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P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 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 was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas LJ SPLUG ❑ Other ❑ Abandoned ❑✓ Suspended E] 1b. Well Class: 20AAc25.105 20Aac25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: _ 0 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date mp., Susp., or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC Aba .. 10/5/2019 216-038 / 319-395 3. Address: ate Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 March 28, 2016 50-029-23567-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 3744' FSL, 2020' FEL, Sec 3, T12N, R11 E. UM, AK • April 8, 2016 MPU K-44 Top of Productive Interval: 9. Ref Elevations: KB: 63.1' 17. Field / Pool(s): Milne Point Field N/A GL: 29.3' •BF: 29.3' • Kuparuk Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 604' FNL, 1423' FWL, Sec 2, T12N, R11E, UM, AK 5,597' MD / 4,952' TVD • _ ADL375133 / ADL375132 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 54535 �$ y- 6005880 • Zone- 4 11. Total Depth MD/TVD: 8,370' MD / 7,376' TVD 19. DNR Approval Number: N/A TPI: x- N/A y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 587965 y- 6006850 • Zone- 4 N/A 1,994' MD / 1,940' TVD 5. Directional or Inclination Survey: Yes LJ (attached) No Q 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 5,597' MD / 4,952' TVD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A RECEIVED NOV 12 2019 23. CASING, LINER AND CEMENTING RECORD WT. PER CASING FT GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT HOLE SIZE CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 78.6 A-53 Surface 80' Surface 80' Cond 10-3/4" 45.5 L-80 Surface 5,597' Surface 4,952' Sig 1 L-278.5 bbls/T-63.5 bbls 13-1/2' Stg 2 L-195 bbls/T 65 bbls 7-5/8" 29.7 L-80 5,766' (Cut) 8,361' 5,094' 7,367' 9-7/8" 56 bbls 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ^^II,,,, SIZE DEPTH SET (MD) IPACKER SET (MD/TVD) - Gyl. TE �O ZOO( V RIF ED 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. hydraulic fracturing used during completion? Yes No D Per Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate Form 10-407 Revised 5/2017 1( j� _CONTINUED ON PAGE 2�gDMSl �" NOV 1 4 1019 Submit ORIGINAL only 28. CORE DATA Conventional Corals): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas orwater (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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval N/A N/A information, including reports, per 20 AAC 25.071. Formation at total depth: Kuparuk 31. List of Attachments: Wellbore Schematic, Decomplete Reports Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Monty Myers Contact Name: Cody Dinger Authorized Title: Drilling Manager Contact Email: cdinger@hilcorp.com Authorized Contact Phone: 777-8389 Signature: — 1 S 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 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region W-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the tap 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 thedata pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only HBcorp Alaska. I.LC 04 KB Elev.: 63.1!/GL Bey.: 293! I et.uv 10-3/4• tom. Type Wt/Grade/Conn Drift lD Top Btm 20" Conductor Mtil Surface 80' 10-3/4" Surface 45.5/L-80/BTC arae, 5,597' 4150 MD I// TOCQ 7,058 pa C8L 7,9V MD aBP@4140' B -sats wei �' -- � 7,518- y k TD = 8,370 (MD) /TD = 7,376(TVD) PBTD = 5,597' (MD) / PBTD= 4,952(TVD) P&A SCHEMATIC CASING nFTAII Milne Point Unit Well: MPU K-44 Abandoned: 10/5/2019 PTD: 216-038 Size Type Wt/Grade/Conn Drift lD Top Btm 20" Conductor 78.6/A-53/Weld Surface 80' 10-3/4" Surface 45.5/L-80/BTC 9,79q Surface 5,597' 7-5/8" Production 29.7 / L-80 / BTC -M 6.750 5,766 Cut) 8361' TUBING DETAIL OPEN HOLE /CEMENT DFTAII Cond Cunt to surface 13-1/2" Cunt w/ 342 bbls (Lead) 120 buts (Tail) Cunt to Surface 9-7/8" Cmt w/ 55 bbls Class G Perf from 8,144' to 8,154'/Attempt to squeeze 10 bbls of 15.8 ppg Class G curt thru perfs, no success 14.7 bbls pumped below Cement Retainer at 7,960' MD to abandon Paris -25.3 bbls on top of retainer 29.5 bbls pumped on top of CIBP at 6,150' MD–tagged 5,381' MD WELL INCLINATION DETAIL K— @ 789' Max Hole Angle = 35.1 deg. @ 2,391' MD PERFORATION DETAIL Sands Top(M D) Btm(M D) Top ITVDI Btm(TVD) FT Size/SPF/Status Kup. C-1 1 8,071' 8,128' 1 7,082' 7,139' 1 S7 3-3/8"/6spf/Isolated Kup. B-7 I .," 11 0,154 i 7,154' 7,164' 1 10 3-3/8" / 10spf/ Isolated GENERAL WELL INFO API: 50-029-23567-00-00 Abandoned/Sidetracked by Innovation Rig 10/5/19 Drilled and Cased, Kill String Installed by Doyon 14 - 4/12/2016 Completion and Perforation by ASR 1 – 5/13/16 ESP Swap 6y ASR 1-6/16/2019 Created By: CJD 11/8/2019 H Well Name: MP K-44 Field: County/State: , Alaska (LAT/LONG): avation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: Job Name: 1914444P MPU K -44A PreDrill Contractor AFE #: AFE $: Aativilli Date Ops Summary 9/19/2019 PJSM Perform rig move checklist. Install jeep on Gen Mod. Move out matt boards Gen Mod side of rig. Pull out Beyond choke skid. Prep roof, stairs and landing.,Peak trucks on location 02:00. Separate and stage Gen mod, Pit Mod, Cattle Chute, Break Shack and Enviro Vac, Walk Sub off well and rotate for the road.. Pull matt boards and take to K Pad. 9/20/2019 Take Cattle Chute and Pipe Shed to K Pad, Move Gen Mod and Pit Mod to the Y at Milne Point and Sub at entrance to S Pad. Pick matting boards from S Pad road and lay them along K Pad road. Cont. hauling miss truck loads to K Pad.,Cont laying down matting boards along K Pad road. Move Gen Mod Pit Mad , and Sub to K Pad. Move Camp, Enviro Vac and break shack to K Pad. Spot Sub over K 44A. Spot Cattle Chute to Sub. Cont. hauling misc truck loads to K Pad. 9/21/2019 Spot Pipe Shed, Pit Mod, Gen Mod and cutting boz. Spot Break Shack and Enviro Vac. Hook up inner connects. R/U stairs, roof top and landings. Start steam around the rig. Remove matting boards from K Pad road.,PJSM Spot Beyond shack. Prep and scope up Derrick. Bridle down. Work on plumbing in Pits. Work on rig acceptance check list. Cont. removing matting boards from K Pad road.,PJSM Rig accepted at 18:00. Ensure 0 PSI on tubing. W EII on vac. NOS bled off control line. N/D Tree. Checked 2 7/8" Hanger EUE 8rd thread Wl pup to ensure threads are good. Prep Well Head for DSA. SIMOPS Cont, rig up check list. Cont. removing matting boards from K Pad road.,PJSM Install 11" X 13.625" DSA. N/U BOPE. Hook up Choke and Kill lines. Modify riser and install on top of BOPE. Install MPD plumbing. SIMOPS load and process 4" D.P. 14# ht 38. Cont. removing matting boards from K Pad road.,PJSM Cont. installing MPD plumbing. Install Drip Pan and drain hoses. Obtain RKB. R/U Mouse Hole. Install Koomey lines and energize system. SIMOPS load and process 4" D.P. 14# ht 38. Perform Koomey monthly maintenance.,PJSM UD all 5" test subs and PIU 4" subs and test Equip. M/U HT 38 Dart Valve, TIW, pump in sub and XIO to 4" test Int. R/U X/O and test nipple to Top Drive-,PJSM P/U Tee Bar and NOS pulled BPV and set TWC.,PJSM R/U 4" test Jnt to Top Drive and flood stack and lines W/ H2O. Cont. pulling matting boards. 9/22/2019 PJSM, R/U to test BOP'S. Set TWC in tbg hanger. R/U on 5" donut test it. Flood stack and choke/kill lines with H2O. Purge air. Shut annular. Flood choke manifold and purge air. Attempt to obtain shell test (no test). Troubleshoot valves and BOP's.,R/D test equipment and UD test it. C/O TWC and rig back up W15" test it. Tighten LDS on hanger. Shell test 300 low /3500 high (test good). Trouble shot Top Drive.,PJSM Perform BOPE test W15" & 2 7/8" to 250 PSI low and 3,500 PSI high for 5 Min. Tested Choke Manifold 1-15, 4" & 5" Dart, 4" & 5" TW, Dart, Upper and lower, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875" X 5.5") Blind Rams, Annular W/ 3.5" test Jnt. Fail/ Pass, rebuild Super Choke.,Koomey draw drown Initial System 2,950 PSI, Manifold 1,400 PSI, Annular 1,525 PSI, after System 1,500 PSI, Man 1,500 PSI, Annular 1,475 PSI. 200 PSI increase 25 Sec, full charge 83 sec. Nitrogen 6 bottle average 2,300 PSI. