w/30k overpull at 2465'MD, wipe 2x with no reduction in overpull. Back ream out of hole from 2465'MD to 2003'MD with 750 gpm, 1890 psi, 60%flow out,4k TQ and from 2003' MD to 1814'MD with 650gpm, 1700psi,50%flow out,60 rpm,4k TQ. 11/11/2015 11/12/2015 0.75 SURFAC CASING TRIP P Blow down topdrive,pull out of hole on 1,814.0 1,529.0 23:15 00:00 elevators from 1814'MD to 1529'MD monitoring displacement via trip tank. 11/12/2015 11/12/2015 3.50 SURFAC CASING TRIP P Continue POOH from 1529'MD to 1,529.0 215.0 00:00 03:30 215'MD,rack back all 5"DP,5" HWDP stands including jar stand and drill collars.Lay down 12 jts of 5" HWDP.P/U=60k,S/O=62k.Tight spots @ 1480', 1348', 1271', 1100', 978',819'and 757'15-35k over.Wipe through tight spots until cleaned up. 11/12/2015 11/12/2015 3.50 SURFAC CASING BHAH P PJSM,L/D BHA,lay down stabilizer 215.0 0.0 03:30 07:00 and ARC.Pick up to bit,drain motor, break bit.L/D Telescope,Gyro sub, 2nd stab and mud motor. Clean up rig floor,get rid of short BHA tools. Bit grade 2-2-WT-A-E-IN-NO-TD. 11/12/2015 11/12/2015 1.75 SURFAC CASING RURD P Rig up to run 13-3/8"Surface Casing. 0.0 0.0 07:00 08:45 Install 6ft bail extensions,volant casing running tool,and all remaining 13-3/8"casing running equipment. Page 4/35 Report Printed: 1/7/2016 Operations Summary (with Timelog IIepths) 0 1C-155 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time - Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) '. End Depth(EKE) 11/12/2015 11/12/2015 3.25 SURFAC CASING PUTB P PJSM,Run 13-3/8",68#,hydril 563, 0.0 400.0 08:45 12:00 surface casing. P/U shoe track and Baker Loc 1st 4 connections.Check flow path and floats. Continue running in hole with 13-3/8"surface casing to 400'. Bow spring centralizers instated on every collar. 11/12/2015 11/12/2015 4.00 SURFAC CASING PUTB P Continue RIH with 13-3/8"68#L80 400.0 1,100.0 12:00 16:00 surface casing with volant casing running tool fom 400'MD to 1100'MD filling on the fly and topping off each 10 joints.Monitor displacement via active pits. 11/12/2015 11/12/2015 1.00 SURFAC CASING PUTB T Lay out jt#25 and#26 due to galled 1,100.0 1,100.0 16:00 17:00 threads.Replace damaged joints with joints A and B from outside of casing shed.Swapped out jts#50 for#68 and #56 for#69 in running order and Tally as per CPAI. 11/12/2015 11/12/2015 1.00 SURFAC CASING CIRC T PU and work tight hole from 1010ft to 1,100.0 1,100.0 17:00 18:00 1100ft after circulating bottoms up with flow rate=210gpm,200psi,and 45% flow out. 11/12/2015 11/12/2015 4.50 SURFAC CASING PUTB P Continue to run in hole with 13-3/8" 1,100.0 1,868.0 18:00 22:30 68#L-80 hydril 563 surface casing from 1100'MD to 1868'MD. Tight hole spots at 1100'MD to 1190'MD and from 1460'MD to 1660'MD.(Up drag up to 40k) 11/12/2015 11/12/2015 1.00 SURFAC CASING CIRC P CBU at base of permafrost from 1828 1,868.0 1,868.0 22:30 23:30 to 1868 MD.Stage pump up to 294gpm,FCP=250psi,55%flow out, for 2550 total strokes. 11/12/2015 11/13/2015 0.50 SURFAC CASING PUTB P Continue running in hole from 1868' 1,868.0 1,948.0 23:30 00:00 MD to 1948' MD with casing running tool filling while monitoring displacement via active pits. P/U= 145k,S/O=105k 11/13/2015 11/13/2015 3.50 SURFAC CASING PUTB P Continue running in the hole with 13- 1,948.0 2,570.0 00:00 03:30 3/8"surface casing using volant casing running tool from 1948'MD to 2570'MD. Tight spot seen at 2149' MD.Monitor displacment via active pits.P/U=198k and S/O=135k. 11/13/2015 11/13/2015 0.75 SURFAC CASING CIRC P Circulate bottoms up from shoe track 2,570.0 2,570.0 03:30 04:15 to base of permafrost(-1840'MD)at 168 GPM and 174psi. 11/13/2015 11/13/2015 0.25 SURFAC CASING HOSO P Make up 13-3/8"casing hanger and 2,570.0 2,618.0 04:15 04:30 landing joint and run in hole to land out casing hanger at 2618'MD. 11/13/2015 11/13/2015 4.25 SURFAC CEMENT CIRC P Circulate and condition spud mud in 2,618.0 2,618.0 04:30 08:45 preparation for cement job whil reciprocating pipe 20'. Flow rate was 294 GPM and SPP was 213psi with 90%flow out.P/U=195k and S/O= 150k. Page 5/35 Report.Printed: 1/7/2016 • Operations Summary (with Timelog IIepths) 0 1C-155 conodo`IPhilGps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 11/13/2015 11/13/2015 0.75 SURFAC CEMENT RURD P PJSM:Surface cement job.Rig up 2,618.0 2,618.0 08:45 09:30 cement hose,90deg and low TQ valve to cement swivel on casing running tool.Circulate through cement hose until Schlumberger cementers have batched up with CW100 and Mud Push II. 11/13/2015 '11/13/2015 0.50 SURFAC CEMENT CMNT P 'Line up the Schlumberger cementers. 2,618.0 2,618.0 09:30 10:00 Pump 5bbl of CW100 and pressure test lines to 4000psi(Good Test). 11/13/2015 11/13/2015 2.00 SURFAC CEMENT CMNT P Pump 70 additional bbls of CW100 at 2,618.0 2,618.0 10:00 12:00 7 BPM,300psi,26%flow out.P/U= 198k,S/O=148k. Follow CW100 with 75bbls of Mud Push II.Drop bottom plug.Schlumberger cementers batch up and pump 551.9bbls of 11ppg Lead cement.P/U=205k,S/O=144k. Reciprocate pipe 20'thoughout. 11/13/2015 11/13/2015 2.75 SURFAC CEMENT CMNT P Pump 77.3bbls of 12ppg tail cement 2,618.0 2,618.0 12:00 14:45 while reciprocating casing 15'. P/U=230k,S/0=115k.Drop Top Plug and kick out with 10bbI of H20.Swap over from Schlumberger cementers to rig pump for remainder of displacement. Pump with rig pump and displace cement with conditioned spud mud @ 6BPM initial rate.Pick up 4'to reciprocate casing with 50k overpull from las PU wt of 230k.Un- able to land casing on landing ring with hanger 4-1/2"off landing ring. Continue attemps to land hanger, initial rate of 6 BPM,300psi,26%flow out for 490stk.Divert returns to cellar and reduce rate to 3 BPM, 150 psi ICP with 363psi FCP. Reduce rate to 1 BPM,280psi FCP.Bump plug at 3643stks,increase to 500psi over FCP to 800psi and hold for 5min. Bleed pressure off and check floats (holding).Casing in Place at 14:26 and set at 2618'MD. 11/13/2015 11/13/2015 2.25 SURFAC CEMENT RURD P Blow down cement line.Rig down 2,618.0 2,618.0 14:45 17:00 volant casing running tool.Flush stack,surface annular,jet and hole fill lines and flow line with back water pills.Break out and pull landing joint and lay down same. Clean and inspect all cement line DEMCO valves.Pull master bushings and clean flow box. Concurrently, Weld unions on new injection line at pit interconnect. Page 6/35 Report Printed: 1/7/2016 0 Operations Summary (with Timelog!epths) rt 6. 1C-155 LonocoPhilhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time'' End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 11/13/2015 11/13/2015 4.50 SURFAC CEMENT NUND P Nipple down and secure surface 2,618.0 2,618.0 17:00 21:30 annular,flow line and jet/hole fill lines, and flow box. Pull riser and diverter 'T' to rig floor and lower same through beaver slide. Nipple down and pull Vetco Gray diverter adaptor to rig floor. 11/13/2015 11/13/2015 2.00 SURFAC WHDBOP OTHR T Install master bushings and pick up 2,618.0 2,618.0 21:30 23:30 landing joint. Lower to cellar and make up to hanger.Pull 270k several times to attempt to get enough stretch to provide enough room to set emergency slips(pulled 4"). (Unsuccessful). Rig down 150 ton elevators 11/13/2015 11/14/2015 0.50 SURFAC WHDBOP WAIT T Wait on 350 ton elevators,clean and 2,618.0 2,618.0 23:30 00:00 clear rig floor.Service and inspect top drive. 11/14/2015 11/14/2015 1.00 SURFAC WHDBOP WAIT T Wait on 13-3/8"350 ton elevators. 2,618.0 2,618.0 00:00 01:00 Continue to service and inspect top drive and blocks.Clean and clear rig floors and perform PM's.Locate top of cement AT 3.7'from top of conductor. 11/14/2015 11/14/2015 1.00 SURFAC WHDBOP OTHR T Install 6'bail extensions,350 ton 2,618.0 2,618.0 01:00 02:00 elevators,pull 350k work up to 400k, 450k.Pull 6"of stretch.Unable to pull enough stretch into pipe to install emergency slips. 11/14/2015 11/14/2015 2.50 SURFAC WHDBOP WAIT T Consult with town and develop new 2,618.0 2,618.0 02:00 04:30 plan for setting hanger. Concurrently, Perform housekeeping and remove 4" conductor valves and clean cellar box in preparation for cutting conductor. 11/14/2015 11/14/2015 1.50 SURFAC WHDBOP OTHR T Pull 300k and slack off to 150k to 2,618.0 2,618.0 04:30 06:00 obtain stretch measurements to determine length of conductor required to add to existing 20" conductor.Stretch=2". Begin permitting process to be able to cut conductor.(Hot work permit and Confined space) 11/14/2015 11/14/2015 6.00 SURFAC WHDBOP OTHR T PJSM and perform hazard assement 2,618.0 2,618.0 06:00 12:00 with CPAI,DDI HSE and DDI rig welder. Cut 20"conductor and install 7"of 20"conductor spacer and weld. Slack off to 100k and continue to weld 20"conductor spacer to conductor. Post heat welds and wrap with insulation to allow to slow cool. 11/14/2015 11/14/2015 2.00 SURFAC WHDBOP WAIT T Wait on conductor weld to cool.Clean 2,618.0 2,618.0 12:00 14:00 BOP deck and chink cellar.Replace cuttings tank discharge valves. Page 7/35 Report Printed: 1/7/2016 Operations Summary (with Timelog IIepths) 0 1C-155 Conor hilGps ALtska Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/14/2015 11/14/2015 1.00 SURFAC WHDBOP OTHR T Conductor welds cooled.Set down 2,618.0 2,618.0 14:00 15:00 remaining 60k weight of string.Rig down 350k ton elevators and bail extensions.Back out landing joint and lay down same. 11/14/2015 11/14/2015 3.00 SURFAC WHDBOP NUND P Clean and install vetco wellhead 0.0 0.0 15:00 18:00 adaptor.Lower wellhead to cellar and nipple up. Test seals to 5000psi for 10min witnessed by CPAI.Pick up 14' riser to floor and remove 18" extension.Lower and install OA, IA and production port valves on Vetco Gray wellhead.Lower 14'riser and 1' extension to cellar nad nipple up same. Concurrently, Re-position slop tank discharge line at pits interconnect. 11/14/2015 11/14/2015 5.00 SURFAC WHDBOP NUND P Remove 8"drilling spool adapter from 0.0 0.0 18:00 23:00 BOP stack.Nipple up BOP stack on top of riser.Torque all flanged connections.Nipple up choke and kill lines to stack.Position Joe's box under rotary table.Install flowline and dresser sleeve.Lower pincher nipple to stack,air up boots,chink up Joe's box,install strip-o-matic. Concurrently, Get wear rings,puller,and test plugs to rig floor 11/14/2015 11/15/2015 1.00 SURFAC WHDBOP RURD P Rig up to test BOP's,Make up XT-39 0.0 0.0 23:00 00:00 and 4-1/2"IF dart and TIW valves. Install rocket launcher on quill.Pick up 9-5/8"test joint.Make up to test plug and lower into wellhead.Fill stack through kill line with H20.Purge air out of lines. 11/15/2015 11/15/2015 0.50 SURFAC WHDBOP RGRP T PJSM,drain stack due faulty blind ram 0.0 0.0 00:00 00:30 door seal.Change out door seal. 11/15/2015 11/15/2015 1.00 SURFAC WHDBOP RURD P Fill stack and flood lines,continue rig 0.0 0.0 00:30 01:30 up to test. 11/15/2015 11/15/2015 5.00 SURFAC WHDBOP BOPE P Test BOPE to 250/3500 psi 5 min 0.0 0.0 01:30 06:30 each charted,AOGCC Chuck Scheve waived witness of test.Tested manual operated and auto choke to 250/2000 psi.Tested annular with 9-5/8"and 4" test joint,Tested Upper pipe rams with 9-5/8".Test 2-7/8"x 5-1/2"lower rams with 4"and 5"test joint.Tested choke valves 1-15,manual operated and super choke,choke and kill manuals and HCR's.4"valve on kill line,4" TIW,4"Dart valve,5"TIW,5"Dart valve,upper and lower!BOP,blind rams. Page 8/35 Report Printed: 1/7/2016 1, 0 oz. ....._ Operations Summary (with Timeloggepths) 1C-155 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation ; (ftKB) End Depth(ftKB) 11/15/2015 11/15/2015 0.50 SURFAC WHDBOP BOPE P Perform Koomey drawdown test 0.0 0.0 06:30 07:00 Accumulator=3100 psi,Manifold=xxx psi.Accumulator pressure after cycling all rams,annular and HCR's=1600 psi,200 psi attained=18 sec with 2 electric pumps,full system recovery=110 sec with two electric and two air pumps.6 bottle N2 average=1850 psi.Closing times for annular=23 sec,UPR=21 sec, Blind/shears=16 sec,LPR=17 sec, Choke HCR=2 sec,Kill HCR=2 sec. 11/15/2015 11/15/2015 1.00 SURFAC WHDBOP RURD P Pull test plug,drain BOP stack,set 12- 0.0 0.0 07:00 08:00 3/8"ID wear ring.Blow down choke, kill lines and choke manifold.Rig down BOPE test equipment. 11/15/2015 11/15/2015 2.75 SURFAC CEMENT BHAH P PJSM for Making up BHA#.Make up 0.0 94.0 08:00 10:45 BHA from 0'MD to 94'MD.Monitor displacement via Pit#2 11/15/2015 11/15/2015 0.50 SURFAC CEMENT SFTY P Safety Stand down with CPAI Wellsite 94.0 94.0 10:45 11:15 Lead(Rob Reinhardt) 11/15/2015 11/15/2015 2.00 SURFAC CEMENT BHAH P Continue make up of BHA#3 from 94' 94.0 2,079.0 11:15 13:15 MD to 2079'MD.Monitor displacement via Pit#2.P/U=110k, S/0=100k. 11/15/2015 11/15/2015 0.75 SURFAC CEMENT DHEQ P Shallow pulse test MWD.Staged up 2,079.0 2,079.0 13:15 14:00 pumps to 500gpm,1210 psi,30%flow out,blow down top drive. 11/15/2015 11/15/2015 0.25 SURFAC CEMENT TRIP P Run in hole from 2079'MD to 2320' 2,079.0 2,265.0 14:00 14:15 MD,encountering cement stringers at 2320'MD with 15k drag.Pick up to 2265'MD and make up top drive. 11/15/2015 11/15/2015 0.50 SURFAC CEMENT COCF P Wash and ream down from 2265'MD 2,265.0 2,523.0 14:15 14:45 to 2523'MD with 300gpm,745psi, 23%flow out,30 rpm,7-8k TQ.Tag up on cement/plugs at 2523'MD, P/U=115k,S/O=103k. 11/15/2015 11/15/2015 0.75 SURFAC CEMENT CIRC P Rack back 2 stands and circulate 2,523.0 2,523.0 14:45 15:30 bottoms up while rotating and reciprocating from 2320'MD to 2250' MD with 400gpm,970 psi,24%flow out,40 rpm,8-10k TQ. Total stk's pumped 3150,rack stand to 2545' MD. 11/15/2015 11/15/2015 1.25 SURFAC CEMENT PRTS P Blow down top drive,PJSM for testing 2,523.0 2,523.0 15:30 16:45 casing.Test casing to 3000psi for 30min(charted).Rig down and blow down test equipment. 11/15/2015 11/15/2015 2.25 SURFAC CEMENT DRLG P Drill out plugs,float collar and shoe 2,523.0 2,609.0 16:45 19:00 track from 2523'MD to 2609'MD with 550gpm, 1310psi,32%flow out,40 rpm,5k WOB,7-9k TQ.P/U=118k, S/0=100k,ROT=109k,with off bottom TQ=6k.Drill out rat hole. 11/15/2015 11/15/2015 1.00 SURFAC CEMENT DDRL P Drill 20'of new formation from 2609' 2,609.0 2,649.0 19:00 20:00 MD to 2649'MD with 550gpm, 1154psi,28%flow out,40 rpm,3k WOB,6-9k TQ.P/U=118k,5/0=100k, ROT=109k,with off bottom TQ=4-6k Page 9/35 Report Printed: 1/7/2016 w tperations Summary (with Timelogfepths) pp1C-155 t x nocd'hilbps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-TA Operation (ftKB) End Depth(ftKB) 11/15/2015 11/15/2015 0.50 SURFAC CEMENT CIRC P Circulate bottoms up while rotating 2,643.0 2,643.0 20:00 20:30 and reciprocating from 2643'MD t 2607'MD with 550gpm, 1154psi,28% flow out,40 rpm,3k WOB,6-9k TQ. P/U=118k,S/0=100k,ROT=109k, with off bottom TQ=4-6k 11/15/2015 11/15/2015 1.00 SURFAC CEMENT FIT P Rack stand to 2549'MD,blow down 2,643.0 2,549.0 20:30 21:30 topdrive,RU test euipmet an perform FIT obtaining 12.8ppg EMW. Pump additional 3bbl after break over @ 500psi for total of 51 stk. 11/15/2015 11/15/2015 1.25 INTRM1 DRILL DISP P Pump 40bbI high vis spacer,displace 2,549.0 2,649.0 21:30 22:45 well over to 9.3ppg LSND mud with 550gpm,850psi,flow out=30%, 40rpm,TQ=6-7,4851 stks total. 11/15/2015 11/16/2015 1.25 INTRM1 DRILL DDRL P Drill 12-1/4"intermediate hole section 2,649.0 2,740.0 22:45 00:00 form 2649'MD to 2740'MD/2462'TVD with 600 GPM,60 rpm,6-7k TQ,3k WOB,ECD=9.52ppg. Off bottom, 985psi,P/U=118k T,S/0=101 k, Rot=108k,4-6k TQ. AST=0.47,ART=0.16,Total bit hours 0.63,total jars= 169.43. 11/16/2015 11/16/2015 5.00 INTRM1 DRILL DDRL P Directional drilling 12-1/4"intermediate 2,740.0 3,058.0 00:00 05:00 hole from 2740'MD to 3058'MD/2625' TVD with 700gpm,1235psi,33%flow out,80 rpm,7k TQ,2-30k WOB,ECD 9.83ppg.P/U= 130k,S/0=100k,and ROT=113k. AST=1.63 ART=0.63,ADT=2.26 11/16/2015 11/16/2015 1.50 INTRM1 DRILL BKRM T PJSM for Backreaming out of the 3,058.0 2,552.0 05:00 06:30 hole/Backream out of hole from 3058' MD to 2552'MD with 700gpm, 1235psi,33%flow out, 100rpm,and 7k TQ. 11/16/2015 11/16/2015 0.50 INTRM1 DRILL SVRG P Service and inspect top drive 2,552.0 2,552.0 06:30 07:00 11/16/2015 11/16/2015 1.50 INTRM1 DRILL TRIP T Trip in hole from 2552'MD to 3058' 2,552.0 3,058.0 07:00 08:30 MD while obtaining directional surveys at 2742'MD,2837'MD,2931'MD, 3026'MD,3121'MD,3215'MD,3310' MD,3404'MD,3499'MD,and 3050' MD. P/U=130k S/0=100k ROT=113k. 11/16/2015 11/16/2015 1.00 INTRM1 DRILL CIRC T Circulate bottoms up while rotating 3,058.0 3,058.0 08:30 09:30 and reciprocating from 3058'MD to 3026'MD with 500gpm,750psi,27% flow out,60 rpm,8k TQ.P/U=113 S/0=100k ROT=113k.ECD=9.68ppg Page 10/35 Report Printed: 1/7/2016 tperations Summary (with Timelogfepths) 0 ,g1 ►Zt 1C-155 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/16/2015 11/16/2015 2.50 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 3,058.0 3,229.0 09:30 12:00 hole section from 3058'MD to 3229' MD/2709'TVD with 650gpm, 1130 psi, 31%flow out,80 rpm,on/off bottom7/6k TQ,2-8k WOB. ECD=9.76ppg. P/U=126k S/O= 107k,ROT=115k. AST=1.63 ART=0.63,ADT=2.26 11/16/2015 11/16/2015 6.00 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 3,229.0 3,615.0 12:00 18:00 hole section from 3229'MD to 3615' MD/2917'TVD with 700gpm, 1490psi,34%flow out,80 rpm,on/off bottom 8/6k TQ,8k WOB, ECD=9.91pg. P/U=130k S/O=111k, ROT=116k. AST=1.72,ART=0.75,ADT=2.47 Pumped 40bbl nut plug sweep @ 17:45 at 3590'MD 11/16/2015 11/17/2015 6.00 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 3,615.0 4,125.0 18:00 00:00 hole section from 3615'MD to 4125' MD/3186'TVD with 700gpm, 1500psi,33%flow out,80 rpm,on/off bottom 8/6k TQ,2-5k WOB. ECD=9.79ppg.P/U=145k S/O=113k. AST=1.73,ART=0.74,ADT=2.47 Pumped 30bbl nut plug sweep @ 22:30 at 4007'MD 11/17/2015 11/17/2015 5.25 INTRMI DRILL DDRL P Directional drill 12-1/4"intermediate 4,125.0 4,390.0 00:00 05:15 hole from 4125'MD to 4390'MD/ 3320'TVD with 700 gpm, 1470psi, 33%flow out,2-22k WOB, 100 rpm, 9k TQ.P/U=153k,S/O=111k,and ROT=128k AST=0.82,ART=0.3,ADT=1.12 11/17/2015 11/17/2015 3.00 INTRM1 DRILL BKRM T PJSM for backreaming out of hole. 4,390.0 3,499.0 05:15 08:15 Monitor well 10min.Backream out of hole from 4390'MD to 3499'MD with 700 gpm,1528psi,33%flow out,80 rpm.P/U=149k S/O=116k,and ROT=131 k. 11/17/2015 11/17/2015 2.00 INTRM1 DRILL TRIP T TIH from 3499'MD to 4390'MD with 3,499.0 4,390.0 08:15 10:15 700 gpm, 1478psi,33%flow out,20 rpm,and 6k TQ. 11/17/2015 11/17/2015 1.75 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 4,390.0 4,535.0 10:15 12:00 hole from 4390'MD to 4535'MD/ 3397'TVD with 700 gpm, 1466psi, 33%flow out,50k WOB,80 rpm,9k TQ.P/U=147k,S/O=114k,and ROT=130k. ECD=9.73ppg AST=2.0,ART=0.610,ADT=2.61 ; Total Bit hrs:13.82,Total Jars=182.62 Page 11/35 Report Printed: 1/7/2016 !perations Summary (with Timelogfepths) 0 1 1C-155 conoc hiiiiEss Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time `, End Time Dur(hr) r Phase Op Code Activity Code Time P-T-X Operation (5KB) l End Depth(ftKB) 11/17/2015 11/17/2015 6.00 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 4,535.0 5,009.0 12:00 18:00 hole from 4535'MD to 5009'MD/ 3606'TVD with 775 gpm,2004psi, 33%flow out, 10k WOB, 120 rpm, on/off bottom 11/10k TQ. P/U=164k, S/O=113k,and ROT=130k. ECD=9.79ppg AST=1.46,ART=1.27,ADT=2.73 11/17/2015 11/18/2015 6.00 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 5,009.0 5,576.0 18:00 00:00 hole from 5009'MD to 5576'MD/ 3783'TVD with 775 gpm,2100psi, 35%flow out,25k WOB, 120 rpm, 14/11k TQ.P/U= 164k,5/0=113k, and ROT=130k.ECD=9.72ppg AST=1.45,ART=1.28,ADT=2.73; Total Bit hrs: 19.28,Total Jars=188.08 11/18/2015 11/18/2015 6.00 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 5,576.0 6,035.0 00:00 06:00 hole from 5575'MD to 6035'MD/ 3855'TVD with 775gm,2205 psi,36% flow out, 120 rpm, 11k TQ, 11-22k WOB,and ECD=10.05ppg. P/U= 165k,S/O=108k,ROT=133k. AST=1.97 ART=1.36 ADT=3.34 11/18/2015 11/18/2015 5.50 INTRM1 DRILL DDRL P Directional drill 12-1/4"intermediate 6,035.0 6,413.0 06:00 11:30 hole from 6035'MD to 6413'MD/ 3899'TVD with 775gm,2205 psi,36% flow out, 120 rpm, 11k TQ, 11-22k WOB,and ECD=10.06ppg.P/U= 165k,S/0=108k,ROT=129k. AST=1.98 ART=1.37 ADT=3.34 11/18/2015 11/18/2015 0.25 INTRM1 CASING OWFF P PJSM,obtain directional survey and 6,413.0 6,413.0 11:30 11:45 monitor well for 10 min(static) 11/18/2015 11/18/2015 0.25 INTRM1 CASING BKRM P Backream out of hole from 6413'MD 6,413.0 6,337.0 11:45 12:00 to 6337'MD with 700 gpm,33%flow out, 120 rpm, 12k TQ. Concurrently, Mix in 240bb1 of 9.2ppg of new LSND into active. 11/18/2015 11/18/2015 6.00 INTRM1 CASING BKRM P Backream out of hole from 6337'MD 6,337.0 3,493.0 12:00 18:00 to 3493'MD with 700 gpm, 1480 psi, 33%flow out, 100 rpm,7-12k TQ at 1500ft/hr unless hole conditions dictated otherwise.PU=165k,S/0= 106k,ROT=129k.Monitor displacement via active pits. 11/18/2015 11/18/2015 2.75 INTRM1 CASING BKRM P Continue to backream from 3493'MD 3,493.0 2,606.0 18:00 20:45 to 2620'MD.FCP=1300psi,pump out of hole with no rotation while pulling through the shoe to 2606'MD with 600 gpm, 1050 psi,32%flow out while monitoring displacement via active pits. Page 12/35 Report Printed: 1/7/2016 4Pperations Summary (with Timelog!epths) 00 1C-155 Corillips I,kr.kn Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/18/2015 11/18/2015 0.75 INTRM1 CASING CIRC P Circulate bottoms up with rotating and 2,606.0 2,544.0 20:45 21:30 reciprocation from 2606'MD to 2544' MD at 600 gpm,1015 psi,29%flow out,60 rpm,5-7k TQ,for 3250stk. Pump 40bbl hi-vis sweep to surface at same parameters for 4447 stks. P/U=117k S/O wt=103k 11/18/2015 11/18/2015 0.25 INTRM1 CASING OWFF P Observe well for flow for 10min.(well 2,544.0 2,544.0 21:30 21:45 static) 11/18/2015 11/18/2015 1.00 INTRM1 CASING TRIP P Blow down top drive,POOH on 2,544.0 475.0 21:45 22:45 elevators from 2544'MD to 475'MD racking back 5"DP and HWDP. Monitor displacement via trip tank.P/U =75k,S/O=76k. 11/18/2015 11/19/2015 1.25 INTRM1 CASING PULD P Lay down 15 doubles of 5"DP. 475.0 475.0 22:45 00:00 SIMOPS-Mobilize 9-5/8"casing equipment to rig floor,buck up 4" doubles in pipe shed. 11/19/2015 11/19/2015 1.00 INTRM1 CASING BHAH P Lay down BHA from 475'MD to 410' 475.0 410.0 00:00 01:00 MD while monitoring displacement via Trip Tank 11/19/2015 11/19/2015 2.00 INTRM1 CASING BHAH T 6-1/4"Hydraulic jars partially cocked 410.0 410.0 01:00 03:00 when they reached rig floor. Attempted to trouble shoot jars at surface. Ran jars back below rotary and attemped to pump on jars with 600gpm,747psi,700gpm,995psi. Jars still failed to open(11"of 18.5"to open.)Discuss options and risk assess with CPAI and Weatherford Reps Chaz,Bryce,Brian). Decision made to lay out jars as is and continue pulling out of the hole.Lay down Jars and blow down Top Drive. 11/19/2015 11/19/2015 3.50 INTRM1 CASING BHAH P Continue laying down BHA from 410' 410.0 0.0 03:00 06:30 to surface. 12-1/8"non-mag top stabilizer worn on top and bottom of blades.Monitor well displacement via trip tank. 11/19/2015 11/19/2015 2.00 INTRM1 CASING RURD P Clean and clear rig floor,Drain bop 0.0 0.0 06:30 08:30 stack,pull wear pushing and remove strip-o-matic. 11/19/2015 11/19/2015 2.00 INTRM1 CASING RURD P PJSM for rigging up to run casing.Rig 0.0 0.0 08:30 10:30 up to run 9-5/8"casing. 11/19/2015 11/19/2015 1.50 INTRM1 CASING PUTB P Pick up/Make up 9-5/8"40#Hyd-563, 0.0 127.0 10:30 12:00 L-80 casing,Make up shoe track, Baker Loc'ing Joints#1 to pin end of Joint#4.Fill and check floats.Make up TQ=16kft/Ibs. Fill each joint on the fly and top off every 10jts run.Monitor displacement via Pit#1-2. Run in hole to 127'MD Page 13/35 Report Printed: 1/7/2016 Iterations Summary (with Timelogepths) 0 1C-155 Conoco'hilrps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/19/2015 11/19/2015 5.75 INTRM1 CASING PUTB P Fill and check floats.Continue running 127.0 2,455.0 12:00 17:45 in the hole with 9-5/8"40#Hyd-563,L- 80 casing from 127'MD to 2455'MD. Torque connections to 15kft/Ibs,fill pipe on fly and top off each 1 Ojts via volant casing running tool. Monitor displacement via Pits#2 and#3. PU =120k,S/O=107k. Noted 20k drag from 2400'MD to 2455'MD.(Install solid bow springs with sop rings on jt's 39 throu#46 on rig floor.) 11/19/2015 11/19/2015 0.50 INTRM1 CASING CIRC T Wash down jt#60 from 2455'MD t 2,455.0 2,539.0 17:45 18:15 2496'MD due to drag.Stage pumps to 3BPM,200psi, 18%flow out and RIH from 2496'MD to 2539'MD. 11/19/2015 11/19/2015 1.00 INTRM1 CASING CIRC T Circulate bottoms up while working 9- 2,539.0 2,580.0 18:15 19:15 5/8"casing from 2539'MD to 2580' MD. Circulation rate,gradully staged up to 6BPM, 187psi and 20%flow out during bottoms up circulation. 11/19/2015 11/20/2015 4.75 INTRM1 CASING PUTB P Continue running in hole with 9-5/8" 2,580.0 5,620.0 19:15 00:00 40#,Hydril-563 intermediate casing from 2580'MD to 5620'filling on fly and topping off each 10 jts. Monitor displacement via Pit#2 and Pit#3. S/O=118k 11/20/2015 11/20/2015 1.25 INTRM1 CASING PUTB P Cont RIH w/9-5/8",40#,L-80 Hyd 563 5,620.0 6,361.0 00:00 01:15 Intermediate csg f/5620-6361'MD filling on the fly and topping off each 10 jt's. Monitor displacement via pit 2 &3. SO=122K 11/20/2015 11/20/2015 0.75 INTRM1 CASING HOSO P M/U Vetco csg hgr,PU landing jt and 6,361.0 6,403.0 01:15 02:00 make up into hgr. Break circ @ 1.5 BPM, 215 PSI,5%flow. Wash down f/6361'and land csg @ 0157 hrs. 11/20/2015 11/20/2015 1.50 INTRM1 CEMENT CIRC P Stage rate up from 3 BPM,200 PSI, 6,403.0 6,403.0 02:00 03:30 17%flow to 5 BPM,260 PSI, 17% flow to a max of 6 BPM,330 PSI,21% flow. Circ total stks of 3900. Recip f/ 6402-6384'MD. PU=250K,SO= 115K. MW 9.3+ in and out 11/20/2015 11/20/2015 1.25 INTRMI CEMENT RURD P Swap to cement line,RU cement 6,403.0 6,403.0 03:30 04:45 hose,cont circ @ 6 BPM,390 PSI, 20%flow. PU=250K,SO=122K. Recip f/6402-6284'MD. 11/20/2015 11/20/2015 1.00 INTRM1 CEMENT RGRP T Cuttings tank hose started leaking. 6,403.0 6,403.0 04:45 05:45 Held PJSM to clean up mud and c/o hose. Cont circ @ 6 BPM,295 PSI, 18%flow. 11/20/2015 11/20/2015 0.75 INTRM1 CEMENT CMNT P PJSM f/Cmt job with Sch,MI&trk 6,403.0 6,403.0 05:45 06:30 drivers. Batch up cmt. Cont circ @ 6 BPM,297 PSI,17%flow. PU=255K, SO=121K. Circ total stks=13191 Page 14/35 Report Printed: 1/7/2016 operations Summary (with Timelog!epths) 0.w 1C-155 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P T X Operation -:: (ftKB) End Depth(ftKB) 11/20/2015 11/20/2015 2.75 INTRM1 CEMENT CMNT P SLB pumped 5.3 bbl 11.5 ppg 6,403.0 6,403.0 06:30 09:15 MudPush,PT lines to 3500 psi. Continue pumping 35 bbl MudPush @ 3 bpm,315 psi,8%flow out for a total of 40.2 bbl.Drop bottom Weatherford plug,pump 187 bbl 15.8 ppg cement @ 6 bpm,260 psi 22%flow out.Drop top Weatherford plug,kick out with 10 bbl water.Swap to rig pumps and displace with 464 bbl 9.3 ppg LSND @ 6 bpm,730 psi, 18%flow out.Slow pump rate in stages to 3 BPM @ 690 PSI, 17%flow. Bump plug @ 4619 stks,pressure up 500 psi over to 1212 psi and hold for 5 minutes.Bleed pressure to 0 psi,bled back 2.9 bbl. Check floats-good.Final P/U=230k, 5/0=70k.CIP:09:14 hrs 11-20-15. 11/20/2015 11/20/2015 1.00 INTRM1 CEMENT PRTS T PJSM. Attempted to test csg to 3500 6,403.0 6,403.0 09:15 10:15 PSI. At 2800 PSI sensator failed. Bled off and deferred test until prior to float drill-out. 11/20/2015 11/20/2015 1.75 INTRM1 CEMENT WWSP P Back-out landing jt,c/o elevators to 5" 0.0 0.0 10:15 12:00 DP. Set pack-off on hanger w/10K do and run in lock down screws. PT pack -off to 5000 PSI. Set wear bushing. 11/20/2015 11/20/2015 3.00 INTRM1 CEMENT RURD P Rig down Volant CRT. Install drilling 0.0 0.0 12:00 15:00 bails and 4"DP elevators. RU to perform LOT on OA. Perform weekly BOP ram function. Install 4"slip inserts. Service pipe skate. 11/20/2015 11/20/2015 3.25 INTRM1 CEMENT PULD P PU 4"DP and RIH for pipe 0.0 4,080.0 15:00 18:15 management to 4080'MD. 11/20/2015 11/20/2015 1.00 INTRM1 CEMENT LOT P Perform injection LOT on OA. Pump 4,080.0 4,080.0 18:15 19:15 166 stks @ 7 SPM. SI with 555 PSI f/ 10 min,bled to 380 PSI. Flush OA with 175 bbl fresh H2O staging up to 3 BPM @ 1 BPM-450 PSI,2 BPM- 685 PSI,3 BPM-790 to 830 PSI. Total pumped=1728 STKS 11/20/2015 11/20/2015 1.75 INTRM1 CEMENT PULD P Cont RIH picking up 4"DP f/4080- 4,080.0 6,073.0 19:15 21:00 6073'MD. 11/20/2015 11/20/2015 1.00 INTRM1 CEMENT TRIP P TOH standing back f/6073-4743' 6,073.0 4,743.0 21:00 22:00 MD. 11/20/2015 11/20/2015 0.75 INTRM1 CEMENT CIRC P CBU while ROT&RECIP f/4743- 4,743.0 4,743.0 22:00 22:45 4650'MD @ 550 GPM, 1020 PSI, 28%flow.Total pumped=2929 stks. Concurrent operations, Freeze protect 9-5/8"X 13-3/8"OA w/ Isotherm using Little Red Services. PT lines to 2200 PSI. Pump 136.2 bbl total @ 2.6 BPM,Initial Pres=700 PSI, Final Pres=870 PSI. Freeze Protect in place @ 2230hrs. Final SI =130 PSI.Estimated depth of Freeze Protect-2278 MD/2154 TVD. 11/20/2015 11/21/2015 1.25 INTRM1 CEMENT TRIP P Cont TOH standing back f/4743- 4,743.0 2,374.0 22:45 00:00 2374"MD. Page 15/35 Report Printed: 1/7/2016 Operations Summary (with Timelog!pths) 0 1C-155 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth. Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2015 '11/21/2015 1.00 INTRM1 CEMENT TRIP P Cont.TOH f/2374'MD-Surface 2,374.0 0.0 00:00 01:00 standing back 4"DP. 11/21/2015 11/21/2015 1.00 INTRM1 CEMENT PULD P RIH picking up 4"DP singles from 0.0 1,233.0 01:00 02:00 surface to 1233'MD. 11/21/2015 11/21/2015 1.00 INTRM1 CEMENT TRIP P TOH f/1233'MD-Surface standing 1,233.0 0.0 02:00 03:00 back 4"DP. 11/21/2015 11/21/2015 0.50 INTRM1 CEMENT BHAH P Mobilize remainder of 8-3/4"clean out 0.0 0.0 03:00 03:30 BHA to rig floor. Clean and clear floor in prep to RIH.Make up 8-3/4"BHA. 11/21/2015 11/21/2015 6.75 INTRM1 CEMENT TRIP P PJSM.RIH on 5"HWDP from Surface 0.0 6,219.0 03:30 10:15 to 1498.61'MD drifting to 2.25". RIH on 4"DP to 1971'MD and fill DP w/ mud. Continue to 3864'MD and fill DP.Cont RIH to 6219'MD. 11/21/2015 11/21/2015 ' 1.25 INTRM1 CEMENT CIRC P Rotate and recip f/6219'to 6179'MD 6,219.0 6,219.0 10:15 11:30 @ 30 RPM, 19K ft-lbs torque, 17% flow,6 BPM ramping up to 12 BPM, 1197 PSI,27%flow. PU=202K,SO =89K,ROT=124K,TQ=19K ft-lb. 11/21/2015 11/21/2015 1.25 INTRM1 CEMENT PRTS P PJSM. RU to pres test casing. Test 6,219.0 6,219.0 11:30 12:45 casing to 3500 PSI for 30 minutes on chart.59 stks to pressure up to 3600 psi and shut in.Bleed back 5.9bbls. Rig down and blow down test equipment. 11/21/2015 11/21/2015 3.50 INTRM1 CEMENT DRLG P Tag top of cement at 6286'MD. Drill 6,219.0 6,413.0 12:45 16:15 cement w/500 GPM, 1350 PSI,60 RPM, 18K ft-lbs, 14K WOB,27%flow. Top of plug @ 6315.5'and top of shoe @ 6401.65'MD. Drill plugs w/12K WOB. Clean out to 6413'MD. 11/21/2015 11/21/2015 0.25 INTRM1 CEMENT DDRL P Drill 20'of new hole from 6413-6433' 6,413.0 6,433.0 16:15 16:30 MD w/510 GPM, 1340 PSI,28% Flow, 100 RPM, 15K ft-lbs„ 18K WOB, PU=222K,SO=91K ADT =.24,Total Bit hrs=.24. Total jar hrs =.24. 11/21/2015 11/21/2015 2.25 INTRM1 CEMENT CIRC P Circ bottoms up while rot and recip f/ 6,433.0 6,267.0 16:30 18:45 6433-6351'MD. Rackback 1 stand and recip f/6359-6267'MD @ 650 GPM, 1920 PSI,35%flow, 100 RPM, 18K ft-lbs. Total pumped 19762 stks. MW in&out=9.2+. 11/21/2015 11/21/2015 1.00'INTRM1 CEMENT FIT P Perform FIT to 13.5 EMW. 15 stks 6,267.0 6,267.0 18:45 19:45 (1.5bbl)to pressure up to 850psi with 9.2+ppg LSND drilling fluid. 1.Ibbl bleed back. 11/21/2015 11/21/2015 1.75 PROD1 DRILL DISP P PJSM.Displace well to 9.2 PPG Faze 6,267.0 6,267.0 19:45 21:30 -Pro MOBM @ 424 GPM, 1270 PSI, 25%flow,80 RPM,10.5K ft-lbs,PU= 167K,SO=119K.Obtain SPR. 11/21/2015 11/21/2015 1.00 PROD1 DRILL OTHR P Pull PS-21's and clean Joe's box. 6,267.0 6,267.0 21:30 22:30 Blow down hole fill&jet lines. Clean flow line,under shakers and trough. 11/21/2015 11/21/2015 1.00 PROD1 DRILL SLPC P Cut and slip drill line(94ft). Continue 6,267.0 6,267.0 22:30 23:30 to clean flow line,under shakers and trough. Page 16/35 Report Printed: 1/7/2016 Operations Summary (with Timeloggepths) 0 • 3 1C-155 Conochilhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/21/2015 11/22/2015 0.50 PROD1 DRILL SVRG P Service top drive and blocks. 6,267.0 6,267.0 23:30 00:00 Calibrate block height. Prep to POH. 11/22/2015 11/22/2015 4.00 PROD1 DRILL TRIP P PJSM. POH f/6267-1498'MD. 6,267.0 0.0 00:00 04:00 Monitor well. Continue POH while monitoring well via trip tank. PU= 177K,SO=115K. Recover 2.38"Drift on top of jars. 11/22/2015 11/22/2015 0.50 PROD1 DRILL RURD P Clean and clear rig floor. 0.0 0.0 04:00 04:30 11/22/2015 11/22/2015 2.00 PROD1 DRILL RURD P PJSM. Change out saver sub to 4"XT 0.0 0.0 04:30 06:30 -39. Torque to 42K ft-lbs. 11/22/2015 11/22/2015 1.75 PROD1 DRILL BHAH P PJSM. Make up 6-3/4"production 0.0 377.0 06:30 08:15 BHA to 377'MD. 11/22/2015 11/22/2015 1.75 PROD1 DRILL PULD P RIH on 4"DP picking up doubles to 377.0 1,705.0 08:15 10:00 1705'MD. 11/22/2015 11/22/2015 1.00 PROD1 DRILL DHEQ P Shallow hole test MWD @ 1705'MD, 1,705.0 1,705.0 10:00 11:00 210 GPM,905 PSI, 18%flow,Blow do top drive. 11/22/2015 11/22/2015 3.50 PROD1 DRILL PULD P Continue picking up 4"doubles from 1,705.0 6,354.0 11:00 14:30 1705'-6354'MD. Fill pipe every 2000'. PU=82K,SO=82K. 11/22/2015 11/22/2015 0.25 PROD1 DRILL REAM P Wash and ream to bottom at 250 6,345.0 6,433.0 14:30 14:45 GPM, 1840 PSI, 17%flow,80,RPM, 3.5K ft-lbs TQ. 11/22/2015 11/22/2015 3.25 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/6433- 6,433.0 6,659.0 14:45 18:00 6659'MD @ 280 GPM,2470 PSI, 19%flow, 150 RPM,5K ft-lbs TQ,5K WOB,ECD=9.72,Off bottom pres= 2450 PSI,PU=108K,SO=89K,ROT =98K,3.5K ft-lbs TQ of bottom, ART/ADT=2.41 hrs,Total bit hrs= 2.41,Total jar hrs=2.41. 11/22/2015 11/23/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/6659- 6,659.0 7,378.0 18:00 00:00 7378'MD @ 290 GPM,2810 PSI, 20%flow, 190 RPM,6K ft-lbs TQ,2K WOB,ECD=10.02,Off bottom pres= 2800 PSI,PU= 108K,SO=88K,ROT =98K,4K ft-lbs TQ of bottom, ART/ADT=4.15 hrs,Total bit hrs= 6.56,Total jar hrs=6.56. No mud losses for the day 11/23/2015 11/23/2015 1.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/7378- 7,378.0 7,490.0 00:00 01:00 7490'MD,3895'TVD,@ 290 GPM, 2815 PSI on Bot,2615 PSI off Bot, 21%flow, 190 RPM, 1-2K WOB,ECD =9.98,PU=111K,SO=86K,ROT= 97K,5K ft-lbs TQ on bottom,4K ft-lbs TQ off bottom 11/23/2015 11/23/2015 1.00 PROD1 DRILL CIRC T Downlink Power Drive. 290 GPM, 7,490.0 7,490.0 01:00 02:00 2615 PSI,21%flow,circ 3050 stks, ECD=9.83 11/23/2015 11/23/2015 4.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/7490- 7,490.0 7,858.0 02:00 06:00 7858'MD,3898'TVD,@ 290 GPM, 2652 PSI on Bot,2630 PSI off,Bot, 21%flow, 190 RPM,2-8K WOB, ECD=9.78,PU= 112K,SO=86K, ROT=98K,8K ft-lbs TQ on bottom, 4K ft-lbs TQ off bottom Page 17/35 Report Printed: 1/7/2016 0 !perations Summary (with Timelogtepths) ►y 1C-155 ConocoPhdlips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth '... Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/23/2015 11/23/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/7858- 7,858.0 8,305.0 06:00 12:00 8305'MD,3889'TVD,@ 290 GPM, 2815 PSI on Bot,2673 PSI off Bot, 20%flow, 150 RPM,2-8K WOB, ECD=9.91,PU=120K,SO=80K, ROT=96K,5K ft-lbs TQ on bottom, 4K ft-lbs TQ off bottom ART/ADT= 8.16 hrs,Total bit hrs=14.72,Total jar hrs=14.72. 11/23/2015 11/23/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/8305- 8,305.0 8,890.0 12:00 18:00 8890'MD,3875'TVD,@ 290 GPM, 2680 PSI on Bot,2660 PSI off Bot, 21%flow, 150 RPM, 1K WOB,ECD= 10.01,PU=113K,SO=81K,ROT= 97K,5K ft-lbs TQ on bottom,4K ft-lbs TQ off bottom ART/ADT=4.83 hrs, Total bit hrs=19.48,Total jar hrs= 19.48. 11/23/2015 11/24/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/8890- 8,890.0 9,309.0 18:00 00:00 9309'MD,3896'TVD,@ 295 GPM, 3005 PSI on Bot,3000 PSI off Bot, 21%flow, 170 RPM,3K WOB,ECD= 10.27,PU=124K,SO=75K,ROT= 100K,7K ft-lbs TQ on bottom,6K ft- lbs TQ off bottom ART/ADT=3.98 hrs,Total bit hrs=23.46,Total jar hrs =23.46. Losses for tour=0 BBLS 11/24/2015 11/24/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/9309- 9,309.0 9,620.0 00:00 06:00 9620'MD,3898'TVD,@ 295 GPM, 3130 PSI on Bot,2865 PSI off Bot, 21%flow, 170 RPM, 1K WOB,ECD= 10.19,PU=124K,SO=72K,ROT= 100K,6K ft-lbs TQ on bottom,6K ft- lbs TQ off bottom ART/ADT=5.36 hrs,Total bit hrs=28.82,Total jar hrs =28.82. 11/24/2015 11/24/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/9620- 9,620.0 9,968.0 06:00 12:00 9968'MD,3895'TVD,@ 291 GPM, 2905 PSI on Bot,2868 PSI off Bot, 22%flow,90 RPM, 1K WOB,ECD= 10.19,PU=125K,SO=71K,ROT= 98K,6K ft-lbs TQ on bottom,6K ft-lbs TQ off bottom ART/ADT=3.55 hrs, Total bit hrs=32.25,Total jar hrs= 32.25. Losses for tour=0 BBLS 11/24/2015 11/24/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/9968- 9,968.0 10,324.0 12:00 18:00 10324'MD,3888'TVD,@ 290 GPM, 3005 PSI on Bot,3000 PSI off Bot, 20%flow, 150 RPM,2K WOB,ECD= 10.44,PU=124K,SO=72K,ROT= 99K,7.0K ft-lbs TQ on bottom,6.5K ft- lbs TQ off bottom ART/ADT=5.22 hrs,Total bit hrs=37.47,Total jar hrs =37.47. Page 18/35 Report Printed: 1/7/2016 • Operations Summary (with Timelog Depths) 1C-155 ConocoPhiflips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/24/2015 11/25/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/10324 10,324.0 10,619.0 18:00 00:00 -10619'MD,3878'TVD,@ 295 GPM, 3015 PSI on Bot,3000 PSI off Bot, 21%flow,90 RPM,2K WOB,ECD= 10.37,PU=129K,SO=70K,ROT= 100K,7.0K ft-lbs TQ on bottom,7K ft- lbs TQ off bottom ART/ADT=4.29 hrs,Total bit hrs=41.76,Total jar hrs =41.76.Losses for tour=0 BBLS 11/25/2015 11/25/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/10619 10,619.0 11,229.0 00:00 06:00 -11229'MD,3877'TVD,@ 295 GPM, 3255 PSI on Bot,3250 PSI off Bot, 21%flow, 160 RPM, 1K WOB,ECD= 10.70,PU=123K,SO=69K,ROT= 101K,7.0K ft-lbs TQ on bottom,6.5K ft-lbs TQ off bottom ART/ADT=4.69 hrs,Total bit hrs=46.45,Total jar hrs =46.45. 11/25/2015 11/25/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/11229 11,229.0 11,795.0 06:00 12:00 -11795'MD,3878'TVD,@ 275 GPM, 3115 PSI on Bot,3100 PSI off Bot, 22%flow, 160 RPM, 1K WOB,ECD= 10.34,PU=132K,SO=60K,ROT= 100K,7.0K ft-lbs TQ on bottom,6.5K ft-lbs TQ off bottom ART/ADT=4.76 hrs,Total bit hrs=51.21,Total jar hrs =51.21.No mud loss. OA= 180 PSI 11/25/2015 11/25/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/11795 11,795.0 12,325.0 12:00 18:00 -12325'MD,3879'TVD,@ 295 GPM, 3190 PSI on Bot,3150 PSI off Bot, 21%flow,160 RPM,2K WOB,ECD= 10.68,PU=132K,SO=58K,ROT= 99K,7.5K ft-lbs TQ on bottom,7.0K ft- lbs TQ off bottom ART/ADT=4.94 hrs,Total bit hrs=56.15,Total jar Firs =56.15. 11/25/2015 11/26/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/12325 12,325.0 12,844.0 18:00 00:00 -12844'MD,3878'TVD,@ 290 GPM, 3275 PSI on Bot,3270 PSI off Bot, 20%flow, 160 RPM,2K WOB,ECD= 10.74,PU=130K,SO=61K,ROT= 100K,8K ft-lbs TQ on bottom,7.0K ft- lbs TQ off bottom ART/ADT=4.45 hrs,Total bit hrs=60.60,Total jar hrs =60.60. No mud loss. OA=200 PSI 11/26/2015 11/26/2015 6.00 PROD1 DRILL DDRL P Drilling 6-3/4"production hole f/12844 12,844.0 13,435.0 00:00 06:00 -13435'MD,3876'TVD,@ 290 GPM, 3770 PSI on Bot,3770 PSI off Bot, 21%flow, 160 RPM, 1K WOB,ECD= 10.97,PU=133K,SO=57K,ROT= 90K,8K ft-lbs TQ on bottom,7.0K ft- lbs TQ off bottom ART/ADT=4.57 hrs,Total bit hrs=65.27,Total jar hrs =65.27. No mud loss. OA=200 PSI 11/26/2015 11/26/2015 0.75 PROD1 CASING CIRC P Rotate and Recip f/13435-13365 13,435.0 13,435.0 06:00 06:45 'MD,@ 309 GPM,3770 PSI,22% flow, 180 RPM,PU=133K,SO=57K, ROT=90K, 7.0K ft-lbs TQ off bottom. Displaced OH volume w/fresh mud. Pumped 2025 stks, Page 19/35 Report Printed: 1/7/2016 Operations Summary (with Timelo Depths) # • ON 1C-155 cont iiilhps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/26/2015 11/26/2015 5.25 PROD1 CASING BKRM P PJSM. BROOH f/13435-10907'MD. 13,435.0 10,907.0 06:45 12:00 295 GPM,3650 PSI,22%flow,100 RPM,PU=133K,SO=57K,ROT= 90K, 7.0K ft-lbs TQ off bottom. OA=180 PSI. Loss for tour=0 BBLS. 11/26/2015 11/26/2015 8.00 PROD1 CASING BKRM P Cont.BROOH f/10907-6070'MD. 10,907.0 6,070.0 12:00 20:00 290 GPM,2435 PSI, 19%flow, 100 RPM,PU=105K,SO=88K, 6.0K ft- lbs TQ, 1500 FPH. 11/26/2015 11/26/2015 0.75 PROD1 CASING CIRC P Drop Ball for Well Commander Tool 6,070.0 6,588.0 20:00 20:45 and RIH f/6070'to 6588'MD. Pump ball down at 2 BPM,480 PSI. Ball on seat at 209 stks. Pres up to 1300 PSI and hold f/30 sec. Continue to pres to 1660 PSI and observe activation. Confirm tool is open pumping 85 GPM at 330 PSI. 11/26/2015 11/26/2015 1.25 PROD1 CASING BKRM P Cont.BROOH f/6588-5875"MD. 6,588.0 5,875.0 20:45 22:00 500 GPM,2230 PSI,28%flow,60 RPM,4.0K ft-lbs TQ, 1500 FPH. 11/26/2015 11/26/2015 0.50 PROD1 CASING SVRG P Service top drive and blocks. 5,875.0 5,875.0 22:00 22:30 11/26/2015 11/27/2015 1.50 PROD1 CASING BKRM P Cont.BROOH f/5875-4931'MD. 5,875.0 4,931.0 22:30 00:00 500 GPM, 1910 PSI,28%flow,60 RPM,3.0K ft-lbs TQ, 1500 FPH. OA=130 PSI Loss for tour=0 BBLS 11/27/2015 11/27/2015 5.50 PROD1 CASING BKRM P Cont.BROOH f/4931 -1895'MD. 4,931.0 1,895.0 00:00 05:30 500 GPM,950 PSI,28%flow,60 RPM, 1.5K ft-lbs TQ, 1500 FPH. 11/27/2015 11/27/2015 1.00 PROD1 CASING CIRC P Monitor well. Pump 45 BBL Hi Vis 1,895.0 1,895.0 05:30 06:30 sweep and chase @ 500 GPM, 1023 PSI,29%Flow. Total strokes circulated=2500. 11/27/2015 11/27/2015 0.50 PROD1 CASING CIRC P Drop 1.75"ball to close Well 1,895.0 1,895.0 06:30 07:00 Commander. Chase @ 2 BPM, 105 PSI,14%Flow,Ball on seat @ 42 stks. Pres up to 800 PSI f/30 sec. Increase to 1400 PSI to shift closed. Circ @ 2 BPM,230 PSI and 5 BPM @ 900 PSI to confirm closed. Blow down top drive. 11/27/2015 11/27/2015 3.00 PROD1 CASING TRIP P PJSM. RIH f/1895-7018'MD filling 1,895.0 7,018.0 07:00 10:00 DP every 20 stands. 11/27/2015 11/27/2015 1.00 PROD1 CASING BHAH P PJSM. Change slip inserts to hand 7,018.0 7,063.0 10:00 11:00 slips. MU scraper and brush assembly to 7063'MD. 11/27/2015 11/27/2015 3.50 PROD1 CASING TRIP P RIH f/7063-13357'MD. PU=139K, 7,063.0 13,357.0 11:00 14:30 SO=62K. 11/27/2015 11/27/2015 2.75 PROD1 CASING CIRC P PU to 13433'MD. Circ thru bit while 13,357.0 13,433.0 14:30 17:15 rotating and recip from 13433-13349' MD @ 295 GPM,3520 PSI,20%flow, 150 RPM,7.5K ft-lbs TQ,10.95 ECD, Mud wt in=9.1,Out=9.0 PPG. Total pumped=11600 Stks. Page 20/35 Report Printed: 1/7/2016 Operations Summary (with Timelo 0 III Depths) .,� 9 1C-155 Como;Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time, End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) P End Depth(ftKB) 11/27/2015 11/27/2015 0.50 PROD1 CASING CIRC P Drop 2.115"ball to open Well 13,433.0 13,433.0 17:15 17:45 Commander. Chase @ 2 BPM,840 PSI. Ball on seat @ 334 stks. Pres up to 1000 PSI f/30 sec. Increase to 1620 PSI to shift open. Circ @ 2 BPM,300 PSI and 5 BPM @ 900 PSI to confirm open. 11/27/2015 11/27/2015 1.25 PROD1 CASING CIRC P PU to 13425'MD. Circ thru Well 13,433.0 13,425.0 17:45 19:00 Commander while rotating and recip from 13425-13349'MD w/Well Commander at 6395-6320'MD @ 600 GPM,3080 PSI,31%flow,80 RPM,7.5K ft-lbs TQ,Mud wt in=9.1, Out=9.0 PPG. Total pumped=9693 Stks. 11/27/2015 11/27/2015 0.50 PROD1 CASING CIRC P Drop 2.115"ball to close Well 13,425.0' 13,425.0 19:00 19:30 Commander. Chase @ 2 BPM,310 PSI, Ball on seat @ 326 stks. Pres up to 1490 PSI f/30 sec to shift closed. Circ @ 2 BPM,850 PSI to confirm closed. Verify w/good MWD detection. 11/27/2015 11/28/2015 4.50 PROD1 CASING CIRC P Pump 95 Bbl of 9.75 PPG spacer and 13,425.0 13,425.0 19:30 00:00 displace well to 9.4 PPG EMS 6800 SFMOBM @ 3.5 BPM, 1240 PSI, 18% Flow. Pumping directly from vac truck. Total pumped 9018 strokes. 11/28/2015 11/28/2015 0.25 PROD1 CASING OWFF P Monitor well for 10 minutes. Static. 13,425.0 13,425.0 00:00 00:15 PU=127K,SO=72K,ROT=94K. Obtain SPR's. 11/28/2015 11/28/2015 8.75 PROD1 CASING PMPO P Pump out of hole from 13425-7063' 13,425.0 7,063.0 00:15 09:00 MD @ 5 SPM, 125 PSI,PU=127K. Pumping DP capacity plus.5 BBL/ stand. 11/28/2015 11/28/2015 2.00 PROD1 CASING BHAH P LD part of BHA consisting of Baker 7,063.0 7,018.0 09:00 11:00 brush,scraper,Well Commander and ball catcher. Retrieve activation balls. 11/28/2015 11/28/2015 1.00 PROD1 CASING PMPO P Cont.to Pump OOH f/7018-6354' 7,018.0 6,354.0 11:00 12:00 MD @ 5 SPM, 105 PSI,PU=108K. 11/28/2015 11/28/2015 7.50 PROD1 CASING OTHR P Clean rig floor,drain pan,joes box 6,354.0 6,354.0 12:00 19:30 and flow line. Remove all hatches and sleeves on flow line and clean. Recovered several large chunks of SafeCarb and cuttings in the flow line. Clean trip tank. Simops slip and cut drill line. Bring 128 Super Sliders to rig floor. 11/28/2015 11/28/2015 3.00 PROD1 CASING TRIP P TOH from 6354-377'MD. 6,354.0 377.0 19:30 22:30 11/28/2015 11/29/2015 1.50 PROD1 CASING BHAH P LD BHA#5 f/377'-48'MD. 377.0 48.0 22:30 00:00 Losses for tour=7 BBL. OA=120 PSI 11/29/2015 11/29/2015 2.00 PROD1 CASING BHAH P Lay down BHA consisting of 48.0 0.0 00:00 02:00 Periscope,Powerdrive and Bit. Bit graded 1,2 and BHA looked in good shape with no damage. C/O slip inserts and install mousehole in rotary table. Page 21/35 Report Printed: 1/7/2016 III erations Summary (with Timelo •# 0 De the 0:73 pg p 1C-155 Conoco hillps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-Xi Operation (ftKB) End Depth(ftKB) 11/29/2015 11/29/2015 5.25 PROD1 CASING PULD P Lay down 51 doubles in shed and 0.0 0.0 02:00 07:15 send out 111 singles. Flagging singles w/bad hard bands to be repaired. Monitor well w/hole fill via trip tank. Cleaning surface equipment and mud pits. 11/29/2015 11/29/2015 2.25 PROD1 WHDBOP RURD P LD mousehole,pull wear bushing and 0.0 0.0 07:15 09:30 set test plug. RU to test BOPE. 11/29/2015 11/29/2015 6.50 PROD1 WHDBOP BOPE P Test BOPE for all tests at 0.0 0.0 09:30 16:00 Low=250psi/5min,High=3500psi/5min w/exception of Man.Operated& Super choke tested to Low=250psi/5min, High=2000psi/5min. Used 2-7/8"test jt to test annular and 2-7/8"x 5-1/2" LPR,Used 5-1/2"test jt to test annular,2-7/8"x 5-1/2"LPR,choke valves 1-15,Manual Operated and Super choke,Choke and Kill manual valve and NCR's,4"valve on kill line, 4"TIW,4"Dart, 2-7/8"TIW,2-7/8" Dart,5"TIW and 5"Dart,upper and lower IBOP's, Perform Koomey drawdown: Accumulator Pressure: 3000psi,Manifold Pressure: 1500psi, ACC=1650 after all functions on bottles,21 sec for 200psi build with 2 electric pumps. 112 sec to build full system pressure with 2 electric pumps and 2 air pumps. Closing times for Annular=24 sec,Blind/Shears=21 sec, LPR=23sec,Choke HCR=2sec.and Kill HCR=2sec. Kill line 4 way valve at the accumulator had a small leak. Installed rebuild kit and retested GOOD. Witness by Jeff Jones w/ AOGCC. 11/29/2015 11/29/2015 0.50 PROD1 WHDBOP RURD P RD BOPE test equip. Drain stack and 0.0 0.0 16:00 16:30 blow down lines. 11/29/2015 11/29/2015 0.50 PROD1 WHDBOP RURD P Pull test plug and set wear bushing 0.0 0.0 16:30 17:00 11/29/2015 11/29/2015 4.50 PROD1 CASING PULD P Lay down 44 stands via mousehole in 0.0 0.0 17:00 21:30 singles. Monitor well with trip tank. 11/29/2015 11/29/2015 0.75 PROD1 CASING OTHR P Change elevators and move 16 stands 0.0 0.0 21:30 22:15 of 5"HWDP from Off Drillers Side to Drillers Side. 11/29/2015 11/30/2015 1.75 PROD1 CASING PULD P Continue laying down 15 more 4"DP 0.0 0.0 22:15 00:00 stands in singles via mousehole. Monitor well with trip tank. 11/30/2015 11/30/2015 1.50 PROD1 CASING PULD P Continue laying down 10 remaining 4" 0.0 0.0 00:00 01:30 DP stands in singles via mousehole. Monitor well with trip tank. Cleaning pits. 11/30/2015 11/30/2015 2.25 PROD1 CASING RURD P Lay down mousehole,change 0.0 0.0 01:30 03:45 elevators to 5"and clear rig floor. C/O saver sub to 4-1/2"IF,C/O slip inserts. SIMOPS cleaning pits and RU hardline in cellar to flow back tank for spent acid. Page 22/35 Report Printed: 1/7/2016 ei Operations Summary (with Timeloggepths) 0 1C-155 Coco` noPGps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr)- Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/30/2015 11/30/2015 7.00 PROD1 CASING TRIP P Make up mule shoe and magnet and 0.0 6,329.0 03:45 10:45 RIH w/5"DP installing super sliders on every joint to stand#49,total of 147 sliders. Run 51 stands of 5"DP and 16 stands of HWDP to 6329'MD. SIMOPS cleaning pits. 11/30/2015 11/30/2015 0.50 PROD1 CASING SVRG P Service top drive,blocks and iron 6,329.0 6,329.0 10:45 11:15 roughneck. SIMOPS clean pits. 11/30/2015 11/30/2015 0.75 PROD1 CASING OTHR P Cleaning pits,clean rig floor prior to 6,329.0 6,329.0 11:15 12:00 acid job. 11/30/2015 11/30/2015 3.75 PROD1 CASING RURD P RU Schlumberger Acid Pumpers. 6,329.0 6,329.0 12:00 15:45 SIMOPS cleaning pits and shakers. OA=100 psi 11/30/2015 11/30/2015 5.75 PROD1 CASING CIRC P PJSM. Pickle drillpipe prior to 6,329.0 6,329.0 15:45 21:30 completion by pumping 5 BBLS of High-Vis brine, 10 BBLS DeepClean, 6 BBL High-Vis brine. Valve on acid tank was frozen shut. Thaw out and pump 11.9 BBLS 15%HCL. Chase w/ 5 BBLS of High-Vis brine. Displace with 72.5 BBLS of 9.4 PPG brine using rig pumps. ICP=150 PSI,FCP =97 PSI. Close annular and reverse circulate with SFOBM taking returns to tank with a 1"quarter turn valve used as a restriction at 2 BPM,ICP=135 PSI,FCP=280 PSI,drillstring vol.= 98.3 BBLS. Pumped 125 BBLS. 11/30/2015 11/30/2015 0.50 PROD1 CASING RURD P Rig down and blow down hardline to 6,329.0 6,329.0 21:30 22:00 cellar and injection line. 11/30/2015 12/1/2015 2.00 PROD1 CASING CIRC P Circ bottoms up while rotating and 6,329.0 6,329.0 22:00 00:00 recip from 6329—6237'MD @ 84 GPM, 180 PSI, 12%flow,20 RPM and 5K TQ. OA=270 PSI. Ata 1.3 bottoms up started getting a sludge across the 325 mesh shakers as mud was being cleaned up. OA=270 PSI 12/1/2015 12/1/2015 1.00 PROD1 CASING CIRC P Continue circulating bottoms up while 6,329.0 6,329.0 00:00 01:00 rotating and recip from 6329— 6237'MD @ 84 GPM, 180 PSI, 12% flow,20 RPM,5K TQ. Total pumped 6000 Stks. 12/1/2015 12/1/2015 2.50 PROD1 CASING CIRC P Continue circulating bottoms up while 6,329.0 6,329.0 01:00 03:30 rotating and recip from 6329— 6237'MD. Stage pumps up to 210 GPM,380 PSI, 16%flow,20 RPM. Total pumped 10781 Stks. Shut down pumps to clean,inspect and C/O shaker screens. PU=169K,SO= 154K. 12/1/2015 12/1/2015 2.50 PROD1 CASING CIRC P Displace well to new SFOBM direct 6,329.0 6,329.0 03:30 06:00 from truck to mud pumps staging pumps up to 147 GPM while rot& recip f/6329—6237'MD,flow=16%, 235 PSI,5K TQ,Total pumped 5280 Stks. Page 23/35 Report Printed: 1/7/2016 'A' Operations Summary (with Timeloggepths) O 1C-155 ConocaPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/1/2015 12/1/2015 6.00 PROD1 CASING CIRC P Continue circulating bottoms up while 6,329.0 6,329.0 06:00 12:00 rotating and recip from 6329— 6237'MD @ 168 GPM,255 PSI, 16% flow,20 RPM,5K TQ. Total pumped 8400 Stks. Mud samples still not passing,continue pumping over 325 mesh shakers. 12/1/2015 12/1/2015 8.00 PROD1 CASING CIRC P Continue circulating bottoms up while 6,329.0 6,329.0 12:00 20:00 rotating and recip from 6329— 6237'MD @ 210 GPM,310 PSI, 14% flow,20 RPM,5K TQ. Total pumped 35568 Stks. Mud wt in&Out=9.4 PPG,PU=172K,SO=161K. At 2200 hrs mud passed PST test. 12/1/2015 12/1/2015 0.50 PROD1 CASING OWFF P Monitor well for 30 minutes. Blow 6,329.0 6,329.0 20:00 20:30 down top drive and prep to POH. 12/1/2015 12/1/2015 2.25 PROD1 CASING TRIP P TOH from 6329-1961'MD monitoring 6,329.0 1,961.0 20:30 22:45 displacement via trip tank. Clean and inspect super sliders/clamps per\NWT rep. At the bottom of stand#22 the super slider was missing. 12/1/2015 12/2/2015 1.25 PROD1 CASING FISH T Drain stack and found super slider in 1,961.0 1,961.0 22:45 00:00 bottom of stack. Fished slider from stack by holding drillpipe to side of stack and recovered above the annular preventer. 12/2/2015 12/2/2015 1.50 PROD1 CASING TRIP P TOH from 1961'MD to surface. LD 1,961.0 0.0 00:00 01:30 magnet and mule shoe. 12/2/2015 12/2/2015 1.50 COMPZN CASING RURD P Clean and clear rig floor,C/O slips. 0.0 0.0 01:30 03:00 RU casing tongs and casing running equipment. 12/2/2015 12/2/2015 2.00 COMPZN CASING OTHR P Drain stack,MU liner hanger and seal 0.0 03:00 05:00 bore extension. Rack back in derrick. Hold PJSM. 12/2/2015 12/2/2015 0.50 COMPZN CASING PUTB P PU shoe and first jt. MU crossover 0.0 65.0 05:00 05:30 and RIH to 65'MD Establish circ at 1 BPM,87 PSI to check floats. Blow down top drive. 12/2/2015 12/2/2015 12.00 COMPZN CASING PUTB P RIH w/4-1/2", 11.6#,L-80,HYD 563, 65.0 7,141.0 05:30 17:30 Excluder screens and blank 4-1/2" liner from 65—7141'MD. Fluid loss for tour=8 BBLS. 12/2/2015 12/2/2015 0.50 COMPZN CASING OTHR P Make up liner hanger and RIH to re- 7,141.0 7,141.0 17:30 18:00 torque FLCV(Baker noticed it was handy). PU to set string in tension and rack back liner hanger. PU= 112K,SO=90K. 12/2/2015 12/2/2015 0.50 COMPZN CASING RURD P RU false table to run 2-7/8"Washpipe. 7,141.0 7,141.0 18:00 18:30 12/2/2015 12/3/2015 5.50 COMPZN CASING PULD P RIH with 2-7/8",6.5#,L-80,HYD 511 7,141.0 7,141.0 18:30 00:00 washpipe inner string. 12/3/2015 12/3/2015 2.50 COMPZN CASING PULD P Continue RIH with 2-7/8"Hydril 511 7,141.0 7,167.0 00:00 02:30 inner string from 4213'MD to 7167' MD,monitor displacement via trip tank. Page 24/35 Report Printed: 1/7/2016 Or 0 Operations Summary (with Timelog!epths) 1C-155 CNX:so: "hit tips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2015 12/3/2015 1.50 COMPZN CASING HOSO P P/U jt#240,observe entry into 7,167.0 7,167.0 02:30 04:00 packoff bushing 11'down and no-go out 25'down on jt 240.P/U and verify on depth.L/D jt 240 and 239,P/U FLCV shifting tool,XO and 10'pup for space out.P/U 2-7/87"EUE jt-30.95' and M/U.P/U=64k,S/O=57k. 12/3/2015 12/3/2015 1.00 COMPZN CASING OTHR P Change out elevators,P/U HRDE ZXP 7,167.0 7,238.0 04:00 05:00 packer assembly with SBE and FLCV. M/U to 2-7/8"inner string and 5W H563 tubing.RIH from 7143'MD to 7214'MD,mix and pour in Pal Mix. SIMOPS-R/D false rotary,tongs and 2-7/8"handling equipment.M/U 7" Well Commander and Baker magnet, RIH to 7238'MD. 12/3/2015 12/3/2015 1.00 COMPZN CASING RUNL P Run liner on drill pipe from 7238'MD 7,238.0 7,424.0 05:00 06:00 to 7424'MD,M/U top drive and establish circ @ 1 bpm,240 psi, 1% flow out.Remove master bushings, install PS-21 hydraulic slips,blow down top drive.P/U=139k,S/0=111 k. 12/3/2015 12/3/2015 4.75 COMPZN CASING RUNL P Continue run liner on 5"DP and 7,424.0 13,369.0 06:00 10:45 HWDP from 7424'MD to 13369'MD, monitoring displacement via trip tank. Fill pipe every 1500'. 12/3/2015 12/3/2015 0.50 COMPZN CASING HOSO P Fill pipe and establish circulation @ 2 13,369.0 13,395.0 10:45 11:15 bpm,750 psi,4%flow out.Wash down from 13369'MD to 13435'MD tagging bottom on depth.P/U 40'to set depth 13395'MD. 12/3/2015 12/3/2015 4.00 COMPZN CASING PACK P Break out top drive and drop 1" 13,395.0 13,395.0 11:15 15:15 hanger setting ball. Pump down @ 2 bpm,860 psi,6%flow out.Reduce rate to 1 bpm @ 600 stks,570 psi,7% flow out. Cont.pumping and at 1600 stks surge pump to 4 BPM and cont pumping. Slow to 2 BPM,890 PSI and saw ball on seat at 1978 stks. Pres up to 3300 PSI and set hanger. Bleed pres and slack off to verify hanger is set. Pres up to shear out ball,tried 5 attempts with mud pumps to 4400 PSI. Swapped to test pump and pres up to 4600 PSI to shear out. Est circ @ 1 BPM,540 PSI.P/U=230k, S/0=93k. OA pressure @ 12:00 hrs=160 psi. 12/3/2015 12/3/2015 0.50 COMPZN WELLPR PULD P Lay down double&blowdown 13,395.0 13,395.0 15:15 15:45 topdrive. SIMOPS-Making spacers for upcoming brine displacement. 12/3/2015 12/3/2015 0.75 COMPZN WELLPR SFTY P Hold PJSM w/COPA,DDI,SWACO, 13,395.0 13,395.0 15:45 16:30 PEAK and ASRC on pumping procedure. Continue Staging trucks and building spacers for displacement. Page 25/35 Report Printed: 1/7/2016 • 0 8 Operations Summary (with Timeloggepths) 0 1C-155 Co iiIips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase . Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/3/2015 12/4/2015 7.50 COMPZN WELLPR DISP P Displace well to brine pumping 13,395.0 13,395.0 16:30 00:00 spacers as follows: 20 BBLS LVT,70 BBLS High-Vis spacer,75 BBL Citric Acid Spacer then 40 BBL of High-Vis spacer. Followed spacers with 870 BBP of 9.4 PPG brine and 690 BBLS of 9.2 PPG brine. NACL filtered Brine included 3%KCL and 1%Safe-Break. Pumped @ 6 BPM, 1985 PSI, 14% Flow,Final MW=9.2 PPG In&Out. Had to SD pumping for 10 min to blow down line during a valve swap in tank farm at 2040 while on 9.4 PPG brine. OA=140 PSI 12/4/2015 12/4/2015 12.00 COMPZN WELLPR OTHR P Blow down topdrive. Clean mud 13,395.0 13,395.0 00:00 12:00 system prior to brine displacement and acid job. Clean drain pan,Joes box,flow line,shakers,mud trough and pits. Monitor losses via trip tank. Static loss rate=45 BPH. Losses for tour=480 BBLS. 12/4/2015 12/4/2015 5.00 COMPZN WELLPR OTHR P Cont cleaning pits,mud pmp suctions 13,395.0 13,395.0 12:00 17:00 manifolods. Monitor losses via trip tank. Static loss rate=40 BPH. 12/4/2015 12/4/2015 1.00 COMPZN WELLPR CIRC P Drop 2.115" Well Commander 13,395.0 13,395.0 17:00 18:00 activation ball to open ports for circ to casing.Pump @ 84 GPM,240 PSI, 5%flow. Ball on seat @ 294 stks. Increase pres to 1000PSI and hold for 30 sec. Slowly incr pressure and WC activated at 1800PSI. Circ @ 84 GPM 40 PSI,8%flow. Drop 2.063"ball to blank off circ thru 2-7/8". Pump down @ 84 GPM,40 PSI,8%flow. No pressure increase observed. 12/4/2015 12/4/2015 4.50 COMPZN WELLPR CIRC P Pump 75 BBL of Citric acid w/Deep 13,395.0 13,395.0 18:00 22:30 Clean followed by 50 BBL High Vis Brine. Displaced 9-5/8"annulus w/ 9.2 PPG filtered brine @ 252 GPM, 248 PSI, 14%flow,11105 Total Stks w/16 NTU final. 