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Witnessed by AOGCC Rep Matt Herrera. Unable to perform IBOP test due trouble shooting Top Drive.,PJSM Break down test Jnts and R/D test Equip.,PJSM Pull trip riser and install MPD test cap. Flood lines W/ H2O. Test MPD Head and line to Choke to 200 PSI low and 1,000 PSI high for 5 Min. Remove test cap and install trip riser. SIMOPS Cont trouble shoot Top Drive.,PJSM Clean and clear rig floor. P/U Weatherford Power Tongs and Equip. Stage back up tongs and Equip at beaver slide. P/U Baker Centrilifl sheave, tool box, old mans table and tools to rig floor. Bring up Cannon Clamp basket to rig floor.,PJSM Hang Baker double sheave in Derrick. M/U elephant trunk to sheave. Run rope through sheave and elephant trunk to spooler. Lay Herculite around spooler and tape off area. Set out herculite and pipe racks for tubing.,PJSM R/U Weatherford power tongs and 2 7/8" handling Equip.,PJSM M/U XIO's for 2 718" EUE 8 rd to 4" D.P.,Daily hauled 57 bbls to G&I total = 57 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 1,040 bbls H2O from B -Pad Creek total = 1,040 bbls Lost 0 bbis t formation Total fluid lost ZggjjQ0 = 0 bbis 9/23/2019 Continue troubleshoot top drive issue (no rotation). Back up configuration from faulty RCDU card. Remove faulty card and install new card. Load card with proper configuration. Enable top drive w/ out fault. Function test top drive without issue. Top drive fixed. Resume with well operations.,Test upper and lower [BOP. 250 low 13500 high w/ 5 min hold on each. Test #11 & #12. Service choke manifold and HCR's.,Clean and clear rig floor. Remove bell guide, safety wire from tq clamp connections on quill. B/O and UD 5" saver sub. Re -install new 4" HT39 saver sub (46k on top 6-5/8" connection) along with 4" die blocks. Install clamps and wire tie same. Install 4" bell guide.,PJSM, Check psi on choke manifold (psi 0), Open blind rams. WU 4" dp landing jt w/ 3-1/2" EUE xo. M/U to tubing hanger. Open IA and monitor well (static), Monitor tbg (fluid level out of sight). Stage top drive on top of landing it and BOLDS while monitoring IA. P/U and unseat hanger @ 92k up. PIU 5' and monitor while attempting to obtain loss rate (no returns/pumped 75 bbls @ 4 bpm).,Pull hanger to floor and attempt to Iaydown. Unable to free hydraulic elevators from new hard band on 4" drill pipe. Re -land hanger and attempt to free with top drive closer to floor (no go). Pull hanger. Cut ESP cable/control line. B/O and UD tbg hanger. Remove hydraulic elevators and UD with landing it still wedge. Stage in shed. R/U for laying down tbg/esp/control line w/ jewelry.,PJSM POOH 3 jnts and string up ESP and CAP line through sheave in Derrick. M/U line to spools in spooler unit. Cont. UD to 2.875" 6.5# L-80 EUE Tubing, ESP & CAP Line F/ 7,403' to 6,207' MD. P/U 80K Initially pumping down hale 60 bph, reduced to 40 bph of 8.5 ppg Brine/ Seawater. Count Cannon clamps while POOH. Total fluids lost for tour 346 bbls.,PJSM Cont. UD to 2.875" 6.5# L-80 EUE Tubing, ESP & CAP Line F/ 6,207'to 3,392' MD. P/U 63K, SLK 56K Pumping 40 bph down hole of 8.5 ppg Brine/ Seawater. Count Cannon clamps while POOH. Total fluids lost 240 dials., Daily hauled 45 bbls to G&I total = 102 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 520 bb[s H2O from B -Pad Creek total = 1,560 bbls Lost 586 bbls to formation Total fluid lost section= 586 bbls 9/24/2019 Cont. UD to 2.875" 6.5# L-80 EUE Tubing, ESP & CAP Line F13.392- to 105' MD. P/U 38K, SLK 38K Pumping 40 bph down hole of 8.5 ppg Brine/ Seawater every hour. Count Cannon clamps while POOH. Total fluids lost 240 bbis. No damaged control line. ESP and tubing. Came out clean.,PJSM Terminate and tie off ESP cable. Break out Discharge Head and 10' pup. Remove Elevators and install picking slings. P/U ESP and remove pump clamps.,PJSM LID Tap pump had minor sand while turning shaft by hand. Everything else looked good. Total Cannon Clamps 127 ea, Pump Clamps 16.,PJSM R/D Sheave F/ Derrick. Clean and clear rig floor of Baker Centrilift and Weatherford tools and Equip.,PJSM P/U and install 4" Elevators. Load Cement retainer in shed„PJSM Install short body 10" ID X 10,75" OD X 9.75" LN Wear Ring. RILDS 4 ea.,PJSM P/U Cement Retainer and install 3.5" IF P X HT 38 B X/O as per Baker Rep onsite.,PJSM Grease and inspect Crown, Blocks, Top Drive and Iron Roughneck.,PJSM Single in hole Cement Retainer on 4" 3-135 14# HT 38 D.P. to 5,200' MD. P/U 100K, SLK 85K Rabbit (2,375" OD) off the Skate. TRQ to 16K. RIH at 90 fpm as per Baker Rep.,PJSM Single in hole Cement Retainer on 4" S-135 14# HT 38 D.P. F/ 5,200' to 7,960' MO. P/U 152K, SLK 105K Rabbit (2.375" OD) off the Skate. TRQ to 16K. RIH at 90 fpm as per Baker Rep.,PJSM Set Cement Retainer as per Baker Rep onsite. Set 5 rounds right hand turns 5.4K TRQ. P/U 3' to 150K. Let out TRQ in string, Set 8 turns to right TRQ 5.4K slack () V down to set depth at 7.960' MD. Work string up and down F/ 185K up to 75K down. Physical indication on surface Cement Retainer was set.,Start pumping �'✓ down annulus and burping air out of well W/ 8.5 ppg Brine at 3-5 BPM. Pumped 39.5 bbls to fill well, top of fluid about 1,300' MD. R/U test Equip.,PJSM Close Annular Bag flood choke manifold. Pump through Kill back through Choke line. Press up to 1,000 PSI for 10 Min, good. Pumped 1 bbl, returned 1 bbl.,PJSM P/U to unlatch, P/U 5' 153K. Turn right 8X 7 rom TRQ 6.6K to 5.5K. Released TRQ out of string. Weight indicator dropped to 125K. P/U 10' 151 K unlatched from retainer. Slacked back off to set depth at 7,960' MD.,PJSM R/U Head Pin. X/O, and Cement line to 4" D.P.,Daily hauled 0 bbls to G&I total = 102 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 390 bbls H2O from B -Pad Creek total = 1,950 bbls Lost 859 bbls to formation Total fluid lost section = 1,205 bbls 9/25/2019 Continue to RU Cmt Equip. M/U Head Pin, Swing and Lo Torque valves to cement Iine.,PJSM, Fill lines w/5 bbls FW. PT lines to 4000 psi. Pump 15 bbls FW Spacer @ 4bpm. Pump 40 bbls, 15.8 ppg Class G Cmt @ 3.4 bpm/408 psi, 5 bbls FW Spacer. Rig Displace Cmt with 8.6 ppg brine @ 7 bpm/250 psi. Squeeze Cmt and Catch 880 psi (8 14.7 bbls cmt below Retainer. Squeeze total of 18.7 bbls with FCP 1010 psi @ .25 bpm. Un sting, LID single, and drop �/ 21.3 bbls (465 ft) on top of Retainer. Est TOC @ 7495'. CIP @ 09:00.,POOH above cmt racking back 4: DP from 7960'to7591'. PUW 149K, SOW /Vw/�l CAVA 101 K.,PJSM, Drop Foam DP Wiper Ball and Circulate STS @ 10 bpm/1540 psi. Rack back 1 stand. PU single and break out head pin.,Service Rig.,PJSM, POOH racking back 4" DP from 7591' to Surf. LID Retainer running Assy.,PJSM P/U M/U 3.5" Mule Shoe and RIH W/ 4" D.P. F/ Derrick to 7,390' MD. P/U 135K, SLK 93K. Wash down at 2 bpm, 70 PSI F/ 7,390' to 7,640' MD did not tag cement top estimated at 7,495' MD. P/U 146K, SLK 97K.,Break Circ. at 10 BPM, 1,670 PSI At BU seen crude oil and uncured cement W/ the consistency of sand. Cleaned up to brine at shakers. Maybe 6 bbls of cement.,Cont washing down at 1 bpm, 20 PSI F/ 7,640' to 7,703' MD Tagged top of cement 3X W/ 5K. P/U 151 K, SLK 100K. Rack back 1 stand to 7,640' MD. 255 of cement from top of retainer.,PJSM R/U to test cement plug. Pump though Kill, choke and choke manifold to flood everything. Press up to 1,200 PSI and found gland nu leaking on well head. Bled down and tightened, Press up to 2,100 PSI on 7.625" annulus and cement retainer plug Held for 45 Min due to Press drop in first 15 Min. Test 3.1 bbls, bled good.Pumped back 2.9 bbls. All charted and witnessed by