39 BPH dynamic losses. SIMOPS-RU Hardline for SLB acid job. 12/4/2015 12/4/2015 1.00 COMPZN WELLPR CIRC P Drop 2.115" Well Commander 13,395.0 13,395.0 22:30 23:30 activation ball to close ports for circ down to 2-7/8"shoe. Pump @ 84 GPM,45 PSI,7%flow. Ball on seat @ 430 stks. Increase pres to 1000PSI and hold for 30 sec. Slowly incr pressure and WC activated at 1650PSI. Circ @ 84 GPM 475 PSI, 5%flow. 12/4/2015 12/5/2015 0.50 COMPZN WELLPR SFTY P PJSM for Acid job with SLB,COPA, 13,395.0 13,395.0 23:30 00:00 DDI,MI. Monitoring well loss at 25 BPH static loss rate. Losses for tour=425 BBLS. Page 26/35 Report Printed: 1/7/2016 r 00 Operations Summary (with Timelogilepths) 1C-155 ConoocPhilliips hWxkx Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/5/2015 12/5/2015 0.75 COMPZN WELLPR SEQP P Pump 15 BBL of 9.2 PPG filtered brine 13,395.0 13,395.0 00:00 00:45 to SLB pump unit. SLB purged and primed lines prior to job. PT surface lines to cellar at 3500 PSI. Good test. 12/5/2015 12/5/2015 2.75 COMPZN WELLPR CIRC P Pump 385 BBLS of stage#1 9% 13,395.0 13,395.0 00:45 03:30 Formic acid job down to shoe of DP& 2-7/8"inner string with annular closed taking returns to the pits via the IA to utilize the turbine flow meter. (turbine meter did not function well but got accurate 15 min rate from tank straps.) Pumped at 3 BPM,630 PSI for 230 BBLS. Slowed to 2 BPM,375 PSI for remaining 150 BBLS due to excessive losses. Loss rate dropped from 60 to 45 BPH. Total losses 152 BBLS during acid pumping. 12/5/2015 12/5/2015 1.00 COMPZN WELLPR CIRC P Swap to rig pumps and pump 132 13,395.0 13,395.0 03:30 04:30 BBLS of filtered brine as displacement taking returns to the pits. Started at 3 BPM,575 PSI. Reduced rate to 2 BPM,372 PSIA @ 65 BBLS. FCP was 618 PSI. Total losses 72 BBL during displacement 12/5/2015 12/5/2015 7.50 COMPZN WELLPR WAIT P Acid soaked while waiting on chemical 13,395.0 13,395.0 04:30 12:00 transport from Deadhorse to refill. MI filtered brine and Doyon performed misc work orders while waiting. Total loss for tour=395 BBLS OA pres= 100 PSI 12/5/2015 12/5/2015 2.75 COMPZN WELLPR WAIT P Acid continued soaking while waiting 13,395.0 13,395.0 12:00 14:45 on chemical transport from Deadhorse to refill. MI filtered brine and Doyon performed misc work orders while waiting. Total loss for tour=395 BBLS OA pres= 100 PSI 12/5/2015 12/5/2015 0.50 COMPZN WELLPR SFTY P PJSM for 2nd stage Formic acid job 13,395.0 13,395.0 14:45 15:15 12/5/2015 12/5/2015 0.50 COMPZN WELLPR SEQP P Pump 25 BBL of 9.2 PPG filtered brine 13,395.0 13,395.0 15:15 15:45 to SLB pump unit. SLB purged and primed lines prior to job. PT surface lines to cellar at 3500 PSI. Good test. 12/5/2015 12/5/2015 1.25 COMPZN WELLPR CIRC P Pump 150 BBLS of stage#2 of 9% 13,395.0 13,395.0 15:45 17:00 Formic acid job down to shoe of 2-7/8" inner string with annular closed taking returns to the pits via the IA. Pumped at 2 BPM,330-310 PSI for 77 BBLS w/38 BBLS returns. Increased rate to 4 BPM,890-950 PSI. Chase with 10 BBLS of filtered brine prior to ball drop. 160 BBL total BBLS pumped with 91 BBLS returns. Page 27/35 Report Printed: 1/7/2016 • Operations Summary (with Timeloge pths) 1C-155 Con000Phillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/5/2015 12/5/2015 1.25 COMPZN WELLPR CIRC P Drop 2.115 WC ball to open to 9-5/8" 13,395.0 13,395.0 17:00 18:15 annulus per on-site engineer. Pumping 10%down tubing and 90% into casing. Pump w/Formic acid @ 84 GPM,300 PSI. Ball on seat @ 28.6 BBLS. Increase pres to 1000 PSI and hold for 30 sec. Slowly incr pressure and WC activated at 2000 PSI. Cont pumping acidstaging pump up to 5 BPM,350—320 PSI for an additional 239 BBLS of acid. Chased with 10 BBLS 9.2 PPG filtered brine. Total Formic acid pumped=389 BBL and a total of 20 BBLS of brine pumped behind for a total of 409 BBLS pumped and 254 BBLS of returns for a total of 254 BBLS in losses. Approx 60 BPH losses. 12/5/2015 12/5/2015 0.75 COMPZN WELLPR CIRC P Swap to rig pumps and pump 83 13,395.0 13,395.0 18:15 19:00 BBLS of brine(93 BBLS total displacement)of 9.2 PPG filtered brine @ 5 BPM,490 PSI. After pumps off,well continued to flow back 31 BBLS over 15 min. Open annular and well was static after another 10 minutes. Total pumped=492 BBLS w/330 total BBLS returns during 2nd stage acid job and displacement. 12/5/2015 12/6/2015 5.00 COMPZN WELLPR WAIT P Soak acid on formation for a total of 8 13,395.0 13,395.0 19:00 00:00 hours to allow most of the 200 BBL of acid column to leak off into formation. Monitor well via pit#2. Hourly losses from 1900-2400 in BBLS=10.4, 12.9, 17.2, 16, 15.6 Losses for tour=323 BBLS 12/6/2015 12/6/2015 4.00 COMPZN WELLPR WAIT P Cont.to soak formation after the 2nd 13,395.0 13,395.0 00:00 04:00 stage 9%Formic acid.Monitor well via trip tank.Static loss rate of 18 BBLS/HR. 12/6/2015 12/6/2015 1.00 COMPZN WELLPR CIRC P Establish circulation @ 2 BPM,40 13,395.0 13,395.0 04:00 05:00 PSI,F0=1%.Drop well commander closing ball&pump down @ 2 BPM. Ball on seat @ 25.2 BBLS,stage up to 2,000 PSI and see indication of well commander closing.Establish circulation @ 2 BPM,200 PSI, F0=3%increase to 3 BPM,470 PSI, F0=6%,increase to 4 BPM,835 PSI, F0=7%,increase to 4.5 BPM, 1,197 PSI,F0=10%. 12/6/2015 12/6/2015 0.25 COMPZN WELLPR SFTY P Hold PJSM for displacing formic acid 13,395.0 13,395.0 05:00 05:15 out of wellbore 12/6/2015 12/6/2015 0.75 COMPZN WELLPR EQRP T Hold PJSM.Observe open top returns 13,395.0 13,395.0 05:15 06:00 tank outlet valve was frozen-thaw out and add in neautrilzation pill prior to displacing acid from wellbore. Page 28/35 Report Printed: 1/7/2016 !perations Of Summary (with Timelog!epths) ht 1C-155 ConocoPhilfips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Our(hr) Phase Op Code '..Activity Code Time P-T-X Operation (ftKB) End Depth(EKE) 12/6/2015 12/6/2015 5.50 COMPZN WELLPR CIRC P Displace formic acid out of wellbore 13,395.0 13,395.0 06:00 11:30 with 9.2ppg filtered brine from tank farm @ 4.5 BPM, 1,203 PSI, FO=10%,taking returns to pits.After 210 BBLS,observe pH drop below 4.0.Shut down,close annular,and divert returns to open top tank @ 4.5 BPM, 1,197 PSI.Diverted total of 954 BBLS to open top tank.Total losses during circulation of 323 BBLS. 12/6/2015 12/6/2015 1.25 COMPZN WELLPR OWFF P Shut down,line up to take returns to 13,395.0 13,395.0 11:30 12:45 pits,and monitor flowback.Observe decreasing trend down to 5 minutes per BBL.Total volume flowed back= 90 BBLS.Fluid loss for tour=252 BBLS.OA=240 PSI 12/6/2015 12/6/2015 0.75 COMPZN WELLPR PACK P Set Baker ZXP liner top packer as per 13,395.0 13,395.0 12:45 13:30 Baker representative.Verify parameters @ PUW= 175klbs,SOW =153klbs.P/U 4'to expose setting dogs,set down 60klbs while rotating 15 rpm,5k Trq,setting ZXP packer. Pick up and set down 60klbs to re- confirm packer set.Liner shoe @ 13,395'MD,3,877.2'TVD.Top of liner @ 6,187'MD,3,876.8'TVD.Line up and pressure test liner top packer to 1,500psi for 10 minutes-good test. 12/6/2015 12/6/2015 1.50 COMPZN WELLPR CIRC P Lay down 5"DP single to 13,354'MD, 13,395.0 13,354.0 13:30 15:00 make up topdrive,pump 30 BBL 9.2ppg Citric Acid pill#1,and spot with 124 BBLS 9.2ppg filtered brine from tank farm,staging up to 5 BPM, 945 PSI,F0=11%.Blow down top drive. 12/6/2015 12/6/2015 1.75 COMPZN WELLPR PULD P POOH from 13,354' to 13,314'MD tto 13,354.0 11,863.0 15:00 16:45 actuate AB1 shifting tool and activate Fluid Loss Control Valve(FLCV). PUW=175klbs,witness 20klbs overpull when valve shifted.Continue POOH on elevators from 13,314'to 11,863'MD,laying out 5"HWDP sideways.Monitor displacement via trip tank. 12/6/2015 12/6/2015 1.25 COMPZN WELLPR PULD P POOH on elevators from 11,863'to 11,863.0 10,600.0 16:45 18:00 10,600'MD,removing super sliders and laying out 20 x 5"DP doubles into pipe tubs.Monitor displacement via trip tank. 12/6/2015 12/6/2015 1.00 COMPZN WELLPR PULD P POOH on elevators from 10,600'to 10,600.0 9,779.0 18:00 19:00 9,779'MD,removing super sliders and laying out 5"DP singles sideways. Monitor displacement via trip tank. 12/6/2015 12/6/2015 0.75 COMPZN WELLPR CIRC P Make up top drive,pump 30 BBLS 9,779.0 9,779.0 19:00 19:45 9.2ppg Citric Acid pill#2,and spot with 74 BBLS 9.2ppg filtered brine from tank farm,staging up to 5 BPM, 700 PSI,FO=12%.Blow down top drive. Page 29/35 Report Printed: 1/7/2016 Operations Summary (with Timelog!epths) 0 1C-155 c_or►o>coPhitlps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(EKE) 12/6/2015 12/6/2015 3.00 COMPZN WELLPR PULD P POOH on elevators from 9,779'to 9,779.0 7,226.0 19:45 22:45 7,226'MD,removing super sliders and laying out 5"DP singles sideways. Monitor displacement via trip tank. 12/6/2015 12/7/2015 1.25 COMPZN WELLPR BHAH P Lay down Baker magnet,MI Swaco 7,226.0 7,167.0 22:45 00:00 Well Commander,and Baker liner running tools. Magnet had approx.5 lbs of metal shavings.Fluid loss for tour=94 BBLS 12/7/2015 12/7/2015 1.00 COMPZN WELLPR BHAH P L/D Baker liner running tools, 7,167.0 7,120.0 00:00 01:00 clean/clear floor,&R/U 2-7/8"false rotary table and handling equipment. 12/7/2015 12/7/2015 1.00 COMPZN WELLPR PULD P POOH and lay down 2-7/8"space out 7,120.0 6,933.0 01:00 02:00 pups and XO.Continue POOH w/2- 7/8"H511 inner string to 6,933'MD 12/7/2015 12/7/2015 0.75 COMPZN WELLPR CIRC P Make up top drive w/triple connect, 6,933.0 6,933.0 02:00 02:45 pump 40 BBLS 9.2ppg Citric Acid pill #3,and spot with 34 BBLS 9.2ppg filtered brine from tank farm,staging up from 2 BPM, 175 PSI,FO=5%to 3 BPM,360 PSI,FO=8%to 4 BPM,597 PSI,FO=8%,FCP=520psi.Blow down top drive. 12/7/2015 12/7/2015 1.25 COMPZN WELLPR PULD P POOH and lay down 2-7/8"H511 6,933.0 6,230.0 02:45 04:00 inner string from 6,933'to 6,230'.After pulling through FLCV @ 6,241'MD, observe losses stop.Total losses for tour prior to FLCV closing=74 BBLS 12/7/2015 12/7/2015 0.50 COMPZN WELLPR OWFF P Monitor well for flow to confirm FLCV 6,230.0 6,233.0 04:00 04:30 closed-well static 12/7/2015 12/7/2015 2.25 COMPZN WELLPR DISP P Make up top drive w/triple connect 6,233.0 6,233.0 04:30 06:45 and displace hole above FLCV to 9.4ppg filtered brine,pumping 400 BBLS staging up to 5 BPM,850 PSI, FO=12%.Pump 66 BBLS of 9.4ppg Corrosion Inhibited brine at 6 BPM, 1,200 PSI, FO=15%and spot with 29 BBLS of 9.4ppg filtered brine at 3 BPM,400 PSI,FO=10%. 12/7/2015 12/7/2015 7.75 COMPZN WELLPR PULD P POOH and lay down 2-7/8"H511 6,233.0 0.0 06:45 14:30 inner string and slick joint,monitoring displacement via trip tank. 12/7/2015 12/7/2015 0.50 COMPZN WELLPR RURD P Rig down 2-7/8"false rotary table and 0.0 0.0 14:30 15:00 handling equipment.Change out handling equipment for 5". 12/7/2015 12/7/2015 0.25 COMPZN WELLPR PULD P Lay down remaining 2 x stands of 5" 0.0 0.0 15:00 15:15 DP from derrick. 12/7/2015 12/7/2015 2.25 COMPZN RPCOMP RURD P Pull wearbushing,jet stack,blow down 0.0 0.0 15:15 17:30 top drive,and drain stack.Clean/clear rig floor and bring Centrilift equipment to floor.SIMOPS-install test plug and change out blind ram door seal. 12/7/2015 12/7/2015 0.50 COMPZN RPCOMP BOPE T Fill stack and pressure test blind rams 0.0 0.0 17:30 18:00 to 250/3500 PSI for 5/5 minutes. 12/7/2015 12/7/2015 0.75 COMPZN RPCOMP BOPE T Rig down test equipment,blow down, 0.0 0.0 18:00 18:45 and pull test plug. Page 30/35 Report Printed: 1/7/2016 !perations Summary (with Timeloggepths) 0 1C-155 ConocoPhiliips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 12/7/2015 12/7/2015 2.25 COMPZN RPCOMP RURD P Rig up 4-1/2"handling equipment, 0.0 0.0 18:45 21:00 Centrilift spooler,TEC wire spool,and sheave.Verify pipe count and running order.Monitor well via trip tank 12/7/2015 12/7/2015 0.25 COMPZN RPCOMP 'SFTY P PJSM for running 4-1/2"upper 0.0 0.0 21:00 21:15 completion 12/7/2015 12/7/2015 1.50 COMPZN RPCOMP 'PUTB P Run 4-1/2"upper completion to 60' 0.0 60.0 21:15 22:45 MD. 12/7/2015 12/7/2015 1.00 COMPZN RPCOMP DHEQ P Install gauges to gauge carrier,splice 60.0 60.0 22:45 23:45 TEC wire and test same. • 12/7/2015 12/8/2015 0.25 'COMPZN RPCOMP ,PUTB P Run 4-1/2"upper completion from 60' 60.0 155.0 23:45 00:00 to 155'MD. 12/8/2015 12/8/2015 1.00 COMPZN RPCOMP PUTB P Continue RIH with 4W IBT-M 12.6#L- 155.0 375.0 00:00 01:00 80 upper completion per tally to 375' MD. 12/8/2015 12/8/2015 0.75 COMPZN RPCOMP WAIT T Observe kinks in TEC wire due to 375.0 375.0 01:00 01:45 overlap of wire on spool from factory. Wait on decision from Baker Centrilift. Decision made to POOH and L/D 10 joints and re-splice. 12/8/2015 12/8/2015 1.00 COMPZN RPCOMP PULL T PJSM,POOH from 375'MD to 70' 375.0 70.0 01:45 02:45 MD,laying down joints#12 to#3. Monitoring displacement via TT. 12/8/2015 12/8/2015 1.75 COMPZN RPCOMP EQRP T Re-splice TEC wire,discard kinked 70.0 70.0 02:45 04:30 section.Re-rig spooling unit for better visibility and control. 12/8/2015 12/8/2015 0.75 COMPZN RPCOMP PUTB T RIH with 4W upper completion to 375' 70.0 375.0 04:30 05:15 as per tally,monitoring displacement via trip tank 12/8/2015 12/8/2015 8.75 COMPZN RPCOMP PUTB P Continue RIH with 4Y2'upper 375.0 5,305.0 05:15 14:00 completion from 375'MD to 5305'MD as per tally,testing TEC wire every 1000',monitor displacement via trip tank. OA pressure @ 12:00 hrs=100 psi 12/8/2015 12/8/2015 0.75 COMPZN RPCOMP EQRP T Change out Centrilift pneumatic clamp 5,305.0 5,305.0 14:00 14:45 tool for backup tool due to primary tool failure. 12/8/2015 12/8/2015 1.50 COMPZN RPCOMP PUTB P Continue RIH with 4'/2'upper 5,305.0 6,208.0 14:45 16:15 completion from 5305'MD to 6208' MD as per tally,testing TEC wire every 1000',monitor displacement via trip tank. 12/8/2015 12/8/2015 1.00 COMPZN RPCOMP HOSO P Rig up circulating equipment and 6,208.0 6,237.0 16:15 17:15 wash down joint#214 @ 1 BPM,48 PSI,FO=3%and see 100 PSI increase when string entered into seal bore extension.Kill pump,bleed off pressure,rig down circulating equipment,and continue RIH.Tag out on No-Go @ 6,237'MD. 12/8/2015 12/8/2015 1.25 COMPZN RPCOMP HOSO P Lay out joint#'s 215,214,213,&212 6,237.0 6,193.0 17:15 18:30 to 6,151'MD.Make up 2 x space out pups(7.82'&5.88')&joint#212. RIH to 6,193'MD. 12/8/2015 12/8/2015 0.50 COMPZN RPCOMP THGR P Loosen,re-align,&tighten installation 6,193.0 6,232.0 18:30 19:00 seal on hanger.Pick up hanger and landing joint Page 31/35 Report Printed: 1/7/2016 • Operations Summary (with Timelog!epths) ry 1C-155 Conocchiitiips A?sNn Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 12/8/2015 12/8/2015 0.50 COMPZN RPCOMP THGR T Whilst stabbing landing joint into 6,232.0 6,232.0 19:00 19:30 hanger,o-ring was damaged. Successfully stab landing joint without damaging o-ring after 4 x attempts 12/8/2015 12/8/2015 0.50 COMPZN RPCOMP THGR P Secure TEC wire through hanger. 6,232.0 6,232.0 19:30 20:00 Drain stack and land hanger,PUW= 87klbs,SOW=82klbs. Total of 123 cannon clamps and 8 stainless steel bands run in hole. 12/8/2015 12/8/2015 2.50 COMPZN RPCOMP THGR P Run in lock down screws,pressure 6,232.0 0.0 20:00 22:30 test hanger seals to 5,000 PSI for 15 minutes each-good test.Test witnessed by CPAI Nick Lehman. 12/8/2015 12/9/2015 1.50 COMPZN RPCOMP PRTS P Rig up circulating equipment and 0.0 0.0 22:30 00:00 pressure test IA to 1,000 PSI for 5 minutes to verify seals engaged- good test.Bleed of pressure,drop ball &rod,and pressure test tubing to 3,500 PSI for 30 minutes,charted- good test.Bleed tubing pressure to 2,000 PSI,line up and pressure test IA to 3,500 PSI for 30 minutes,charted- good test. 12/9/2015 12/9/2015 0.50 COMPZN RPCOMP PRTS P Continue testing IA to 3,500 PSI for 30 0.0 0.0 00:00 00:30 charted minutes with 2,000 PSI held on the tubing-good test. 12/9/2015 12/9/2015 0.25 COMPZN RPCOMP CIRC P Pump down IA @ 2 BPM and see 0.0 0.0 00:30 00:45 SOV shear after 30 strokes,2,100 PSI.Establish circulation rate through IA @ 2BPM,640 PSI.Pump down tubing and establish circulation rate @ 2 BPM,508 PSI. 12/9/2015 12/9/2015 0.75 COMPZN RPCOMP RURD P Rig down circulating equipment,pull 0.0 0.0 00:45 01:30 landing joint,and drain stack 12/9/2015 12/9/2015 1.00 COMPZN WHDBOP MPSP P Install BPV as per Vetco rep.Test 0.0 0.0 01:30 02:30 from below to 2,000 PSI for 30 charted minutes-good test. Sim-ops-R/U to pull high pressure riser,N/D flow line,drain pits,&prep derrick for rig move 12/9/2015 12/9/2015 2.00 COMPZN WHDBOP NUND P Nipple down BOPE,flow line, 0.0 0.0 02:30 04:30 choke/kill line,high pressure riser, joe's box,&bell nipple 12/9/2015 12/9/2015 6.00 COMPZN WHDBOP NUND P Nipple up tree,install 2"&4"SSV, 0.0 0.0 04:30 10:30 and terminate TEC wire. Sim-ops-Prep derrick for scope, blowdown mud lines&mud pumps, install bridle yokes.Spot MPD PLC& HPU in BOP deck.Remove kelly hose from topdrive,break apart lines in interconnects,&prep rig floor for move. Page 32/35 Report Printed: 1/7/2016 • Operations Summary (with Timelogilepths) 1C-155 conocat ilIps hEr.4 Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/9/2015 12/9/2015 5.50 COMPZN WHDBOP PRTS T Pressure test tubing flange bonnet 0.0 0.0 10:30 16:00 void as per Vetco to 5,000 PSI- unable to get a test.Observe fluid leaking out through penetrator. Remove tree and observe damage to penetrator on hanger and bonnet profile.Buff penetrator and tree bonnet profile with emery cloth& change out o-ring,Lower tree onto wellhead-no indication of mis- alignment.N/U tree and attempt to pressure test void again-unable to get a test as fluid was still leaking out through penetrator.Remove tree and inspect-observe damage to penetrator area on tubing hanger and bonnet profile.Discuss plan forward with town OA pressure @ 12:00-100 PSI 12/9/2015 12/9/2015 5.00 COMPZN WHDBOP PRTS T Remove damaged tree bonnet and 0.0 0.0 16:00 21:00 replace with new one.Re-dress penetrator on tubing hanger and replace o-ring.N/U tree and attempt to pressure test void-observe pressure build to 3,000 PSI and then drop to 0 PSI with no visible leaks at penetrator. Observe fluid leaking into tree bore. Re-torque bonnet flange and re-test with same results.N/D tree,inspect tubing bore seal-no visible damage to tubing hanger bore where metal-to- metal seal is created.Observe damage to wiper seal on one side. Vetco calipered tubing hanger bore and tree bore and found to be within specifications.Observe damage to penetrator bore on tree bonnet. Discuss plan forward with town. 12/9/2015 12/10/2015 3.00 COMPZN WHDBOP NUND T N/U BOPE,install flow box,choke/kill 0.0 0.0 21:00 00:00 lines,flow-line,re-connect mud lines and choke line interconnects. 12/10/2015 12/10/2015 2.00 COMPZN WHDBOP NUND T Continue N/U BOPE,joe's box,& 0.0 0.0 00:00 02:00 interconnects.Check all high pressure flanges for proper torque&install master bushings. SimOps-Bring backup hanger to floor,strap&drift to 3.875" 12/10/2015 12/10/2015 0.25 COMPZN WHDBOP OWFF T Monitor IA for flow-well static. 0.0 0.0 02:00 02:15 12/10/2015 12/10/2015 0.50 COMPZN WHDBOP MPSP T Pull BPV with dry rod and install 2-way 0.0 0.0 02:15 02:45 check. 12/10/2015 12/10/2015 0.75 COMPZN WHDBOP RURD T P/U 4-1/2"IBT-M test joint with ported 0.0 0.0 02:45 03:30 elephant's foot.R/U head pin,test hoses,space out tooljoint below lower VBRs,fill stack,flood choke lines,test pump lines,close VBR's and seat elephant's foot below,bleed air out of system&perform shell test. Page 33/35 Report Printed: 1/7/2016 0 W Operations Summary (with Timelogepths) 1C-155 Conoco`aahilhps Atx,An Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/10/2015 12/10/2015 1.75 COMPZN WHDBOP BOPE T Pressure test 2-7/8"x 5-1/2"VBRs 0.0 0.0 03:30 05:15 and Annular each w/4-1/2"test joint to 250/3500 PSI for 5/5 minutes charted -good tests. 12/10/2015 12/10/2015 0.75 COMPZN WHDBOP RURD T R/D BOPE testing equipment,blow 0.0 0.0 05:15 06:00 down lines,&drain stack. 12/10/2015 12/10/2015 0.25 COMPZN WHDBOP OWFF T Monitor IA for flow-well static 0.0 0.0 06:00 06:15 12/10/2015 12/10/2015 0.25 COMPZN WHDBOP MPSP T Pull 2-way check with dry rod. 0.0 0.0 06:15 06:30 12/10/2015 12/10/2015 2.50 COMPZN WHDBOP PULL T P/U landing joint and make up to 0.0 0.0 06:30 09:00 hanger.Attempt to back out lock down screws.successfully backout all LDS except for one.Observe 2 x LDS w/ galled threads. 12/10/2015 12/10/2015 6.75 COMPZN WHDBOP PULL T Drain stack,rig up DHD crew,back 0.0 0.0 09:00 15:45 out damaged lock down screw, tap/dress threads on 3 x ports,and install 3 x new LDS OA pressure @ 12:00: 100 PSI 12/10/2015 12/10/2015 1.50 COMPZN WHDBOP PULL T Pull hanger off wellhead with PUW= 0.0 0.0 15:45 17:15 91k.Observe TEC wire hanging up in lower ram cavity-troubleshoot. Continue pulling hanger to floor,PUW =87k. 12/10/2015 12/10/2015 1.00 COMPZN WHDBOP PULL T Attempt to pull TEC wire through 0.0 0.0 17:15 18:15 hanger with no success-unable to remove swagelock.Decision made to cut wire and re-splice after new hanger is made up. 12/10/2015 12/10/2015 1.25 COMPZN WHDBOP PULL T L/D hanger and landing joint.POOH F 0.0 0.0 18:15 19:30 6,193'to 6,151'MD and lay down joint 212 and 2 pup joints(7.82'and 5.88'). M/U joint 212,RIH to 6,180'MD,M/U landing joint onto new hanger and make up to stump. 12/10/2015 12/10/2015 1.25 COMPZN WHDBOP 'THGR T Splice tec wire and terminate @ 0.0 0.0 19:30 20:45 hanger,install penetrator in hanger 12/10/2015 12/10/2015 1.75 COMPZN WHDBOP THGR T Land hanger,run in lock down screws, 0.0 0.0 20:45 22:30 and test upper&lower seals to 5000 PSI for 15 minutes each.Witnessed by CPAI Nick Lehman. 12/10/2015 12/10/2015 0.75 COMPZN WHDBOP MPSP T Pull landing joint,suck out stack,and 0.0 0.0 22:30 23:15 install BPV. 12/10/2015 12/10/2015 0.50 COMPZN WHDBOP PRTS T Pressure test IA against BPV to 1500 0.0 0.0 23:15 23:45 PSI for 10 minutes,charted-good test.Bleed off pressure and blow down injection line. 12/10/2015 12/11/2015 0.25 COMPZN WHDBOP OWFF T OWFF via IA for 30 minutes. 0.0 0.0 23:45 00:00 12/11/2015 12/11/2015 0.25 COMPZN WHDBOP OWFF T Continue monitoring well via IA. 0.0 0.0 00:00 00:15 12/11/2015 12/11/2015 1.75 COMPZN WHDBOP NUND T Nipple down BOP's,high pressure 0.0 0.0 00:15 02:00 riser,flow box,pitcher nipple,flow line, choke/kill line, 1'DSA. SIMOPS-Rig down and blow down high pressure lines in mud pits,pump room. Page 34/35 Report Printed: 1/7/2016 101 !perations Summary (with Timelogepths) 0 1C-155 Cono�oo`f't�ill h Fs k: Rig: DOYON 25 Job: DRILLING ORIGINAL Time',Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKB) 12/11/2015 12/11/2015 1.00 COMPZN WHDBOP NUND T Change out bad tree bonnet on tree 0.0 0.0 02:00 03:00 with new.Change out lock down screws on wellhead. SIMOPS-continue rigging down high pressure lines in mud pits and pump room.Change out butterfly valves in pits. 12/11/2015 12/11/2015 6.25 COMPZN WHDBOP OTHR T Troubleshoot TEC wire installation 0.0 0.0 03:00 09:15 due to mis-aligned ports on hanger to tree bonnet.Vetco source 90°fitting for swagelock on top of tubing hanger to successfully route TEC wire from tubing hanger through tree bonnet. 12/11/2015 12/11/2015 2.00 COMPZN WHDBOP NUND T N/U tree 0.0 0.0 09:15 11:15 12/11/2015 12/11/2015 0.75 COMPZN WHDBOP PRTS P Pressure test tubing flange connection 0.0 0.0 11:15 12:00 to 5,000 PSI for 10 minutes,witnessed by CPAI Rob Reinhardt.Pull BPV& install 2-way check.TEC wire test successful-bottomhole temperature @ 76°F and bottomhole pressure @ 1854 PSI 12/11/2015 12/11/2015 1.50 COMPZN WHDBOP PRTS P Fill&test tree with diesel to 250/5000 0.0. 0.0 12:00 13:30 PSI for 5/5 minutes charted-good test.Bleed off pressure and pull 2-way check 12/11/2015 12/11/2015 3.25 COMPZN WHDBOP FRZP P Line up rig's injection pump and freeze 0.0 0.0 13:30 16:45 protect well by pumping 143 BBLS diesel down IA,taking returns through tubing to pits @ 1.57 BPM,ICP=300 PSI,FCP=520 PSI,FO=4%.Line up IA to tubing and allow fluid to u-tube from 15:25-16:35.Shut in IA and tubing w/220 PSI on both.OA pressure=160 PSI. Simops-Lower cattle chute,hold PJSM with crane and rig crew,and set MPD choke skid into BOP deck. Lower lubricator to cellar and rig up snatch block in BOP deck. 12/11/2015 12/11/2015 1.75 COMPZN WHDBOP MPSP P Rig up&test lubricator. Install BPV, 0.0 0.0 16:45 18:30 rig down lubricator,and hoist to BOP deck Simops:Blow down and rig down circulating equipment in cellar.Bridal up and scope derrick down. 12/11/2015 12/11/2015 1.50 DEMOB MOVE RURD P Vetco finish installation of gauges and 0.0 0.0 18:30 20:00 clean/clear lines in cellar. Simops-Continue preparing rig for move,change out manifold on top drive 12/11/2015 12/11/2015 1.50 DEMOB MOVE RURD P Suck out fluid in cellar box,clean out 0.0 0.0 20:00 21:30 wellhead flutes,and shrinkwrap wellhead flutes. Simops-Continue preparing rig for move 12/11/2015 12/12/2015 2.50 DEMOB MOVE RURD P Prepare rig for moving to 2S-01.Rig 0.0 0.0 21:30 00:00 released @ 00:00 12/12/15 Page 35/35 Report Printed: 1/7/2016 • i NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-155 Definitive Survey Report 03 December, 2015 • Schlumberger 0 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Welibore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 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 Well 1C-155 Well Position +N/-S 0.00 usft Northing: 5,968,690.68 usfl Latitude: 70°19'29.948 N +E/-W 0.00 usft Easting: 562,268.34 usfl Longitude: 149°29'42.280 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 57.60 usft teIIbO1toi€1 1C-155 •Magnetics NNlartte Sample Date enation Dip Anglea , Field Strength seri„-. A ;44 ,,,.,.,. BGGM2015 11/30/2015 18.84 80.99 57,504 Design 1C-155 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.74 Vertical Section: a F ,) �� +El W Direction }} y4 39.74 0.00 0.00 350.00 Survey Program Data ``$ � From Toi 40u (usft) (usft) Survey(Welibore) ,Tool IN £"•„: ' iription Survey Date •72.32 1,956.99 1C-155 Srvy#1 -GWD(1C-155) GYD-GC-SS Gyrodata gyro single shots 11/11/2015 9:: 2,051.89 2,546.93 1C-155 Srvy#2-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1:: 2,637.13 2,666.43 1C-155 Srvy#3-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/16/2015 1:: 2,760.65 6,334.51 1C-155 Srvy#4-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1:: 6,385.89 6,385.89 1C-155 Srvy#5-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/23/2015 8:, 6,480.35 13,361.25 1C-155 Srvy#6-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/23/2015 8:, Survey 2,4" Map Map Vertical ,,,..ii . MD Inc Azi TVD TVDSS +Nl-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100')' (ft) Survey Tool Name 39.74 0.00 0.00 39.74 -57.60 0.00 0.00 5,968,690.68 562,268.34 0.00 0.00 UNDEFINED 72.32 0.59 14.24 72.32 -25.02 0.16 0.04 5,968,690.84 562,268.38 1.81 0.15 GYD-GC-SS(1) 119.70 0.60 15.16 119.70 22.36 0.64 0.17 5,968,691 32 562,268.50 0.03 0.60 GYD-GC-SS(1) 20"x 34" 168.15 0.61 16.08 168.14 70.80 1.13 0.30 5,968,691 81 562,268.63 0.03 1.06 GYD-GC-SS(1) 265.69 0.81 14.13 265.68 168.34 2.30 0.62 5,968,692.98 562,268.94 0.21 2.16 GYD-GC-SS(1) 358.70 1.75 50.28 358.66 261.32 3.84 1.87 5,968,694.54 562,270.18 1.29 3.46 GYD-GC-SS(1) 452.24 3.85 69.40 452.09 354.75 5.86 5.91 5,968,696.59 562,274.20 2.43 4.75 GYD-GC-SS(1) 545.70 5.16 75.20 545.26 447.92 8.04 12.91 5,968,698.83 562,281.18 1.48 5.68 GYD-GC-SS(1) 637.71 6.82 79.52 636.76 539.42 10.09 22.28 5,968,700.95 562,290.53 1.87 6.07 GYD-GC-SS(1) 12/3/2015 1:28:17PM Page 2 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Stte: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6©97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map, Map Vertical MD Inc Azi TVD TVDSS +N(.S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°J100') (ft) Survey Tool Name 731.23 8.19 81.98 729.48 632.14 12.03 34.34 5,968,702.99 562,302.57 1.50 5.88 GYD-GC-SS(1) 824.84 8.91 84.30 822.05 724.71 13.68 48.15 5,968,704.76 562,316.37 0.85 5.11 GYD-GC-SS(1) 916.99 8.05 84.19 913.19 815.85 15.04 61.67 5,968,706.23 562,329.88 0.93 4.10 GYD-GC-SS(1) 1,009.23 9.17 84.46 1,004.39 907.05 16.41 75.42 5,968,707.71 562,343.61 1.22 3.06 GYD-GC-SS(1) 1,104.71 11.66 70.82 1,098.30 1,000.96 20.31 92.11 5,968,711.75 562,360.27 3.65 4.01 GYD-GC-SS(1) 1,200.93 12.90 69.37 1,192.32 1,094.98 27.29 111.34 5,968,718.89 562,379.44 1.33 7.54 GYD-GC-SS(1) 1,295.15 13.07 73.91 1,284.13 1,186.79 33.95 131.42 5,968,725.71 562,399.46 1.10 10.61 GYD-GC-SS(1) 1,389.36 16.59 84.62 1,375.21 1,277.87 38.16 155.06 5,968,730.12 562,423.06 4.72 10.66 GYD-GC-SS(1) 1,484.07 16.53 88.38 1,465.99 1,368.65 39.81 181.99 5,968,732.00 562,449.98 1.13 7.61 GYD-GC-SS(1) 1,577.20 17.69 84.58 1,555.00 1,457.66 41.52 209.32 5,968,733.93 562,477.29 1.73 4.54 GYD-GC-SS(1) 1,671.49 19.92 85.86 1,644.25 1,546.91 44.04 239.61 5,968,736.70 562,507.55 2.41 1.76 GYD-GC-SS(1) 1,768.52 25.45 86.28 1,733.74 1,636.40 46.58 276.93 5,968,739.56 562,544.84 5.70 -2.21 GYD-GC-SS(1) 1,862.81 28.26 87.30 1,817.86 1,720.52 48.95 319.45 5,968,742.27 562,587.34 3.02 -7.26 GYD-GC-SS(1) 1,956.99 33.56 83.68 1,898.64 1,801.30 52.87 367.63 5,968,746.59 562,635.49 5.96 -11.77 GYD-GC-SS(1) 2,051.89 35.95 86.05 1,976.61 1,879.27 57.68 421.50 5,968,751.85 562,689.31 2.89 -16.39 MWD+IFR-AK-CAZ-SC(2) 2,109.96 37.07 88.03 2,023.28 1,925.94 59.45 456.00 