AOGCC Rep Austin Mcloud. Blow down all Iines.,PJSM Pump dry job. `\ POOH F/ 7,640'to 7,330' MD. P/U 145K, SLK 96K., PJSM Pump dry job. POOH F/ 7,330'to Surf MD. LID 3.5" Mule Shoe., PJSM P/U M1U CIBP as per Baker tp rep onsite. RIH W/ 4" D.P. to 3,460' MD. P/U 72K, SLK 67K.,Daily hauled 87 bbls to G&I total = 189 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Cid Hauled 520 bbls H2O from B -Pad Creek total = 2,470 bbls Lost 180 bbls to formation Total fluid lost section = 1,385 bbts 9/26/2019 Continue to TIH w/CIBP from 3640' to 6150'. PUW 125K, SOW 89K.,Set CIBP (rD 6150' as Per BOT Rep Setting Procedure. Pull 35K over and Set down 35K over to verify set. PU to 125K, Rotate Right 10 turns to release from CIBP. PU and verify release., Displace well from 8.5 ppg Brine to 9.5 ppg LSND Mud @ 500 gpm, 1330 psi. Monitor Well.,Service Rig. Mix and pump Slug. Install stripping rubber & air slips.,PJSM, POOH on elevators from 6150' MD to Surface. A L/D CIBP Running tool.,MU BOT Multistring Casing Cutter assy. TIH on 4" DP. Tag CIBP @ 6150' MD. PUH to 6075'. Bring on pumps @ 1.5 bpm/250 psi f� ( and open cutter blades. slack off slowly and set down on and locate 7 5/8" Csg Collar at 6084'. Rack back i stand.,Obtain pump rates every 100 PSI to 500 PSI W/ out rotary. Slack off W/ 250 PSI and locate 7 5/8" Csg collar 6,084' MD U at and 6,125' MD, setting down 4K. Rack back 1 stand and space out to start out at 6,075' MD. Stage pumps up to 5 bpm, 1,170 PSI, 70 RPM, TRQ 4K. SLK off while cutting saw TRQ F/ 4 - 5.2K then smoothed out to 4K. Pump Press fell 40 PSI, OA Press went F/ 0 PSI to 100 PSI.,Shut down pumps and close Annular Bag, Attempted to establish circulation to flow back tank at 1 bpm. Saw minimal return to tank. Press up to 1,800 PSI and started injecting 9.2 ppg LSND into formation. Pumped away 15 bbls. Shut down pumps, Press stabilized at 1,000 PSI. Bleed down and monitor well, static.,PJSM Build and pump dry job. POOH 4" D.P. W/ Csg cutter F/ 6,075' to Surf. LID Csg cutter as per Baker rep onsite.,PJSM C/O upper rams F/ VRB's to 7 5/8" solid body.,PJSM R/U Test Equip. Pull Wear Ring. P/U M/U 7 5/8" test Jnt. Set test plug and flood lines. Test 7 5/8" Rams to 500 PSI low and 2,000 PSI high for 5 min on chart, UD 7 5/8" and R/D test Equip.,PJSM R/U Weatherford 7 5/8" handling Equip and power tongs. C/O elevators and remove bell guide.,P/U 7 5/8" landing joint and M/U to Pack Off. Squeeze plastic out of Pack Off. Pull 16K over to unseat/ UD Pack Off. M/U 7 5/8" landing joint to 7 5/8" Hanger. M/U 7 518" BTC to 45" IF X10 and head pin. R/U swing, 2 ea low torques and cement line. Worked string up to 255K, 75K over buoyancy weight. Decision was made to kelly up with top drive. R/U X/O F/ 4.5" IF to HT 38. Trq 7 5/8" BTC to 8K.,Daily hauled 647 bbls to G&I total = 836 bbls Hauled 0 blots H2O from A -Pad reserve total = 0 bbls Hauled 0 bbls H2O from B -Pad Creek total = 2,470 bbls Lost 21 bbls to formation Total fluid lost section = 1,406 bbls 9/2712019 PU 4" HT -38 single. M/U Top Drive. Bring on pumps and see 1000 psi. Begin working pipe staging up to 358K. (80% of 4"DP). Attempt multiple time to free pipe and gain circulation up back side. Work pie with and without pressure. Apply as much as 1800 psi, and see 1300 psi injection pressure. Close bag and attempt establish Reverse circulation. See 900 psi before establishing injection.,UD Single, UD landing joint. CIO elevators. PU and stage BOT tools on rig floor. Grab stand and MU Multistring Casing Cutter and Stabilizer. TIH on 4" DP to 800'.,Slip and cut drill line/ Service Rig.,Continue TIH with casing cutter from 800' to 5523'.,Obtain pump rates every 100 PSI to 500 PSI W/ out rotary. Slack off W/ 250 PSI and locate 7 518" Csg collar at 5564" MD , setting down 4K. PU 4' and start cut at 5560' MD. Stage pumps up to 3.5 bpm, 625 PSI, 80 RPM, TRO 4K. Cut for 20 minutes and see 330 psi drop. Minutes later see DSL @ surface -Shut down pump, Close Bag and line up to Flow Back Tank. Allow well to U -Tube Diesel back to Tank. Bring on pump staging up to 5 bpm/450 psi. CBU 7 5/8" Annulus to Flow Back Tank. 170 bbls. Obtain 9.5 ppg in/out-TIH from 5564'to 6,071' MD.,Pumps on at 2 bpm, 367 PSI, SLK 92K. Tag cut at 6,075' MD. Pumps down start rotary at 80 RPM, 4.1 K TRQ. Start pumps at 2 bpm, 385 PSI, stage pumps up to 3 bpm, 620 PSI 1,260 U Gas at surface. Press dropped to 580 PSI SLK down 2K 4.6K TRQ 615 PSI Cont. cutting. After 15 min shut down rotary and relocate cut on depth. Start rotary at 80 RPM, 4.4K TRQ increase pump rate up to 5 bpm, 974 PSI.,SLK down 3K TRQ 5K Press dropped F/ 844 PSI to 454 PSI, TRQ 4.5K good indication cut was made. Cut time 30 MIn.,PJSM CBU at 5 bpm, 440 PSI, FIO 37.7%, MAx Gas 789 U.,PJSM Monitor well for 10 Min, static. POOH F/ 6,075' to 5,502' MD. P/U 155K, No issue going through cut at 5,560' MD. Pump dry job. Cont POOH F 5,560' to Surf. UD Cutting tool.,PJSM C/O. elevators to 7 5/8" Csg and R/U Weatherford power tongs. P/U M/U 7 5/8" landing joint to Hanger as per NOS onsite. M/U Head pin and cement line to landing joint.,PJSM Establish Circ. through Hanger. Shut in Annular and Circ. out OA 10 3/4" X 7 5/8" to flow back tank. Displace W/ 9.5 ppg LSND. Pump rate 226 gpm, 480 PSI. Circ out 205 bbls to flow back tank. Open Annular Bag.,Monitor well, well U Tubing. Circ. back to Pits at 294 gpm, 440 PSI. Max Gas 1,267U. Monitor well for 10 Min, static.,PJSM R/D cement line and break out head pin and swedge. M/U 7 5/8" swedge to floor valve. Pull Hanger broke over 210K and up weight 179K. Break out Hangs and landing joint. UD Landing joint and Hanger.,PJSM C/O elevators to 7 518" 300K side door. Stage 7 5/8" thread protectors on rig floor. SIMOPS Haul off contaminated mud from flow back tank.,PJSM POOH UD 7 518" 29.7# L-80 BTC Mod Csg to pipe shed F/ 5,548' to 5,257' MD. P/U 169K.,Daily hauled 205 bbls to G&I total = 1,041 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bbls H2O from B -Pad Creek total = 2,600 bb]s Lost 24 bbls to formation Total fluid lost section = 1,430 bbis 9/28/2019 PJSM Well started U Tubing up 7 5/8" Csg again. M/U TIW X/O and kelly up. Pump 20 bbls 10.9 ppg dry job. UD XIO. Blow down top drive.,PJSM POOH UD 7 5/8" 29# L-80 to pipe shed F/ 5,257' to 2,100' MD. P/U 103K. No Iosses.,PJSM Grease Crown, Blocks, Top Drive, Drawworks and Iron Roughneck. Check oil in Top Drive. Adjust chain clevis on pipe skate. SIMOPS Build 150 bbls 9.5 ppg LSND.,PJSM POOH UD 7 5/8" 29# L-80 to pipe shed F/ 2,100' to cut joint. (37.76) UD 136 jnts 7 5/8". No Iosses.,Clean and clear rig floor of 7 5/8" handling Equip. No static Iosses.,PJSM P/U 5" D.P. Jnt M/U running tool. Install Wear Ring 10" ID, 26" long. RILDS.,PJSM Load rig floor W/ Baker spear fishing BHA components., PJSM M/U 4.75" Bull Nose, 6.5" Spear Pack Off, TCO Spear W/6 6.767 Grabber, 5.75" Spear Ext, 8.1" Spear Stop Sub, 6.25" Bumper Sub, 6.25" Oil Jars, 6.375" X/O, 6 as 6.25" Drill Collars, 6.25" X/O, 6.25" Energizer Jar and 6.25" X/O to 239,08'. As per Baker rep onsite.,PJSM Service and inspect Iron Roughneck. C/O 2 Grabber Dies.,PJSM RIH Spear Assy W/ 4" D.P. F/ Derrick F/ 239' to 5,560' MD. Break Circ. at 2 bpm, 185 PSI. P/U 118K, SLK 92K. 150 ft/min as per Baker. No losses.,PJSM Shut down pumps. P/U a 4" D.P. working single. RIH and tagged at 5,570' MD. Top of cut. P/U 118K, SLK 92K. Set down to 80K to set Grapple, Picked up to 140K to ensure grapple was set. Set down to 80K, pulled up to 170K jars did not fire. Pulled up to 200K, jars did not fire. Cont. to pull to 220K, jars did not fire. Slacked back down to 70K, pulled up to 240K, Jars fired with no indication fish was Ioose.,Cont. to pull up 275K 7 518" Csg was not free. Slacked back down to 80K, Pulled up to 250K, Jars fired with no indication fish was free. Cont to pull to 300K with no movement. Slacked off and Press up string to 600 PSI. Slacked down to 75K, Pulled up to 263K. Jars fired again with no movement. Cont to pull to 300K, still not free. Slacked back down 75K, pulled up to 282K.,Jars fired and the drill string jumped about 6' string weight was at 118K. Pressure was gone. Worked string up and down appeared we came off the fish. P/U 118K, SLK 92K. Decision was made to come out and look at the spear BHA.,PJSM CBU at 252 GPM, 400 PSI. Max Gas 2,419U. Perform Derrick inspection from Crown to ground. Monitor well for 10 Min, static.,PJSM UD 4" D.P. working single. Pull 5 stands and no sign of swabbing. Pump 10 bbl 10.9 ppg dry job. POOH 4" D.P. F/ 5,255' to 239 MD.,Daily hauled 272 bbls to G&I total = 1,313 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 390 bbls H2O from B -Pad Creek total = 2,990 bb]s Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 9/29/2019 PJSM Rack back 2 stands 6.25" Drill Collars, UD 2 Ea 6.25" Drill Collars. UD Bull Nose, Spear Pack Off, Spear and Spear EM. UD Jars to pipe shed as per Baker Rep onsite. Pack Off rubber damage probably from coming in contact with the cut joint when grapple slipped off of fish. Grapple appeared to have worked up past the Helix and released due to jarring.,PJSM Drain Stack and pull Wear Ring. Set test plug.,PJSM De Energize Koomey. C/O Upper 7 518" Rams to 2 7/8" X 5.5" Variables.,PJSM PIU M/U 3.5" test Jnt, pump in sub, 4" TIW, and 4" Dart Valve. Fill and flood.,PJSMPerform BOPE test W/ 3.5" & 5" to 300 PSI low and 3,000 PSI high for 5 Min. Tested Choke Manifold 1-15, 2 ea 4" Dart, 2 ea 4" TIW, Upper and lower ]BOP, Mez Kill, HCR and manual Choke and Kill, manual and Super Choke, Upper and lower VRB Rams (2,875"X 5.5") Blind Rams, Annular W/ 3.5" test Jnt. Koomey draw drown Initial System 3,000 PSI, Manifold 1,400 PSI, Annular 1,425 PSI, after.,System 1,450 PSI, Man 1,450 PSI, Annular 1,410 PSI. 200 PSI increase 18 Sec, full charge 79 sec. Nitrogen 6 bottle average 2,350 PSI. Test H2S 10-20 ppm, LEL 20-40%, PVT high/ low level alarms. Witnessed waived by AOGCC Rep Austin McLeod.,PJSM R/D 5" test Jnt tools and Equip. Blow down Choke Manifold, Choke and Kill llnes.,PJSM Install Wear Ring (10" ID, 26" Length) RILDS.,PJSM M/U 4.75" Bull Nose, 6.5" Spear Pack Off, TCO Spear W/6 6.767 Grabber, 5.75" Spear Ext, 5.75" Spear EM, 8.1" Spear Stop Sub, 625" Bumper Sub, 6.25" Oil Jars, 6.375" X/O, 6 ea 6.25" Drill Collars, 6.25" X/O, 6.25" Energizer Jar and 6.25" X/O to 241.43'. As per Baker rep onsite.,PJSM RIH Spear Assy W/ 4" D.P. F/ Derrick F/ 239' to 5,560' MD. Break Circ. at 2 bpm, 185 PSI. P/U 120K, SLK 90K. 150 ft/mm as per Baker. No Iosses.,PJSM Shut down pumps. PIU a 4" D.P. working single. RIH and tagged at 5,570' MD. Top of cut. P/U 122K, SLK 92K. Set down to 80K to set Grapple, 7.5" into 7 5/8" Csg., Picked up to 140K then 150K to ensure grapple was set. Set down to 81 K, pulled up to 180K fired jars 6X, Set down to 81 K pulled up to 190K fired jars 6X, Pulled to 200K, jars fired 6X, Pulled to 210K, jars fired 6X. Inspected Derrick, good.,Fired jars 3 X at 210K. Pulled up to 220K, fired jars 8X. Pulled up to 230K, fired jars 5X. Pulled up to 240K, fired jars 3X. Pulled up to 250K fired jars 2X. Max 140K over string weight.,PJSM Inspect Crown to ground. Slack off to 57K, pull to 152K working Grapple. Turn 3X to the right 3K TRQ. Pick up to 122K and released Grapple.,Daily hauled 57 bbls to G&I total = 1,370 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bbls H2O from B -Pad Creek total = 3,120 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 9/30/2019 PJSM CBU at 300 gpm, 478 PSI, Max Gas 747U. Monitor well, static. Pull 5 stands W/ no swabbing. Pump 10.9 ppg Dry Job, Cont, POOH F/ 5,250' to 241'. No Iosses.,Service rig. Grease Crown, Blocks, Top Drive, Drawworks and Iron Roughneck. Check oil in Top Drive.,PJSM Rack back 3 stands 6.25" Drill Collars. LID Bull Nose, Spear Pack off, Spear EM and Jars to Pipe Shed as per Baker Rep onsite.,PJSM P/U M/U 5.5" Multistring Cutter, 6.75" Stabilizer and 5" X/O.,PJSM RIH W/ Cutter BHA on 4" HT 38 D.P. F/ 10' to 5,925' MD. P/U 112K, SLK 91 K. 120 ft/min as per Baker rep. No Iosses.,PJSM Obtain pump rate W/ out rotary to get base line pump Press. Slack off W/ 250 PSI and locate collar at 5,927' MD. Set down 4K at 5,925' to start cut. Cut at 80 RPM, TRQ 4K, stage pump rate up to 3 bpm, 400 PSI. Cont. slacking off to make out. Press fell to 40 PSI, good cut. CBU at 250 GPM, 725 PSI, Max Gas 396U. Monitor well for 10 min, static.,PJSM Pull 8 stands W/ no sign of swabbing. Pump 10.9 ppg Dry Job, Cont. POOH F/ 5,429'to 10' MD. No Iosses.,PJSM LID Multistring BHA as per Baker Rep onsite. Cutter looked good and showed good wear from cutting casing.,PJSM P/U 4.75" Bull Nose, 6.5" Spear Pack Off, TCO Spear W16 6.767 Grabber, 5.75" Spear Ext, 5.75" Spear Ext, 8.1" Spear Stop Sub, 6.25" Bumper Sub, 6.25" Oil Jars F/ Pipe Skate. RIH F/ Derrick 6.375" X/O, 3 stands 6.25" Drill Collars. P/U 6.25" X/O, 6.25" Energizer Jar and 6.25" X/O to 241.43'. As per Baker rep onsite. Cont to RIH to 500' MD.,PJSM RIH Spear Assy W/ 4" D.P. F/ 500" to 5,502' MD. No losses. Wash down F/ 5,502' to 5,557' MD. P/U 4" single off skate. Slack down to engage 7 5/8" Csg. Swallowed 7.5' of grapple.,PJSM P/U 120K, SLK 94K. Set down 5K and pull to 10K over to ensure grapple was set. Come on W/ pump at 0.75 bpm, pressured up to 600 PSI and held. Bleed off Press. Pull up to 180K, 60K over string weight. Start jarring operations.Pull to 180K, 60K over, Fred jars SX, 190K 70K over 5X, 200K 80K over 5X, 215K 95K over 5X. 225K 105K over, 235K 115K over 5X, 245K 125K over, 3X. Pulled up to 280K 160K over with no movement.,PJSM Inspect Derrick and Top Drive.,Daily hauled 0 bbis to G&I total = 1,370 bbls Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 130 bbis H2O from B -Pad Creek total = 3,250 bbis Lost 0 tools to formation Total fluid lost section= 1,430 bbls 10/1/2019 Continue to attempt and free fish jarring from 80K to 130K over with no success. Un -sting spear from fish.,Service rig: grease and inspect crown, blocks, top drive, drawworks and roughneck. Check oil in top drive. perform derrick inspection. Monitor well for 10 minutes - static -POOH 5 stands from 5560', no indication of swabbing. Pump dry job and continue to POOH to 241'. Calculated hole fill.,Rack back 3 stands of drill collars. LID Jars, Spear and bullnose.,Pick up multi -string cutter and RIH to 5711'. PUW 108K, SOW 87K.,Obtain pump rates from 100 psi to 500 psi. Slack off with 275 psi and located casing collar at 5,769', and 5728'. Pick up and cut casing at 5,766' with 80 rpms/3500 ft -lbs. Observe 200 psi pressure drop, top drive stalled out at 7000 ft- Ibs.,Circulate bottoms up at 6 bpm/1200 psi, max gas 150U.,POOH 5 stands from 5,750' with no indication of swabbing. Pump dry job and continue to POOH. LID spear, good indication of cut. Calculated hole fll.,Pick up spear assembly and RIH on 4" drill pipe to 2808'. PUW 90K, SOW 67K.,Continue to RIH with spear from 2808' to 5560'; PUW 121 K, SOW92K. Pickup single and engage fish at 5560' to 5572'., Pickup to 150K, Slack off to 86K. Jar x 3 working up to 240K with straight pull to 320K falling to 160K., Establish circulation staging pumps up to 6.5 bpm/555 Monitor psi. well - static.,POOH from 5766'to 5420' with initial 40K drag in open hole. PUW 125K. Calculated hole displacement.,5ewice rig: Grease crown, blocks, top drive, and drawworks. Perform derrick inspection. Monitor well on trip tank -static., Pump dry job. Continue to POOH with fish from 5420' to 4500'. PUW 115K, calculated displacement., Daily hauled 0 bbis to G&I total = 1,370 bbls Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 130 bbls H2O from B -Pad Creek total = 3,250 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/2/2019 Cont. to POOH with 7-5/8" fish from 4500' to 447'. Calculated