5,968,753.91 562,723.79 2.80 -20.63 MWD+IFR-AK-CAZ-SC(2) 2,205.31 38.06 90.63 2,098.86 2,001.52 60.12 514.12 5,968,755.06 562,781.89 1.96 -30.07 MWD+IFR-AK-CAZ-SC(2) 2,300.42 42.63 92.27 2,171.34 2,074.00 58.52 575.65 5,968,753.97 562,843.43 4.93 -42.33 MWD+IFR-AK-CAZ-SC(2) 2,394.77 45.42 92.97 2,239.17 2,141.83 55.51 641.15 5,968,751 50 562,908.94 3.00 -56.67 MWD+IFR-AK-CAZ-SC(2) 2,489.15 47.23 94.01 2,304.35 2,207.01 51.35 709.28 5,968,747.91 562,977.10 2.08 -72.60 MWD+IFR-AK-CAZ-SC(2) 2,546.93 51.38 96.04 2,342.01 2,244.67 47.49 752.90 5,968,744.41 563,020.75 7.66 -83.97 MWD+IFR-AK-CAZ-SC(2) 2,617.70 50.42 96.03 2,386.64 2,289.30 41.71 807.52 5,968,739.09 563,075.41 1.35 -99.15 INC+TREND(3) 13.318"x 16" 2,637.13 50.16 96.03 2,399.06 2,301.72 40.14 822.38 5,968,737.64 563,090.28 1.35 -103.27 INC+TREND(3) 2,666.43 52.96 95.98 2,417.27 2,319.93 37.74 845.20 5,968,735.43 563,113.12 9.56 -109.60 INC+TREND(3) 2,760.65 53.76 95.47 2,473.50 2,376.16 30.20 920.43 5,968,728.51 563,188.40 0.95 -130.09 MWD+IFR-AK-CAZ-SC(4) 2,853.32 53.92 97.23 2,528.18 2,430.84 21.93 994.78 5,968,720.86 563,262.81 1.54 -151.15 MWD+IFR-AK-CAZ-SC(4) 2,947.34 62.35 99.82 2,577.78 2,480.44 10.02 1,073.66 5,968,709.61 563,341.77 9.27 -176.57 MWD+IFR-AK-CAZ-SC(4) 3,043.78 61.74 101.04 2,622.99 2,525.65 -5.40 1,157.43 5,968,694.88 563,425.67 1.28 -206.30 MWD+IFR-AK-CAZ-SC(4) 3,137.58 60.81 94.36 2,668.11 2,570.77 -16.43 1,238.88 5,968,684.53 563,507.19 6.32 -231.31 MWD+IFR-AK-CAZ-SC(4) 3,232.30 57.75 92.00 2,716.50 2,619.16 -20.98 1,320.16 5,968,680.66 563,588.50 3.88 -249.90 MWD+IFR-AK-CAZ-SC(4) 3,326.86 57.26 86.47 2,767.32 2,669.98 -19.92 1,399.86 5,968,682.38 563,668.18 4.96 -262.70 MWD+IFR-AK-CAZ-SC(4) 3,420.95 57.68 80.60 2,817.95 2,720.61 -10.99 1,478.63 5,968,691.96 563,746.87 5.28 -267.58 MWD+IFR-AK-CAZ-SC(4) 3,514.77 58.17 73.22 2,867.82 2,770.48 7.01 1,555.97 5,968,710.60 563,824.05 6.68 -263.29 MWD+IFR-AK-CAZ-SC(4) 3,610.78 59.79 68.11 2,917.32 2,819.98 34.27 1,633.56 5,968,738.50 563,901.40 4.86 -249.92 MWD+IFR-AK-CAZ-SC(4) 3,704.90 61.43 62.16 2,963.54 2,866.20 68.76 1,707.90 5,968,773.60 563,975.45 5.78 -228.86 MWD+IFR-AK-CAZ-SC(4) 3,799.43 61.75 56.67 3,008.54 2,911.20 111.05 1,779.43 5,968,816.48 564,046.62 5.12 -199.64 MWD+IFR-AK-CAZ-SC(4) 3,893.61 57.74 53.53 3,055.99 2,958.65 157.54 1,846.15 5,968,863.51 564,112.95 5.14 -165.44 MWD+IFR-AK-CAZ-SC(4) 3,988.46 54.73 52.86 3,108.71 3,011.37 204.76 1,909.29 5,968,911.26 564,175.68 3.23 -129.89 MWD+IFR-AK-CAZ-SC(4) 4,083.17 55.09 49.01 3,163.16 3,065.82 253.59 1,969.43 5,968,960.58 564,235.41 3.35 -92.25 MWD+IFR-AK-CAZ-SC(4) 12/3/2015 1:28:17PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference; Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD S +NIS +FJ-W Northing Easting DLS Section (usft) (°) (°) (usft) lust) (usft) (usft) (ft)', (ft) (°1100') (ft) Survey Tool Name 4,179.07 55.71 45.47 3,217.63 3,120.29 307.18 2,027.37 5,969,014.64 564,292.90 3.11 -49.54 MWD+IFR-AK-CAZ-SC(4) 4,274.96 58.01 39.17 3,270.09 3,172.75 366.53 2,081.34 5,969,074.43 564,346.37 6.00 -0.46 MWD+IFR-AK-CAZ-SC(4) 4,367.16 60.57 33.29 3,317.20 3,219.86 430.46 2,128.11 5,969,138.74 564,392.60 6.14 54.38 MWD+IFR-AK-CAZ-SC(4) 4,461.80 60.94 31.69 3,363.44 3,266.10 500.11 2,172.46 5,969,208.75 564,436.37 1.53 115.27 MWD+IFR-AK-CAZ-SC(4) 4,557.03 62.11 27.13 3,408.86 3,311.52 573.01 2,213.54 5,969,281.98 564,476.83 4.38 179.93 MWD+IFR-AK-CAZ-SC(4) 4,650.87 62.40 23.72 3,452.55 3,355.21 648.00 2,249.18 5,969,357.26 564,511.85 3.23 247.59 MWD+IFR-AK-CAZ-SC(4) 4,744.72 63.79 16.93 3,495.06 3,397.72 726.43 2,278.20 5,969,435.92 564,540.21 6.62 319.79 MWD+IFR-AK-CAZ-SC(4) 4,839.02 65.48 13.13 3,535.47 3,438.13 808.70 2,300.27 5,969,518.36 564,561.60 4.06 396.98 MWD+IFR-AK-CAZ-SC(4) 4,934.43 64.01 14.02 3,576.17 3,478.83 892.58 2,320.52 5,969,602.40 564,581.15 1.76 476.07 MWD+IFR-AK-CAZ-SC(4) 5,029.56 64.54 14.28 3,617.47 3,520.13 975.68 2,341.47 5,969,685.66 564,601.41 0.61 554.27 MWD+IFR-AK-CAZ-SC(4) 5,123.87 68.47 16.31 3,655.06 3,557.72 1,059.08 2,364.30 5,969,769.24 564,623.55 4.61 632.43 MWD+IFR-AK-CAZ-SC(4) 5,218.83 72.36 17.08 3,686.89 3,589.55 1,144.76 2,390.00 5,969,855.12 564,648.54 4.17 712.34 MWD+IFR-AK-CAZ-SC(4) 5,312.90 74.02 16.53 3,714.09 3,616.75 1,230.96 2,416.04 5,969,941.52 564,673.85 1.85 792.72 MWD+IFR-AK-CAZ-SC(4) 5,407.74 74.18 15.92 3,740.07 3,642.73 1,318.54 2,441.52 5,970,029.30 564,698.60 0.64 874.54 MWD+IFR-AK-CAZ-SC(4) 5,502.68 75.67 13.39 3,764.77 3,667.43 1,407.22 2,464.70 5,970,118.17 564,721 05 3.01 957.85 MWD+IFR-AK-CAZ-SC(4) 5,597.27 79.09 10.41 3,785.44 3,688.10 1,497.52 2,483.72 5,970,208.61 564,739.31 4.75 1,043.47 MWD+IFR-AK-CAZ-SC(4) 5,692.49 81.17 6.03 3,801.76 3,704.42 1,590.34 2,497.11 5,970,301.53 564,751.93 5.03 1,132.56 MWD+IFR-AK-CAZ-SC(4) 5,786.05 79.87 1.57 3,817.18 3,719.84 1,682.39 2,503.24 5,970,393.62 564,757.29 4.90 1,222.15 MWD+IFR-AK-CAZ-SC(4) 5,881.82 79.05 357.92 3,834.71 3,737.37 1,776.52 2,502.82 5,970,487.74 564,756.09 3.84 1,314.93 MWD+IFR-AK-CAZ-SC(4) 5,976.79 82.02 357.43 3,850.32 3,752.98 1,870.11 2,499.02 5,970,581.29 564,751.52 3.17 1,407.75 MWD+IFR-AK-CAZ-SC(4) 6,070.87 82.57 355.64 3,862.94 3,765.60 1,963.17 2,493.38 5,970,674.28 564,745.11 1.97 1,500.37 MWD+IFR-AK-CAZ-SC(4) 6,165.06 83.65 353.60 3,874.24 3,776.90 2,056.26 2,484.61 5,970,767.29 564,735.57 2.44 1,593.57 MWD+IFR-AK-CAZ-SC(4) 6,260.18 83.11 351.76 3,885.20 3,787.86 2,149.97 2,472.58 5,970,860.89 564,722.76 2.00 1,687.95 MWD+IFR-AK-CAZ-SC(4) 6,334.51 86.83 351.17 3,891.72 3,794.38 2,223.18 2,461.59 5,970,934.00 564,711.16 5.07 1,761.96 MWD+IFR-AK-CAZ-SC(4) 6,385.89 87.39 350.12 3,894.31 3,796.97 2,273.81 2,453.25 5,970,984.55 564,702.40 2.31 1,813.27 INC+TREND(5) 6,403.90 87.45 349.98 3,895.12 3,797.78 2,291.54 2,450.14 5,971,002.25 564,699.15 0.85 1,831.26 MWD+IFR-AK-CAZ-SC(6) 9 515:)i-12,144F4 6,480.35 87.70 349.38 3,898.36 3,801.02 2,366.68 2,436.46 5,971,077.27 564,684.84 0.85 1,907.64 MWD+IFR-AK-CAZ-SC(6) 6,575.03 88.97 348.60 3,901.11 3,803.77 2,459.58 2,418.38 5,971,170.00 564,666.00 1.57 2,002.26 MWD+IFR-AK-CAZ-SC(6) 6,670.19 88.93 347.13 3,902.85 3,805.51 2,552.59 2,398.38 5,971,262.84 564,645.23 1.55 2,097.34 MWD+IFR-AK-CAZ-SC(6) 6,764.99 88.75 346.76 3,904.77 3,807.43 2,644.92 2,376.97 5,971,354.98 564,623.06 0.43 2,191.98 MWD+IFR-AK-CAZ-SC(6) 6,860.01 90.75 345.71 3,905.18 3,807.84 2,737.21 2,354.36 5,971,447.07 564,599.69 2.38 2,286.79 MWD+IFR-AK-CAZ-SC(6) 6,954.56 91.68 344.16 3,903.18 3,805.84 2,828.48 2,329.80 5,971,538.13 564,574.36 1.91 2,380.95 MWD+IFR-AK-CAZ-SC(6) 7,049.54 92.16 342.21 3,900.00 3,802.66 2,919.35 2,302.34 5,971,628.75 564,546.15 2.11 2,475.20 MWD+IFR-AK-CAZ-SC(6) 7,143.82 91.51 343.87 3,896.98 3,799.64 3,009.48 2,274.85 5,971,718.64 564,517.92 1.89 2,568.73 MWD+IFR-AK-CAZ-SC(6) 7,239.06 90.68 343.78 3,895.16 3,797.82 3,100.93 2,248.32 5,971,809.86 564,490.64 0.88 2,663.40 MWD+IFR-AK-CAZ-SC(6) 7,333.98 90.31 342.44 3,894.34 3,797.00 3,191.75 2,220.75 5,971,900.44 564,462.32 1.46 2,757.63 MWD+IFR-AK-CAZ-SC(6) 7,430.05 89.17 342.01 3,894.77 3,797.43 3,283.23 2,191.42 5,971,991.67 564,432.23 1.27 2,852.81 MWD+IFR-AK-CAZ-SC(6) 7,523.69 88.80 340.36 3,896.43 3,799.09 3,371.85 2,161.23 5,972,080.02 564,401.31 1.81 2,945.33 MWD+IFR-AK-CAZ-SC(6) 7,618.22 89.72 338.82 3,897.65 3,800.31 3,460.43 2,128.26 5,972,168.32 564,367.62 1.90 3,038.29 MWD+IFR-AK-CAZ-SC(6) 12/3/2015 1:28:17PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map ,. •.t ;� tical MD Inc Azi TVD TVDSS' +NI-S +E1-W Northing Easting DLS Section (usft) (°) () (usft) (usft) (usft) (usft) (ft) (ft) (1100') (ft) Survey Tool Name 7,713.82 89.86 336.97 3,898.00 3,800.66 3,549.00 2,092.29 5,972,256.58 564,330.91 1.94 3,131.76 MWD+IFR-AK-CAZ-SC(6) 7,808.02 89.76 334.70 3,898.32 3,800.98 3,634.94 2,053.73 5,972,342.19 564,291.64 2.41 3,223.09 MWD+IFR-AK-CAZ-SC(6) 7,902.33 90.58 333.71 3,898.04 3,800.70 3,719.85 2,012.69 5,972,426.75 564,249.91 1.36 3,313.84 MWD+IFR-AK-CAZ-SC(6) 7,998.07 90.99 332.36 3,896.72 3,799.38 3,805.17 1,969.29 5,972,511.70 564,205.80 1.47 3,405.40 MWD+IFR-AK-CAZ-SC(6) 8,093.37 90.75 333.83 3,895.28 3,797.94 3,890.14 1,926.17 5,972,596.30 564,161.98 1.56 3,496.57 MWD+IFR-AK-CAZ-SC(6) 8,186.95 91.68 333.89 3,893.29 3,795.95 3,974.13 1,884.95 5,972,679.94 564,120.07 1.00 3,586.44 MWD+IFR-AK-CAZ-SC(6) 8,281.44 94.00 334.74 3,888.61 3,791.27 4,059.18 1,844.05 5,972,764.63 564,078.47 2.61 3,677.29 MWD+IFR-AK-CAZ-SC(6) 8,376.55 93.05 337.26 3,882.76 3,785.42 4,145.89 1,805.44 5,972,851.01 564,039.15 2.83 3,769.39 MWD+IFR-AK-CAZ-SC(6) 8,471.01 91.82 339.80 3,878.75 3,781.41 4,233.71 1,770.90 5,972,938.53 564,003.88 2.99 3,861.87 MWD+IFR-AK-CAZ-SC(6) 8,565.72 90.68 341.72 3,876.68 3,779.34 4,323.10 1,739.70 5,973,027.65 563,971.95 2.36 3,955.33 MWD+IFR-AK-CAZ-SC(6) 8,660.80 90.34 344.14 3,875.84 3,778.50 4,413.98 1,711.80 5,973,118.29 563,943.29 2.57 4,049.67 MWD+IFR-AK-CAZ-SC(6) 8,754.59 89.89 345.99 3,875.65 3,778.31 4,504.60 1,687.63 5,973,208.70 563,918.37 2.03 4,143.11 MWD+IFR-AK-CAZ-SC(6) 8,850.05 88.25 344.89 3,877.20 3,779.86 4,596.98 1,663.63 5,973,300.86 563,893.61 2.07 4,238.25 MWD+IFR-AK-CAZ-SC(6) 8,945.18 86.53 341.34 3,881.53 3,784.19 4,687.89 1,636.04 5,973,391.54 563,865.27 4.14 4,332.58 MWD+IFR-AK-CAZ-SC(6) 9,038.66 85.86 341.38 3,887.73 3,790.39 4,776.28 1,606.23 5,973,479.66 563,834.73 0.72 4,424.79 MWD+IFR-AK-CAZ-SC(6) 9,134.65 87.43 344.79 3,893.35 3,796.01 4,867.94 1,578.35 5,973,571.08 563,806.10 3.91 4,519.91 MWD+IFR-AK-CAZ-SC(6) 9,228.61 89.60 348.68 3,895.79 3,798.45 4,959.34 1,556.81 5,973,662.29 563,783.80 4.74 4,613.66 MWD+IFR-AK-CAZ-SC(6) 9,322.41 89.93 352.49 3,896.17 3,798.83 5,051.86 1,541.47 5,973,754.67 563,767.69 4.08 4,707.44 MWD+IFR-AK-CAZ-SC(6) 9,419.25 89.89 353.65 3,896.33 3,798.99 5,147.99 1,529.78 5,973,850.69 563,755.21 1.20 4,804.13 MWD+IFR-AK-CAZ-SC(6) 9,514.72 89.35 353.43 3,896.96 3,799.62 5,242.85 1,519.04 5,973,945.45 563,743.68 0.61 4,899.42 MWD+IFR-AK-CAZ-SC(6) 9,607.76 89.72 353.46 3,897.71 3,800.37 5,335.28 1,508.42 5,974,037.78 563,732.30 0.40 4,992.29 MWD+IFR-AK-CAZ-SC(6) 9,704.03 89.83 351.71 3,898.09 3,800.75 5,430.74 1,496.00 5,974,133.13 563,719.08 1.82 5,088.46 MWD+IFR-AK-CAZ-SC(6) 9,798.27 90.10 346.06 3,898.15 3,800.81 5,523.17 1,477.84 5,974,225.40 563,700.16 6.00 5,182.64 MWD+IFR-AK-CAZ-SC(6) 9,850.00 90.34 343.67 3,897.95 3,800.61 5,573.10 1,464.33 5,974,275.21 563,686.24 4.64 5,234.16 MWD+IFR-AK-CAZ-SC(6) 9,906.93 91.32 340.90 3,897.13 3,799.79 5,627.32 1,447.01 5,974,329.28 563,668.47 5.16 5,290.56 MWD+IFR-AK-CAZ-SC(6) 9,987.77 91.10 341.55 3,895.42 3,798.08 5,703.84 1,421.00 5,974,405.57 563,641.83 0.85 5,370.44 MWD+IFR-AK-CAZ-SC(6) 10,083.02 91.13 343.33 3,893.57 3,796.23 5,794.64 1,392.27 5,974,496.11 563,612.35 1.87 5,464.84 MWD+IFR-AK-CAZ-SC(6) 10,179.12 91.30 345.58 3,891.53 3,794.19 5,887.19 1,366.52 5,974,588.45 563,585.84 2.35 5,560.46 MWD+IFR-AK-CAZ-SC(6) 10,273.62 92.90 345.22 3,888.07 3,790.73 5,978.58 1,342.72 5,974,679.62 563,561.28 1.74 5,654.59 MWD+IFR-AK-CAZ-SC(6) 10,369.01 92.08 345.45 3,883.92 3,786.58 6,070.77 1,318.59 5,974,771.60 563,536.39 0.89 5,749.57 MWD+IFR-AK-CAZ-SC(6) 10,463.29 93.09 347.94 3,879.67 3,782.33 6,162.42 1,296.92 5,974,863.06 563,513.96 2.85 5,843.59 MWD+IFR-AK-CAZ-SC(6) 10,558.31 89.57 347.62 3,877.46 3,780.12 6,255.25 1,276.81 5,974,955.71 563,493.09 3.72 5,938.50 MWD+IFR-AK-CAZ-SC(6) 10,653.64 88.76 346.31 3,878.85 3,781.51 6,348.11 1,255.32 5,975,048.38 563,470.82 1.62 6,033.68 MWD+IFR-AK-CAZ-SC(6) 10,749.09 89.21 343.42 3,880.54 3,783.20 6,440.22 1,230.40 5,975,140.27 563,445.14 3.06 6,128.72 MWD+IFR-AK-CAZ-SC(6) 10,844.24 90.68 340.95 3,880.63 3,783.29 6,530.80 1,201.29 5,975,230.60 563,415.29 3.02 6,222.98 MWD+IFR-AK-CAZ-SC(6) 10,938.95 90.96 340.28 3,879.28 3,781.94 6,620.13 1,169.86 5,975,319.66 563,383.12 0.77 6,316.41 MWD+IFR-AK-CAZ-SC(6) 11,033.99 90.68 339.81 3,877.92 3,780.58 6,709.46 1,137.43 5,975,408.70 563,349.95 0.58 6,410.01 MWD+IFR-AK-CAZ-SC(6) 11,128.65 89.86 340.13 3,877.47 3,780.13 6,798.39 1,105.01 5,975,497.35 563,316.80 0.93 6,503.22 MWD+IFR-AK-CAZ-SC(6) 11,222.36 88.34 339.43 3,878.95 3,781.61 6,886.31 1,072.62 5,975,584.99 563,283.69 1.79 6,595.43 MWD+IFR-AK-CAZ-SC(6) 11,316.99 88.80 339.83 3,881.31 3,783.97 6,974.99 1,039.70 5,975,673.39 563,250.03 0.64 6,688.49 MWD+IFR-AK-CAZ-SC(6) 12/32015 1:28:17PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map map Vertical MD Inc Azi TVD TVDSS +NI-S +EMN Northing Fasting DIS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft)'', (ft) 0100') (ft), Survey Tool Name 11,412.91 90.42 342.11 3,881.96 3,784.62 7,065.66 1,008.42 5,975,763.79 563,218.01 2.92 6,783.21 MWD+IFR-AK-CAZ-SC(6) 11,507.27 90.34 344.51 3,881.33 3,783.99 7,156.04 981.33 5,975,853.93 563,190.16 2.54 6,876.91 MWD+IFR-AK-CAZ-SC(6) 11,602.13 90.75 346.66 3,880.43 3,783.09 7,247.90 957.71 5,975,945.58 563,165.79 2.31 6,971.48 MWD+IFR-AK-CAZ-SC(6) 11,697.41 90.38 348.72 3,879.49 3,782.15 7,340.98 937.40 5,976,038.48 563,144.71 2.20 7,066.68 MWD+IFR-AK-CAZ-SC(6) 11,791.35 90.24 347.88 3,878.98 3,781.64 7,432.97 918.35 5,976,130.30 563,124.90 0.91 7,160.57 MWD+IFR-AK-CAZ-SC(6) 11,886.11 90.24 349.37 3,878.59 3,781.25 7,525.86 899.66 5,976,223.03 563,105.44 1.57 7,255.30 MWD+IFR-AK-CAZ-SC(6) 11,981.51 89.96 349.18 3,878.42 3,781.08 7,619.59 881.91 5,976,316.60 563,086.91 0.35 7,350.69 MWD+IFR-AK-CAZ-SC(6) 12,075.49 89.21 348.26 3,879.10 3,781.76 7,711.75 863.53 5,976,408.60 563,067.77 1.26 7,444.65 MWD+IFR-AK-CAZ-SC(6) 12,170.39 87.97 347.74 3,881.44 3,784.10 7,804.55 843.80 5,976,501.22 563,047.28 1.42 7,539.46 MWD+IFR-AK-CAZ-SC(6) 12,265.05 91.41 348.03 3,881.95 3,784.61 7,897.09 823.94 5,976,593.58 563,026.65 3.65 7,634.04 MWD+IFR-AK-CAZ-SC(6) 12,359.55 89.39 348.74 3,881.29 3,783.95 7,989.64 804.92 5,976,685.96 563,006.86 2.27 7,728.49 MWD+IFR-AK-CAZ-SC(6) 12,454.39 90.31 347.84 3,881.54 3,784.20 8,082.51 785.67 5,976,778.66 562,986.84 1.36 7,823.29 MWD+IFR-AK-CAZ-SC(6) 12,551.27 90.96 346.15 3,880.46 3,783.12 8,176.89 763.87 5,976,872.85 562,964.26 1.87 7,920.02 MWD+IFR-AK-CAZ-SC(6) 12,644.81 90.34 345.50 3,879.40 3,782.06 8,267.58 740.96 5,976,963.33 562,940.61 0.96 8,013.31 MWD+IFR-AK-CAZ-SC(6) 12,739.68 90.10 346.07 3,879.04 3,781.70 8,359.54 717.67 5,977,055.09 562,916.55 0.65 8,107.92 MWD+IFR-AK-CAZ-SC(6) 12,830.37 88.97 344.53 3,879.77 3,782.43 8,447.26 694.66 5,977,142.60 562,892.82 2.11 8,198.30 MWD+IFR-AK-CAZ-SC(6) 12,929.88 88.52 343.48 3,881.95 3,784.61 8,542.89 667.24 5,977,238.00 562,864.61 1.15 8,297.24 MWD+IFR-AK-CAZ-SC(6) 13,024.92 89.52 344.15 3,883.58 3,786.24 8,634.15 640.76 5,977,329.02 562,837.37 1.27 8,391.71 MWD+IFR-AK-CAZ-SC(6) 13,118.82 90.41 344.44 3,883.64 3,786.30 8,724.54 615.34 5,977,419.19 562,811.21 1.00 8,485.14 MWD+IFR-AK-CAZ-SC(6) 13,212.14 90.96 344.32 3,882.52 3,785.18 8,814.41 590.22 5,977,508.84 562,785.34 0.60 8,578.01 MWD+IFR-AK-CAZ-SC(6) 13,310.26 91.95 343.50 3,880.03 3,782.69 8,908.65 563.03 5,977,602.85 562,757.38 1.31 8,675.54 MWD+IFR-AK-CAZ-SC(6) 13,361.25 91.89 343.98 3,878.32 3,780.98 8,957.58 548.76 5,977,651.64 562,742.71 0.95 8,726.20 MWD+IFR-AK-CAZ-SC(6) 13,395.00 91.89 343.98 3,877.21 3,779.87 8,990.00 539.45 5,977,683.98 562,733.13 0.00 8,759.74 4 112"x 6-3/4" 13,435.00 91.89 343.98 3,875.89 3,778.55 9,028.42 528.42 5,977,722.31 562,721.78 0.00 8,799.50 PROJECTED to TD 12/3/2015 1:28:17PM Page 6 COMPASS 5000.1 Build 74 • 6 Cement Detail Report 1 C-155 Conoco hiiiips String: Conductor Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 9/2/2015 06:00 9/2/2015 23:00 1C-155 Comment Cement Stages Stage#9 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Tack conductor 106.0 120.0 Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid , Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 106.0 120.0 87 G 14.3 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CrrprStr 1(psi) 1.40 5.25 15.70 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Conductor Cement Cement conductor 62.5 106.0 Q Pump Init(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 62.5 106.0 262 G 43.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.40 5.20 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 1/7/2016 • • Cement Detail Report 1C-155 ConocoPhilliprs String: Surface Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Cement 11/13/2015 08:45 11/13/2015 14:26 1C-155 Comment Pump 70 additional bbls of CW100 at 7 BPM,300psi,26%flow out. P/U=198k,S/O= 148k. Follow CW100 with 75bbls of Mud Push II.Drop bottom plug. Schlumberger cementers batch up and pump 551.9bbls of 11 ppg Lead cement. P/U=205k,S/O= 144k. Reciprocate pipe 20'thoughout. Pump 77.3bbls of 12ppg tail cement while reciprocating casing 15'. P/U=230k,S/0=115k. Drop Top Plug and kick out with 10bbI of H20.Swap over from Schlumberger cementers to rig pump for remainder of displacement. Pump with rig pump and displace cement with conditioned spud mud @ 6BPM initial rate. Pick up 4'to reciprocate casing with 50k overpull from las PU wt of 230k. Un-able to land casing on landing ring with hanger 4-1/2"off landing ring. Continue attemps to land hanger, initial rate of 6 BPM,300psi,26%flow out for 490stk. Divert returns to cellar and reduce rate to 3 BPM, 150 psi ICP with 363psi FCP. Reduce rate to 1 BPM, 280psi FCP. Bump plug at 3643stks,increase to 500psi over FCP to 800psi and hold for 5min. Bleed pressure off and check floats(holding). Casing in Place at 14:26 and set at 2618'MD. 264bbl to surface. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Cement 45.8 2,118.0 No 264.0 Yes No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 1 7 261.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Cement Set 13-3/8"Surface 2,118.0 2,618.0 Yes No Yes Casing Q Pump!nit(bbl/m...Q Pump Final(bb!/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 7 7 261.0 300.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 70 additional bbls of CW100 at 7 BPM,300psi,26%flow out. P/U=198k,S/O= 148k. Follow CW100 with 75bbls of Mud Push II.Drop bottom plug. Schlumberger cementers batch up and pump 551.9bbls of 11ppg Lead cement. P/U=205k,S/O=144k. Reciprocate pipe 20'thoughout. Pump 77.3bbls of 12ppg tail cement while reciprocating casing 15'. P/U=230k,S/0=115k. Drop Top Plug and kick out with 10bbI of H20.Swap over from Schlumberger cementers to rig pump for remainder of displacement. Pump with rig pump and displace cement with conditioned spud mud @ 6BPM initial rate.Pick up 4'to reciprocate casing with 50k overpull from las PU wt of 230k. Un-able to land casing on landing ring with hanger 4-1/2"off landing ring. Continue attemps to land hanger, initial rate of 6 BPM, 300psi,26%flow out for 490stk. Divert returns to cellar and reduce rate to 3 BPM, 150 psi ICP with 363psi FCP. Reduce rate to 1 BPM, 280psi FCP. Bump plug at 3643stks, increase to 500psi over FCP to 800psi and hold for 5min. Bleed pressure off and check floats(holding).Casing in Place at 14:26 and set at 2618'MD. 264bbl to surface. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,118.0 2,618.0 227 G 77.3 Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.63 5.48 12.00 3.88 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.03 gal/sx Additive Type Concentration Conc Unit label D046 BWOB Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D185 Dispersant 0.06 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead 48.3 2,118.0 1,619 G 551.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.91 6.83 11.00 5.75 Page 1/2 Report Printed: 1/7/2016 it 0 • • Cement Detail Report a i 1C-155 '• PhiWps String: Surface Cement Job: Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 1/7/2016 ,.. e c ...,...,, Cement Detail Report • :4 &W EIRS i. 1C-155 ConocoPhillips String: Intermediate Cement Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Cement 11/20/2015 06:15 11/20/2015 09:15 1C-155 Comment SLB pumped 5.3 bbl 11.5 ppg MudPush, PT lines to 3500 psi. Continue pumping 35 bbl MudPush @ 3 bpm,315 psi, 8%flow out for a total of 40.2 bbl. Drop bottom Weatherford plug, pump 187 bbl 15.8 ppg cement @ 6 bpm,260 psi 22%flow out. Drop top Weatherford plug,kick out with 10 bbl water.Swap to rig pumps and displace with 464 bbl 9.2 ppg LSND @ 6 bpm,730 psi, 18%flow out.Slow pump rate in stages to 3 BPM @ 690 PSI, 17%flow. Bump plug @ 4619 stks, pressure up 500 psi over to 1212 psi and hold for 5 minutes. Bleed pressure to 0 psi,bled back 2.9 bbl.Check floats-good. Final P/U=230k,S/O=70k.CIP: 09:14 hrs 11-20-15. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Cement Get Tail cement 500ft 3,758.0 6,413.0 Yes 0.0 Yes Yes above Ugnu C @ 4258' MD Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg (bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 6 3 6 380.0 600.0 Yes 18.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment SLomB pumped 5.3 bbl 11.5 ppg MudPush, PT lines to 3500 psi. Continue pumping 35 bbl MudPush©3 bpm,315 psi,8%flow out for a total of 40.2 bbl. Drop bottom Weatherford plug, pump 187 bbl 15.8 ppg cement @ 6 bpm,260 psi 22%flow out. Drop top Weatherford plug,kick out with 10 bbl water.Swap to rig pumps and displace with 464 bbl 9.2 ppg LSND @ 6 bpm,730 psi, 18%flow out. Slow pump rate in stages to 3 BPM @ 690 PSI, 17%flow. Bump plug @ 4619 stks,pressure up 500 psi over to 1212 psi and hold for 5 minutes. Bleed pressure to 0 psi, bled back 2.9 bbl.Check floats-good. Final P/U=230k,S/O=70k. CIP: 09:14 hrs 11-20-15. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 3,758.0 6,413.0 905 G 187.0 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 4.93 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D167 Fluid Loss 0.4 %BWOC Additive Type Concentration Conc Unit label D177 Retarder 0.005 gal/sx Page 1/1 Report Printed: 1/7/2016 215180 L6 5 4 1 RECEJV- Schlumber er rl�C � � t01J Transmittal#: 11DEC15-SP01 g ^� Drilling & Measurements DATA LOGGED AOA, MWD/LWD Log Product Delivery 1 /2014. K. BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-155 Date Dispatched: 11-Dec-15 Job#: 15AKA0095 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2'TVD x x VISION*Service 2'TVDSS x x VISION*Service 5'MD x x VISION*Service 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(a�conocophillips.com AlaskaPTSPrintCenter@slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 ,A" ") �cit.-0 ‹.-/) 6.,,,,„...at Received By: ��// lipiteGOV 2 1 5 1 8 0 Iry FINAL NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-155 Definitive Survey Report 03 December, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 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 Well 1C-155 Well Position +NI-S 0.00 usft Northing: 5,968,690.68 usfi Latitude: 70° 19'29.948 N +EI-W 0.00 usft Easting: 562,268.34 usfi Longitude: 149°29'42.280 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-155 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/30/2015 18.84 80.99 57,504 Design 1C-155 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.74 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (0) 39.74 0.00 0.00 350.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 72.32 1,956.99 1C-155 Srvy#1 -GWD(1C-155) GYD-GC-SS Gyrodata gyro single shots 11/11/2015 9:: 2,051.89 2,546.93 1C-155 Srvy#2-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1: 2,637.13 2,666.43 1C-155 Srvy#3-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/16/2015 1:: 2,760.65 6,334.51 1C-155 Srvy#4-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1:: 6,385.89 6,385.89 1C-155 Srvy#5-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/23/2015 8:. 6,480.35 13,361.25 1C-155 Srvy#6-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/23/2015 8:. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 39.74 0.00 0.00 39.74 -57.60 0.00 0.00 5,968,690.68 562,268.34 0.00 0.00 UNDEFINED 72.32 0.59 14.24 72.32 -25.02 0.16 0.04 5,968,690.84 562,268.38 1.81 0.15 GYD-GC-SS(1) 119.70 0.60 15.16 119.70 22.36 0.64 0.17 5,968,691.32 562,268.50 0.03 0.60 NOT an Actual Survey 20"x 34" 168.15 0.61 16.08 168.14 70.80 1.13 0.30 5,968,691.81 562,268.63 0.03 1.06 GYD-GC-SS(1) 265.69 0.81 14.13 265.68 168.34 2.30 0.62 5,968,692.98 562,268.94 0.21 2.16 GYD-GC-SS(1) 358.70 1.75 50.28 358.66 261.32 3.84 1.87 5,968,694.54 562,270.18 1.29 3.46 GYD-GC-SS(1) 452.24 3.85 69.40 452.09 354.75 5.86 5.91 5,968,696.59 562,274.20 2.43 4.75 GYD-GC-SS(1) 545.70 5.16 75.20 545.26 447.92 8.04 12.91 5,968,698.83 562,281.18 1.48 5.68 GYD-GC-SS(1) 637.71 6.82 79.52 636.76 539.42 10.09 22.28 5,968,700.95 562,290.53 1.87 6.07 GYD-GC-SS(1) 12/3/2015 1:28:17PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 731.23 8.19 81.98 729.48 632.14 12.03 34.34 5,968,702.99 562,302.57 1.50 5.88 GYD-GC-SS(1) 824.84 8.91 84.30 822.05 724.71 13.68 48.15 5,968,704.76 562,316.37 0.85 5.11 GYD-GC-SS(1) 916.99 8.05 84.19 913.19 815.85 15.04 61.67 5,968,706.23 562,329.88 0.93 4.10 GYD-GC-SS(1) 1,009.23 9.17 84.46 1,004.39 907.05 16.41 75.42 5,968,707.71 562,343.61 1.22 3.06 GYD-GC-SS(1) 1,104.71 11.66 70.82 1,098.30 1,000.96 20.31 92.11 5,968,711.75 562,360.27 3.65 4.01 GYD-GC-SS(1) 1,200.93 12.90 69.37 1,192.32 1,094.98 27.29 111.34 5,968,718.89 562,379.44 1.33 7.54 GYD-GC-SS(1) 1,295.15 13.07 73.91 1,284.13 1,186.79 33.95 131.42 5,968,725.71 562,399.46 1.10 10.61 GYD-GC-SS(1) 1,389.36 16.59 84.62 1,375.21 1,277.87 38.16 155.06 5,968,730.12 562,423.06 4.72 10.66 GYD-GC-SS(1) 1,484.07 16.53 88.38 1,465.99 1,368.65 39.81 181.99 5,968,732.00 562,449.98 1.13 7.61 GYD-GC-SS(1) 1,577.20 17.69 84.58 1,555.00 1,457.66 41.52 209.32 5,968,733.93 562,477.29 1.73 4.54 GYD-GC-SS(1) 1,671.49 19.92 85.86 1,644.25 1,546.91 44.04 239.61 5,968,736.70 562,507.55 2.41 1.76 GYD-GC-SS(1) 1,768.52 25.45 86.28 1,733.74 1,636.40 46.58 276.93 5,968,739.56 562,544.84 5.70 -2.21 GYD-GC-SS(1) 1,862.81 28.26 87.30 1,817.86 1,720.52 48.95 319.45 5,968,742.27 562,587.34 3.02 -7.26 GYD-GC-SS(1) 1,956.99 33.56 83.68 1,898.64 1,801.30 52.87 367.63 5,968,746.59 562,635.49 5.96 -11.77 GYD-GC-SS(1) 2,051.89 35.95 86.05 1,976.61 1,879.27 57.68 421.50 5,968,751.85 562,689.31 2.89 -16.39 MWD+IFR-AK-CAZ-SC(2) 2,109.96 37.07 88.03 2,023.28 1,925.94 59.45 456.00 5,968,753.91 562,723.79 2.80 -20.63 MWD+IFR-AK-CAZ-SC(2) 2,205.31 38.06 90.63 2,098.86 2,001.52 60.12 514.12 5,968,755.06 562,781.89 1.96 -30.07 MWD+IFR-AK-CAZ-SC(2) 2,300.42 42.63 92.27 2,171.34 2,074.00 58.52 575.65 5,968,753.97 562,843.43 4.93 -42.33 MWD+IFR-AK-CAZ-SC(2) 2,394.77 45.42 92.97 2,239.17 2,141.83 55.51 641.15 5,968,751.50 562,908.94 3.00 -56.67 MWD+IFR-AK-CAZ-SC(2) 2,489.15 47.23 94.01 2,304.35 2,207.01 51.35 709.28 5,968,747.91 562,977.10 2.08 -72.60 MWD+IFR-AK-CAZ-SC(2) 2,546.93 51.38 96.04 2,342.01 2,244.67 47.49 752.90 5,968,744.41 563,020.75 7.66 -83.97 MWD+IFR-AK-CAZ-SC(2) 2,617.70 50.42 96.03 2,386.64 2,289.30 41.71 807.52 5,968,739.09 563,075.41 1.35 -99.15 NOT an Actual Survey 13-3/8"x 16" 2,637.13 50.16 96.03 2,399.06 2,301.72 40.14 822.38 5,968,737.64 563,090.28 1.35 -103.27 INC+TREND(3) 2,666.43 52.96 95.98 2,417.27 2,319.93 37.74 845.20 5,968,735.43 563,113.12 9.56 -109.60 INC+TREND(3) 2,760.65 53.76 95.47 2,473.50 2,376.16 30.20 920.43 5,968,728.51 563,188.40 0.95 -130.09 MWD+IFR-AK-CAZ-SC(4) 2,853.32 53.92 97.23 2,528.18 2,430.84 21.93 994.78 5,968,720.86 563,262.81 1.54 -151.15 MWD+IFR-AK-CAZ-SC(4) 2,947.34 62.35 99.82 2,577.78 2,480.44 10.02 1,073.66 5,968,709.61 563,341.77 9.27 -176.57 MWD+IFR-AK-CAZ-SC(4) 3,043.78 61.74 101.04 2,622.99 2,525.65 -5.40 1,157.43 5,968,694.88 563,425.67 1.28 -206.30 MWD+IFR-AK-CAZ-SC(4) 3,137.58 60.81 94.36 2,668.11 2,570.77 -16.43 1,238.88 5,968,684.53 563,507.19 6.32 -231.31 MWD+IFR-AK-CAZ-SC(4) 3,232.30 57.75 92.00 2,716.50 2,619.16 -20.98 1,320.16 5,968,680.66 563,588.50 3.88 -249.90 MWD+IFR-AK-CAZ-SC(4) 3,326.86 57.26 86.47 2,767.32 2,669.98 -19.92 1,399.86 5,968,682.38 563,668.18 4.96 -262.70 MWD+IFR-AK-CAZ-SC(4) 3,420.95 57.68 80.60 2,817.95 2,720.61 -10.99 1,478.63 5,968,691.96 563,746.87 5.28 -267.58 MWD+IFR-AK-CAZ-SC(4) 3,514.77 58.17 73.22 2,867.82 2,770.48 7.01 1,555.97 5,968,710.60 563,824.05 6.68 -263.29 MWD+IFR-AK-CAZ-SC(4) 3,610.78 59.79 68.11 2,917.32 2,819.98 34.27 1,633.56 5,968,738.50 563,901.40 4.86 -249.92 MWD+IFR-AK-CAZ-SC(4) 3,704.90 61.43 62.16 2,963.54 2,866.20 68.76 1,707.90 5,968,773.60 563,975.45 5.78 -228.86 MWD+IFR-AK-CAZ-SC(4) 3,799.43 61.75 56.67 3,008.54 2,911.20 111.05 1,779.43 5,968,816.48 564,046.62 5.12 -199.64 MWD+IFR-AK-CAZ-SC(4) 3,893.61 57.74 53.53 3,055.99 2,958.65 157.54 1,846.15 5,968,863.51 564,112.95 5.14 -165.44 MWD+IFR-AK-CAZ-SC(4) 3,988.46 54.73 52.86 3,108.71 3,011.37 204.76 1,909.29 5,968,911.26 564,175.68 3.23 -129.89 MWD+IFR-AK-CAZ-SC(4) 4,083.17 55.09 49.01 3,163.16 3,065.82 253.59 1,969.43 5,968,960.58 564,235.41 3.35 -92.25 MWD+IFR-AK-CAZ-SC(4) 12/3/2015 1:28:17PM Page 3 COMPASS 5000.1 Build 74 S Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,179.07 55.71 45.47 3,217.63 3,120.29 307.18 2,027.37 