hole fill observed.,Monitor well - static. UD (6) DC, Jars. Unsting spear from 7-5/8" casing and LID spear. From 447' to 206'.,POOH with 7-5/8" casing fish from 206' to surface. Calculated hole fill observed.,Clean and clear rig floor of Baker tools, lift sub and 7-5/8" handling equipment. Pick up 3-1/2" handling equipment. Change out elevators.,RIH to 491'; Pick up and single in the hole with mule shoe and 3- 1/2" EUE 8rd cement stinger. Crossover to HT -38. Rig down Weatherford, change out pipe handling equipment.,RIH with 3-112" cement stinger on 4" HT38 drill pipe from 491' to 5563'. PUW 104K, SOW 84K. Calculated displacement observed. Continue washing in hole from 5563' to 6140' at 200 gpm, 300 psi. Pick up pup joints and space out for cement job -Circulate hole clean staging up to 9 bpm/800 psi. CBU x 2, while rigging up Halliburton cementers. Rig up to cement. PUW 112K, SOW 89K.,Halliburton pump 5 bbis and PT lines 1000/4000 psi -good. Mix and pump 26.5 bbls, 10# spacer at 3 bpm/210 psi, 30 bbis 15.8# Class G cement at 2 bpm/270 psi, 3.5 bbls 10# spacer at 2 bpm/131 psi. Clear lines with 1 bbis water. Displace cement with 50 bbis 9.7 ppg drilling fluid at 7 bpm/679 psi. Slow to 3 bpm with 5 bbls to go FCP 132 psi.,No losses during cement job. Cement wet at 21:25, CIP at 22:00. Open valve and drill pipe on initial slight vac. Calculated TOC at 5625'.,POOH from 6140' to 5625' at 30 fpm, continue POOH to 5375'. PUW 114K.,Drop wiper ball. Establish circulation and stage pumps up to 10 bpm/750 psi, reciprocating pipe. Monitor well, static., POOH from 5313' to 5133' with no indication of swabbing. Pump dryjob. Continue to POOH and inspect diffuser/mule shoe -good. Calculated hole displacement.,RIH with 3-1/2" cement stinger from surface to 2371', PUW 58K, SOW 58K. Calculated displacement obsewed.,Daily hauled 57 bbis to G&I total = 1,427 bbis Hauled 0 bbis H2O from A -Pad reserve total = 0 bbls Hauled 130 bbis H2O from B -Pad Creek total = 3,380 bbis Lost 0 bbls to formation Total fluid lost section = 1,430 bbls 10/3/2019 Continue to RIH with 3-1/2" stinger assembly to 2371' to 5563'. Wash down at 2 bpm/140psi to 5624' tag TOC x2 with 5K. PUW 105K, SOW 84K. -Circulate bottoms up at 420 gpm/820 psi reciprocating pipe., Rig up cement hose and valves. Establish circulation at 2 bpm/130psi while cementers batch up spacer.,Cement as per detail: Hal pump 5 bbis to fill lines, PT 1000/4000 psi -good. Mix and pump 13.5 bbis 10 ppg spacer at 3bpm/240 psi, 15 bbls 15.8 ppg Class G cement at 2 bpm/205 psi, 1.5 bbls 10.5 ppg spacer, swap to rig pumps and displace with 51.4 bbls 9.7 ppg drilling fluid at 6 bpm/315 psi. Slow to 3 bpm for last 10 bible FCP 150 psi. No losses during cement job. DIP at 11:15. EST TOC 5468'.,R/D cement line. POOH on elevators from 5618' to 5187' at 20 fpm, PUW 102K.,Drop wiper ball and circulate STS at 10 bpm/715 psi.,Monitcr well, static. Pump dry job. B/D TD. POOH from 5,187' to 2621'. PUW 74K, SOW 48K. Calculated hole fill observed.,Slip and cut 95' of drilling line. Set TD limits. Check brakes - within specs.,Service rig: grease/inspect crown sheave, blocks, service iron roughneck.,RIH from 2621' to 5313', PUW 103K, SOW 83K. Calculated hole fill observed.,Wash down from 5313' at 2 bpm ICP 120 psi, observe 25-30 psi increase at 5450' but did not take weight. Slow pumps to 1 bpm/ 120 - 150 psi at 5500'; tag soft cement at 5537' but washes off. Tag hard cement at 5544' with 7K x 2 without washing off.,Circulate STS while reciprocating pipe at 9.5 bpm/730 psi, observe cement over shakers; dump contaminated mud.,Rig up for casing test and purge air. Pressure up to 2900 psi: held good for -2.5 min bleeding 17 psi first minute and 12 psi second minute, pressure then bled 30 psi and consistently 40 psi every minute. Lost 300 psi in 10 minutes before bleeding off. PT to 1000psi for 8 minutes -good. RIH and tag cement at 5537'. Discuss options with town.,Pressure back up to 2900 psi losing 25-40 psi per minute, lost 500 psi in 15 min. Pumped 7 bbls with 6 bbls returned.,Contact HES cementers, cementers loading out additional cement and discuss options with town. While CBU at 10 bpm/820 psi.,Monitor well - static. POOH from 5501' to 2870' while waiting on cement. PUW 69K, SOW 66K. Calculated hole fill obsewed.,Change out pipe handling equipment. Drift, pickup and single in hole with 5" drill pipe to 3850' while waiting on cement. PUW 87K, SOW 75K. Calculated hole displacement observed., Daily hauled 189 bbls to G&I total = 1,616 bbls Hauled 0 bbis H2O from A -Pad reserve total = 0 bbis Hauled 130 bbls H2O from B -Pad Creek total = 3,510 bbls Lost 0 bible to formation Total fluid lost section= 1,430 bbis 10/4/2019 Pick up, drift and single in the hole with 5" drill pipe from 3850' to 5420'. PUW 125K, SOW 105K. Calculated hole displacement observed.,POOH racking back 5" drill pipe from 5420' to 2870'. PUW 69K, SOW 66K. C/O pipe handing equipment to 4".,RIH with cement stinger on 4" drill pipe to 5438'. PUW 103, SOW 83 -Wash down at 2 bpm/120psi from 5438' tagging TOC at 5514' setting down 7K.,Circulate STS at 575 gpm/1475 psi.,Rig up and attempt to PT casing to 2900 psi, lost 80 psi every 5 minutes. Pumped 7 bbls, returned 6. Blow down choke/kill Iines.,Rig up HES cementers. Flood lines and PT 1500/4000 - good. Pumped 27 bbls, 10 ppg spacer at 2.5 bpm/170 psi, 14.5 bbls, 15.8 ppg Class G cement at 2.5 bpm/220 psi, 3 bbls 10 ppg spacer at 2.5 bpm/315 psi. Flush lines with 1 bbl of freshwater. Swap to rig pumps and displace with 49.6 bills of 9.7 ppg drilling fluid at 6 bpm/360 psi, slow to 3 bpm with 10 bbls to go. FCP 180 psi. No losses during cement job.,CIP at 15:30. Est. TOC 5366'. POOH from 5507' to 4999' at 20 fpm.,Drop wiper ball. Circulate STS while reciprocating at 11 bpm/900 psi.,Monitor well, static. Pump dry job. POOH from 4937' to 490'. PUW 74K, SOW 48K. Calculated hole fII.,Change pipe handling equipment, rig up power tongs. UD cement stinger: 15 jnts 3-1/2" EUE 8rd tubing, and mule shoe.,Clean and clear rig floor. R/D and UD poweitongs, Change out pipe handling equipment for 5".,Change out saver sub from HT -38 to 4.5" IF -Daily hauled 105 bbls to G&I total = 1,721 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bbls H2O from B -Pad Creek total = 3,640 bbls Lost 0 bbls to formation Total fluid lost section= 1,430 bbls U Well Name: MP K -44A Field: County/State: , Alaska (LAT/LONG): ovation (RKB): API #: Hilcorp Energy Company Composite Report Spud Date: Job Name: 1914444D MPU K -44A Drilling Contractor Innovation APE #: AFE $: Activity Date CPS Summary 10/4/2019 Cont, changing out saver sub. Change out air slip inserts to 5";Pick up Bit, bit breaker, DM, TM, lift subs and floats for BHA via tool slide.;PJSM. M/U BHA, pick up motor and make up bit and DM collar. Measure RFO = 0.68"!7.01" = 34.92". M/U TM, float, (2) flex collars and 1 HWDP. Shallow pulse test. Pick up drift and single in with (5) HWDP, Jars and (11) HWDP to 670.08'.;Daily hauled 105 bbls to G&I total = 1,721 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 130 bills H2O from B -Pad Creek total = 3,640 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bills 10/5/2019 Pick up, drift and single in the hole with 5" drill pipe from 670' to 5183'. PUW 163K, SOW 120K. Wash down from 5183' at 2 bpm/300 psi. Tag TOC at 5381'x 2 with 5K.;Circulate bottoms up while reciprocating pipe stage pumps up to 540 gpm/1725 psi.; Rig up, flood lines and purge air. PT casing to 2800 psi pumping down drill string and annulus -failed test. Bleed off. Pump a drill string volume and purge air. PT casing to 2800 psi for 30 minutes - good test. Pumped 5.4 bbls, bled back 4.9 bills. Rig down, blow down choke/kill.;RIH and lag cement at 5381' Drill cement from 5381' to 5610' to get mud motor bend out of shoe. 540 gpm/1770 psi with 80 psi diff, 40 rpms/9,000 ft -lbs, WOB 8-10K. PUW 178K, SOW 125K, ROTW 144K.;Kick off sliding at 5610', observe formation over shakers at 5618'. Drill 20' of new hole to 5638', Initial ROP limited to 10fph increasing to 30 fph. WOB 0-10K, 540 gpm/1680 psi. PUW 174K, SOW 125K.; Rack one stand back and circulate bottoms up at 540 gpm/1720 psi -even mud weights 9.7 ppg in/out.; Rig up, fill lines and purge. Shut top rams. Perform FIT to 12.5 ppg EMW with 730 psi -good. Blow down lines, rig down.;RIH to TD at 5638'. Continue sidetracking well -bore drilling from 5638' to 5753' sliding as needed at 540 gpm/1880 psi. WOB 8-10K. 40 rpms/11 Kft-lbs PUW 185K, SOW 125K, ROT 146K. Gain 2.72' C -C separation by 5657', and 11.75' C -C separation by projected survey at 5753'.;Circulate bottoms up at 540 gpm/1790 psi.40 rpms/10Kft-lbs, reciprocating pipe. Obtain SPR's.;POOH from 5753' to inside casing shoe at 5560', no indication of swabbing. Monitor well -static. Pump dryjob. Continue to POOH to 670'. PUW 63K, SOW 63K.; Distance to WP #5: 2.4', 1.481, 1.9' R; Daily hauled 177 bbls to G&I total= 1,898 bbls Hauled 0 bbls H2O from A -Pad reserve total = 0 bbls Hauled 260 bbls H2O from B -Pad Creek total = 3,770bbis Hauled 130 bbls H2O from K -Pad lake, Total = 260 bbls Lost 0 bbls to formation Total fluid lost section = 1,430 bills DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160830 Well Name/No. KUPARUK RIV UNIT 2M-38 MD 18483 TVD 6053 REQUIRED INFORMATION Completion Date 2/13/2017 Mud Log No V DATA INFORMATION Types Electric or Other Logs Run: GR/Res/Sonic Log/TOC/Neu/Den Well Log Information: Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20746-00-00 Completion Status 1 -OIL Samples No Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data ED C 28075 Digital Data Current Status 1 -OIL UIC No Directional Survey Yes V (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 124 3054 3/16/2017 Electronic Data Set, Filename: CPAI 2M-38 ` VISION Service RM LWD001.las 2822 13306 3/16/2017 Electronic Data Set, Filename: CPA] 2M-38. VISION Service RM LWD002.las 13222 14120 3/16/2017 Electronic Data Set, Filename: CPAI 2M-38, VISION Service RM LWD003.las 13982 18482 3/16/2017 Electronic Data Set, Filename: CPAI 2M-38 , VISION Service RM LWD004.las 124 18482 3/16/2017 Electronic Data Set, Filename: CPAI 2M-38 VISION Service RM.las 124 18482 3/16/2017 Electronic Data Set, Filename: CPAI 2M-38 VISION Service Customer Channel LAS.las 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM LWD002 DLIS.dlis 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM LWD002 DLIS.html ' 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM' LWD003 DLIS.dlis 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM . LWD003 DLIS.html 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM , LWD004 DLIS.dlis 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM LWD004 DLIS.html 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM LWD001 DLIS.dlis AOGCC Pagel of 3 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160830 Well Name/No. KUPARUK RIV UNIT 2M-38 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20746-00-00 MD 18483 TVD 6053 Completion Date 2/13/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM LWD001 DLIS.html ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM DLIS.dlis ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service RM DLIS.html ED C 28075 Digital Data p3/16/2017 Electronic File: CPAI 2M-38 VISION Service 2in- MD.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service 2in- TVD.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service 5in' P MD.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: CPAI 2M-38 VISION Service 5in' TVD.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 Nad27 EOW. CompassSurveys.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 Nad83 EOW + CompassSurveys.pdf ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Canvas] NAD 27.txt' ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Canvas] NAD 83.txt ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Macro] NAD 27.txt ' ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Macro] NAD 83.txt ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Petrel] NAD 27.txt ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Petrel] NAD 83.txt ' ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Survey] NAD 27.txt ' ED C 28075 Digital Data 3/16/2017 Electronic File: 2M-38 [Survey] NAD 83.txt ' Log C 28075 Log Header Scans 0 0 2160830 KUPARUK RIV UNIT 2M-38 LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments AOGCC Page 2 ol'3 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160830 Well Name/No. KUPARUK RIV UNIT 2M-38 Operator CONOCOPHILLIPS ALASKA INC MD 18483 TVD 6053 Completion Date 2/13/2017 Completion Status 1 -OIL Current Status 1 -OIL INFORMATION RECEIVED Completion Report Y Directional / Inclination Data Mud Logs, Image Files, Digital D V Production Test Informatio Y NA Mechanical Integrity Test Information Y /s Composite Logs, Image, Data File Y 7� Geologic Markers/Tops �Y Daily Operations Summary Cuttings Samples Y / Nq COMPLIANCE HISTORY Completion Date: 2/13/2017 Release Date: 7/7/2016 Description Date Comments Comments: Compliance Reviewed By: Date: API No. 50-103-20746-00-00 UIC No Core Chips Y & Core Photographs Y /A Laboratory Analyses Y AOGCC Page 3 of 3 Wednesday, April 26, 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED MAR 15 2017 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil Q � Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 1b. Well Class: Development R 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.: 2/13/2017 216-083 / 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 1/3/2017 50-103-20746-00-00 ' 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 5165' FNL, 4756' FEL, Sec 27, T11 N, R8E, UM 2/7/2017 KRU 2M-38 ' Top of Productive Interval: T. Ref Elevations: KB:130.8 17. Field / Pool(s): 1697' FNL, 5203' FEL, Sec 32, T11 N, R8E, UM GL: 101.3 BF: Kupurak River Field/Kuparuk Oil Pool 10. Plug Back Depth MD/TVD: 18. Property Designation: Total Depth: 1304' FNL, 4376' FEL, Sec 31, T11 N, R8E, UM N/A ADL 25586, ADL 25585 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 488364 y- 5948986 Zone- 4 18483/6053 931894000, 931893000 TPI: x- 477359 y- 5947199 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 472906 y- 5947607 Zone- 4 N/A 1501/1468 5. Directional or Inclination Survey: Yes I] (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) I 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 COMPLETION AT GR/Res/Sonic Log/TOC/Neu/Den 2 �O J'� VERIFIED 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20 94 H-40 31 160 31 160 42 Cement in place 13.375 68 L-80 31 3035 31 2654 16 46 sx LiteCrete Lead Cement 1859 sx LiteCrete Lead Cement w/cem net, 247 sx LiteCrete 9.625 40 L-80 2077 13305 1982 5821 12.25 806 sx 15.8 ppg Class G 7 26 L-80 28 13147 28 5759 8.75 324 sx 15.8 ppg Class G 7 26 L-80 13138 14110 5755 6085 8.75 Liner 4.5 12.6 L-80 13591 18475 5934 6053 6.125 Liner 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation 31/2 13646 1313795755 Size and Number): PERFORATIONS: 13591//5933 14390-14396 MD and 6094-6094 TVD, 14982-14988 MD and 6064-6064 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 15102-15108 MD and 6064-6064 TVD, 15449-15455 MD and 6069-6069 TVD 15771-15577 MD and 6069-6069 TVD, 15959-15965 MD and 6075-6075 TVD 16082-16088 MD and 6078-6078 TVD, 16431-16437 MD and 6086-6086 TVD 16595-16601 MD and 6091-6092 TVD, 17413-17419 MD and 6071-6071 TVD Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 17576-17611 MD and 6063-6061 TVD, 17736-17771 MD and 6052-6053 TVD 17899-17935 MD and 6050-6050 TVD, 18063-18098 MD and 6052-6053 TVD 18226-18261 MD and 6054-6054 TVD, 4- 054 6954 -TVD, 18388-18423 MD and 6052-6052 TVD 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 3/8/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: 3/14/2017 12 Test Period 2364 4520 54 936 0 Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 311 psi 1303 24 -Hour Rate _.Jp� 4220 2117 104 0 Form 10 407 j2e is 1,1/20151 ATLs�`�11 � CQTI � pn (f' % GE 2 RBDMJ LL MAR, 1 7 2��bmit ORIGINAL 28. CORE DATA Conventional Core(s): Yes ❑ No 21 Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1501 1468 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 13984 6063 information, including reports, per 20 AAC 25.071. Kuparuk C sand W Sak 2101 2003 C-80 3652 2923 C-37 9744 4663 HRZ 13257 5802 Kalubik 13667 5964 Kup C 13984 6063 TD 18483 6053 Formation at total depth: Ku aruk C 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematics Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, len I ical rer)ort. oroduction or well test results, r 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jake Voss (a7 265-6935 Email: 'ake.voss co .com Printed Name: G.L. #qrdl Title: Alaska Drilling Manager f`; Y Si nature: 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 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 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 M-38 Grass Roots Horizontal "C" Sand Producer Proposed Wellbore Schematic (4 -String) (WP22) ConocoPhillips FMC Big Bore Well Head Last Uodate: 02/16/17 - JBV Conductor To Be Installed: 20" set @ +/-110' Spud mud 16" Surface Hole 8.6-9.6 PPG :. 1Nes .Sak::::::: 9 5/8" x 13 3/8" Liner hanger: ± 2,077' MD' Surface Casing: Below West Sak 13-3/8" 68# L-80 Hydril 563 Ali ±3,044' MD / 2,657' TVD M SS`::. . -... .. -.... .. .... 12-1/4" Intermediate Hole AD WBM 5-10.5 PPG Tubine: ± 13,950' 3%" 9.3# L-80 EUE 8RD ............................................................................. .................................................................................... ;.:.;.:. .. .:•:•:•:.•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:••:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:.:•:•:•:•::•: 37:..b :::: .....:.........................:................................ TOC @ ± 12,100' MD 9 5/8" x 7" liner hanger @ ± 13,138' MD Intermediate 1: 9 5/8" 40#, L80,Hydril 563 @ ± 13,305' MD / 5,821' TVD LSND WBM 8-1/2" x 9-7/8" Intermediate Hole 10.5-12.0 PPG 7" x 4-1/2, ZXP Liner Top Packer ± 13,934' MD 6-1/8" Production Hole C -Sand Top: 14,040' MD / 6,074" TVD 7" x 4-%" Baker Flex Lock Liner hanger Intermediate 2: 7" 26#, L80, Hydril563 Production TD: @ ± 14,110' MD / 6,085' TVD @ ± 18,483' MD / 6,053' TVD ioPro WBM ■ ■ ® ■ ■ N. 10.5-11 PPG —I Production Liner: 4-1/2" 12.6# L-80 IBTM 5.75" x 4'/2" Swell Packer for fault Perforated Joints 13,59V —18,475' MD isolation KUP PROD 2M-38 Rig: DOYON 141 Time Log Operations Summary (with Timelog Depths) 2M-38 Start Time End Time Dur (hr) Phase Op Code 1/1/2017 1/1/2017 1.75 MIRU MOVE 18:00 19:45 22:30 23:00 P 1/1/2017 1/1/2017 2.25 MIRU MOVE 19:45 22:00 hydraulic hoses to diverter, spot 1/3/2017 1/1/2017 1/1/2017 1.00 MIRU MOVE 22:00 23:00 spud mud and strap 5" DP. RURD P 1/1/2017 1/2/2017 1.00 MIRU MOVE 23:00 00:00 PULD P PJSM. Pick up and rack back 18 x 1/2/2017 1/2/2017 1.00 MIRU MOVE 00:00 01:00 bottom at 80' MD. Perform diverter 1/2/2017 1/2/2017 1.75 MIRU MOVE 01:00 02:45 Continue racking back 7 x stands 5" 1/2/2017 1/2/2017 0.50 MIRU MOVE 02:45 03:15 NMDC, stand back in derrick. 1/2/2017 1/2/2017 2.00 MIRU MOVE 03:15 05:15 1/2/2017 1/2/2017 0.75 MIRU MOVE 05:15 06:00 1/2/2017 1/2/2017 3.50 MIRU MOVE 06:00 09:30 1/2/2017 1/2/2017 0.50 MIRU MOVE 09:30 10:00 1/2/2017 1/2/2017 0.25 MIRU MOVE 10:00 10:15 1/2/2017 1/2/2017 0.25 MIRU MOVE 10:15 10:30 1/2/2017 1/2/2017 1.50 MIRU MOVE 10:30 12:00 1/2/2017 1/2/2017 1.50 MIRU MOVE 12:00 13:30 1/2/2017 1/2/2017 2.00 MIRU MOVE 13:30 15:30 15:30 119:30 19:30 120:30 1/2/2017 1/2/2017 2.00 MIRU 20:30 22:30 P Spot pits, pump room, motor room, and boiler room modules. 1/2/2017 1/2/2017 0.50 MIRU 22:30 23:00 P 1 Soot second pipe shed module. 1/2/2017 1/3/2017 1.00 MIRU 23:00 00:00 hydraulic hoses to diverter, spot 1/3/2017 1/3/2017 1.50 MIRU 00:00 01:30 flu MOB MOB MOB Job: DRILLING ORIGINAL Start Depth Code Time P -T -X Operation (ftKB) End Depth (ftKB) P PJSM, RDMO to 2M-37. Move 0.0 0.0 pipshed modules and rockwasher and stage on end of pad. P Move boiler, motor complex, pump 0.0 0.0 module, and pit module and stage on pad. area, SIM -OPS remove empty drilling line spool w/ crane. P PJSM. Prep pad for moving sub to next well. P Move sub from 2M-37 to 2M-38. RURD mats. P Pull sub over 2M-38 and center over well. P Lay mats for power pack. P Spot pits, pump room, motor room, and boiler room modules. P Lay mats for pipe shed. P Spot first pipe shed module P Lay mats for second pipe shed module P 1 Soot second pipe shed module. RURD P Work on rig acceptance check list, hook up electrical, air, steam, and water lines. Berm up rockwasher, set stairways, level pipeshed, assemble mud pumps, and set up enviro vac. Rig accepted at 15:30 hrs. NUND P Nipple up diverter spool bolts, install hydraulic hoses to diverter, spot pipeshed air heater, and install riser. SIMOPS Load pits w/ un -weighted spud mud and strap 5" DP. RURD P Install mouse hole, clear rig floor, and change out handling gear and ironrough neck dies for 5" DP. PULD P PJSM. Pick up and rack back 18 x stands 5" DP in mousehole. BOPE P RIH w/ 1 x stand 5" drillpipe and tag bottom at 80' MD. Perform diverter test, AOGCC rep Guy Cook waived witness. PULD P Continue racking back 7 x stands 5" DP and 4 x stands 4" HWDP. PULD P PJSM, P/U 4 stands of 5" HWDP and 1 joint of HWDP on top of 2 joints of 7" NMDC, stand back in derrick. Page 1/69 0.0 0.0 0.01 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.01 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 inted: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/3/2017 1/3/2017 0.25 MIRU MOVE RURD P L/D mouse hole and clear rig floor. 0.0 0.0 01:30 01:45 1/3/2017 1/3/2017 0.75 MIRU MOVE SECIP P Flood conductor with spud mud and 0.0 0.0 01:45 02:30 test surface equipment to 3500 psi., good. Tag formation @ 80' 1/3/2017 1/3/2017 0.75 MIRU MOVE BHAH P Mobilize SLB BHA and tools to rig 0.0 0.0 02:30 03:15 floor. 1/3/2017 1/3/2017 0.50 MIRU MOVE SFTY P Hold Pre -Spud meeting with drilling 0.0 0.0 03:15 03:45 crew. Discussed all hazards and mitigations as per well plan. 1/3/2017 1/3/2017 1.25 MIRU MOVE BHAH P M/U clean our BHA as per SLB to 80' 0.0 80.0 03:45 05:00 MD. 1/3/2017 1/3/2017 1.75 SURFAC DRILL DDRL P Drill ahead f/ 80' MD to 200' MD, 80.0 200.0 05:00 06:45 TVD= 200'. AST=O, ART=1.75, ADT - 1.75. Bit hours= 1.75. P/U= 43K, S/O= 43K, ROT= 43K. Pump @ 500 gpm= 385 psi w/ 70-90% FO. Rotate @ 40 rpm's w/ .5K Tq on/off. WOB 0-4K. 1/3/2017 1/3/2017 0.50 SURFAC DRILL TRIP P POOH w/ clean out BHA f/ 200' MD to 200.0 37.0 06:45 07:15 37' MD. 1/3/2017 1/3/2017 2.00 SURFAC DRILL BHAH P PJSM, M/U drilling BHA #2 as per 37.0 200.0 07:15 09:15 SLB 1/3/2017 1/3/2017 2.75 SURFAC DRILL DDRL P Drill from 200' to 308' (308' TVD). 200.0 308.0 09:15 12:00 AST = .53 hrs, ART = .32 hrs, ADT _ .85 hrs, Bit hours = 2.6 hrs, Total Jars hours = 188.74 hrs, P/U = 60 kips, S/O = 60 kips, ROT = 60 kips, Torque on bottom = 0 ft -lbs, Torque off bottom = 0 ft -lbs, Flow out = 74 %, WOB = 1-10 kips, Rotary = 40 rpm, Flow in = 410 gpm, Total strokes = 106 spm, Standpipe pressure = 368 psi, Max gas = 0 units. 1/3/2017 1/3/2017 5.00 SURFAC DRILL DDRL P Drill from 308' to 647' (645' TVD). 308.0 647.0 12:00 17:00 AST = .71 hrs, ART = 2.01 hrs, ADT = 2.72 hrs, Bit hours = 3.90 hrs, Total Jar hours = 190.61 hrs, P/U = 64 kips, S/O = 64 kips, ROT = 65 kips, Torque on bottom = 2-4 k ft -lbs, Torque off bottom = 1 k ft -lbs, Flow out = 49 %, WOB = 5-10 kips, Rotary = 40 rpm, Flow in = 612 gpm, Total strokes = 120 spm, Standpipe pressure = 700 psi, Max gas = 0 units. 