5,969,014.64 564,292.90 3.11 -49.54 MWD+IFR-AK-CAZ-SC(4) 4,274.96 58.01 39.17 3,270.09 3,172.75 366.53 2,081.34 5,969,074.43 564,346.37 6.00 -0.46 MWD+IFR-AK-CAZ-SC(4) 4,367.16 60.57 33.29 3,317.20 3,219.86 430.46 2,128.11 5,969,138.74 564,392.60 6.14 54.38 MWD+IFR-AK-CAZ-SC(4) 4,461.80 60.94 31.69 3,363.44 3,266.10 500.11 2,172.46 5,969,208.75 564,436.37 1.53 115.27 MWD+IFR-AK-CAZ-SC(4) 4,557.03 62.11 27.13 3,408.86 3,311.52 573.01 2,213.54 5,969,281.98 564,476.83 4.38 179.93 MWD+IFR-AK-CAZ-SC(4) 4,650.87 62.40 23.72 3,452.55 3,355.21 648.00 2,249.18 5,969,357.26 564,511.85 3.23 247.59 MWD+IFR-AK-CAZ-SC(4) 4,744.72 63.79 16.93 3,495.06 3,397.72 726.43 2,278.20 5,969,435.92 564,540.21 6.62 319.79 MWD+IFR-AK-CAZ-SC(4) 4,839.02 65.48 13.13 3,535.47 3,438.13 808.70 2,300.27 5,969,518.36 564,561.60 4.06 396.98 MWD+IFR-AK-CAZ-SC(4) 4,934.43 64.01 14.02 3,576.17 3,478.83 892.58 2,320.52 5,969,602.40 564,581.15 1.76 476.07 MWD+IFR-AK-CAZ-SC(4) 5,029.56 64.54 14.28 3,617.47 3,520.13 975.68 2,341.47 5,969,685.66 564,601.41 0.61 554.27 MWD+IFR-AK-CAZ-SC(4) 5,123.87 68.47 16.31 3,655.06 3,557.72 1,059.08 2,364.30 5,969,769.24 564,623.55 4.61 632.43 MWD+IFR-AK-CAZ-SC(4) 5,218.83 72.36 17.08 3,686.89 3,589.55 1,144.76 2,390.00 5,969,855.12 564,648.54 4.17 712.34 MWD+IFR-AK-CAZ-SC(4) 5,312.90 74.02 16.53 3,714.09 3,616.75 1,230.96 2,416.04 5,969,941.52 564,673.85 1.85 792.72 MWD+IFR-AK-CAZ-SC(4) 5,407.74 74.18 15.92 3,740.07 3,642.73 1,318.54 2,441.52 5,970,029.30 564,698.60 0.64 874.54 MW D+I FR-AK-CAZ-SC(4) 5,502.68 75.67 13.39 3,764.77 3,667.43 1,407.22 2,464.70 5,970,118.17 564,721.05 3.01 957.85 MWD+IFR-AK-CAZ-SC(4) 5,597.27 79.09 10.41 3,785.44 3,688.10 1,497.52 2,483.72 5,970,208.61 564,739.31 4.75 1,043.47 MWD+IFR-AK-CAZ-SC(4) 5,692.49 81.17 6.03 3,801.76 3,704.42 1,590.34 2,497.11 5,970,301.53 564,751.93 5.03 1,132.56 MWD+IFR-AK-CAZ-SC(4) 5,786.05 79.87 1.57 3,817.18 3,719.84 1,682.39 2,503.24 5,970,393.62 564,757.29 4.90 1,222.15 MWD+IFR-AK-CAZ-SC(4) 5,881.82 79.05 357.92 3,834.71 3,737.37 1,776.52 2,502.82 5,970,487.74 564,756.09 3.84 1,314.93 MWD+IFR-AK-CAZ-SC(4) 5,976.79 82.02 357.43 3,850.32 3,752.98 1,870.11 2,499.02 5,970,581.29 564,751.52 3.17 1,407.75 MWD+IFR-AK-CAZ-SC(4) 6,070.87 82.57 355.64 3,862.94 3,765.60 1,963.17 2,493.38 5,970,674.28 564,745.11 1.97 1,500.37 MWD+IFR-AK-CAZ-SC(4) 6,165.06 83.65 353.60 3,874.24 3,776.90 2,056.26 2,484.61 5,970,767.29 564,735.57 2.44 1,593.57 MWD+IFR-AK-CAZ-SC(4) 6,260.18 83.11 351.76 3,885.20 3,787.86 2,149.97 2,472.58 5,970,860.89 564,722.76 2.00 1,687.95 MWD+IFR-AK-CAZ-SC(4) 6,334.51 86.83 351.17 3,891.72 3,794.38 2,223.18 2,461.59 5,970,934.00 564,711.16 5.07 1,761.96 MWD+IFR-AK-CAZ-SC(4) 6,385.89 87.39 350.12 3,894.31 3,796.97 2,273.81 2,453.25 5,970,984.55 564,702.40 2.31 1,813.27 INC+TREND(5) 6,403.90 87.45 349.98 3,895.12 3,797.78 2,291.54 2,450.14 5,971,002.25 564,699.15 0.85 1,831.26 NOT an Actual Survey(6) 9 5/8"x 12-1/4 6,480.35 87.70 349.38 3,898.36 3,801.02 2,366.68 2,436.46 5,971,077.27 564,684.84 0.85 1,907.64 MWD+IFR-AK-CAZ-SC(6) 6,575.03 88.97 348.60 3,901.11 3,803.77 2,459.58 2,418.38 5,971,170.00 564,666.00 1.57 2,002.26 MWD+IFR-AK-CAZ-SC(6) 6,670.19 88.93 347.13 3,902.85 3,805.51 2,552.59 2,398.38 5,971,262.84 564,645.23 1.55 2,097.34 MWD+IFR-AK-CAZ-SC(6) 6,764.99 88.75 346.76 3,904.77 3,807.43 2,644.92 2,376.97 5,971,354.98 564,623.06 0.43 2,191.98 MWD+IFR-AK-CAZ-SC(6) 6,860.01 90.75 345.71 3,905.18 3,807.84 2,737.21 2,354.36 5,971,447.07 564,599.69 2.38 2,286.79 MWD+IFR-AK-CAZ-SC(6) 6,954.56 91.68 344.16 3,903.18 3,805.84 2,828.48 2,329.80 5,971,538.13 564,574.36 1.91 2,380.95 MWD+IFR-AK-CAZ-SC(6) 7,049.54 92.16 342.21 3,900.00 3,802.66 2,919.35 2,302.34 5,971,628.75 564,546.15 2.11 2,475.20 MWD+IFR-AK-CAZ-SC(6) 7,143.82 91.51 343.87 3,896.98 3,799.64 3,009.48 2,274.85 5,971,718.64 564,517.92 1.89 2,568.73 MW D+I FR-AK-CAZ-SC(6) 7,239.06 90.68 343.78 3,895.16 3,797.82 3,100.93 2,248.32 5,971,809.86 564,490.64 0.88 2,663.40 MWD+IFR-AK-CAZ-SC(6) 7,333.98 90.31 342.44 3,894.34 3,797.00 3,191.75 2,220.75 5,971,900.44 564,462.32 1.46 2,757.63 MWD+IFR-AK-CAZ-SC(6) 7,430.05 89.17 342.01 3,894.77 3,797.43 3,283.23 2,191.42 5,971,991.67 564,432.23 1.27 2,852.81 MWD+IFR-AK-CAZ-SC(6) 7,523.69 88.80 340.36 3,896.43 3,799.09 3,371.85 2,161.23 5,972,080.02 564,401.31 1.81 2,945.33 MWD+IFR-AK-CAZ-SC(6) 7,618.22 89.72 338.82 3,897.65 3,800.31 3,460.43 2,128.26 5,972,168.32 564,367.62 1.90 3,038.29 MWD+IFR-AK-CAZ-SC(6) 12/3/2015 1:28:17PM Page 4 COMPASS 5000.1 Build 74 • i Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 7,713.82 89.86 336.97 3,898.00 3,800.66 3,549.00 2,092.29 5,972,256.58 564,330.91 1.94 3,131.76 MWD+IFR-AK-CAZ-SC(6) 7,808.02 89.76 334.70 3,898.32 3,800.98 3,634.94 2,053.73 5,972,342.19 564,291.64 2.41 3,223.09 MWD+IFR-AK-CAZ-SC(6) 7,902.33 90.58 333.71 3,898.04 3,800.70 3,719.85 2,012.69 5,972,426.75 564,249.91 1.36 3,313.84 MWD+IFR-AK-CAZ-SC(6) 7,998.07 90.99 332.36 3,896.72 3,799.38 3,805.17 1,969.29 5,972,511.70 564,205.80 1.47 3,405.40 MWD+IFR-AK-CAZ-SC(6) 8,093.37 90.75 333.83 3,895.28 3,797.94 3,890.14 1,926.17 5,972,596.30 564,161.98 1.56 3,496.57 MWD+IFR-AK-CAZ-SC(6) 8,186.95 91.68 333.89 3,893.29 3,795.95 3,974.13 1,884.95 5,972,679.94 564,120.07 1.00 3,586.44 MWD+IFR-AK-CAZ-SC(6) 8,281.44 94.00 334.74 3,888.61 3,791.27 4,059.18 1,844.05 5,972,764.63 564,078.47 2.61 3,677.29 MWD+IFR-AK-CAZ-SC(6) 8,376.55 93.05 337.26 3,882.76 3,785.42 4,145.89 1,805.44 5,972,851.01 564,039.15 2.83 3,769.39 MWD+IFR-AK-CAZ-SC(6) 8,471.01 91.82 339.80 3,878.75 3,781.41 4,233.71 1,770.90 5,972,938.53 564,003.88 2.99 3,861.87 MWD+IFR-AK-CAZ-SC(6) 8,565.72 90.68 341.72 3,876.68 3,779.34 4,323.10 1,739.70 5,973,027.65 563,971.95 2.36 3,955.33 MWD+IFR-AK-CAZ-SC(6) 8,660.80 90.34 344.14 3,875.84 3,778.50 4,413.98 1,711.80 5,973,118.29 563,943.29 2.57 4,049.67 MWD+IFR-AK-CAZ-SC(6) 8,754.59 89.89 345.99 3,875.65 3,778.31 4,504.60 1,687.63 5,973,208.70 563,918.37 2.03 4,143.11 MWD+IFR-AK-CAZ-SC(6) 8,850.05 88.25 344.89 3,877.20 3,779.86 4,596.98 1,663.63 5,973,300.86 563,893.61 2.07 4,238.25 MWD+IFR-AK-CAZ-SC(6) 8,945.18 86.53 341.34 3,881.53 3,784.19 4,687.89 1,636.04 5,973,391.54 563,865.27 4.14 4,332.58 MWD+IFR-AK-CAZ-SC(6) 9,038.66 85.86 341.38 3,887.73 3,790.39 4,776.28 1,606.23 5,973,479.66 563,834.73 0.72 4,424.79 MWD+IFR-AK-CAZ-SC(6) 9,134.65 87.43 344.79 3,893.35 3,796.01 4,867.94 1,578.35 5,973,571.08 563,806.10 3.91 4,519.91 MWD+IFR-AK-CAZ-SC(6) 9,228.61 89.60 348.68 3,895.79 3,798.45 4,959.34 1,556.81 5,973,662.29 563,783.80 4.74 4,613.66 MWD+IFR-AK-CAZ-SC(6) 9,322.41 89.93 352.49 3,896.17 3,798.83 5,051.86 1,541.47 5,973,754.67 563,767.69 4.08 4,707.44 MWD+IFR-AK-CAZ-SC(6) 9,419.25 89.89 353.65 3,896.33 3,798.99 5,147.99 1,529.78 5,973,850.69 563,755.21 1.20 4,804.13 MWD+IFR-AK-CAZ-SC(6) 9,514.72 89.35 353.43 3,896.96 3,799.62 5,242.85 1,519.04 5,973,945.45 563,743.68 0.61 4,899.42 MWD+IFR-AK-CAZ-SC(6) 9,607.76 89.72 353.46 3,897.71 3,800.37 5,335.28 1,508.42 5,974,037.78 563,732.30 0.40 4,992.29 MWD+IFR-AK-CAZ-SC(6) 9,704.03 89.83 351.71 3,898.09 3,800.75 5,430.74 1,496.00 5,974,133.13 563,719.08 1.82 5,088.46 MWD+IFR-AK-CAZ-SC(6) 9,798.27 90.10 346.06 3,898.15 3,800.81 5,523.17 1,477.84 5,974,225.40 563,700.16 6.00 5,182.64 MWD+IFR-AK-CAZ-SC(6) 9,850.00 90.34 343.67 3,897.95 3,800.61 5,573.10 1,464.33 5,974,275.21 563,686.24 4.64 5,234.16 MWD+IFR-AK-CAZ-SC(6) 9,906.93 91.32 340.90 3,897.13 3,799.79 5,627.32 1,447.01 5,974,329.28 563,668.47 5.16 5,290.56 MWD+IFR-AK-CAZ-SC(6) 9,987.77 91.10 341.55 3,895.42 3,798.08 5,703.84 1,421.00 5,974,405.57 563,641.83 0.85 5,370.44 MWD+IFR-AK-CAZ-SC(6) 10,083.02 91.13 343.33 3,893.57 3,796.23 5,794.64 1,392.27 5,974,496.11 563,612.35 1.87 5,464.84 MWD+IFR-AK-CAZ-SC(6) 10,179.12 91.30 345.58 3,891.53 3,794.19 5,887.19 1,366.52 5,974,588.45 563,585.84 2.35 5,560.46 MWD+IFR-AK-CAZ-SC(6) 10,273.62 92.90 345.22 3,888.07 3,790.73 5,978.58 1,342.72 5,974,679.62 563,561.28 1.74 5,654.59 MWD+IFR-AK-CAZ-SC(6) 10,369.01 92.08 345.45 3,883.92 3,786.58 6,070.77 1,318.59 5,974,771.60 563,536.39 0.89 5,749.57 MWD+IFR-AK-CAZ-SC(6) 10,463.29 93.09 347.94 3,879.67 3,782.33 6,162.42 1,296.92 5,974,863.06 563,513.96 2.85 5,843.59 MWD+IFR-AK-CAZ-SC(6) 10,558.31 89.57 347.62 3,877.46 3,780.12 6,255.25 1,276.81 5,974,955.71 563,493.09 3.72 5,938.50 MWD+IFR-AK-CAZ-SC(6) 10,653.64 88.76 346.31 3,878.85 3,781.51 6,348.11 1,255.32 5,975,048.38 563,470.82 1.62 6,033.68 MWD+IFR-AK-CAZ-SC(6) 10,749.09 89.21 343.42 3,880.54 3,783.20 6,440.22 1,230.40 5,975,140.27 563,445.14 3.06 6,128.72 MWD+IFR-AK-CAZ-SC(6) 10,844.24 90.68 340.95 3,880.63 3,783.29 6,530.80 1,201.29 5,975,230.60 563,415.29 3.02 6,222.98 MWD+IFR-AK-CAZ-SC(6) 10,938.95 90.96 340.28 3,879.28 3,781.94 6,620.13 1,169.86 5,975,319.66 563,383.12 0.77 6,316.41 MWD+IFR-AK-CAZ-SC(6) 11,033.99 90.68 339.81 3,877.92 3,780.58 6,709.46 1,137.43 5,975,408.70 563,349.95 0.58 6,410.01 MWD+IFR-AK-CAZ-SC(6) 11,128.65 89.86 340.13 3,877.47 3,780.13 6,798.39 1,105.01 5,975,497.35 563,316.80 0.93 6,503.22 MWD+IFR-AK-CAZ-SC(6) 11,222.36 88.34 339.43 3,878.95 3,781.61 6,886.31 1,072.62 5,975,584.99 563,283.69 1.79 6,595.43 MWD+IFR-AK-CAZ-SC(6) 11,316.99 88.80 339.83 3,881.31 3,783.97 6,974.99 1,039.70 5,975,673.39 563,250.03 0.64 6,688.49 MWD+IFR-AK-CAZ-SC(6) 12/3/2015 1:28:17PM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 11,412.91 90.42 342.11 3,881.96 3,784.62 7,065.66 1,008.42 5,975,763.79 563,218.01 2.92 6,783.21 MWD+IFR-AK-CAZ-SC(6) 11,507.27 90.34 344.51 3,881.33 3,783.99 7,156.04 981.33 5,975,853.93 563,190.16 2.54 6,876.91 MWD+IFR-AK-CAZ-SC(6) 11,602.13 90.75 346.66 3,880.43 3,783.09 7,247.90 957.71 5,975,945.58 563,165.79 2.31 6,971.48 MWD+IFR-AK-CAZ-SC(6) 11,697.41 90.38 348.72 3,879.49 3,782.15 7,340.98 937.40 5,976,038.48 563,144.71 2.20 7,066.68 MWD+IFR-AK-CAZ-SC(6) 11,791.35 90.24 347.88 3,878.98 3,781.64 7,432.97 918.35 5,976,130.30 563,124.90 0.91 7,160.57 MWD+IFR-AK-CAZ-SC(6) 11,886.11 90.24 349.37 3,878.59 3,781.25 7,525.86 899.66 5,976,223.03 563,105.44 1.57 7,255.30 MWD+IFR-AK-CAZ-SC(6) 11,981.51 89.96 349.18 3,878.42 3,781.08 7,619.59 881.91 5,976,316.60 563,086.91 0.35 7,350.69 MWD+IFR-AK-CAZ-SC(6) 12,075.49 89.21 348.26 3,879.10 3,781.76 7,711.75 863.53 5,976,408.60 563,067.77 1.26 7,444.65 MWD+IFR-AK-CAZ-SC(6) 12,170.39 87.97 347.74 3,881.44 3,784.10 7,804.55 843.80 5,976,501.22 563,047.28 1.42 7,539.46 MWD+IFR-AK-CAZ-SC(6) 12,265.05 91.41 348.03 3,881.95 3,784.61 7,897.09 823.94 5,976,593.58 563,026.65 3.65 7,634.04 MWD+IFR-AK-CAZ-SC(6) 12,359.55 89.39 348.74 3,881.29 3,783.95 7,989.64 804.92 5,976,685.96 563,006.86 2.27 7,728.49 MWD+IFR-AK-CAZ-SC(6) 12,454.39 90.31 347.84 3,881.54 3,784.20 8,082.51 785.67 5,976,778.66 562,986.84 1.36 7,823.29 MWD+IFR-AK-CAZ-SC(6) 12,551.27 90.96 346.15 3,880.46 3,783.12 8,176.89 763.87 5,976,872.85 562,964.26 1.87 7,920.02 MWD+IFR-AK-CAZ-SC(6) 12,644.81 90.34 345.50 3,879.40 3,782.06 8,267.58 740.96 5,976,963.33 562,940.61 0.96 8,013.31 MWD+IFR-AK-CAZ-SC(6) 12,739.68 90.10 346.07 3,879.04 3,781.70 8,359.54 717.67 5,977,055.09 562,916.55 0.65 8,107.92 MWD+IFR-AK-CAZ-SC(6) 12,830.37 88.97 344.53 3,879.77 3,782.43 8,447.26 694.66 5,977,142.60 562,892.82 2.11 8,198.30 MWD+IFR-AK-CAZ-SC(6) 12,929.88 88.52 343.48 3,881.95 3,784.61 8,542.89 667.24 5,977,238.00 562,864.61 1.15 8,297.24 MWD+IFR-AK-CAZ-SC(6) 13,024.92 89.52 344.15 3,883.58 3,786.24 8,634.15 640.76 5,977,329.02 562,837.37 1.27 8,391.71 MWD+IFR-AK-CAZ-SC(6) 13,118.82 90.41 344.44 3,883.64 3,786.30 8,724.54 615.34 5,977,419.19 562,811.21 1.00 8,485.14 MWD+IFR-AK-CAZ-SC(6) 13,212.14 90.96 344.32 3,882.52 3,785.18 8,814.41 590.22 5,977,508.84 562,785.34 0.60 8,578.01 MWD+IFR-AK-CAZ-SC(6) 13,310.26 91.95 343.50 3,880.03 3,782.69 8,908.65 563.03 5,977,602.85 562,757.38 1.31 8,675.54 MWD+IFR-AK-CAZ-SC(6) 13,361.25 91.89 343.98 3,878.32 3,780.98 8,957.58 548.76 5,977,651.64 562,742.71 0.95 8,726.20 MWD+IFR-AK-CAZ-SC(6) 13,395.00 91.89 343.98 3,877.21 3,779.87 8,990.00 539.45 5,977,683.98 562,733.13 0.00 8,759.74 NOT an Actual Survey 4 112"x 6-3/4" 13,435.00 91.89 343.98 3,875.89 3,778.55 9,028.42 528.42 5,977,722.31 562,721.78 0.00 8,799.50 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. ❑O Yes ❑ No I have checked to the best of my ability that the following data is correct: (J Surface Coordinates n Declination & Convergence (J GRS Survey Corrections ❑ Survey Tool Codes nuc, omce,`� Vincent �stou, , SLB DE: Osara a,t wstr .t_L, _ Pate241S'PEG 139Qia OWEC steve.shultzc+contrad ..-m....o o... Client Representative: or.conocophlllips.com Date: 03-Dec-2015 12/3/2015 1:28:17PM Page 6 COMPASS 5000.1 Build 74 L1 51 80 • Lb541 RECEN FINAL 7,;c. i i �Us� ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1C-155 Definitive Survey Report 02 December, 2015 NAD 83 0 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1C-155 Well Position +N/-S 0.00 usft Northing: 5,968,442.44 usfl Latitude: 70° 19'28.904 N +E/-W 0.00 usft Easting: 1,702,300.26 usfi Longitude: 149°29'53.458 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-155 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 11/30/2015 18.84 80.99 57,504 Design 1C-155 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.74 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (usft) (usft) (usft) (0) 39.74 0.00 0.00 350.00 Survey Program Date 12/2/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 72.32 1,956.99 1C-155 Srvy#1 -GWD(1C-155) GYD-GC-SS Gyrodata gyro single shots 11/11/2015 9:: 2,051.89 2,546.93 1C-155 Srvy#2-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1:: 2,637.13 2,666.43 1C-155 Srvy#3-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/16/2015 1:: 2,760.65 6,334.51 1C-155 Srvy#4-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/16/2015 1:: 6,385.89 6,385.89 1C-155 Srvy#5-Inc only(1C-155) INC+TREND Inclinometer+known azi trend 11/23/2015 8:. 6,480.35 13,361.25 1C-155 Srvy#6-GMAG(1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/23/2015 8:, Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 39.74 0.00 0.00 39.74 -57.60 0.00 0.00 5,968,442.44 1,702,300.26 0.00 0.00 UNDEFINED 72.32 0.59 14.24 72.32 -25.02 0.16 0.04 5,968,442.60 1,702,300.30 1.81 0.15 GYD-GC-SS(1) 119.70 0.60 15.16 119.70 22.36 0.64 0.17 5,968,443.08 1,702,300.42 0.03 0.60 NOT an Actual Survey 20"x 34" 168.15 0.61 16.08 168.14 70.80 1.13 0.30 5,968,443.57 1,702,300.56 0.03 1.06 GYD-GC-SS(1) 265.69 0.81 14.13 265.68 168.34 2.30 0.62 5,968,444.74 1,702,300.86 0.21 2.16 GYD-GC-SS(1) 358.70 1.75 50.28 358.66 261.32 3.84 1.87 5,968,446.30 1,702,302.10 1.29 3.46 GYD-GC-SS(1) 452.24 3.85 69.40 452.09 354.75 5.86 5.91 5,968,448.35 1,702,306.12 2.43 4.75 GYD-GC-SS(1) 545.70 5.16 75.20 545.26 447.92 8.04 12.91 5,968,450.58 1,702,313.10 1.48 5.68 GYD-GC-SS(1) 637.71 6.82 79.52 636.76 539.42 10.09 22.28 5,968,452.71 1,702,322.46 1.87 6.07 GYD-GC-SS(1) 12/2/2015 4:43:38PM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 731.23 8.19 81.98 729.48 632.14 12.03 34.34 5,968,454.75 1,702,334.50 1.50 5.88 GYD-GC-SS(1) 824.84 8.91 84.30 822.05 724.71 13.68 48.15 5,968,456.51 1,702,348.30 0.85 5.11 GYD-GC-SS(1) 916.99 8.05 84.19 913.19 815.85 15.04 61.67 5,968,457.99 1,702,361.80 0.93 4.10 GYD-GC-SS(1) 1,009.23 9.17 84.46 1,004.39 907.05 16.41 75.42 5,968,459.46 1,702,375.53 1.22 3.06 GYD-GC-SS(1) 1,104.71 11.66 70.82 1,098.30 1,000.96 20.31 92.11 5,968,463.51 1,702,392.19 3.65 4.01 GYD-GC-SS(1) 1,200.93 12.90 69.37 1,192.32 1,094.98 27.29 111.34 5,968,470.64 1,702,411.37 1.33 7.54 GYD-GC-SS(1) 1,295.15 13.07 73.91 1,284.13 1,186.79 33.95 131.42 5,968,477.47 1,702,431.39 1.10 10.61 GYD-GC-SS(1) 1,389.36 16.59 84.62 1,375.21 1,277.87 38.16 155.06 5,968,481.88 1,702,454.99 4.72 10.66 GYD-GC-SS(1) 1,484.07 16.53 88.38 1,465.99 1,368.65 39.81 181.99 5,968,483.75 1,702,481.90 1.13 7.61 GYD-GC-SS(1) 1,577.20 17.69 84.58 1,555.00 1,457.66 41.52 209.32 5,968,485.68 1,702,509.21 1.73 4.54 GYD-GC-SS(1) 1,671.49 19.92 85.86 1,644.25 1,546.91 44.04 239.61 5,968,488.44 1,702,539.47 2.41 1.76 GYD-GC-SS(1) 1,768.52 25.45 86.28 1,733.74 1,636.40 46.58 276.93 5,968,491.30 1,702,576.77 5.70 -2.21 GYD-GC-SS(1) 1,862.81 28.26 87.30 1,817.86 1,720.52 48.95 319.45 5,968,494.02 1,702,619.27 3.02 -7.26 GYD-GC-SS(1) 1,956.99 33.56 83.68 1,898.64 1,801.30 52.87 367.63 5,968,498.33 1,702,667.41 5.96 -11.77 GYD-GC-SS(1) 2,051.89 35.95 86.05 1,976.61 1,879.27 57.68 421.50 5,968,503.58 1,702,721.24 2.89 -16.39 MWD+IFR-AK-CAZ-SC(2) 2,109.96 37.07 88.03 2,023.28 1,925.94 59.45 456.00 5,968,505.64 1,702,755.72 2.80 -20.63 MWD+IFR-AK-CAZ-SC(2) 2,205.31 38.06 90.63 2,098.86 2,001.52 60.12 514.12 5,968,506.79 1,702,813.82 1.96 -30.07 MWD+IFR-AK-CAZ-SC(2) 2,300.42 42.63 92.27 2,171.34 2,074.00 58.52 575.65 5,968,505.70 1,702,875.36 4.93 -42.33 MWD+IFR-AK-CAZ-SC(2) 2,394.77 45.42 92.97 2,239.17 2,141.83 55.51 641.15 5,968,503.23 1,702,940.87 3.00 -56.67 MWD+IFR-AK-CAZ-SC(2) 2,489.15 47.23 94.01 2,304.35 2,207.01 51.35 709.28 5,968,499.63 1,703,009.02 2.08 -72.60 MWD+IFR-AK-CAZ-SC(2) 2,546.93 51.38 96.04 2,342.01 2,244.67 47.49 752.90 5,968,496.13 1,703,052.67 7.66 -83.97 MWD+IFR-AK-CAZ-SC(2) 2,617.70 50.42 96.03 2,386.64 2,289.30 41.71 807.52 5,968,490.80 1,703,107.33 1.35 -99.15 I NOT an Actual Survey 13-3/8"x 16" 2,637.13 50.16 96.03 2,399.06 2,301.72 40.14 822.38 5,968,489.36 1,703,122.21 1.35 -103.27 INC+TREND(3) 2,666.43 52.96 95.98 2,417.27 2,319.93 37.74 845.20 5,968,487.14 1,703,145.04 9.56 -109.60 INC+TREND(3) 2,760.65 53.76 95.47 2,473.50 2,376.16 30.20 920.43 5,968,480.23 1,703,220.32 0.95 -130.09 MWD+IFR-AK-CAZ-SC(4) 2,853.32 53.92 97.23 2,528.18 2,430.84 21.93 994.78 5,968,472.56 1,703,294.73 1.54 -151.15 MWD+IFR-AK-CAZ-SC(4) 2,947.34 62.35 99.82 2,577.78 2,480.44 10.02 1,073.66 5,968,461.31 1,703,373.70 9.27 -176.57 MWD+IFR-AK-CAZ-SC(4) 3,043.78 61.74 101.04 2,622.99 2,525.65 -5.40 1,157.43 5,968,446.58 1,703,457.59 1.28 -206.30 MWD+IFR-AK-CAZ-SC(4) 3,137.58 60.81 94.36 2,668.11 2,570.77 -16.43 1,238.88 5,968,436.22 1,703,539.11 6.32 -231.31 MWD+IFR-AK-CAZ-SC(4) 3,232.30 57.75 92.00 2,716.50 2,619.16 -20.98 1,320.16 5,968,432.35 1,703,620.42 3.88 -249.90 MWD+IFR-AK-CAZ-SC(4) 3,326.86 57.26 86.47 2,767.32 2,669.98 -19.92 1,399.86 5,968,434.06 1,703,700.10 4.96 -262.70 MWD+IFR-AK-CAZ-SC(4) 3,420.95 57.68 80.60 2,817.95 2,720.61 -10.99 1,478.63 5,968,443.65 1,703,778.79 5.28 -267.58 MWD+IFR-AK-CAZ-SC(4) 3,514.77 58.17 73.22 2,867.82 2,770.48 7.01 1,555.97 5,968,462.28 1,703,855.98 6.68 -263.29 MWD+IFR-AK-CAZ-SC(4) 3,610.78 59.79 68.11 2,917.32 2,819.98 34.27 1,633.56 5,968,490.17 1,703,933.33 4.86 -249.92 MWD+IFR-AK-CAZ-SC(4) 3,704.90 61.43 62.16 2,963.54 2,866.20 68.76 1,707.90 5,968,525.27 1,704,007.37 5.78 -228.86 MWD+IFR-AK-CAZ-SC(4) 3,799.43 61.75 56.67 3,008.54 2,911.20 111.05 1,779.43 5,968,568.14 1,704,078.55 5.12 -199.64 MWD+IFR-AK-CAZ-SC(4) 3,893.61 57.74 53.53 3,055.99 2,958.65 157.54 1,846.15 5,968,615.18 1,704,144.88 5.14 -165.44 MWD+IFR-AK-CAZ-SC(4) 3,988.46 54.73 52.86 3,108.71 3,011.37 204.76 1,909.29 5,968,662.92 1,704,207.61 3.23 -129.89 MWD+IFR-AK-CAZ-SC(4) 4,083.17 55.09 49.01 3,163.16 3,065.82 253.59 1,969.43 5,968,712.24 1,704,267.35 3.35 -92.25 MWD+IFR-AK-CAZ-SC(4) 12/2/2015 4:43:38PM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,179.07 55.71 45.47 3,217.63 3,120.29 307.18 2,027.37 5,968,766.29 1,704,324.84 3.11 -49.54 MWD+IFR-AK-CAZ-SC(4) 4,274.96 58.01 39.17 3,270.09 3,172.75 366.53 2,081.34 5,968,826.08 1,704,378.31 6.00 -0.46 MWD+IFR-AK-CAZ-SC(4) 4,367.16 60.57 33.29 3,317.20 3,219.86 430.46 2,128.11 5,968,890.39 1,704,424.55 6.14 54.38 MWD+IFR-AK-CAZ-SC(4) 4,461.80 60.94 31.69 3,363.44 3,266.10 500.11 2,172.46 5,968,960.40 1,704,468.32 1.53 115.27 MWD+IFR-AK-CAZ-SC(4) 4,557.03 62.11 27.13 3,408.86 3,311.52 573.01 2,213.54 5,969,033.63 1,704,508.79 4.38 179.93 MWD+IFR-AK-CAZ-SC(4) 4,650.87 62.40 23.72 3,452.55 3,355.21 648.00 2,249.18 5,969,108.90 1,704,543.81 3.23 247.59 MWD+IFR-AK-CAZ-SC(4) 4,744.72 63.79 16.93 3,495.06 3,397.72 726.43 2,278.20 5,969,187.56 1,704,572.17 6.62 319.79 MWD+IFR-AK-CAZ-SC(4) 4,839.02 65.48 13.13 3,535.47 3,438.13 808.70 2,300.27 5,969,270.01 1,704,593.56 4.06 396.98 MWD+IFR-AK-CAZ-SC(4) 4,934.43 64.01 14.02 3,576.17 3,478.83 892.58 2,320.52 5,969,354.04 1,704,613.12 1.76 476.07 MWD+IFR-AK-CAZ-SC(4) 5,029.56 64.54 14.28 3,617.47 3,520.13 975.68 2,341.47 5,969,437.30 1,704,633.38 0.61 554.27 MWD+IFR-AK-CAZ-SC(4) 5,123.87 68.47 16.31 3,655.06 3,557.72 1,059.08 2,364.30 5,969,520.88 1,704,655.52 4.61 632.43 MWD+IFR-AK-CAZ-SC(4) 5,218.83 72.36 17.08 3,686.89 3,589.55 1,144.76 2,390.00 5,969,606.75 1,704,680.52 4.17 712.34 MWD+IFR-AK-CAZ-SC(4) 5,312.90 74.02 16.53 3,714.09 3,616.75 1,230.96 2,416.04 5,969,693.16 1,704,705.83 1.85 792.72 MWD+IFR-AK-CAZ-SC(4) 5,407.74 74.18 15.92 3,740.07 3,642.73 1,318.54 2,441.52 5,969,780.94 1,704,730.59 0.64 874.54 MWD+IFR-AK-CAZ-SC(4) 5,502.68 75.67 13.39 3,764.77 3,667.43 1,407.22 2,464.70 5,969,869.80 1,704,753.04 3.01 957.85 MWD+IFR-AK-CAZ-SC(4) 5,597.27 79.09 10.41 3,785.44 3,688.10 1,497.52 2,483.72 5,969,960.24 1,704,771.31 4.75 1,043.47 MWD+IFR-AK-CAZ-SC(4) 5,692.49 81.17 6.03 3,801.76 3,704.42 1,590.34 2,497.11 5,970,053.16 1,704,783.94 5.03 1,132.56 MWD+IFR-AK-CAZ-SC(4) 5,786.05 79.87 1.57 3,817.18 3,719.84 1,682.39 2,503.24 5,970,145.25 1,704,789.30 4.90 1,222.15 MWD+IFR-AK-CAZ-SC(4) 5,881.82 79.05 357.92 3,834.71 3,737.37 1,776.52 2,502.82 5,970,239.37 1,704,788.11 3.84 1,314.93 MWD+IFR-AK-CAZ-SC(4) 5,976.79 82.02 357.43 3,850.32 3,752.98 1,870.11 2,499.02 5,970,332.92 1,704,783.54 3.17 1,407.75 MWD+IFR-AK-CAZ-SC(4) 6,070.87 82.57 355.64 3,862.94 3,765.60 1,963.17 2,493.38 5,970,425.91 1,704,777.13 1.97 1,500.37 MWD+IFR-AK-CAZ-SC(4) 6,165.06 83.65 353.60 3,874.24 3,776.90 2,056.26 2,484.61 5,970,518.92 1,704,767.60 2.44 1,593.57 MWD+IFR-AK-CAZ-SC(4) 6,260.18 83.11 351.76 3,885.20 3,787.86 2,149.97 2,472.58 5,970,612.52 1,704,754.79 2.00 1,687.95 MWD+IFR-AK-CAZ-SC(4) 6,334.51 86.83 351.17 3,891.72 3,794.38 2,223.18 2,461.59 5,970,685.63 1,704,743.20 5.07 1,761.96 MWD+IFR-AK-CAZ-SC(4) 6,385.89 87.39 350.12 3,894.31 3,796.97 2,273.81 2,453.25 5,970,736.19 1,704,734.44 2.31 1,813.27 INC+TREND(5) 6,403.90 87.45 349.98 3,895.12 3,797.78 2,291.54 2,450.14 5,970,753.88 1,704,731.19 0.85 1,831.26 I,NOT anActual Survey`6) 9 5/8"x 12-1/4 6,480.35 87.70 349.38 3,898.36 3,801.02 2,366.68 2,436.46 5,970,828.90 1,704,716.89 0.85 1,907.64 MWD+IFR-AK-CAZ-SC(6) 6,575.03 88.97 348.60 3,901.11 3,803.77 2,459.58 2,418.38 5,970,921.64 1,704,698.05 1.57 2,002.26 MWD+IFR-AK-CAZ-SC(6) 6,670.19 88.93 347.13 3,902.85 3,805.51 2,552.59 2,398.38 5,971,014.48 1,704,677.28 1.55 2,097.34 MWD+IFR-AK-CAZ-SC(6) 6,764.99 88.75 346.76 3,904.77 3,807.43 2,644.92 2,376.97 5,971,106.62 1,704,655.11 0.43 2,191.98 MWD+IFR-AK-CAZ-SC(6) 6,860.01 90.75 345.71 3,905.18 3,807.84 2,737.21 2,354.36 5,971,198.70 1,704,631.75 2.38 2,286.79 MWD+IFR-AK-CAZ-SC(6) 6,954.56 91.68 344.16 3,903.18 3,805.84 2,828.48 2,329.80 5,971,289.77 1,704,606.43 1.91 2,380.95 MWD+IFR-AK-CAZ-SC(6) 7,049.54 92.16 342.21 3,900.00 3,802.66 2,919.35 2,302.34 5,971,380.39 1,704,578.23 2.11 2,475.20 MWD+IFR-AK-CAZ-SC(6) 7,143.82 91.51 343.87 3,896.98 3,799.64 3,009.48 2,274.85 5,971,470.28 1,704,550.00 1.89 2,568.73 MWD+IFR-AK-CAZ-SC(6) 7,239.06 90.68 343.78 3,895.16 3,797.82 3,100.93 2,248.32 5,971,561.50 1,704,522.72 0.88 2,663.40 MWD+IFR-AK-CAZ-SC(6) 7,333.98 90.31 342.44 3,894.34 3,797.00 3,191.75 2,220.75 5,971,652.09 1,704,494.40 1.46 2,757.63 MWD+IFR-AK-CAZ-SC(6) 7,430.05 89.17 342.01 3,894.77 3,797.43 3,283.23 2,191.42 5,971,743.31 1,704,464.32 1.27 2,852.81 MWD+IFR-AK-CAZ-SC(6) 7,523.69 88.80 340.36 3,896.43 3,799.09 3,371.85 2,161.23 5,971,831.67 1,704,433.40 1.81 2,945.33 MWD+IFR-AK-CAZ-SC(6) 7,618.22 89.72 338.82 3,897.65 3,800.31 3,460.43 2,128.26 5,971,919.97 1,704,399.71 1.90 3,038.29 MWD+IFR-AK-CAZ-SC(6) 12/2/2015 4:43:38PM Page 4 COMPASS 5000.1 Build 74 0 • Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,713.82 89.86 336.97 3,898.00 3,800.66 3,549.00 2,092.29 5,972,008.23 1,704,363.02 1.94 3,131.76 MWD+IFR-AK-CAZ-SC(6) 7,808.02 89.76 334.70 3,898.32 3,800.98 3,634.94 2,053.73 5,972,093.84 1,704,323.75 2.41 3,223.09 MWD+IFR-AK-CAZ-SC(6) 7,902.33 90.58 333.71 3,898.04 3,800.70 3,719.85 2,012.69 5,972,178.40 1,704,282.02 1.36 3,313.84 MWD+IFR-AK-CAZ-SC(6) 7,998.07 90.99 332.36 3,896.72 3,799.38 3,805.17 1,969.29 5,972,263.36 1,704,237.91 1.47 3,405.40 MWD+IFR-AK-CAZ-SC(6) 8,093.37 90.75 333.83 3,895.28 3,797.94 3,890.14 1,926.17 5,972,347.96 1,704,194.10 1.56 3,496.57 MWD+IFR-AK-CAZ-SC(6) 8,186.95 91.68 333.89 3,893.29 3,795.95 3,974.13 1,884.95 5,972,431.60 1,704,152.20 1.00 3,586.44 MWD+IFR-AK-CAZ-SC(6) 8,281.44 94.00 334.74 3,888.61 3,791.27 4,059.18 1,844.05 5,972,516.29 1,704,110.60 2.61 3,677.29 MWD+IFR-AK-CAZ-SC(6) 8,376.55 93.05 337.26 3,882.76 3,785.42 4,145.89 1,805.44 5,972,602.68 1,704,071.28 2.83 3,769.39 MWD+IFR-AK-CAZ-SC(6) 8,471.01 91.82 339.80 3,878.75 3,781.41 4,233.71 1,770.90 5,972,690.20 1,704,036.02 2.99 3,861.87 MWD+IFR-AK-CAZ-SC(6) 8,565.72 90.68 341.72 3,876.68 3,779.34 4,323.10 1,739.70 5,972,779.33 1,704,004.09 2.36 3,955.33 MWD+IFR-AK-CAZ-SC(6) 8,660.80 90.34 344.14 3,875.84 3,778.50 4,413.98 1,711.80 5,972,869.96 1,703,975.44 2.57 4,049.67 MWD+IFR-AK-CAZ-SC(6) 8,754.59 89.89 345.99 3,875.65 3,778.31 4,504.60 1,687.63 5,972,960.37 1,703,950.52 2.03 4,143.11 MWD+IFR-AK-CAZ-SC(6) 8,850.05 88.25 344.89 3,877.20 3,779.86 4,596.98 1,663.63 5,973,052.54 1,703,925.77 2.07 4,238.25 MWD+IFR-AK-CAZ-SC(6) 8,945.18 86.53 341.34 3,881.53 3,784.19 4,687.89 1,636.04 5,973,143.22 1,703,897.43 4.14 4,332.58 MWD+IFR-AK-CAZ-SC(6) 9,038.66 85.86 341.38 3,887.73 3,790.39 4,776.28 1,606.23 5,973,231.34 1,703,866.89 0.72 4,424.79 MWD+IFR-AK-CAZ-SC(6) 9,134.65 87.43 344.79 3,893.35 3,796.01 4,867.94 1,578.35 5,973,322.76 1,703,838.27 3.91 4,519.91 MWD+IFR-AK-CAZ-SC(6) 9,228.61 89.60 348.68 3,895.79 3,798.45 4,959.34 1,556.81 5,973,413.97 1,703,815.97 4.74 4,613.66 MWD+IFR-AK-CAZ-SC(6) 9,322.41 89.93 352.49 3,896.17 3,798.83 5,051.86 1,541.47 5,973,506.35 1,703,799.87 4.08 4,707.44 MWD+IFR-AK-CAZ-SC(6) 9,419.25 89.89 353.65 3,896.33 3,798.99 5,147.99 1,529.78 5,973,602.37 1,703,787.39 1.20 4,804.13 MWD+IFR-AK-CAZ-SC(6) 9,514.72 89.35 353.43 3,896.96 3,799.62 5,242.85 1,519.04 5,973,697.13 1,703,775.87 0.61 4,899.42 MWD+IFR-AK-CAZ-SC(6) 9,607.76 89.72 353.46 3,897.71 3,800.37 5,335.28 1,508.42 5,973,789.46 1,703,764.49 0.40 4,992.29 MWD+IFR-AK-CAZ-SC(6) 9,704.03 89.83 351.71 3,898.09 3,800.75 5,430.74 1,496.00 5,973,884.81 1,703,751.28 1.82 5,088.46 MWD+IFR-AK-CAZ-SC(6) 9,798.27 90.10 346.06 3,898.15 3,800.81 5,523.17 1,477.84 5,973,977.08 1,703,732.36 6.00 5,182.64 MWD+IFR-AK-CAZ-SC(6) 9,850.00 90.34 343.67 3,897.95 3,800.61 5,573.10 1,464.33 5,974,026.90 1,703,718.45 4.64 5,234.16 MWD+IFR-AK-CAZ-SC(6) 9,906.93 91.32 340.90 3,897.13 3,799.79 5,627.32 1,447.01 5,974,080.97 1,703,700.68 5.16 5,290.56 MWD+IFR-AK-CAZ-SC(6) 9,987.77 91.10 341.55 3,895.42 3,798.08 5,703.84 1,421.00 5,974,157.26 1,703,674.04 0.85 5,370.44 MWD+IFR-AK-CAZ-SC(6) 10,083.02 91.13 343.33 3,893.57 3,796.23 5,794.64 1,392.27 5,974,247.80 1,703,644.57 1.87 5,464.84 MWD+IFR-AK-CAZ-SC(6) 10,179.12 91.30 345.58 3,891.53 3,794.19 5,887.19 1,366.52 5,974,340.14 1,703,618.06 2.35 5,560.46 MWD+IFR-AK-CAZ-SC(6) 10,273.62 92.90 345.22 3,888.07 3,790.73 5,978.58 1,342.72 5,974,431.31 1,703,593.51 1.74 5,654.59 MWD+IFR-AK-CAZ-SC(6) 10,369.01 92.08 345.45 3,883.92 3,786.58 6,070.77 1,318.59 5,974,523.30 1,703,568.62 0.89 5,749.57 MWD+IFR-AK-CAZ-SC(6) 10,463.29 93.09 347.94 3,879.67 3,782.33 6,162.42 1,296.92 5,974,614.75 1,703,546.19 2.85 5,843.59 MWD+IFR-AK-CAZ-SC(6) 10,558.31 89.57 347.62 3,877.46 3,780.12 6,255.25 1,276.81 5,974,707.40 1,703,525.33 3.72 5,938.50 MWD+IFR-AK-CAZ-SC(6) 10,653.64 88.76 346.31 3,878.85 3,781.51 6,348.11 1,255.32 5,974,800.07 1,703,503.07 1.62 6,033.68 MWD+IFR-AK-CAZ-SC(6) 10,749.09 89.21 343.42 3,880.54 3,783.20 6,440.22 1,230.40 5,974,891.97 1,703,477.40 3.06 6,128.72 MWD+IFR-AK-CAZ-SC(6) 10,844.24 90.68 340.95 3,880.63 3,783.29 6,530.80 1,201.29 5,974,982.30 1,703,447.54 3.02 6,222.98 MWD+IFR-AK-CAZ-SC(6) 10,938.95 90.96 340.28 3,879.28 3,781.94 6,620.13 1,169.86 5,975,071.36 1,703,415.38 0.77 6,316.41 MWD+IFR-AK-CAZ-SC(6) 11,033.99 90.68 339.81 3,877.92 3,780.58 6,709.46 1,137.43 5,975,160.40 1,703,382.22 0.58 6,410.01 MWD+IFR-AK-CAZ-SC(6) 11,128.65 89.86 340.13 3,877.47 3,780.13 6,798.39 1,105.01 5,975,249.06 1,703,349.06 0.93 6,503.22 MWD+IFR-AK-CAZ-SC(6) 11,222.36 88.34 339.43 3,878.95 3,781.61 6,886.31 1,072.62 5,975,336.70 1,703,315.96 1.79 6,595.43 MWD+IFR-AK-CAZ-SC(6) 11,316.99 88.80 339.83 3,881.31 3,783.97 6,974.99 1,039.70 5,975,425.10 1,703,282.30 0.64 6,688.49 MWD+IFR-AK-CAZ-SC(6) 12/2/2015 4:43:38PM Page 5 COMPASS 5000.1 Build 74 • I Schlumberger Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-155 Project: Kuparuk River Unit TVD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Rig:39.74+57.6 @ 97.34usft(Doyon25) Well: 1C-155 North Reference: True Wellbore: 1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 11,412.91 90.42 342.11 3,881.96 3,784.62 7,065.66 1,008.42 5,975,515.50 1,703,250.29 2.92 6,783.21 MWD+IFR-AK-CAZ-SC(6) 11,507.27 90.34 344.51 3,881.33 3,783.99 7,156.04 981.33 5,975,605.64 1,703,222.45 2.54 6,876.91 MWD+IFR-AK-CAZ-SC(6) 11,602.13 90.75 346.66 3,880.43 3,783.09 7,247.90 957.71 5,975,697.30 1,703,198.08 2.31 6,971.48 MWD+IFR-AK-CAZ-SC(6) 11,697.41 90.38 348.72 3,879.49 3,782.15 7,340.98 937.40 5,975,790.20 1,703,177.01 2.20 7,066.68 MWD+IFR-AK-CAZ-SC(6) 11,791.35 90.24 347.88 3,878.98 3,781.64 7,432.97 918.35 5,975,882.01 1,703,157.20 0.91 7,160.57 MWD+IFR-AK-CAZ-SC(6) 11,886.11 90.24 349.37 3,878.59 3,781.25 7,525.86 899.66 5,975,974.74 1,703,137.75 1.57 7,255.30 MWD+IFR-AK-CAZ-SC(6) 11,981.51 89.96 349.18 3,878.42 3,781.08 7,619.59 881.91 5,976,068.32 1,703,119.23 0.35 7,350.69 MWD+IFR-AK-CAZ-SC(6) 12,075.49 89.21 348.26 3,879.10 3,781.76 7,711.75 863.53 5,976,160.31 1,703,100.09 1.26 7,444.65 MWD+IFR-AK-CAZ-SC(6) 12,170.39 87.97 347.74 3,881.44 3,784.10 7,804.55 843.80 5,976,252.94 1,703,079.60 1.42 7,539.46 MWD+IFR-AK-CAZ-SC(6) 12,265.05 91.41 348.03 3,881.95 3,784.61 7,897.09 823.94 5,976,345.30 1,703,058.97 3.65 7,634.04 MWD+IFR-AK-CAZ-SC(6) 12,359.55 89.39 348.74 3,881.29 3,783.95 7,989.64 804.92 5,976,437.68 1,703,039.19 2.27 7,728.49 MWD+IFR-AK-CAZ-SC(6) 12,454.39 90.31 347.84 3,881.54 3,784.20 8,082.51 785.67 5,976,530.38 1,703,019.18 1.36 7,823.29 MWD+IFR-AK-CAZ-SC(6) 12,551.27 90.96 346.15 3,880.46 3,783.12 8,176.89 763.87 5,976,624.57 1,702,996.60 1.87 7,920.02 MWD+IFR-AK-CAZ-SC(6) 12,644.81 90.34 345.50 3,879.40 3,782.06 8,267.58 740.96 5,976,715.06 1,702,972.95 0.96 8,013.31 MWD+IFR-AK-CAZ-SC(6) 12,739.68 90.10 346.07 3,879.04 3,781.70 8,359.54 717.67 5,976,806.82 1,702,948.90 0.65 8,107.92 MWD+IFR-AK-CAZ-SC(6) 12,830.37 88.97 344.53 3,879.77 3,782.43 8,447.26 694.66 5,976,894.33 1,702,925.17 2.11 8,198.30 MWD+IFR-AK-CAZ-SC(6) 12,929.88 88.52 343.48 3,881.95 3,784.61 8,542.89 667.24 5,976,989.72 1,702,896.97 1.15 8,297.24 MWD+IFR-AK-CAZ-SC(6) 13,024.92 89.52 344.15 3,883.58 3,786.24 8,634.15 640.76 5,977,080.75 1,702,869.74 1.27 8,391.71 MWD+IFR-AK-CAZ-SC(6) 13,118.82 90.41 344.44 3,883.64 3,786.30 8,724.54 615.34 5,977,170.92 1,702,843.58 1.00 8,485.14 MWD+IFR-AK-CAZ-SC(6) 13,212.14 90.96 344.32 3,882.52 3,785.18 8,814.41 590.22 5,977,260.57 1,702,817.71 0.60 8,578.01 MWD+IFR-AK-CAZ-SC(6) 13,310.26 91.95 343.50 3,880.03 3,782.69 8,908.65 563.03 5,977,354.58 1,702,789.76 1.31 8,675.54 MWD+IFR-AK-CAZ-SC(6) 13,361.25 91.89 343.98 3,878.32 3,780.98 8,957.58 548.76 5,977,403.38 1,702,775.09 0.95 8,726.20 MWD+IFR-AK-CAZ-SC(6) 13,395.00 91.89 343.98 3,877.21 3,779.87 8,990.00 539.45 5,977,435.72 1,702,765.51 0.00 8,759.74 NOT an Actual Survey 4 1/2"x 6-3/4" 13,435.00 91.89 343.98 3,875.89 3,778.55 9,028.42 528.42 5,977,474.05 1,702,754.16 0.00 8,799.50 PROJECTED to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. 2 Yes ❑ No l have checked to the best of my ability that the following data is correct: U Surface Coordinates n Declination & Convergence [J GRS Survey Corrections D Survey Tool Codes Vincent °"m'-",mer°" °7 c5[hUmOerget. tw-w,iu"ae ger. SLB DE: Osara N= SEDIVII.t=1i$ Mite:Q11.11a03134030.0403 steveshultz@contras Client Representative: or.conocophillips.com n -"- -"- Date: 03-Dec-2015 12/2/2015 4:43:38PM Page 6 COMPASS 5000.1 Build 74 �, OF Tit • wP,1 �,� THE STATE Alaska Oil and Gas ��,,;, = � of L /\ sK.A Conservation Commission -'moi �. 1� l4 ttx 4_= 333 West Seventh Avenue ----4z- 7.,"' • GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F - � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-155 ConocoPhillips Alaska, Inc. Permit No: 215-180 (revised) Surface Location: 1548.5' FNL, 4018.5' FEL, SEC. 12, T11N, R10E, UM Bottomhole Location: 3066' FNL, 3471' FEL, SEC. 36, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. 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. 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, / Pt6,4&,_ Cathy I. Foerster Chair DATED this q day of November, 2015. 11, 4110 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION If)Jl5IQp) aAY 4r PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: lb Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone [7( I 1 c.Specify if well is proposed for: I Drill ❑✓ Lateral❑ Stratigraphic Test❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: ❑✓ ,Blanket ❑ Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 , KRU 1C-155 3.Address: 6.Proposed Depth' r ;Y`� 12. Field/Pool(s): 13'V4ce P.O. Box 100360 Anchorage,AK 99510-0360 MD: 1 ' TVD: 3865' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1548.5'FNL,4018.5'FEL, Sec. 12,T11N, R10E, UM , ADL 25649,25638 . West Sak Oil Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4606'FNL, 1553'FEL, Sec. 1,T11N, R10E, UM 467,463 11/15/2015 Total Depth: 9.Acres in Property: 14.Distance to 3066'FNL, 3471'FEL, Sec. 36,T12N, R10E, UM , 5120 - Nearest Property: >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 97 feet 15.Distance to Nearest Well Open Surface:x- 562269 y- 5968690 Zone- 4 - GL Elevation above MSL: 57 feet to Same Pool: 1C-184,28.5 16.Deviated wells: Kickoff depth: , 560 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: , 91° deg Downhole: 1745 psig Surface: 1306 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quaniity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# K-55 welded 80' 39.5' 39.5' 119.5' 119.5' 200 cf ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 3024' 39.5' 39.5' .eepCRETE,246 s, 12.25" 9.625" 40# L-80 Hydril 563 6299' 39.5' 39.5' 3890' 950 sx Class G 6.75" 4.5" 11.6# L-80 Hydril 563 7288' 6150' 3881' 3865' screens-no cement 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD RECEIVED nci302015 Perforation Depth MD(ft): Perforation Depth TVD(ft): AOGCO 20.Attachments: Property Plal❑ BOP Sketch ❑ Drilling Prograrr 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report❑ Drilling Fluid Program 11 20 AAC 25.050 requirements EI 21.Verbal Approval: Commission Representative: Date: .e..17)., 7/ 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Email Steve.Shultzcontractor.cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature /J(.,�/. A Phone: 265-6120 Date l0(Zedzoes- Commission Use Only Permit to Drill API Number: ^ r Permit Approval See cover letter Number: aI5 - i'SO 50-(aq- 4 `�)'ter az. I Date: IOI, It 9 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m ane,gas hydrates,or gas contained in shales: d Other: 36 p f r5,f p rc Ste,vre to 35-- &f>56£ry�ples req'd: Yes 4No Mud log req'd: Yes[1] No L1' r1-y1,ri,t,ka rr)r-e-ve,v7prep' f ZSGG m asures: Yes No [1,lDirectional svy req'd: Yes/' es No❑ Spacing exception req'd: Yes CI No N Inclination-only svy req'd: Yes❑ NoRr APPROVED BY THE �� Approved by014 /9,4_1,1(1/......__commis§lovR COMMISSION Date: i /-9 - vri /r3e)/15- <3 13 .s ll /, Form 10-401 (Revised 10/2012) This permit is valid for 24 nnlit p4A4 (20 AAC 25.005(g)) • fiation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 Permit It - West Sak Well #1C-155 Revision #1 '"66' +'k Application for Permit to Drill Document MaWell maximize Well Value 111111w— Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(0 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005(c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 5. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (Ml FazePro OBM) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 9. Seismic Analysis 5 Requirements of 20 AAC 25.005(c)(10) 5 10.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005(c)(11) 5 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 1C-155 PERMIT WP-Revision#1.doc Page 1 of 7 Printed:29-Oct-15 • ,ation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Program Summary 7 Attachment 4 Well Schematic 7 Attachment 5 Doyon 25 BOP Stack Configuration 7 Attachment 6 Doyon 25 on 1C-155 7 1. Well Name Requirements of 20 AAC 25.005(f Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-155 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1548.5' FNL 4018.5' FEL Sec. 12 T11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 91.7'AMSL Northings 5,968,690.10 Eastings:562,268.64 Pad Elevation 52.2'AMSL Location of 9 5/8"shoe 4606' FNL 1553' FEL Sec. 1 T11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6346' Northings: 5,970933 Eastings:564714 Total Vertical Depth, RKB: 3890' Total Vertical Depth, SS: 3793' Location at Total Depth 3065.9'FNL 3471.1' FEL Sec. 36 T12N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13446' ' Northings: 5,977,736.02 Eastings: 562,736.14 Total Vertical Depth, RKB: 3865' Total Vertical Depth, SS: 3768' and (D)other information required by 20 AAC 25.050(b); 1C-155 PERMIT WP-Revision#1.doc Page 2 of 7 Printed:29-Oct-15 • •ation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: 1C-155 Well Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-155. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. Please see Attachment 5 for Doyon 25 BOP stack configuration. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum expected reservoir pressure in the West Sak D sand in the 1C area is 0.447 psi/ft, or 8.6 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D" sand formation is 1,302 psi. MPSP = (3874 ft TVD)(0.447 - 0.11 psi/ft) = 1,306 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-155 Drilling Hazards Summary. There are no close approach issues with all surrounding wells passing any major risk. 1C-155 PERMIT WP-Revision#1.doc Page 3 of 7 Printed:29-Oct-15 • cation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 4. Procedure for Cciducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Perm Orill must be accompanied by each of the following items, except for an item already on file with the commission and identifier )e application: (5)a description of the p ire for conducting formation integrity tests,as required under 20 AAC 25.030(f); 1C-155 will be completed with a 9-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 42 94 K55 Welded 80 39.5/ 39.5 119.5/ 119.5 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 2597 39.5/ 39.5 2636/ 2400 1563 sx 11.0ppg Deeperete Lead, sx 12.0ppg DeepCRETE Tail Cement Top planned @ 3500' 9.625 12.25 40 L-80 Hydril 563 6307 39.5/ 39.5 6346/ 3890 MD Cemented w/950 sx 15.8 ppg Class‘G' 4.5 6.75 11.6 L-80 Hydril 563 7061 6150/ 3881 13407/ 3865 screens-no cement screens 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Doll must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-155 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1C-155 PERMIT WP-Revision#1.doc Page 4 of 7 Printed:29-Oct-15 • ration for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 Surface Hole Mud Program Spud Mud Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8-11.2 Intermediate Hole Mud Program (LSND) Lateral Mud Program (Ml FazePro OBM) Value 13 5/8"Csg Shoe to 9-5/8"Csg Point Density(ppg) 9.2 Value Fann 35 6 RPM Density(ppg) 9.2 (lb/100 ft2) 4-8 Fann 35 6 RPM HTHP Fluid Loss (lb/100 ft2) 12 - 16 (ml/30min) ` 5 API Filtrate < 6 Drill Solids < 5% (cc/30 min)) pH 9.5 — 10.0 Oil water Ratio 70:30 Drill Solids <7 Electrical >400 Stability(mV) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(17; Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(b); Not applicable: Application is not for an offshore well. 1C-155 PERMIT WP-Revision#1.doc Page 5 of 7 Printed:29-Oct-15 ,ilkation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 11.Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the fol owing items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34" insulated conductor to +/- 119.5' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 25. Install 211/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 2636' MD/ 2303'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 133/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 135/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 6. PU 121/4" bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 95/8"casing point at ' MD / 3890'TVD. Pull out of hole. 9. Run 95/8", 40# L80, Hydril 563 casing to surface. (top of cement to be <3500' MD which corresponds to 500'above the Ugnu C formation). 10. Install slips and 95/8" packoff and test to 3500 psi. 11. Flush 133/8"x 95/8"annulus with water, followed by isotherm. 12. PU 63/4" PDC Bit and 41/2"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3500 psi for 30 minutes. 13. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 14. Directionally drill 63/4" hole to West Sak D Sand TD at +/- MD / 3865'TVD as per directional plan. 15. Backream to 95/8"shoe. TIH and perform final circulations and displace well to solids free oil base mud. Pump out of Hole. 16. PU and run 41/2"screened liner. 17. Once all the liner is in the hole, rig up false rotary table and run 27/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 18. Finish running liner to TD to land liner and set liner hanger @ +/- 6188'MD/ 3883'TVD, then displace well to filtered brine 19. Pump Schlumberger acid through wash pipe (9% formic acid for 1C-155). 1C-155 PERMIT WP-Revision#1.doc Page 6 of 7 Printed:29-Oct-15 • Sation for Permit to Drill,Well 1C-155 Revision No.1 Saved:29-Oct-15 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 41/2"tubing and RIH 23. Land tubing. Set BPV 24. Nipple down BOPE, nipple up tree and test. Pull BPV. 25. Freeze protect well with diesel by pumping into 41/2"x 95/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 26. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Doyon 25 BOP Stack Configuration Attachment 6 Doyon 25 on 1C-155 1C-155 PERMIT WP-Revision#1.doc Page 7 of 7 Printed:29-Oct-15 1C-155 Schlumberger CemCADE* Preliminary Job Design 9 5/8" Intermediate (V3) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date: October.8, 2015 Volumes are based on 20% excess. Prepared by: Jenna HoL _ton Location:Anchorage, AR Tail Slurry (total) Minimum thickening: -245 min. (pump time plus 120 min.). Phone: (907)263-4207 15.8 ppg Class G + adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.ccm 0.31321 ft3/ft x(6338' -3500') x 1.2 (20% excess) = 1067 ft3 Shoe Volume: 0.42572 ft3/ft x 80' x 1.00 (no excess) = 34 ft3 Totals: 1067 ft3+ 34 ft3= 1101 ft3 1101 ft3/ 1.16 ft3/sk = 950 sks (960 sks) BHST = 102 °F, Estimated BHCT= 82 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) 13 3/8",68#casing MUDPUSH II 6.00 40.0 6.7 6.7 at 2638'MD Pause 0.00 0.0 5.0 11.7 Tail Slurry 6.00 196.032.7 44.4 Pause 0.00 0.0 5.0 49.4 Fresh Water 6.00 10.0 1.7 51.1 Pause 0.00 0.0 5.0 56.1 Top of Tail at Mud 6.00 454.5 75.8 131.9 end of pumping Mud 3.00 10.0 3.3 135.2 < 3500'MD MUD REMOVAL Recommended Mud Properties: 9.2 ppg, Pv < 20, Tv < 20. As thin and light as 9 5/8 40# possible to aid in mud removal during cementing. in 12 1/4"hole Spacer Properties: 11.5 ppg MudPUSH* II, Pv 25- 30, Ty 30-40 Centralizers: As per CPAi program TD at-6338'MD (3890'TVD) Mark of Schlumberger 1C-155 Schlumberger CemCADE* Preliminary Job Design 13 3/8" Surface Casing (V4) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 Volumes are based on 250% excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2138' MD. Client: CPAI Revision Date: October 28, 2015 Prepared by: Jenna Houston Location:Anchorage, AK Phone: (907)263-4207 Lead Slurry Minimum pump time: -310 min. (pump time plus 120 min.) Mobile: (907)223-8916 DeepCRETE @ 11.0 ppg- 1.91 ft3/100 lb sk Email:jhouston2@slb.com 0.9933 ft3/ft x 80 x 1.0 (no excess) = 80 ft3 < TOC at Surface 0.42059 ft3/ft x (1966-80) x 3.50 (250% excess) = 2777 ft3 0.42059 ft3/ft x (2138-1966) x 1.50 (50% excess) = 109 ft3 2777 ft3 + 109 ft3 + 80 ft3= 2966 ft3 2966 ft3/ 1.91 ft3/sk = 1553 sks(1563 sks) Have additional DeepCRETE on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -230 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE- 1.63 ft3/1001b sk 0.42059 ft3/ft x(2638-2138) x 1.50 (50% excess) = 316 ft3 0.84065 ft3/ft x 80' (Shoe Joint) = 68 ft3 316 ft3+ 68 ft3 = 384 ft3 384 ft3/ 1.63 ft3/sk = 236 sks Round up to 246 sks BHST= 57°F, Estimated BHCT= 74°F. (Based on 2.1°F/100 ft. from surface) < Base of Permafrost at PUMP SCHEDULE 1,966'MD(1,898 TVD) Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) cw 100 7.00 75.0 10.7 10.7 MUDPUSH II 7.00 75.0 10.7 21.4 Pause 0.00 0.0 5.0 26.4 < Top of Tail at 211ppg DeepCRETE 7.00 527.9 75.4 ,138'MD Lead 101.8 Surface Tail 7.00 68.2 9.7 '' DeepCRETE Slurry 111.5 Pause 0.00 0.0 5.0 116.5 Fresh Water 7.00 10.0 1.4 197.9 Pause 0.00 0.0 5.0 122.9 Mud 8.00 263.0 32.9 155.8 Mud 3.00 100.0 333 189.1 < 13 3/8",68#casing Mud 1.00 10.0 10.0 199.1 i in 16"OH MUD REMOVAL TD at 2,638'MD Expected Mud Properties: 9.2 ppg, Pv < 20, Ty < 20 (2,400 TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv- 17-21, Ty 20-25 Centralizers: As per CPAi program. *Mark of Schlumberger I C-I 541p 05 6 . 93D�8 Plan Summary _ Top Ugnu B _ Top Ugnu C Top West Sak D a5- T3 K15 • I9 5/8"x 12-1/41 -5 , > - a� 4--' - pFrost I •I'Top Ugnu A Top N Sands o 0 , \ \ \1, - 13-3 8"x 161' " ' I. 0 1 I I I 1 I" I 1 1 t f I I 0 11/ 0 3000 6000 9000 12000 ��', Measured Depth ,' , ' Aili, o- Geodetic Datum: North American Datum 1983 "0400,10"‘ �� ��� o` I13-3/8"x 16I' I Depth Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) �) / Rig: Doyon 25 1®00 \ �. 0,-....°Q.er 9 5/8"x 12-1/4 •p 0 rp / 14 1/2"x 6-3/41 ', o 0) 00 _ mtD, co r- cn 1 \ I I I I I I I I e I -I w 6/ I ` 1 �" `r' I 0 1500 3000 4500 6000 75 0 09000 S 105Ej00 u 40 --.. 750 Horizontal Departure ' 560 - 750 330 s �0 0 - \� 940 `e 1130 -- r 'lair �� 1130 - 1320 Z I� - • ♦� ji ia0�,��-'�4� 11320 -520 1710 0 rli 60 '. 300 tai-A.' .44 I r�i����,��. 60 a - I. . .... _. _ ii '•% ''��►'" �11���jg�i� 1710 - 1900 N ` � E _ _ ti��9 +0 '���=�� n(I I��'�4l�d N ` \ . •` 1 C-154 _ -. FS*��taa�' ' r';.e',�s�i �e i�r�i 2380 2380 .\ a � ' ' ` Qa ' -•c ._. _. .. - _.... p-i° '��`�` ���,• ib�%•, • 2850 - 3330 rj 30- --.:.. __ " • • 1E�28(AcLtat)-wp14 )• 'ss►t�,.. - "'�.%' 1,�1 o - " 1C-14 270 `c. �; !J 3330 - 3800 ...ter _ \ 4280 \ \ m'111111111; . • 3800 rrm4280 4750 .1 C-14A - U `.\ '�1 C-150 - -; iii `�� • 4750 - 5230 0 10 15 :1C-,15111 '' - r.':O 7!s:1 :-03 5230 - 5700 I I I I I I I I I I I I I I i .� pith .0k. a 5700 - 6670 0 2000 4000 6000 8000 10000 12000 1400C 240 ' ..1•i ' i0 6670 - 7640 SURVEY PROGRAM 7640 - 8600 Surface Location North/Y: 5968442.44z�) 8600 - 9570 Depth From Depth To Survey/Plan Tool _ 9570 - 10540 39.50 1650.00 1C-155wp06(Plan:1C-155) GYD-GC-SS East/X: 1702300.26 210/'� '.� • 150 1650.00 2636.14 1C-155wp06(Plan:1C-155) MWD Pad Elevation: 57.60 _ ,-� 10540 11510 1650.00 2636.14 1C-155wp06(Plan:1C-155) MWD+IFR-AK-CAZ-SC 180 11510 "- 12480 2636.14 3100.00 1C-155wp06(PIan:1C-155) MWD CASING DETAILS 2636.14 3100.00 1C-155wp06(Plan:1C-155) MWD+IFR-AK-CAZ-SC 12480 - 13446 3100.00 4600.00 1C-155wp06(Plan:1C-155) MWD TVD MD Name 3100.00 6346.00 1C-155wp06(Plan:1C-155) MWD+IFR-AK-CAZ-SC 2400.10 2636.14 13-3/8"x 16" Magnetic Model: BGGM2015 T 6346.00 7846.00 1C-155wp06(Plan:1C-155) MWD 3890.10 6346.00 9 5/8"x 12-1/4 Magnetic Model Date: 30-Nov-15 A 6346.00 13445.77 1C-155wp06(Plan:1C-155) MWD+IFR-AK-CAZ-SC 3865.10 13445.77 41/2"x6-3/4" Magnetic Declination: 18.84° To convert a Magnetic Direction to a True Direction,Add 18.84°East SECTION DETAILS 1792.1 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 pFrost 2 560.00 0.00 0.00 560.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,85°TF,for 150.04' 3 710.04 2.25 85.00 710.00 0.26 2.94 1.50 85.00 -0.26 Start 2°/100'DLS,-5°TF,for 200.59' -2025.1 4 910.63 6.26 81.79 910.00 2.16 17.68 2.00 -5.00 -0.94 Start 2.5°/100'DLS,0°TF,for 876.44' 5 1787.08 28.17 81.79 1742.10 38.96 272.82 2.50 0.00 -9.01 Hold for 113.43' T3 6 1900.51 28.17 81.79 1842.10 46.60 325.82 0.00 0.00 -10.68 Start 3.5°/100'DLS,26.1°TF,for 1056.22' 7 2956.73 63.29 99.02 2570.45 6.84 1064.30 3.50 26.10 -178.08 Hold for 24.11' 8 2980.83 63.29 99.02 2581.28 3.47 1085.57 0.00 0.00 -185.09 Start 4°/100'DLS,-110.39°TF,for 1852.02' -2303.1 9 4832.85 65.00 15.00 3523.93 798.38 2292.84 4.00 -110.39 388.11 Hold for 180' 10 5012.85 65.00 15.00 3600.00 955.96 2335.06 0.00 0.00 535.96 1C-155 0.PTangent 092515 Start 4°/100'DLS,15.43°TF,for 158.15' 11 5171.00 71.11 16.78 3659.08 1096.96 2375.25 4.00 15.43 667.84 Hold for 251.67' 12 5422.67 71.11 16.78 3740.57 1324.94 2443.97 0.00 0.00 880.42 Start 4°/100'DLS,-59.57°TF,for 634.45' 13 6057.12 85.00 355.00 3873.10 1937.16 2504.04 4.00 -59.57 1472.91 1C-155 1.Top WSD 092515 DH Start 3.5°/100'DLS,-64.73°TF,for 17.02' 14 6074.15 85.25 354.46 3874.55 1954.05 2502.48 3.50 -64.73 1489.82 Hold for 58.75' 15 6132.90 85.25 354.46 3879.41 2012.33 2496.83 0.00 0.00 1548.19 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 16 6346.00 89.00 348.00 3890.10 2222.53 2464.39 3.50 -60.06 1760.83 1C-155 2.T1 Landing 092515 DH Hold for 30' K15 17 6376.00 89.00 348.00 3890.62 2251.87 2458.15 0.00 0.00 1790.80 Start 2°/100'DLS,92.7°TF,for 63.43' 18 6439.44 88.94 349.27 3891.76 2314.04 2445.65 2.00 92.70 1854.21 Hold for 384.35' 19 6823.78 88.94 349.27 3898.87 2691.60 2374.09 0.00 0.00 2238.46 Start 2°/100'DLS,-84.68°TF,for 563.79' 20 7387.57 90.00 338.04 3904.10 3231.71 2215.67 2.00 -84.68 2797.86 1C-155 3.T2 092515 DH Adjust TF to-61.72°,for 59.52' 21 7447.10 90.56 336.99 3903.81 3286.70 2192.91 2.00 -61.72 2855.98 Hold for 1007.05' 22 8454.14 90.56 336.99 3893.90 4213.60 1799.33 0.00 0.00 3837.13 Start 2°/100'DLS,89.99°TF,for 386.43' 23 8840.57 90.56 344.72 3890.10 4578.36 1672.71 2.00 89.99 4218.34 1C-155 4.T3 092515 DH Adjust TF to 0°,for 11.36' -3233.1 24 8851.93 90.79 344.72 3889.97 4589.32 1669.72 2.00 0.00 4229.65 Hold for 718.17' 25 -9570.09 - 90.79 344.72 3880.10 5282.04 1480.49 0.00 ..0.00 4944.71 1C-155 5.T4 092515 DH - Start 2°/100'DLS,107.91 TF,for 78.62' - -- 26 9648.71 90.30 346.22 3879.35 5358.13 1460.76 2.00 107.91 5023.07 Hold for 1558.22' Top Ugnu C 27 11206.93 90.30 346.22 3871.10 6871.47 1089.54 0.00 0.00 6577.88 1C-155 6.T5 092515 DH Start 2°/100'DLS,-93.54°TF,for 43.7' 28 11250.63 90.25 345.35 3870.89 6913.83 1078.81 2.00 -93.54 6621.46 Hold for 1297.14' -3466.1 29 12547.77 90.25 345.35 3865.24 8168.76 750.64 0.00 0.00 7914.31 Start 2°/100'DLS,100.93°TF,for65.77' Top Ugnu B 30 12613.54 90.00 346.64 3865.10 8232.57 734.72 2.00 100.93 7979.92 1C-155 7.T6 092515 DH Hold for 832.22' -3586.1 31 13445.77 90.00 346.64 3865.10 9042.26 542.37 0.00 0.00 8810.71 1C-155 8.TD 092515 DH TD:13445.77'MD,3865.1'TVD Top Ugnu A -3704.1 Top N Sands -38/4p iWest Sak D 0 signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise.all targets have a 100 feet lateral tolerance. 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I LU o LU O LC) 0 N O N- LU N O LO (fl CO N- 00 0) CO CO (ui�}lsn SL)yldeo Ieo!pan anal CO CO S • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-155 Plan:1 C-155 Plan: 1 C-155wp06 Report - Map Coordinates 28 October, 2015 • Schlumberger 0 1 Comments apply to Report- Map Coordinates the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 1C Pad Site Position: Northing: 5,968,274.22 usft Latitude: 70° 19'27.241 N From: Map Easting: 1,702,403.98 usft Longitude: 149°29'50.471 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.47 ° Well Plan: 1C-155 Well Position +N/-S 0.00 usft Northing: 5,968,442.44 usfi Latitude: 70° 19'28.904 N +EI-W 0.00 usft Easting: 1,702,300.26 usfi Longitude: 149°29'53.458 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore Plan:1C-155 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2015 11/30/2015 18.84 80.99 57,504 Design 1C-155wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.50 0.00 0.00 350.00 Survey Tool Program Date 10/28/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,650.00 1C-155wp06(PIan:1C-155) GYD-GC-SS Gyrodata gyro single shots 1,650.00 2,636.14 1C-155wp06(PIan:1C-155) MWD MWD-Standard 1,650.00 2,636.14 1C-155wp06(Plan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,636.14 3,100.00 1C-155wp06(Plan:1C-155) MWD MWD-Standard 2,636.14 3,100.00 1C-155wp06(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC I 3,100.00 4,600.00 1C-155wp06(PIan:1C-155) MWD MWD-Standard 3,100.00 6,346.00 1C-155wp06(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,346.00 7,846.00 1C-155wp06(PIan:1C-155) MWD MWD-Standard 6,346.00 13,445.77 1C-155wp06(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 39.50 0.00 0.00 39.50 -57.60 0.00 0.00 0.00 100.00 0.00 0.00 100.00 2.90 0.00 0.00 0.04 200.00 0.00 0.00 200.00 102.90 0.00 0.00 0.19 300.00 0.00 0.00 300.00 202.90 0.00 0.00 0.33 400.00 0.00 0.00 400.00 302.90 0.00 0.00 0.48 10/28/2015 1:48:59PM Page 2 COMPASS 5000.1 Build 74 . Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kupl Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 500.00 0.00 0.00 500.00 402.90 0.00 0.00 0.62 560.00 0.00 0.00 560.00 462.90 0.00 0.00 0.71 KOP:Start 1.5°/100'DLS,90°TF,for 150.04' 600.00 0.60 85.00 600.00 502.90 1.50 85.00 0.76 700.00 2.10 85.00 699.97 602.87 1.50 0.00 0.85 710.04 2.25 85.00 710.00 612.90 1.50 0.00 0.86 Start 2°/100'DLS,-5°TF,for 200.59' 800.00 4.05 82.78 799.82 702.72 2.00 -5.00 0.96 900.00 6.04 81.86 899.43 802.33 2.00 -2.78 1.08 910.63 6.26 81.79 910.00 812.90 2.00 -1.86 1.09 Start 2.5°/100'DLS,5°TF,for 997.21' 1,000.00 8.49 81.79 998.62 901.52 2.50 0.00 1.21 1,100.00 10.99 81.79 1,097.17 1,000.07 2.50 0.00 1.36 1,200.00 13.49 81.79 1,194.89 1,097.79 2.50 0.00 1.51 1,300.00 15.99 81.79 1,291.59 1,194.49 2.50 0.00 1.69 1,400.00 18.49 81.79 1,387.09 1,289.99 2.50 0.00 1.88 1,500.00 20.99 81.79 1,481.21 1,384.11 2.50 0.00 2.10 1,600.00 23.49 81.79 1,573.76 1,476.66 2.50 0.00 2.34 1,700.00 25.99 81.79 1,664.57 1,567.47 2.50 0.00 2.49 1,787.08 28.17 81.79 1,742.10 1,645.00 2.50 0.00 2.66 1,800.00 28.17 81.79 1,753.49 1,656.39 0.00 0.00 2.69 1,843.79 28.17 81.79 1,792.10 1,695.00 0.00 0.00 3.09 pFrost 1,900.00 28.17 81.79 1,841.65 1,744.55 0.00 0.00 3.09 1,900.51 28.17 81.79 1,842.10 1,745.00 0.00 0.00 3.09 1,907.84 28.40 82.03 1,848.56 1,751.46 3.50 26.10 3.63 Hold for 116.87' 2,000.00 31.33 84.74 1,928.47 1,831.37 3.50 25.89 3.63 2,024.71 32.12 85.39 1,949.49 1,852.39 3.50 23.54 4.34 Start 3.5°/100'DLS,-0.44°TF,for 848.26' 2,100.00 34.56 87.20 2,012.38 1,915.28 3.50 22.99 4.34 2,115.49 35.07 87.55 2,025.10 1,928.00 3.50 21.47 5.18 T3 2,200.00 37.84 89.29 2,093.07 1,995.97 3.50 21.19 5.18 2,300.00 41.15 91.09 2,170.23 2,073.13 3.50 19.79 6.15 2,400.00 44.48 92.67 2,243.58 2,146.48 3.50 18.40 7.24 2,485.56 47.35 93.87 2,303.10 2,206.00 3.50 17.24 8.42 K15 2,500.00 47.83 94.06 2,312.84 2,215.74 3.50 16.40 8.42 2,600.00 51.20 95.32 2,377.76 2,280.66 3.50 16.27 9.69 2,636.14 52.42 95.75 2,400.10 2,303.00 3.50 15.46 5.06 13-3/8"x 16" 2,700.00 54.58 96.47 2,438.09 2,340.99 3.50 15.19 5.06 2,800.00 57.97 97.52 2,493.61 2,396.51 3.50 14.76 5.81 10/28/2015 1:48:59PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 2,872.97 60.44 98.24 2,530.96 2,433.86 3.50 14.18 6.84 Hold for 295.38' 2,900.00 61.36 98.49 2,544.11 2,447.01 3.50 13.81 6.84 2,956.73 63.29 99.02 2,570.45 2,473.35 3.50 13.69 7.53 2,980.83 63.29 99.02 2,581.28 2,484.18 0.00 0.00 7.83 3,000.00 63.03 98.21 2,589.94 2,492.84 4.00 -110.39 8.07 3,100.00 61.72 93.95 2,636.32 2,539.22 4.00 -110.03 9.30 3,168.35 60.91 90.97 2,669.13 2,572.03 4.00 -108.05 6.40 Start 4°/100'DLS,-106.46°TF,for 1656.62' 3,200.00 60.55 89.58 2,684.61 2,587.51 4.00 -106.62 6.40 3,300.00 59.53 85.11 2,734.56 2,637.46 4.00 -105.94 7.20 3,400.00 58.66 80.56 2,785.94 2,688.84 4.00 -103.71 8.14 3,500.00 57.95 75.94 2,838.50 2,741.40 4.00 -101.37 9.14 3,600.00 57.42 71.24 2,891.98 2,794.88 4.00 -98.94 10.15 3,700.00 57.06 66.51 2,946.11 2,849.01 4.00 -96.43 11.13 3,800.00 56.88 61.74 3,000.64 2,903.54 4.00 -93.87 12.06 3,900.00 56.88 56.96 3,055.30 2,958.20 4.00 -91.27 12.92 4,000.00 57.07 52.20 3,109.82 3,012.72 4.00 -88.66 13.70 4,100.00 57.43 47.46 3,163.94 3,066.84 4.00 -86.06 14.39 4,200.00 57.97 42.77 3,217.39 3,120.29 4.00 -83.49 14.99 4,229.70 58.17 41.39 3,233.10 3,136.00 4.00 -80.99 15.51 Top Ugnu C 4,300.00 58.68 38.15 3,269.92 3,172.82 4.00 -80.26 15.51 4,400.00 59.56 33.60 3,321.26 3,224.16 4.00 -78.56 15.95 4,500.00 60.59 29.14 3,371.17 3,274.07 4.00 -76.22 16.32 4,600.00 61.76 24.77 3,419.41 3,322.31 4.00 -74.00 16.62 4,700.00 63.07 20.51 3,465.73 3,368.63 4.00 -71.89 7.40 4,700.82 63.08 20.47 3,466.10 3,369.00 4.00 -69.91 7.40 Top Ugnu B 4,800.00 64.50 16.35 3,509.92 3,412.82 4.00 -69.90 7.38 4,824.98 64.88 15.32 3,520.59 3,423.49 4.00 -68.08 7.37 Hold for 180' 4,832.85 65.00 15.00 3,523.93 3,426.83 4.00 -67.64 7.37 4,900.00 65.00 15.00 3,552.31 3,455.21 0.00 0.00 7.63 4,979.96 65.00 15.00 3,586.10 3,489.00 0.00 0.00 7.94 Top Ugnu A 5,000.00 65.00 15.00 3,594.57 3,497.47 0.00 0.00 7.94 5,004.98 65.00 15.00 3,596.67 3,499.57 0.00 0.00 7.98 Start 4°/100'DLS,15.43°TF,for 158.15' 5,012.85 65.00 15.00 3,600.00 3,502.90 0.00 0.00 7.98 5,100.00 68.36 16.00 3,634.49 3,537.39 4.00 15.43 8.36 5,163.13 70.80 16.69 3,656.51 3,559.41 4.00 15.03 8.66 Hold for 251.67' 5,171.00 71.11 16.78 3,659.08 3,561.98 4.00 14.79 8.66 5,200.00 71.11 16.78 3,668.47 3,571.37 0.00 0.00 8.75 10/28/2015 1:48:59PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger III Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan: 39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Planned Survey I MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 5,300.00 71.11 16.78 3,700.85 3,603.75 0.00 0.00 9.15 5,310.04 71.11 16.78 3,704.10 3,607.00 0.00 0.00 9.55 Top N Sands 5,400.00 71.11 16.78 3,733.23 3,636.13 0.00 0.00 9.55 5,414.80 71.11 16.78 3,738.02 3,640.92 0.00 0.00 9.65 Start 4°/100'DLS,-59.57°TF,for 634.45' 5,422.67 71.11 16.78 3,740.57 3,643.47 0.00 0.00 9.65 5,500.00 72.70 13.98 3,764.59 3,667.49 4.00 -59.57 9.68 5,600.00 74.80 10.44 3,792.58 3,695.48 4.00 -58.70 9.77 5,700.00 76.97 6.97 3,816.98 3,719.88 4.00 -57.71 9.86 5,800.00 79.17 3.56 3,837.65 3,740.55 4.00 -56.86 9.96 5,900.00 81.42 0.20 3,854.51 3,757.41 4.00 -56.16 10.06 6,000.00 83.69 356.88 3,867.47 3,770.37 4.00 -55.59 10.17 6,049.25 84.82 355.26 3,872.40 3,775.30 4.00 -55.16 10.23 Start 3.5°/100'DLS,-64.73°TF,for 17.02' 6,057.12 85.00 355.00 3,873.10 3,776.00 4.00 -55.00 10.23 6,066.27 85.14 354.71 3,873.89 3,776.79 3.48 -64.73 10.25 Hold for 58.75' 6,068.80 85.17 354.63 3,874.10 3,777.00 3.48 -64.71 10.25 Top West Sak D 6,074.15 85.25 354.46 3,874.55 3,777.45 3.48 -64.70 10.25 6,100.00 85.25 354.46 3,876.69 3,779.59 0.00 0.00 10.37 6,125.03 85.25 354.46 3,878.76 3,781.66 0.00 0.00 10.51 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 6,132.90 85.25 354.46 3,879.41 3,782.31 0.00 0.00 10.51 6,200.00 86.43 352.42 3,884.28 3,787.18 3.50 -60.06 10.54 6,300.00 88.19 349.39 3,888.97 3,791.87 3.50 -59.91 10.66 6,338.13 88.86 348.24 3,889.96 3,792.86 3.51 -59.77 10.73 Hold for 30' 6,346.00 89.00 348.00 3,890.10 3,793.00 3.51 -59.74 10.73 9 5/8"x 12-1/4 6,368.13 89.00 348.00 3,890.49 3,793.39 0.00 -59.73 10.93 Start 2°/100'DLS,92.7°TF,for 63.43' 6,376.00 89.00 348.00 3,890.62 3,793.52 0.00 0.00 10.93 6,400.00 88.98 348.48 3,891.05 3,793.95 2.00 92.70 11.18 6,431.56 88.95 349.11 3,891.62 3,794.52 2.00 92.69 11.60 Hold for 384.35' 6,439.44 88.94 349.27 3,891.76 3,794.66 2.00 92.68 11.60 6,500.00 88.94 349.27 3,892.88 3,795.78 0.00 0.00 12.10 6,600.00 88.94 349.27 3,894.73 3,797.63 0.00 0.00 13.02 6,700.00 88.94 349.27 3,896.58 3,799.48 0.00 0.00 14.06 6,800.00 88.94 349.27 3,898.43 3,801.33 0.00 0.00 15.18 6,815.91 88.94 349.27 3,898.73 3,801.63 0.00 0.00 15.46 Start 2°/100'DLS,-84.68°TF,for 563.79' 6,823.78 88.94 349.27 3,898.87 3,801.77 0.00 0.00 15.46 6,900.00 89.08 347.75 3,900.19 3,803.09 2.00 -84.68 16.07 10/28/2015 1:48:59PM Page 5 COMPASS 5000.1 Build 74 • 3chlumberger • R ,,ort- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 7,000.00 89.27 345.76 3,901.62 3,804.52 2.00 -84.65 16.85 7,100.00 89.46 343.77 3,902.74 3,805.64 2.00 -84.62 17.70 7,200.00 89.65 341.78 3,903.52 3,806.42 2.00 -84.60 18.60 7,300.00 89.83 339.78 3,903.97 3,806.87 2.00 -84.59 19.54 7,379.70 89.99 338.20 3,904.10 3,807.00 2.00 -84.58 20.39 Adjust TF to-61.72°,for 59.52' 7,387.57 90.00 338.04 3,904.10 3,807.00 2.00 -84.57 20.39 7,400.00 90.12 337.82 3,904.09 3,806.99 2.00 -61.72 20.52 7,439.22 90.49 337.13 3,903.88 3,806.78 2.00 -61.72 21.03 Hold for 1007.05' 7,447.10 90.56 336.99 3,903.81 3,806.71 2.00 -61.73 21.03 7,500.00 90.56 336.99 3,903.29 3,806.19 0.00 0.00 21.79 7,600.00 90.56 336.99 3,902.30 3,805.20 0.00 0.00 23.20 7,700.00 90.56 336.99 3,901.32 3,804.22 0.00 0.00 24.64 7,800.00 90.56 336.99 3,900.33 3,803.23 0.00 0.00 26.10 7,900.00 90.56 336.99 3,899.35 3,802.25 0.00 0.00 13.57 8,000.00 90.56 336.99 3,898.37 3,801.27 0.00 0.00 14.01 8,100.00 90.56 336.99 3,897.38 3,800.28 0.00 0.00 14.45 8,200.00 90.56 336.99 3,896.40 3,799.30 0.00 0.00 14.90 8,300.00 90.56 336.99 3,895.41 3,798.31 0.00 0.00 15.37 8,400.00 90.56 336.99 3,894.43 3,797.33 0.00 0.00 15.84 8,446.27 90.56 336.99 3,893.97 3,796.87 0.00 0.00 16.10 Start 2°/100'DLS,89.99°TF,for 386.43' 8,454.14 90.56 336.99 3,893.90 3,796.80 0.00 0.00 16.10 8,500.00 90.56 337.91 3,893.44 3,796.34 2.00 89.99 16.44 8,600.00 90.56 339.91 3,892.46 3,795.36 2.00 90.00 17.11 8,700.00 90.56 341.91 3,891.48 3,794.38 2.00 90.02 17.77 8,800.00 90.56 343.91 3,890.50 3,793.40 2.00 90.04 18.42 8,832.69 90.56 344.56 3,890.18 3,793.08 2.00 90.06 18.69 Adjust TF to 0°,for 11.36' 8,840.57 90.56 344.72 3,890.10 3,793.00 2.00 90.07 18.69 8,844.05 90.63 344.72 3,890.06 3,792.96 2.00 0.00 18.73 Hold for 718.17' 8,851.93 90.79 344.72 3,889.97 3,792.87 2.00 0.00 18.73 8,900.00 90.79 344.72 3,889.31 3,792.21 0.00 0.00 18.96 9,000.00 90.79 344.72 3,887.93 3,790.83 0.00 0.00 19.44 9,100.00 90.79 344.72 3,886.56 3,789.46 0.00 0.00 19.93 9,200.00 90.79 344.72 3,885.18 3,788.08 0.00 0.00 20.43 9,300.00 90.79 344.72 3,883.81 3,786.71 0.00 0.00 20.92 9,400.00 90.79 344.72 3,882.44 3,785.34 0.00 0.00 21.43 9,500.00 90.79 344.72 3,881.06 3,783.96 0.00 0.00 21.93 9,562.22 90.79 344.72 3,880.21 3,783.11 0.00 0.00 22.29 Start 2°/100'DLS,107.91°TF,for 78.62' 9,570.09 90.79 344.72 3,880.10 3,783.00 0.00 0.00 22.29 9,600.00 90.60 345.29 3,879.74 3,782.64 2.00 107.91 22.49 10/28/2015 1:48:59PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 9,640.84 90.35 346.07 3,879.40 3,782.30 2.00 107.92 22.77 Hold for 1558.22' 9,648.71 90.30 346.22 3,879.35 3,782.25 2.00 107.92 22.77 9,700.00 90.30 346.22 3,879.08 3,781.98 0.00 180.00 22.99 9,800.00 90.30 346.22 3,878.55 3,781.45 0.00 0.00 23.50 9,900.00 90.30 346.22 3,878.02 3,780.92 0.00 0.00 24.01 10,000.00 90.30 346.22 3,877.49 3,780.39 0.00 0.00 24.53 10,100.00 90.30 346.22 3,876.96 3,779.86 0.00 0.00 25.05 10,200.00 90.30 346.22 3,876.43 3,779.33 0.00 0.00 25.57 10,300.00 90.30 346.22 3,875.90 3,778.80 0.00 0.00 26.10 10,400.00 90.30 346.22 3,875.37 3,778.27 0.00 0.00 26.63 10,500.00 90.30 346.22 3,874.84 3,777.74 0.00 0.00 27.16 10,600.00 90.30 346.22 3,874.31 3,777.21 0.00 0.00 27.69 10,700.00 90.30 346.22 3,873.78 3,776.68 0.00 0.00 28.23 10,800.00 90.30 346.22 3,873.25 3,776.15 0.00 0.00 28.77 10,900.00 90.30 346.22 3,872.73 3,775.63 0.00 0.00 29.31 11,000.00 90.30 346.22 3,872.20 3,775.10 0.00 0.00 29.85 11,100.00 90.30 346.22 3,871.67 3,774.57 0.00 0.00 30.39 11,199.06 90.30 346.22 3,871.14 3,774.04 0.00 0.00 30.94 Start 2°/100'DLS,-93.54°TF,for 43.7' 11,200.00 90.30 346.22 3,871.14 3,774.04 0.00 0.00 30.94 11,206.93 90.30 346.22 3,871.10 3,774.00 0.00 0.00 30.98 11,242.76 90.26 345.50 3,870.92 3,773.82 2.00 -93.54 31.07 Hold for 1297.14' 11,250.63 90.25 345.35 3,870.89 3,773.79 2.00 -93.55 31.07 11,300.00 90.25 345.35 3,870.67 3,773.57 0.00 0.00 31.29 11,400.00 90.25 345.35 3,870.24 3,773.14 0.00 0.00 31.84 11,500.00 90.25 345.35 3,869.80 3,772.70 0.00 0.00 32.39 11,600.00 90.25 345.35 3,869.37 3,772.27 0.00 0.00 32.94 11,700.00 90.25 345.35 3,868.93 3,771.83 0.00 0.00 33.50 11,800.00 90.25 345.35 3,868.50 3,771.40 0.00 0.00 34.05 11,900.00 90.25 345.35 3,868.06 3,770.96 0.00 0.00 34.60 12,000.00 90.25 345.35 3,867.63 3,770.53 0.00 0.00 35.16 12,100.00 90.25 345.35 3,867.19 3,770.09 0.00 0.00 35.72 12,200.00 90.25 345.35 3,866.76 3,769.66 0.00 0.00 36.27 12,300.00 90.25 345.35 3,866.32 3,769.22 0.00 0.00 36.83 12,400.00 90.25 345.35 3,865.89 3,768.79 0.00 0.00 37.39 12,500.00 90.25 345.35 3,865.45 3,768.35 0.00 0.00 37.95 12,539.90 90.25 345.35 3,865.28 3,768.18 0.00 0.00 38.22 Start 2°/100'DLS,100.93°TF,for 65.77' 12,547.77 90.25 345.35 3,865.24 3,768.14 0.00 0.00 38.22 12,600.00 90.05 346.37 3,865.11 3,768.01 2.00 100.93 38.57 12,605.67 90.03 346.48 3,865.10 3,768.00 2.00 100.93 38.64 Hold for 832.22' 12,613.54 90.00 346.64 3,865.10 3,768.00 2.00 100.93 38.64 10/28/2015 1:48:59PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (0) (usft) (usft) (°/100usft) (°) (usft) 12,700.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 39.02 12,800.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 39.58 12,900.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 40.14 13,000.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 40.70 13,100.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 41.27 13,200.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 41.83 13,300.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 42.39 13,400.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 42.96 13,437.89 90.00 346.64 3,865.10 3,768.00 0.00 0.00 43.22 TD: 13437.89'MD,3865.1'TVD 13,445.77 90.00 346.64 3,865.10 3,768.00 0.00 0.00 43.22 10/28/2015 1:48:59PM Page 8 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan: 39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp06 Database: OAKEDMP2 2,636.14 2,400.10 13-3/8"x 16" 13-3/8 16 6,346.00 3,890.10 9 5/8"x 12-1/4 9-5/8 12-1/4 13,445.77 3,865.10 4 1/2"x 6-3/4" 4-1/2 6-3/4 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 4,700.82 3,466.10 Top Ugnu B 0.00 4,979.96 3,586.10 Top Ugnu A 0.00 2,115.49 2,025.10 T3 0.00 2,485.56 2,303.10 K15 0.00 6,068.80 3,874.10 Top West Sak D 0.00 1,843.79 1,792.10 pFrost 0.00 5,310.04 3,704.10 Top N Sands 0.00 4,229.70 3,233.10 Top Ugnu C 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 560.00 560.00 0.00 0.00 KOP:Start 1.5°/100'DLS,90°TF,for 150.04' 710.04 710.00 0.00 2.95 Start 2°/100'DLS,-5°TF,for 200.59' 910.63 910.00 0.61 17.81 Start 2.5°/100'DLS,5°TF,for 997.21' 1,907.84 1,847.10 -0.25 335.11 Hold for 116.87' 2,024.71 1,947.10 -1.16 395.58 Start 3.5°/100'DLS,-0.44°TF,for 848.26' 2,872.97 2,529.65 -8.59 999.04 Hold for 295.38' 3,168.35 2,673.51 -11.35 1,257.02 Start 4°/100'DLS,-106.46°TF,for 1656.62' 4,824.98 3,523.93 798.38 2,292.84 Hold for 180' 5,004.98 3,600.00 955.96 2,335.06 Start 4°/100'DLS, 15.43°TF,for 158.15' 5,163.13 3,659.08 1,096.96 2,375.25 Hold for 251.67' 5,414.80 3,740.57 1,324.94 2,443.97 Start 4°/100'DLS,-59.57°TF,for 634.45' 6,049.25 3,873.10 1,937.16 2,504.04 Start 3.5°/100'DLS,-64.73°TF,for 17.02' 6,066.27 3,874.55 1,954.05 2,502.48 Hold for 58.75' 6,125.03 3,879.41 2,012.33 2,496.83 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 6,338.13 3,890.10 2,222.53 2,464.39 Hold for 30' 6,368.13 3,890.62 2,251.87 2,458.15 Start 2°/100'DLS,92.7°TF,for 63.43' 6,431.56 3,891.76 2,314.04 2,445.65 Hold for 384.35' 6,815.91 3,898.87 2,691.60 2,374.09 Start 2°/100'DLS,-84.68°TF,for 563.79' 7,379.70 3,904.10 3,231.71 2,215.67 Adjust TF to-61.72°,for 59.52' 7,439.22 3,903.81 3,286.70 2,192.91 Hold for 1007.05' 8,446.27 3,893.90 4,213.60 1,799.33 Start 2°/100'DLS,89.99°TF,for 386.43' 8,832.69 3,890.10 4,578.36 1,672.71 Adjust TF to 0°,for 11.36' 8,844.05 3,889.97 4,589.32 1,669.72 Hold for 718.17' 9,562.22 3,880.10 5,282.04 1,480.49 Start 2°/100'DLS, 107.91°TF,for 78.62' 9,640.84 3,879.35 5,358.13 1,460.76 Hold for 1558.22' 11,199.06 3,871.10 6,871.47 1,089.54 Start 2°/100'DLS,-93.54°TF,for 43.7' 11,242.76 3,870.89 6,913.83 1,078.81 Hold for 1297.14' 12,539.90 3,865.24 8,168.76 750.64 Start 2°/100'DLS, 100.93°TF,for 65.77' 12,605.67 3,865.10 8,232.57 734.72 Hold for 832.22' 13,437.89 3,865.10 9,042.26 542.37 TD: 13437.89'MD,3865.1'TVD Checked By: Approved By: Date: 10/28/2015 1:48:59PM Page 9 COMPASS 5000.1 Build 74 • • rTs d a , E M •E D N o I :o m �• m 0 V 4o N92 C v, c a m c o 3 N W o L LnX) 0 xO as � 0 r o LL 0 r SNem r Z O Cl) L Y o //_��I V illi ‘tm U N c N C O N r y t Q C 0 m aa Lo c 3 v N aL. 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C 3 O O O O O O N- 9 a) U j 0 0 0 0 0 0 0 CO Ln a) .0 C a= LO COCO O O V +- U N Co CO (0 COV CO CO uj C C C N— N N M M cr CO I- CO o 2 C6 0 a ocn , z 2 a� c .o C 0 As w c 114 Oo0 � stooao 0 a`) a, — a = 000 0000 �, m a, c c a 0 O o N M Co co coMCo •OC) OC M M N N 3 Lo O LL 3 — — Cs CV CO-CO Cfl CO to U N N 0 a0 w C6 all Cal al m w cu 0 6'i LL a `n In C d 8 2" m 2 m 3 �' o 0 O N •C 2 N 0 V) (n N N C II as N •▪N E N a, a, o f a) n w 3 ° 0 0 O o a m " 0 0 C a o- To ani ca N as co Q W O 0 O 0 Q Lad&r View 13:57, October 28 2C 15 1C-1 55wp06 The Reference Well is along the X-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors , v _ a oQ .,; 3 ,="":;- -1..-,gym 3 .,i;--- 4 n n p.F3 4 _ N .N A N U 1 U C:J� U U " U ��' 300 , Ip iblIOV�l111i II:ILI A_11 ilUl�ionil� _._ —�1 P �1 I 1 i Ilei @I, III II ( I � \ir mnlu I 1 1 i1 ,) I 1 1 1 I � I ' d�iJy ' _ qr •- 111 ' 72- .emu ai@Pb I' II nd � i ��III I� � III y i114/ ll � I o nua) 1 IIII l :.:.1:: 11,1' II' I ....-- .. -. N 150 I ....'!:1:1,11%,11',11, 11, 1,,,11111114"IIIIII 1111111'1 I I oIa .IQ' 1 41 ,� „ .40: 1? p i 1 p 92 ��II I � �II 11 a I . III �dh�1,11I1l, ,,,H a) : aN 1 pp.,,I,,,��I111,11,,1 IIS, .. ..�I,�IrGIIo0 .. ._ - ...... .�IIIIgI��INIIIII _ nn,,„.. 9I�1. IIIIIIIIIIIIIIIIIII�I�Il llp� I Equivelant Magnetic Distance I I I I 1 I I I I I I I IT 1 I I - I 1 I I I I I I 0 2000 4000 6000 8000 10000 12000 14000 Displayed interval could be less than entire well:Measured Depth 39.50 To 13445.77 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 1650.00 1 C-155wp06 (Plan:1C-155) GYD-GC-SS 2400.12636.14 13-3/8" x 16" 1650.00 2636.14 1C-155wp06 (Plan:1C-155) MWD 3890.16.846.00 9 5/8"x 12-1/4 1650.00 2636.14 1C-155wp06 (Plan:1C-155) MWD+IFR-AK-CAZ-SC 3865:113445.77 4 1/2"x 6-3/4" 2636.14 3100.00 1 C-155wp06 (Plan:1C-155) MWD 2636.14 3100.00 1C-155wp06 (Plan:1C-155) MWD+IFR-AK-CAZ-SC . 3100.00 4600.00 1 C-155wp06 (PIan:1 C-155) MWD 3100.00 6346.00 1C-155wp06 (Plan:1C-155) MWD+IFR-AK-CAZ-SC 6346.00 7846.00 1C-155wp06 (Plan:1C-155) MWD 6346.0013445.77 1 C-155wp06 (Plan:1 C-155) MWD+IFR-AK-CAZ-SC e Q U U c , i ,!( Ids Fil II co ""440.,_-,____...iw . L. , i Al / 235 c U o y \ ' I j — I I 0I w I I I I I i I 1 I 1 1 I I 1 1 I I I I 1 I 1 I 1 I 1 1 1 I 1 0 , 500 1000 1500 2000 2500 3000 3500 Equivelant Magnetic Distance Partial Measured Depth • • Bettis, Patricia K (DOA) From: Shultz, Steve (Orbis Engineering,Inc.) <Steve.Shultz@contractor.conocophillips.com> Sent: Friday, October 30, 2015 3:11 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1C-155: Permit to Drill (Revised) 215-180 Attachments: 1C-155wp06 PlanSummary.pdf Patricia, It looks like we may have sent the wp-05 copy of the Schlumberger directional. Since we had to make the changes we now have a wp-06 which has a new TD of 13,445.77'MD. I have attached the wp-06. So the new TD of the well is 13,445.77'MD. Steve From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, October 30, 2015 12:43 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL]KRU 1C-155: Permit to Drill (Revised) 215-180 Good afternoon Steve, Please verify the total measured depth for the well. Form 10-401, Box 6, has 13,407'. On page 2 of the Application for Permit to Drill Document, it shows 13446'. The Schlumberger planned wellbore survey states TD: 13,437.89'. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Friday, October 30, 2015 12:43 PM To: Shultz, Steve (Orbis Engineering, Inc.) (Steve.Shultz@contractor.conocophillips.com) Subject: KRU 1C-155: Permit to Drill (Revised) 215-180 Good afternoon Steve, Please verify the total measured depth for the well. Form 10-401, Box 6, has 13,407'. On page 2 of the Application for Permit to Drill Document, it shows 13446'. The Schlumberger planned wellbore survey states TD: 13,437.89'. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, October 29, 2015 9:17 AM To: 'Shultz, Steve (Orbis Engineering, Inc.)' Subject: RE: Requesting Change for West Sak 1C-155(PTD 215-180) Follow Up Flag: Follow up Flag Status: Completed Steve, Please submit a revised permit showing the changes in red text. A revised 10-401 form will also need to be signed and submitted. Please mark"Revised"on the top of the permit. Only those sections that change need to be submitted. Thanx, Victoria From: Shultz, Steve (Orbis Engineering, Inc.) [mailto:Steve.ShultzCcocontractor.conocophillips.com] Sent: Thursday, October 29, 2015 8:59 AM To: Loepp, Victoria T(DOA) Subject: Requesting Change for West Sak 1C-155 « File: 1C-155 13.375in Surface Summary v4 10.28.15.pdf» « File: 1C-155wp06 PlanSummary.pdf» Victoria, As you are aware, 1C-154 requested a change for moving the surface casing up due to a thicker silt stone which gave a better LOT when they drilled out. Geology is now requesting the same change for 1C-155. The old TD was 3063'MD and the new one is now 2,636'MD (2400'TVD). I have attached the directional and cement volume calculations for this new surface shoe. Is there anything else you require as far as information or AOGCC forms for this request? Thanks, Steve • • TRANSMITTAL LETTER CHECKLIST WELL NAME: Kk()L. 1 G-/s5 PTD: 021S---/.% 4evelopment _Service Exploratory Stratigraphic Test Non-Conventional FIELD: klArckil."A RiV POOL: KAA/CO44PilAlfi /.J& fSq . Cl/ Check Box for Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC / within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 io a III ❑❑ Tu C co f al , , 1 0 r 13 O : oo' �' : : : :ate) a) 0 Z. `. 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N. c. _, v 4 a a), m. fa, o. o. _, 2, 2, 2, 0, v. @, -0 O. o. _c 0 a) m, a). a) o, p ' = a � 0 �', �, �, c o o, aao �; a; az, o c U o o o a, - a o mmo, �, �, 2, a; 0 � onU, W d O N M u) ID F- CO 03 O N CO V' IO (D h CO O O .- N M1.0 CO f- 00 O) U 0 N- N M V f0 CO r.... CO O -. .I- .- .- .- N N N N N N N N N N M M CO CO CO MVICOCOM a~ O NO NO OcC C 0 ce OO 00 cp 0 MCr)) OO OO CO .N COO N I- W OO Rw p ` p p O ' a 0w-7) - a) E N v_r a) C7 E J #tIC a m c LI -1 O am U '�'! a Q a a w a > C7 a a OF rh. • 0w\�\\!1//7;_s?, THE STATE Alaska Oil and Gas Of/� j /� SJ( /� Conservation Commission "; == 11LA `1`1 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �FALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-155 ConocoPhillips Alaska, Inc. Permit No: 215-180 Surface Location: 1548.5' FNL, 4018.5' FEL, SEC. 12, T1 IN, R10E, UM Bottomhole Location: 3066' FNL, 3471' FEL, SEC. 36, T12N, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. 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. 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 P. Foerster Chair DATED this�day of October, 2015. • R F • STATE OF ALASKA -:141;07.: ALASKA OIL AND GAS CONSERVATION COMMISSION o�� ;00 PERMIT TO DRILL AOGCC 20 AAC 25.005 i0 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil Q• Service-Winj ❑ Single Zone Q 1c.Specify if well is proposed for: Drill E,, Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill ❑ Reentry C Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: I-1 Blanket. ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. • Bond No. 59-52-180„ KRU 1C-155 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13438' • TVD: 3865' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): WLSi S41. Cc) Surface: 1548.5'FNL,4018.5'FEL, Sec. 12,T11N, R10E, UM • ADL 25649,25638. lemperittiritiVerellMarl 114i3 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4606'FNL, 1553'FEL,Sec. 1,T11N, R10E, UM 467,463 11/15/2015 Total Depth: 9.Acres in Property: 14.Distance to 3066'FNL,3471'FEL, Sec.36,T12N, R10E, UM ,, 5120 . Nearest Property: >1 mile 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 97 feet 15.Distance to Nearest Well Open Surface:x- 562269 y- 5968690 Zone- 4 ., GL Elevation above MSL: •57 feet to Same Pool: 1C-184,28.5 16.Deviated wells: Kickoff depth: • 560 ft. 17.Maximum.r4rit eipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 91° deg Downhole: 1745 psig Surface: 1316 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) 42" 20" 94# K-55 welded 80' 39.5' 39.5' 119.5' 119.5' 200 cf ArcticCRETE 16" 13.375" 68# L-80 Hydril 563 3024' 39.5' 39.5' 3064' 2622' 1472 sx DeepCRETE,261 sx DeepCRETE 12.25" 9.625" 40# L-80 Hydril 563 6299' 39.5' 39.5' 6338' 3890' 1100 sx Class G 6.75" 4.5" 11.6# L-80 Hydril 563 7288' 6150' 3881' 13438' 3865' screens-no cement 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) Casing Length Size Cement Volume MD TVD Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements O 21.Verbal Approval: Commission Representative: Date: 1,,2 C 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Email Steve.Shultz(a�contractor.cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature /4 / at Phone:265-6120 Date 10/1 le..0(5- - Commission Use Only Permit to Drill API Number: Permit Approval ✓ See cover letter Number: c2 I §,- Igo 50-0a9- Z356I-00-Q� Date: '/� l ?/J h for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed/:':l bane,gas hydrates,or gas contained in shales: d Other: [3C I) l-51 1-o 3 wC p'5'9 Samples req'd: Yes ❑ No [A Mud log req'd: Yes[1] No V f}yin�L arpre.Ve rn'Or ¢-est-d-o ZsvoP 5/5 H2S measures: Yes LA No ❑ Directional svy req'd: Yes 7. No❑ Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No d J/ / APPROVED THE /O 2.--."3 / Approved by: / t�•r•../ COMMISSIONER COMMISSION -N Date: } Form 10-401�R`ise 10/2012) �i�r�iy11►v�i4fo�2gkno�ths from the date of approval(20 AAC 25.005(g)) y/�([� SOI/t')S � /��� O/ Ill _ �'\\VV1I ////��\\ !U/ ConocohiIIips RECEivED OCT ® 9 2015 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4297 October 6, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, 1C-155 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permit to Drill a grass roots onshore producer well, a horizontal well in the West Sak"D"sand. f The expected spud date for 1C-155 is, November 15, 2015. The West Sak in the 1C area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1C-155 well will be drilled in the"D"sand down structure to the North with a planned lateral length of approximately 7055'. The lateral will cross two minor faults with throws anticipated between 5 — 25'. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 8.6 ppg equivalent during the drilling of this well. A FIT test to a minimum of 11.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 211/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1C-155. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the intermediate and production sections. It will be tested to 3500 psi (annular preventer to 3500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Sincerely' / , ./., 4,.„ ,,,,,,,_ \ , ._. S Shultz West Sak Drilling Engineer • S Alpation for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 Permit It - West Sak Well #1C-155 r.■ Application for Permit to Drill Document Abr. MaAVell klciximixe Well Value Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (1) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005 (c)(4) 3 4. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005 (c)(5) 4 5. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 6. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 7. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 Surface Hole Mud Program (Drilplex AR) 5 Intermediate Hole Mud Program (LSND) 5 Lateral Mud Program (MI FazePro OBM) 5 8. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 9. Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 10.Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005 (c)(12) 6 1C-155 PERMIT WP.doc Page 1 of 7 Printed:6-Oct-15 • illation for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 Cement Program Summary 7 Attachment 4 Well Schematic 7 Attachment 5 Doyon 25 BOP Stack Configuration 7 Attachment 6 Doyon 25 on 1C-155 7 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-155 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1548.5' FNL 4018.5' FEL Sec. 12 T11N Rng 10E UM 4(13 ASP Zone 4 NAD 27 Coordinates RKB Elevation 9,Y.f AMSL Northings 5,968,690.10 Eastings:562,268.64 Pad Elevation 52.2'AMSL Location of 9 5/8"shoe 4606' FNL 1553' FEL Sec. 1 T11N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 6338' Northings: 5,970933 Eastings:564714 Total Vertical Depth, RKB: 3890' Total Vertical Depth, SS: 3793' Location at Total Depth 3065.9' FNL 3471.1' FEL Sec. 36 T12N Rng 10E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13438' Northings: 5,977,736.02 Eastings: 562,736.14 Total Vertical Depth, RKB: 3865' Total Vertical Depth, SS: 3768' and (D)other information required by 20 AAC 25.050(6); 1C-155 PERMIT WP.doc Page 2 of 7 Printed:6-Oct-15 • Allation for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wel/bores within 200 feet of any portion of the proposed well; Please see Attachment 1: 1C-155 Well Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPS)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-155. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. Please see Attachment 5 for Doyon 25 BOP stack configuration. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The maximum expected reservoir pressure in the West Sak D sand in the 1C area is 0.447 psi/ft, or 8.6 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak"D" sand formation is 1,302 psi. MPSP = (3904 ft TVD)(0.447 - 0.11 psi/ft) = 1,316 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-155 Drilling Hazards Summary. There are no close approach issues with all surrounding wells passing any major risk. 1C-/55 PERMIT WP.doc Page 3 of 7 Printed:6-Oct-15 • Altion for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(1); 1C-155 will be completed with a 9-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 MC 25.030,and a description of any slotted liner,pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3:Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 42 94 K55 Welded 80 39.5/ 39.5 119.5/ 119.5 Cemented to surface with 200 cf ArcticCRETE Cemented to Surface with 13.375 16 68 L-80 Hydril 563 3024 39.5 / 39.5 3064/ 2622 1472 sx 11.0ppg Deeperete Lead, 261 sx 12.0ppg DeepCRETE Tail Cement Top planned @ 3500' 9.625 12.25 40 L-80 Hydril 563 6299 39.5/ 39.5 6338/ 3890 MD Cemented w/1100 sx 15.8 ppg Class'G' 4.5 6.75 11.6 L-80 Hydril 563 7288 6150/ 3881 13438/ 3865 screens-no cement screens 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 MC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-155 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1C-155 PERMIT WP.doc Page 4 of 7 Printed:6-Oct-15 • Aetion for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 Surface Hole Mud Program Spud Mud Spud to Surface TD Value Density(ppg) 8.5 —9.2 LSYP 30 - 50 API Fluid Loss No Control (cc/30 min) Chlorides < 1000 pH 10.8-11.2 Intermediate Hole Mud Program (LSND) Lateral Mud Program (Ml FazePro OBM) Value 13 5/8"Csg Shoe to 9-5/8"Csg Point Density(ppg) 9.2 Value Fann 35 6 RPM 4 8 Density(ppg) 9.2 (lb/100 ft2) Fann 35 6 RPM HTHP Fluid Loss (lb/100 f9) 12 - 16 (ml/30min) < 5 API Filtrate < 6 Drill Solids < 5% (cc/30 min)) pH 9.5 — 10.0 Oil water Ratio 70:30 Drill Solids <7 Electrical >400 Stability(mV) Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(!); Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 MC 25.061(6); Not applicable: Application is not for an offshore well. 1C-155 PERMIT WP.doc Page 5 of 7 Printed:6-Oct-15 Allation for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 34" insulated conductor to +/- 119.5' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 25. Install 211/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3062' MD/ 2622'TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 133/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 135/8"x 5,000 psi BOP's to 3500 psi (annular preventer to 3500 v psi). Notify AOGCC 24 hrs before test. 6. PU 121/4" bit and 8"drilling assembly, with MWD. RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 95/s"casing point at 6338' MD/ 3890'TVD. Pull out of hole. 9. Run 95/8", 40# L80, Hydril 563 casing to surface. (top of cement to be <3723' MD which corresponds to 500'above the Ugnu C formation). 10. Install slips and 95/s" packoff and test to 3500 psi. 11. Flush 133/8"x 95/8"annulus with water, followed by isotherm. 12. PU 63/4"PDC Bit and 41/2"drilling assembly, with MWD and LWD logging tools. RIH, clean out cement to top of float equipment. Test casing to 3500 psi for 30 minutes. 13. Drill out cement and 20'of new hole. Displace hole to lateral drilling FazePro OBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 14. Directionally drill 63/4" hole to West Sak D Sand TD at +/- 13438' MD/ 3865'TVD as per directional plan. 15. Backream to 95/8"shoe. TIH and perform final circulations and displace well to solids free oil base mud. Pump out of Hole. 16. PU and run 41/2"screened liner. 17. Once all the liner is in the hole, rig up false rotary table and run 27/e wash pipe string into the entire length of the liner. Make up liner hanger running tool. 18. Finish running liner to TD to land liner and set liner hanger @ +/- 6188'MD/3883'TVD, then displace well to filtered brine 19. Pump Schlumberger acid through wash pipe (9% formic acid for 1C-155). 1C-155 PERMIT WP.doc Page 6 of 7 Printed:6-Oct-15 • AllIllation for Permit to Drill,Well 1C-155 Revision No.0 Saved:6-Oct-15 20. Allow acid to act on the filter cake. Once break time has been achieved, circulate out the formic acid and replace with inhibited brine. 21. Set liner top packer. POOH across fluid loss control valve (FLCV) to shift FLCV closed. Displace packer fluid and then continue to POOH. 22. PU 41/2"tubing and RIH 23. Land tubing. Set BPV 24. Nipple down BOPE, nipple up tree and test. Pull BPV. 25. Freeze protect well with diesel by pumping into 41/2"x 95/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 26. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Doyon 25 BOP Stack Configuration Attachment 6 Doyon 25 on 1C-155 1C-155 PERMIT WP.doc Page 7 of 7 Printed:6-Oct-15 • • IC-I 55wp05 DDT 6 . 911 Plan Summary 13.3/8"x 161' `.. - 5 1 195/8"x12-1/4 _5 in pFrost d� 412"x6314' �W 0 �� /. % , 0111111111111111.111V111-111;yz- /I _ j/ \ : - il 11 - '', 11 o 1 I' 11III I I ( I I, I 0 .,,. ,-4°/41ltt� , \ 0 3000 6000 9000 12000 Measured Depth ' ®1 o-0 Geodetic Datum: North American Datum 1983 -' 00 .7., „‘ ,, 0' Depth Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Rig: Doyon 25 11/#,, iiii ., 0 1Q90 113-3/8"x 161' ,r) ‘. pc,.i / ,. .. Ilt,„ y 6 :5;:12 41/2x63/41 -,,o i". _ axon co rm I I I I I � I I I I ,l g/4 cc,w Ei l `SV E 0 0 1500 3000 4500 6000 7590 09000 a 105,90a 940 7550 560 - 750 Horizontal Departure 330 `�� 750 - 940 t ® _ Fr/L.... ♦•�`� 940 - 1130 ! ® ......� ,y/131.9:,.:..A"11111111". ' .,o i� 1130 1320 E 60 d III .� clir4ti e im������'•� 1320 - 1520 `m I Q I 300 4iI����i��\ \A.+71%.'4...--•-4,, 60 1520 - 1710 III ..\. a .... -. ��,f I� li �1 ♦nso,4 1710 - 1900 ulcbat .•.',„:1C-18, P:;i :P ✓.,'�� Z t41�. ®t4� 1900 2380 E ^ .... \ ` �� ,fi • Z• 'Ire,-sTar4 2380 2850 Sy o U 30 d�I ki \ ,.. . _. - ,n _ .j `t���1i� i .ar' ! 2850 - 3330 o . \ �� 1C-14• 270 -IV (2.).--tag II 3330 - 3800 v? .�.1C-14A �„'!�� 3600 - a26o \ � ^: �� /r t�r�t\� •�'� 4280 - 4750 U i��: .........1\ �.1C-150 . _. J , itlllk"�t. '"� 52304750 - 5700 5230 0 1 -15L1 I or O :1iy�, oa 0 2000 4000 6000 8000 10000 12000 1400C t s 4t6 s«l� 'r!/ -.1205700 - 6670 240 T141 f ,..fir ylgf fiV.y �� 6670 - 7630 SURVEY PROGRAM =��, ',t,As r4. -:64,i*1�1 7630 - 8600 Surface Location - .- €` Depth From Depth To Survey/Plan Tool North/Y: 5968442.44 ;'� `a`,r.i)c� 6600 - 9570 39.50 1650.00 1C-155wp05(PIan:1C-155 GYD-GC-SS East/X: 1702300.26 21 'I•, �g 160 9570 - 10540 1650.00 2650.00 1C-155wp05(PIan:1C-155) MWD Pad Elevation:57.60 _ '° ';. 10540 11500 1650.00 3062.80 1C-155wp05(Plan:1C-155) MWD+IFR-AK-CAZ-SC 180 11500 - 12470 3062.80 4562.80 1C-155wp05(Plan:1C-155) MWD CASING DETAILS 3062.80 6338.13 1C-155wp05(Plan:1C-155) MWD+IFR-AK-CAZ-SC 12470 - 13438 6338.13 7838.13 1C-155wp05(PIan:1C-155) MWD TVD MD Name TM 6338.13 13437.89 1C-155wp05(Plan:1C-155) MWD+IFR-AK-CAZ-SC 2622.10 3062.80 13-3/8"x 16" Magnetic Model: BGGM2015 3890.10 6338.13 9 5/8"x 12-1/4 Magnetic Model Date: 30-Nov-15 A 3865.10 13437.89 41/2"x 6-3/4" Magnetic Declination: 18.84° To convert a Magnetic Direction to a True Direction,Add 18.84°East SECTION DETAILS - Sec MD Inc Azi TVD SN/-S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 560.00 0.00 0.00 560.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,90°TF,for 150.04' 3 710.04 2.25 90.00 710.00 0.00 2.95 1.50 90.00 0.18 Start 2°/100'DLS,-5°TF,for 200.59' 4 910.63 6.26 86.79 910.00 0.61 17.81 2.00 -5.00 1.70 Start 2.5°/100'DLS,5°TF,for 997.21' 5 1907.84 31.17 90.86 1847.10 -0.25 335.11 2.50 5.00 20.21 Hold for 116.87' 6 2024.71 31.17 90.86 1947.10 -1.16 395.58 0.00 0.00 22.99 Start 3.5°/100'DLS,-0.44°TR for 848.26' 7 2872.97 60.86 90.61 2529.65 -8.59 999.04 3.50 -0.44 52.41 Hold for 295.38' 8 3168.35 80.88 90.61 2673.51 -11.35 1257.02 0.00 0.00 65.41 Start 4°/100'DLS,-106.46°TF,for 1656.62' 9 4824.98 65.00 15.00 3523.93 798.38 2292.84 4.00 -106.46 936.87 Hold for 180' 10 5004.98 65.00 15.00 3600.00 955.96 2335.06 0.00 0.00 1096.73 1C-155 0.PTangent 092515 Start 4°/100'DLS,15.43°TE,for 158.15' 11 5163.13 71.11 16.78 3659.08 1096.96 2375.25 4.00 15.43 1239.92 Hold for 251.67' 12 5414.80 71.11 16.78 3740.57 1324.94 2443.97 0.00 0.00 1471.67 Start 4°/100'DLS,-59.57°TF,for 634.45' 13 6049.25 85.00 355.00 3873.10 1937.16 2504.04 4.00 -59.57 2086.42 1C-155 1.Top WSD 092515 DH Start 3.5°/100'DLS,-64.73°TF,for 17.02' 14 6066.27 85.25 354.46 3874.55 1954.05 2502.48 3.50 -64.73 2103.18 Hold for 58.75' 15 6125.03 85.25 354.46 3879.41 2012.33 2496.83 0.00 0.00 2161.01 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 16 6338.13 89.00 348.00 3890.10 2222.53 2484.39 3.50 -60.06 2368.83 1C-155 2.T1 Landing 092515 DH Hold for 30' 17 6368.13 89.00 348.00 3890.62 2251.87 2458.15 0.00 0.00 2397.73 Start 2°/100'DLS,92.7°TF,for 63.43' pFrost 18 6431.56 88.94 349.27 3891.76 2314.04 2445.65 2.00 92.70 2459.03 Hold for 384.35' 19 6815.91 88.94 349.27 3898.87 2691.60 2374.09 0.00 0.00 2831.52 Start 2°/100'DLS,-84.68°TF,for 563.79' 20 7379.70 90.00 338.04 3904.10 3231.71 2215.67 2.00 -84.68 3360.95 1C-155 3.T2 092515 DH Adjust TF to-61.72°,for 59.52' 21 7439.22 90.56 336.99 3903.81 3286.70 2192.91 2.00 -61.72 3414.45 Hold for 1007.05' 22 844627 90.56 336.99 3893.90 4213.60 1799.33 0.00 0.00 4315.59 Start 2°/100'DLS,89.99°TF,for 386.43' 23 8832.69 90.56 344.72 3890.10 4578.36 1672.71 2.00 89.99 4671.94 1C-155 4.T3 092515 DH Adjust TF to 0°,for 11.36' 24 8844.05 90.79 344.72 3889.97 4589.32 1669.72 2.00 0.00 4682.69 Hold for 718.17' 25 9562.22 90.79 344.72 3880.10 5282.04 1480.49 0.00 0.00 5362.57 1C-155 5.T4 092515 DH Start 21/100'DLS,107.91°TF,for 78.62' 26 9640.84 90.30 346.22 3879.35 5358.13 1460.76 2.00 107.91 5437.32 Hold for 1558.22' 27 11199.06 90.30 346.22 3871.10 6871.47 1089.54- 0.00 0.00 6925.17 1C-155 6.T5 092515 DH Start 2°/100'DLS,-93.54°TF,for 43.7' 28 11242.76 90.25 345.35 3870.89 6913.83 1078.81 2.00 -93.54 6966.79 Hold for 1297.14' 29 12539.90 90.25 345.35 3865.24 8168.76 750.64 0.00 0.00 8199.35 Start 2°/100'DLS,100.93°TF,for 65.77' 30 12605.67 90.00 346.64 3865.10 8232.57 734.72 2.00 100.93 8262.07 1C-155 7.T6 092515 DH Hold for 832.22' 31 13437.89 90.00 346.64 3865.10 904226 542.37 0.00 0.00 9058.51 1C-155 8.TD 092515 DH TD:13437.89'MD,3865.1'TVD E signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and ollision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified otherwise,all targets have a 100 feet lateral tolerance. Prepared by: Checked by: Accepted by: Approved by: Vinent Osara Nate Beck Ifeanyi Ifesie ,N N N • 'ff` 16(NI 6 Northin?(2000 usftlin) 6 u.� 0 .10000W , iIiii , [ , , , I , <, iI I I , , , I i , N U • : M J N N ,D 9 C \\I / U U S F 61, t' m 1 U .r J rn . A ion% �? /11 0*111 N .• O o ip , - II//t; c 1111hv '1 pp,� V'" C iii#11111b...‘: al 0110, fier: Ne � '01 - O = 1 U 0 C ,4,._. „--- C 03 ;. W .) � J ,- m W . a, '' At , ,_ v _ ___.........___ . c„ ,_ • aa / , N • Um'/� / N d(j p .. JJ 1 9- ,_:-., — ___--, i / QN J . �' _ N� MM__ O i ,�' Iii �-B� I N 63� UU `cam . u W N 6. N ,_ U . J N.. J Um - . d o QUU� O o o . ti "`� U O Q J _ co o r 00 Qo .g3 '. 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Ln 4 I - ca � Lo �00 Lo o ULo °06', U n U 000L rn o U) 0 .rt 068 0 0o 0 ii Zr) 2 > N 0009 J 0 O i O0CL .9 N soin LO inN o o0 °m0�S d > , o Ur , LC) ILO 0 o c—e-) U i o ram �m 0 N /80 - 0 o o —o a.c s o o X Q Ln LO LO 60 o Uo Ln -L() U 0 0 0 0 0 0 0 0 0 0 0 Ln Lr) o in o co ..4- co (u!/TJsn 0091-) q deQ leOilaa^ anal • • I 0 1 C-1 55wp05 Ln LU N 0 O M 3436 o rn a) . cd .— N x0000 a O 0 ooO .F▪ .i 21,400 � a I Ln 0 o Lno N ', to r• p N CD O C 1\000 Lc) O O LU in O O co O U !0o LO m a)to 0- o 10000 (NI ri 0 0 I 0 I- o c NI- o Ln ui Ln U In a) a) X 1 0 LO co r C,) ¶000 V o F- O i 4 _ LO Ln 0 In It) , Ln i O = U N 0 '000 o O IC) N O rn 006 ri co Lo 0 Ln N O 000L 5coc 0 068 , _o II: CV Ln 7 0009 s in c.0 - to No L) o x 00 7 I bo- l I I 0 0 0 0 in 0 0 Nn- CO cocoOoo a) a) co o co M `7ui/lJsn 017) ylde ieonJan anal co • • ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad Plan: 1C-155 Plan:1C-155 Plan: 1 C-155wp05 Report - Map Coordinates 28 September, 2015 III 0 Schlumberger Comments apply to Report- Map Coordinates the line before it. Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: PIan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155wp05 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site Kuparuk 1C Pad Site Position: Northing: 5,968,274.22 usft Latitude: 70° 19'27.241 N From: Map Easting: 1,702,403.98usft Longitude: 149°29'50.471 W Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.47 ° Well Plan: 1C-155 Well Position +N/-S 0.00 usft Northing: 5,968,442 44 usfi Latitude: 70° 19'28.904 N +EI-W 0.00 usft Easting: 1,702,300.26 usfi Longitude: 149°29'53.458 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore Plan:1C-155 Magnetics Model Name Sample Date Declination Dip Angle Field Strength x i k� -. (°) (°) (nT) BGGM2015 11/30/2015 18.84 80.99 57,504 Design 1C-155wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.50 0.00 0.00 3.50 Survey Tool Program Date 9/28/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description 39.50 1,650.00 1C-155wp05(Plan:1C-155) GYD-GC-SS Gyrodata gyro single shots 1,650.00 2,650.00 1C-155wp05(Plan:1C-155) MWD MWD-Standard 1,650.00 3,062.80 1C-155wp05(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,062.80 4,562.80 1C-155wp05(PIan:1C-155) MWD MWD-Standard 3,062.80 6,338.13 1C-155wp05(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,338.13 7,838.13 1C-155wp05(Plan:1C-155) MWD MWD-Standard 6,338.13 13,437.89 1C-155wp05(PIan:1C-155) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (0) (usft) (usft) (°/100usft) (0) (usft) 39.50 0.00 0.00 39.50 -57.60 0.00 0.00 0.00 1C-155 top D modified 092115 SS-1C-155 BoundingPolygon 072915 BP 100.00 0.00 0.00 100.00 2.90 0.00 0.00 0.04 200.00 0.00 0.00 200.00 102.90 0.00 0.00 0.19 300.00 0.00 0.00 300.00 202.90 0.00 0.00 0.33 400.00 0.00 0.00 400.00 302.90 0.00 0.00 0.48 500.00 0.00 0.00 500.00 402.90 0.00 0.00 0.62 9/28/2015 3:24:03PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 560.00 0.00 0.00 560.00 462.90 0.00 0.00 0.71 KOP:Start 1.5°/100'DLS,90°TF,for 150.04' 600.00 0.60 90.00 600.00 502.90 1.50 90.00 0.75 700.00 2.10 90.00 699.97 602.87 1.50 0.00 0.84 710.04 2.25 90.00 710.00 612.90 1.50 0.00 0.85 Start 2°/100'DLS,-5°TF,for 200.59' 800.00 4.05 87.78 799.82 702.72 2.00 -5.00 0.95 900.00 6.04 86.86 899.43 802.33 2.00 -2.78 1.07 910.63 6.26 86.79 910.00 812.90 2.00 -1.86 1.08 Start 2.5°/100'DLS,5°TF,for 997.21' 1,000.00 8.48 88.11 998.62 901.52 2.50 5.00 1.20 1,100.00 10.98 88.96 1,097.18 1,000.08 2.50 3.69 1.34 1,200.00 13.48 89.49 1,194.90 1,097.80 2.50 2.86 1.49 1,300.00 15.98 89.86 1,291.61 1,194.51 2.50 2.34 1.67 1,400.00 18.48 90.13 1,387.11 1,290.01 2.50 1.98 1.86 1,500.00 20.97 90.34 1,481.24 1,384.14 2.50 1.72 2.07 1,600.00 23.47 90.51 1,573.80 1,476.70 2.50 1.52 2.31 1,700.00 25.97 90.65 1,664.63 1,567.53 2.50 1.37 2.46 1,800.00 28.47 90.76 1,753.55 1,656.45 2.50 1.24 2.68 1,900.00 30.97 90.86 1,840.38 1,743.28 2.50 1.14 3.12 1,907.84 31.17 90.86 1,847.10 1,750.00 2.50 1.06 3.15 Hold for 116.87' 1,966.28 31.17 90.86 1,897.10 1,800.00 0.00 0.00 3.71 pFrost 2,000.00 31.17 90.86 1,925.96 1,828.86 0.00 0.00 3.71 2,024.71 31.17 90.86 1,947.10 1,850.00 0.00 0.00 3.87 Start 3.5°/100'DLS,-0.44°TF,for 848.26' 2,100.00 33.80 90.83 2,010.60 1,913.50 3.50 -0.44 4.42 2,200.00 37.30 90.79 2,091.95 1,994.85 3.50 -0.41 5.27 2,300.00 40.80 90.75 2,169.59 2,072.49 3.50 -0.38 6.25 2,400.00 44.30 90.72 2,243.25 2,146.15 3.50 -0.35 7.34 2,500.00 47.80 90.69 2,312.64 2,215.54 3.50 -0.33 8.53 2,600.00 51.30 90.67 2,377.50 2,280.40 3.50 -0.31 9.81 2,700.00 54.80 90.65 2,437.60 2,340.50 3.50 -0.29 5.10 2,800.00 58.30 90.63 2,492.71 2,395.61 3.50 -0.28 5.61 2,872.97 60.86 90.61 2,529.65 2,432.55 3.50 -0.27 5.99 Hold for 295.38' 2,900.00 60.86 90.61 2,542.82 2,445.72 0.00 0.00 6.13 3,000.00 60.86 90.61 2,591.52 2,494.42 0.00 0.00 6.67 3,062.80 60.86 90.61 2,622.10 2,525.00 0.00 0.00 7.21 13-3/8"x 16" 3,100.00 60.86 90.61 2,640.22 2,543.12 0.00 0.00 7.21 3,168.35 60.86 90.61 2,673.51 2,576.41 0.00 0.00 7.69 Start 4°/100'DLS,-106.46°TF,for 1656.62' 3,200.00 60.50 89.22 2,689.00 2,591.90 4.00 -106.46 7.94 9/282015 3:24:03PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan:1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: PIan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (0) (usft) 3,300.00 59.49 84.75 2,739.02 2,641.92 4.00 -105.78 8.77 3,400.00 58.63 80.19 2,790.45 2,693.35 4.00 -103.55 9.70 3,500.00 57.94 75.56 2,843.04 2,745.94 4.00 -101.20 10.65 3,600.00 57.42 70.87 2,896.53 2,799.43 4.00 -98.77 11.58 3,700.00 57.07 66.13 2,950.66 2,853.56 4.00 -96.26 12.48 3,800.00 56.90 61.36 3,005.16 2,908.06 4.00 -93.69 13.32 3,900.00 56.92 56.59 3,059.78 2,962.68 4.00 -91.09 14.08 4,000.00 57.11 51.83 3,114.24 3,017.14 4.00 -88.49 14.75 4,100.00 57.49 47.09 3,168.29 3,071.19 4.00 -85.89 15.34 4,200.00 58.04 42.41 3,221.65 3,124.55 4.00 -83.33 15.84 4,300.00 58.76 37.79 3,274.06 3,176.96 4.00 -80.83 16.25 4,400.00 59.64 33.25 3,325.28 3,228.18 4.00 -78.41 16.59 4,500.00 60.68 28.79 3,375.05 3,277.95 4.00 -76.09 16.86 4,600.00 61.86 24.44 3,423.14 3,326.04 4.00 -73.87 7.64 4,700.00 63.18 20.18 3,469.29 3,372.19 4.00 -71.77 7.56 4,800.00 64.62 16.02 3,513.30 3,416.20 4.00 -69.81 7.50 4,824.98 65.00 15.00 3,523.93 3,426.83 4.00 -67.98 7.49 Hold for 180' 4,900.00 65.00 15.00 3,555.63 3,458.53 0.00 0.00 7.78 4,984.60 65.00 15.00 3,591.39 3,494.29 0.00 0.00 8.09 1C-155 BasePumpTangent 072915 BP 5,000.00 65.00 15.00 3,597.90 3,500.80 0.00 0.00 8.09 5,004.98 65.00 15.00 3,600.00 3,502.90 0.00 0.00 8.11 Start 4°/100'DLS,15.43°TF,for 158.15'-1C-155 0.PTangent 092515 5,100.00 68.67 16.08 3,637.38 3,540.28 4.00 15.43 8.53 5,163.13 71.11 16.78 3,659.08 3,561.98 4.00 15.00 8.79 Hold for 251.67' 5,187.05 71.11 16.78 3,666.83 3,569.73 0.00 0.00 8.92 1C-155 0.PT 062515 VO 5,187.70 71.11 16.78 3,667.04 3,569.94 0.00 0.00 8.92 1C-155 0.PT 092515 VO 5,200.00 71.11 16.78 3,671.02 3,573.92 0.00 0.00 8.92 5,223.97 71.11 16.78 3,678.78 3,581.68 0.00 0.00 9.31 1C-155 0.Pump tangent 092515 VO 5,300.00 71.11 16.78 3,703.40 3,606.30 0.00 0.00 9.31 5,400.00 71.11 16.78 3,735.78 3,638.68 0.00 0.00 9.71 5,414.80 71.11 16.78 3,740.57 3,643.47 0.00 0.00 9.78 Start 4°/100'DLS,-59.57°TF,for 634.45' 5,500.00 72.86 13.70 3,766.92 3,669.82 4.00 -59.57 9.79 5,600.00 74.97 10.17 3,794.63 3,697.53 4.00 -58.62 9.87 5,700.00 77.14 6.70 3,818.74 3,721.64 4.00 -57.64 9.96 5,800.00 79.35 3.29 3,839.12 3,742.02 4.00 -56.80 10.05 5,900.00 81.60 359.94 3,855.67 3,758.57 4.00 -56.11 10.17 6,000.00 83.87 356.62 3,868.32 3,771.22 4.00 -55.55 10.28 9/28/2015 3:24:03PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger 1 Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1C-155wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (0) (°) (usft) (usft) (°/100usft) (°) (usft) 6,049.25 85.00 355.00 3,873.10 3,776.00 4.00 -55.13 10.35 Start 3.5°/100'DLS,-64.73°TF,for 17.02'-1C-155 1.Top WSD 092515 DH 6,063.00 85.20 354.57 3,874.27 3,777.17 3.48 -64.73 10.37 1C-155 top D 27Oct14 DL 6,066.27 85.25 354.46 3,874.55 3,777.45 3.48 -64.70 10.37 Hold for 58.75' 6,100.00 85.25 354.46 3,877.34 3,780.24 0.00 0.00 10.53 6,125.03 85.25 354.46 3,879.41 3,782.31 0.00 0.00 10.64 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 6,200.00 86.57 352.18 3,884.76 3,787.66 3.50 -60.06 10.69 6,300.00 88.33 349.16 3,889.21 3,792.11 3.50 -59.89 10.83 6,338.13 89.00 348.00 3,890.10 3,793.00 3.51 -59.76 10.89 Hold for 30'-9 5/8"x 12-1/4-1C-155 2.T1 Landing 092515 DH 6,368.13 89.00 348.00 3,890.62 3,793.52 0.00 -59.73 11.10 Start 2°/100'DLS,92.7°TF,for 63.43' 6,400.00 88.97 348.64 3,891.19 3,794.09 2.00 92.70 11.42 6,431.56 88.94 349.27 3,891.76 3,794.66 2.00 92.69 11.75 Hold for 384.35' 6,479.78 88.94 349.27 3,892.66 3,795.56 0.00 0.00 12.31 1C-155 T1 31 Oct14 DL 6,500.00 88.94 349.27 3,893.03 3,795.93 0.00 0.00 12.31 6,600.00 88.94 349.27 3,894.88 3,797.78 0.00 0.00 13.24 6,700.00 88.94 349.27 3,896.73 3,799.63 0.00 0.00 14.27 6,800.00 88.94 349.27 3,898.58 3,801.48 0.00 0.00 15.40 6,815.91 88.94 349.27 3,898.87 3,801.77 0.00 0.00 15.58 Start 2°/100'DLS,-84.68°TF,for 563.79' 6,900.00 89.10 347.59 3,900.31 3,803.21 2.00 -84.68 16.26 7,000.00 89.28 345.60 3,901.72 3,804.62 2.00 -84.65 17.05 7,100.00 89.47 343.61 3,902.81 3,805.71 2.00 -84.62 17.91 7,200.00 89.66 341.62 3,903.57 3,806.47 2.00 -84.60 18.82 7,300.00 89.85 339.63 3,904.00 3,806.90 2.00 -84.58 19.76 7,379.70 90.00 338.04 3,904.10 3,807.00 2.00 -84.58 20.54 Adjust TF to-61.72°,for 59.52'-1C-155 3.T2 092515 DH 7,400.00 90.19 337.68 3,904.07 3,806.97 2.00 -61.72 20.75 7,404.89 90.24 337.60 3,904.05 3,806.95 2.00 -61.72 21.18 1C-155 T2 31Oct14 DL 7,439.22 90.56 336.99 3,903.81 3,806.71 2.00 -61.72 21.18 Hold for 1007.05' 7,500.00 90.56 336.99 3,903.21 3,806.11 0.00 0.00 22.04 7,600.00 90.56 336.99 3,902.22 3,805.12 0.00 0.00 23.45 7,700.00 90.56 336.99 3,901.24 3,804.14 0.00 0.00 24.89 7,800.00 90.56 336.99 3,900.26 3,803.16 0.00 0.00 26.34 7,900.00 90.56 336.99 3,899.27 3,802.17 0.00 0.00 13.85 8,000.00 90.56 336.99 3,898.29 3,801.19 0.00 0.00 14.28 8,100.00 90.56 336.99 3,897.30 3,800.20 0.00 0.00 14.72 8,200.00 90.56 336.99 3,896.32 3,799.22 0.00 0.00 15.17 9/282015 3:24:03PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) TVD TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 8,300.00 90.56 336.99 3,895.34 3,798.24 0.00 0.00 15.62 8,400.00 90.56 336.99 3,894.35 3,797.25 0.00 0.00 16.09 8,446.27 90.56 336.99 3,893.90 3,796.80 0.00 0.00 16.31 Start 2°/100'DLS,89.99°TF,for 386.43' 8,500.00 90.56 338.07 3,893.37 3,796.27 2.00 89.99 16.70 8,600.00 90.56 340.07 3,892.38 3,795.28 2.00 90.00 17.35 8,700.00 90.56 342.07 3,891.40 3,794.30 2.00 90.02 18.00 8,800.00 90.56 344.07 3,890.42 3,793.32 2.00 90.04 18.64 8,832.68 90.56 344.72 3,890.10 3,793.00 2.00 90.06 18.85 1C-155 T3 27Oct14 DL 8,832.69 90.56 344.72 3,890.10 3,793.00 2.00 90.07 18.85 Adjust TF to 0°,for 11.36'-1C-155 4.T3 092515 DH 8,844.05 90.79 344.72 3,889.97 3,792.87 2.00 0.00 18.89 Hold for 718.17' 8,900.00 90.79 344.72 3,889.20 3,792.10 0.00 0.00 19.16 9,000.00 90.79 344.72 3,887.82 3,790.72 0.00 0.00 19.64 9,100.00 90.79 344.72 3,886.45 3,789.35 0.00 0.00 20.12 9,200.00 90.79 344.72 3,885.08 3,787.98 0.00 0.00 20.62 9,300.00 90.79 344.72 3,883.70 3,786.60 0.00 0.00 21.11 9,400.00 90.79 344.72 3,882.33 3,785.23 0.00 0.00 21.61 9,500.00 90.79 344.72 3,880.95 3,783.85 0.00 0.00 22.12 9,562.21 90.79 344.72 3,880.10 3,783.00 0.00 0.00 22.43 1C-155 T4 27Oct14 DL 9,562.22 90.79 344.72 3,880.10 3,783.00 0.00 0.00 22.43 Start 2°/100'DLS,107.91°TF,for 78.62'-1C-155 5.T4 092515 DH 9,600.00 90.55 345.44 3,879.66 3,782.56 2.00 107.91 22.69 9,640.84 90.30 346.22 3,879.35 3,782.25 2.00 107.92 22.92 Hold for 1558.22' 9,700.00 90.30 346.22 3,879.04 3,781.94 0.00 0.00 23.16 9,800.00 90.30 346.22 3,878.51 3,781.41 0.00 0.00 23.67 9,900.00 90.30 346.22 3,877.98 3,780.88 0.00 0.00 24.19 10,000.00 90.30 346.22 3,877.45 3,780.35 0.00 0.00 24.70 10,100.00 90.30 346.22 3,876.92 3,779.82 0.00 0.00 25.22 10,200.00 90.30 346.22 3,876.39 3,779.29 0.00 0.00 25.74 10,300.00 90.30 346.22 3,875.86 3,778.76 0.00 0.00 26.27 10,400.00 90.30 346.22 3,875.33 3,778.23 0.00 0.00 26.80 10,500.00 90.30 346.22 3,874.80 3,777.70 0.00 0.00 27.33 10,600.00 90.30 346.22 3,874.27 3,777.17 0.00 0.00 27.86 10,700.00 90.30 346.22 3,873.74 3,776.64 0.00 0.00 28.40 10,800.00 90.30 346.22 3,873.21 3,776.11 0.00 0.00 28.93 10,900.00 90.30 346.22 3,872.68 3,775.58 0.00 0.00 29.47 11,000.00 90.30 346.22 3,872.15 3,775.05 0.00 0.00 30.01 11,100.00 90.30 346.22 3,871.62 3,774.52 0.00 0.00 30.56 11,199.04 90.30 346.22 3,871.10 3,774.00 0.00 0.00 31.09 1C-155 T5 27Oct14 DL 9/28/2015 3:24:03PM Page 6 COMPASS 5000.1 Build 74 • Schlumberger • Report- Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit TVD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp05 Database: OAKEDMP2 Planned Survey MD Inc Azi(azimuth) ND TVDSS DLeg TFace Lat.Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,199.06 90.30 346.22 3,871.10 3,774.00 0.00 0.00 31.09 Start 2°/100'DLS,-93.54°TF,for 43.7'-1C-155 6.T5 092515 DH 11,200.00 90.30 346.20 3,871.10 3,774.00 2.00 -93.54 31.09 11,242.76 90.25 345.35 3,870.89 3,773.79 2.00 -93.54 31.19 Hold for 1297.14' 11,300.00 90.25 345.35 3,870.64 3,773.54 0.00 0.00 31.45 11,400.00 90.25 345.35 3,870.20 3,773.10 0.00 0.00 32.00 11,500.00 90.25 345.35 3,869.77 3,772.67 0.00 0.00 32.55 11,600.00 90.25 345.35 3,869.33 3,772.23 0.00 0.00 33.10 11,700.00 90.25 345.35 3,868.90 3,771.80 0.00 0.00 33.65 11,800.00 90.25 345.35 3,868.46 3,771.36 0.00 0.00 34.20 11,900.00 90.25 345.35 3,868.03 3,770.93 0.00 0.00 34.75 12,000.00 90.25 345.35 3,867.59 3,770.49 0.00 0.00 35.31 12,100.00 90.25 345.35 3,867.16 3,770.06 0.00 0.00 35.87 12,200.00 90.25 345.35 3,866.72 3,769.62 0.00 0.00 36.42 12,300.00 90.25 345.35 3,866.29 3,769.19 0.00 0.00 36.98 12,400.00 90.25 345.35 3,865.85 3,768.75 0.00 0.00 37.54 12,500.00 90.25 345.35 3,865.42 3,768.32 0.00 0.00 38.10 12,539.90 90.25 345.35 3,865.24 3,768.14 0.00 0.00 38.32 Start 2°/100'DLS,100.93°TF,for 65.77' 12,600.00 90.02 346.53 3,865.10 3,768.00 2.00 100.93 38.72 12,605.67 90.00 346.64 3,865.10 3,768.00 2.00 100.93 38.75 Hold for 832.22'-1C-155 7.T6 092515 DH-1C-155 T6 27Oct14 DL 12,700.00 90.00 346.64 3,865.10 3,768.00 0.00 100.93 39.17 12,800.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 39.73 12,900.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 40.29 13,000.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 40.85 13,100.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 41.41 13,200.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 41.98 13,300.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 42.54 13,400.00 90.00 346.64 3,865.10 3,768.00 0.00 0.00 43.10 13,437.89 90.00 346.64 3,865.10 3,768.00 0.00 0.00 43.32 TD: 13437.89'MD,3865.1'TVD-4 1/2"x 6-3/4"-1C-155 8.TD 092515 DH-1C-155 TD 27Oct14 DL 9/28/2015 3:24:03PM Page 7 COMPASS 5000.1 Build 74 • Schlumberger • Report-Map Coordinates Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well Plan: 1C-155 Project: Kuparuk River Unit ND Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Site: Kuparuk 1C Pad MD Reference: Plan:39.5+57.6 @ 97.10usft(Doyon 25) Well: Plan: 1C-155 North Reference: True Wellbore: Plan:1C-155 Survey Calculation Method: Minimum Curvature Design: 1 C-155wp05 Database: OAKEDMP2 6,338.13 3,890.10 9 5/8"x 12-1/4 9-5/8 12-1/4 13,437.89 3,865.10 4 1/2"x 6-3/4" 4-1/2 6-3/4 3,062.80 2,622.10 13-3/8"x 16" 13-3/8 16 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (°) (°) 1,966.28 1,897.10 pFrost 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W (usft) (usft) (usft) (usft) Comment 560.00 560.00 0.00 0.00 KOP:Start 1.5°/100'DLS,90°TF,for 150.04' 710.04 710.00 0.00 2.95 Start 2°/100'DLS,-5°TF,for 200.59' 910.63 910.00 0.61 17.81 Start 2.5°/100'DLS,5°TF,for 997.21' 1,907.84 1,847.10 -0.25 335.11 Hold for 116.87' 2,024.71 1,947.10 -1.16 395.58 Start 3.5°/100'DLS,-0.44°TF,for 848.26' 2,872.97 2,529.65 -8.59 999.04 Hold for 295.38' 3,168.35 2,673.51 -11.35 1,257.02 Start 4°/100'DLS,-106.46°TF,for 1656.62' 4,824.98 3,523.93 798.38 2,292.84 Hold for 180' 5,004.98 3,600.00 955.96 2,335.06 Start 4°/100'DLS, 15.43°TF,for 158.15' 5,163.13 3,659.08 1,096.96 2,375.25 Hold for 251.67' 5,414.80 3,740.57 1,324.94 2,443.97 Start 4°/100'DLS,-59.57°TF,for 634.45' 6,049.25 3,873.10 1,937.16 2,504.04 Start 3.5°/100'DLS,-64.73°TF,for 17.02' 6,066.27 3,874.55 1,954.05 2,502.48 Hold for 58.75' 6,125.03 3,879.41 2,012.33 2,496.83 Start 3.5°/100'DLS,-60.06°TF,for 213.1' 6,338.13 3,890.10 2,222.53 2,464.39 Hold for 30' 6,368.13 3,890.62 2,251.87 2,458.15 Start 2°/100'DLS,92.7°TF,for 63.43' 6,431.56 3,891.76 2,314.04 2,445.65 Hold for 384.35' 6,815.91 3,898.87 2,691.60 2,374.09 Start 2°/100'DLS,-84.68°TF,for 563.79' 7,379.70 3,904.10 3,231.71 2,215.67 Adjust TF to-61.72°,for 59.52' 7,439.22 3,903.81 3,286.70 2,192.91 Hold for 1007.05' 8,446.27 3,893.90 4,213.60 1,799.33 Start 2°/100'DLS,89.99°TF,for 386.43' 8,832.69 3,890.10 4,578.36 1,672.71 Adjust TF to 0°,for 11.36' 8,844.05 3,889.97 4,589.32 1,669.72 Hold for 718.17' 9,562.22 3,880.10 5,282.04 1,480.49 Start 2°/100'DLS, 107.91°TF,for 78.62' 9,640.84 3,879.35 5,358.13 1,460.76 Hold for 1558.22' 11,199.06 3,871.10 6,871.47 1,089.54 Start 2°/100'DLS,-93.54°TF,for 43.7' 11,242.76 3,870.89 6,913.83 1,078.81 Hold for 1297.14' 12,539.90 3,865.24 8,168.76 750.64 Start 2°/100'DLS,100.93°TF,for 65.77' 12,605.67 3,865.10 8,232.57 734.72 Hold for 832.22' 13,437.89 3,865.10 9,042.26 542.37 TD: 13437.89'MD,3865.1'TVD 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O 61 d1 t- r f- r ,E,, r1 V 0 O O O O O OO1 L L qD Ln d- d- 00 CO 0,2 a1 00 d__ d d' -i n Ir.... 00 a In In in d- d- t d' rn rn M d' d' d' ' 3' OM rn M rn rn rn rn M rn M rn rn rn r n n • p 0 0 d' rn d- ' n in CO CO M O Ln N. rn rn rn q) '- 0 N n N D O if O O 00 a1 nn p� N N- p0 p Ln0� N N N- a- LN P'0 N a e..1 O 0\ O O O n d- N 00 �- may- rn �- 0N ‘0 Ln co 00 Ln 01 a1 ry d- N ( v O rn QD n 01 O NO N N O � d- ,0 N rnn M rn n rn d- rn d- v 00 Ln N N rn �. Lin Ln ,� 0 � ' n N. 000 0000 CO0 O\ c - 1C-155f/thrilling Hazards S mmary 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Intermediate cement reaching Moderate Risk of cement reaching surface casing shoe,put surface casing shoe retarder in for first 60 bbls to extend set up time. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck Lost Circulation Moderate Reduced pump rates,mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds,proper hole filling(use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free oil based mud properties and lubricity while running liner lower completion, monitor torque and drag and use 5"HWDP and super sliders to run the heavy liner Attachment 2-1C-155 Drilling Hazards Summary.doc 9/23/201511:15:11 AM • • Volume Calculations and Cement Systems (West Sak 1C-155) 0.04,1 Surface Cementing Operations (16" hole X 13% Casing) '141' 0.4 Volumes are based on 200% excess in and above the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be 500' over the 13%" �; shoe @ 2561'MD J Lead Slurry Minimum pump time: -270 minutes (pump time plus 120 minutes) 0,°,s 11.0 ppg DeepCRETE— 1.91 ft3/100 lb sk Permafrost 1966' 0.9933 Wilt X 80 X 1.0 (no excess)= 80ft3 0.42059 ft3/ft X (1966-80)X 3.00 (200% excess)= 2380ft3 0.42059 ft3/ft X (2561-1966)X 1.50 (50%excess)= 375ft3 ` 2380ft3 + 375ft3+ 80ft3= 2835ft3 i ` 2835ft3/1.91ft3/sk= 1484 sks (1494 sks) 133/" Csg Tail Slurry Minimum pump time: -200 minutes (pump time plus 120 minutes) dm 3,061'MD 12.0 ppg DeepCRETE— 1.63 ft3/1001b sk 0.42059 ft3/ft X (3061-2561) X 1.5 (50% excess)= 315ft3 0.84065 ft3/ft X 80' (Shoe Joint)= 68ft3 315ft3 + 68ft3 = 383ft3 TOC 383ft3/1.63ft3/sk= 235 sks (245 sks) >3725'MD BHST= 57°F. (Based on 2.1°/100ft gradient) r- t ' Top of Intermediate Cementing Operation12 %4" hole X 9% Casing) UGNU "C" Operation ( @ 4225'MD Slurry (total) Minimum thickening: —240 minutes (pump time plus 120 minutes) It 15.8 ppg Class "G" + additives— 1.16 ft3/sk Top of cement estimated at-3100'MD with gauge hole N.: .31321ft3/ft X (6338'-3725')X 1.2 (20% excess)= 982ft3 0.42572ft3/ft X 80' X 1.0 (no excess)= 34ft3 982ft3+ 34ft3= 1016ft3 * 1016ft3/1.16ft3/sk= 876 sks (886 sx) .1 BHST = 101°F, Estimated BHCT = 81°F lak 9%" g 6,338'MD (BHST calculated using a gradient of 2.1°F/100ft. from surface) I is ,_ ____ /' ,iiik, ---- E / } \ \[ k \wJ2 { } g«a@ ' ` ~ E / \ .o_ 419T t : 0- i . . - •0 . �\ E |� $ 52 0 .: .. \\ 1.0 .1.0 . m 1 vox. 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'19._.0 251-1* o I 026n Z \ 17..-_ 19O0 N O N O H Z 0 HE N • S Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, October 13, 2015 2:17 PM To: 'Steve.shultz@contractor.cop.com' Subject: KRU 1C-155(PTD 215-180) Anti-collision Summary Steve, Please provide the anti-collision report summary. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loer pa.alaska.aov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME: RRCL lC--/S5- PTD: /S5- PTD: 021 S--- /SO V Development _Service _Exploratory _Stratigraphic Test Non-Conventional FIELD: 144,10c444. 2.iI POOL: KurAitik 2,1UL-i k i SAX Oil Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, ✓✓✓ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 0 • El El 0, 0 0 Q NN 2 o U) o " a) a 0 Tu c m. Q d t as , , . 3' O 7 o. o Q O o 43. E O N. a o a in Z. aco 2 a) t Oj O I-, m a o 3 0' c . MS • _L � o , LO rn 3. Lo , o Ln •3, o �_ a w a o, U Q v' o, 3. �� � •m 4 CO,arn F' .0 w E' �, n E O as °' J �. C. O. C. j .. v c , o. , , 0. . m c 2, c0 , a, . , a , 7.-, , O �, a' EE IR -tc ay ay c. �, c a. 3, c o a) L0,� y. CL , od, w, a a2)' ao. , 3, �, � :?. v -o N, 3. Yao , t. (i' S. . E, o T. Y. >, a)' m .y c ami •a E. �. w. .� �'. , o Z' w d a c' coN. �. 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