1/3/20171/3/2017 1.00 SURFAC DRILL RGRP T Replace drag -chain drive motor 647.0 647.0 17:00 18:00 Page 2/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/3/2017 1/4/2017 6.00 SURFAC DRILL DDRL P Drill from 647' to 949' (946' TVD). 647.0 949.0 18:00 00:00 AST = 1.56 hrs, ART = 1.78 hrs, ADT = 3.33 hrs, Bit hours = 7.56 hrs, Total Jar hours = 194.27 hrs, P/U = 84 kips, S/O = 81 kips, ROT = 63 kips, Torque on bottom = 2-5 k ft -lbs, Torque off bottom = 2 k ft -lbs, Flow out = 53 %, WOB = 13-18 kips, Rotary = 40 rpm, Flow in = 557 gpm, Total strokes = 130 spm, Standpipe pressure = 1100 psi, Max gas = 0 units. Losing 28 bbl/hour down hole. Total losses for tour = 172 bbl. Total interval losses = 172 bbl 1/4/2017 1/4/2017 6.00 SURFAC DRILL DDRL P Drill from 949' to 1416' (1369' TVD). 949.0 1,416.0 00:00 06:00 AST = 2.52 hrs, ART = 1.80 hrs, ADT = 4.32 hrs, Bit hours = 13.59 hrs, Total Jar hours = 199.73 hrs, P/U = 89 kips, S/O = 84 kips, ROT = 85 kips, Torque on bottom = 4-6 ft -lbs, Torque off bottom = 1-3 k ft -lbs, Flow out = 54 %, WOB = 15-20 kips, Rotary = 40 rpm, Flow in = 548 gpm, Total strokes = 128 spm, Standpipe pressure = 1175 psi, Max gas = 0 units. Losses stopped @ — 1250' MD, Continue to add 10 sacks per hours of NutPlug M. 1/4/2017 1/4/2017 6.00 SURFAC DRILL DDRL P Drill from 1416' to 1854' (1787' TVD). 1,416.0 1,854.0 06:00 12:00 AST = 1.69 hrs, ART = 2.27 hrs, ADT = 3.96 hrs, Bit hours = 17.55 hrs, Total Jar hours = 203.69 hrs, P/U = 101 kips, S/O = 89 kips, ROT = 94 kips, Torque on bottom = 4-10 ft -lbs, Torque off bottom = 1-5 k ft -lbs, Flow out = 55 %, WOB = 13-20 kips, Rotary = 40 rpm, Flow in = 706 gpm, Total strokes = 164 spm, Standpipe pressure = 1650 psi, Max gas = 0 units. No Losses, Continue to add 10 sacks per hours of NutPlug M. 1/4/2017 1/4/2017 6.00 SURFAC DRILL DDRL P Drill from 1854' to 2256' (2136' TVD). 1,854.0 2,256.0 12:00 18:00 AST = 2.45 hrs, ART = 1.70 hrs, ADT = 4.15 hrs, Bit hours = 21.70 hrs, Total Jar hours = 207.84 hrs, P/U = 110 kips, S/O = 92 kips, ROT = 97 kips, Torque on bottom = 4-6 ft -lbs, Torque off bottom = 2-5 k ft -lbs, Flow out = 60 %, WOB = 10-20 kips, Rotary = 40 rpm, Flow in = 750 gpm, Total strokes = 175 spm, Standpipe pressure = 2000 psi, Max gas = 221 units. No Losses, Continue to add 10 sacks per hours of NutPlug M. Page 3/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 1/4/2017 1/5/2017 6.00 SURFAC DRILL DDRL P Drill from 2256' to 2687' (2457' 2,256.0 2,687.0 18:00 00:00 TVD). AST = 2.68 hrs, ART = 2.24 hrs, ADT = 4.92 hrs, Bit hours = 26.62 hrs, Total Jar hours = 212.76 hrs, P/U = 118 kips, S/O = 92 kips, ROT = 100 kips, Torque on bottom = 8-12 ft -lbs, Torque off bottom = 4-5 k ft -lbs, Flow out = 60 %, WOB = 10-30 kips, Rotary = 40 rpm, Flow in = 750 gpm, Total strokes = 175 spm, Standpipe pressure = 2000 psi, Max gas = 510 units. No Losses, Continue to add 10 sacks per hours of NutPlug M. 1/5/2017 1/5/2017 5.00 SURFAC DRILL DDRL P Drill from 2687' to 3054' (2662' 2,687.0 3,054.0 00:00 05:00 TVD). AST = 1.05 hrs, ART = 2.72 hrs, ADT =3.77 hrs, Bit hours = 28.76 hrs, Total Jar hours = 216.53 hrs, P/U = 132 kips, S/O = 87 kips, ROT = 100 kips, Torque on bottom = 7-9 ft -lbs, Torque off bottom = 4-9 k ft -lbs, Flow out = 62 %, WOB = 20-27 kips, Rotary = 40 rpm, Flow in = 750 gpm, Total strokes = 175 spm, Standpipe pressure = 2200 psi, Max gas = 268 units. Continue to add 10 sacks per hours of NutPlug M. 1/5/2017 1/5/2017 7.00 SURFAC CASING CIRC T Phase 3 -- Circulate at 750 gpm, 2175 3,054.0 3,054.0 05:00 12:00 psi, 61 % flow, Rotate at 10 rpm, Torque off = 5-7 k -ft -lbs. Lost High - line at 05:22 hrs. Reduced circulating rate to 150 gpm @ 300 psi. Rotate at 10 rpm. Flow out = 38%. Reciprocate at 1 stand per 5 minutes.. Lost 93 bbl mud in last 12 hours 1/5/2017 1/6/2017 12.00 SURFAC CASING CIRC T Phase 3 -- Circulate at reduced 3,054.0 3,054.0 12:00 00:00 circulating rate of 150 gpm @ 300 psi. Rotate at 10 rpm. Flow out = 38%. Reciprocate at 1 stand per 5 minutes.. Hig-line power is down. Operating on rig engines 1/6/2017 1/6/2017 5.50 SURFAC CASING CIRC T Phase 3 -- Circulate at reduced 3,054.0 3,054.0 00:00 05:30 circulating rate of 150 gpm @ 275 psi. Rotate at 10 rpm. Flow out = 61 %. Reciprocate at 1 stand per 5 minutes.. Hig-line power is down. Operating on rig engines. Lossing 5 BPH 1/6/2017 1/6/2017 2.25 SURFAC CASING CIRC T Wait on trucks resupply rig after phase 3,054.0 3,054.0 05:30 07:45 3. Suck out cuttings bin and empty fluid from rock washer. Take on water in rig water tank. 1/6/2017 1/6/2017 1.75 SURFAC CASING CIRC P Circulate hole clean, stage pumps up 3,054.0 3,054.0 07:45 09:30 from 2 bpm=275 psi w/ 61 % flow out to 750 gpm=2100 psi w/ 55 % flow out, rotate @ 40 rpm's w/ 4-6K Tq. P/U= 120K, S/O= 92K, ROT= 105K. 1/6/2017 1/6/2017 0.50 SURFAC CASING OWFF P OWFF, static. 3,054.0 3,054.0 09:30 10:00 Page 4/69 Report. Printed: 2/27/2017 f Tib t d - Operations Summary (with Timelog Depths) _h 2M-38 Rig: DOYON 141 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) 1/6/2017 1/6/2017 4.00 SURFAC CASING BKRM P BROOH from 3054' MD to 2442' MD, 3,054.0 2,442.0 10:00 14:00 pump @ 750 gpm=2000 psi, 55% flow out, rotate @ 40 rpm's w/ 5-15K Tq. Stage back reaming speed up to 1000 fph. Actual displacement= 6.8 bbls, Calculated displacement= 3.8 bbls. Total Losses from midnight to 12:00 hours= 58 bbls. 1/6/2017 1/6/2017 2.25 SURFAC CASING BKRM P Backream out of the hole from 2442' 2,442.0 1,511.0 14:00 16:15 to 1511'. Pumping at 650 gpm with standpipe pressure of 1400 psi. Flow out = 35%, Rotate at 40 rpm, Top drive torque of 5-15 k -ft -lbs. Pull at 300 fph while circulating bottoms up every 2 stands pulled. 1/6/2017 1/6/2017 2.25 SURFAC CASING TRIP P Pull out of hole on elevators from 1,511.0 560.0 16:15 18:30 1511' to 952'. Rack back 3 stands of HWDP to 560'. 1/6/2017 1/6/2017 0.50 SURFAC CASING BHAH P Lay down surplus HWDP from BHA #2 560.0 420.0 18:30 19:00 from 560' to 420'. Started pulling over 25-35k.. Attempt to wipe clean without success. 1/6/2017 1/6/2017 2.00 SURFAC CASING BKRM T Continue back reaming out of the hole 420.0 200.0 19:00 21:00 from 420' to 200' due to tight hole 1/6/2017 1/6/2017 2.50 SURFAC CASING BHAH P Lay down BHA # 2. Bit and stabilizer 200.0 0.0 21:00 23:30 balled up with clay. 1/6/2017 1/7/2017 0.50 SURFAC CASING RURD P Clear rig floor and clean same. 0.0 0.0 23:30 00:00 1/7/2017 1/7/2017 0.25 SURFAC CASING RURD P PJSM, Cont to clean and clear rig 0.0 0.0 00:00 00:15 floor. 1/7/2017 1/7/2017 0.50 SURFAC CASING RURD P Mobilize casing equipment to rig floor. 0.0 0.0 00:15 00:45 1/7/2017 1/7/2017 1.00 SURFAC CASING RURD P R/U DDI casing equipment and M/U 0.0 0.0 00:45 01:45 13-3/8" XO to floor valve. 1/7/2017 1/7/2017 1.25 SURFAC CASING PUTB P PJSM, M/U 13-3/8" casing shoe track, 0.0 169.0 01:45 03:00 DavisLynch shoe and float collar and joint # 4. Pump 10 bbis though shoe track and test floats, good. 1/7/2017 1/7/2017 0.75 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80, Hyd 563 169.0 405.0 03:00 03:45 casing from 169' MD to 405' MD Taking weight @ 401' MD, 1/7/2017 1/7/2017 0.75 SURFAC CASING CIRC P Circulate hole clean. Start at 2 bpm 405.0 405.0 03:45 04:30 and stage up to 5 bpm, 25 psi, 43% flow. P/U = 59 kips and S/O = 50 kips 1/7/2017 1/7/2017 3.75 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80, Hyd 563 405.0 1,593.0 04:30 08:15 casing from 405' MD to 1593' MD 1/7/2017 1/7/2017 1.50 SURFAC CASING CIRC P Circulate casing volume at 5 bpm, 110 1,593.0 1,593.0 08:15 09:45 psi, 56% flow, P/U = 134k, S/O = 95 k 1/7/2017 1/7/2017 2.25 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80, Hyd 563 1,593.0 2,401.0 09:45 12:00 casing from 1593' MD to 2401' MD Total losses in last 12 hours = 45 bbl Page 5169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) x: 2M-38 Rig: DOYON 141 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) 1/7/2017 1/7/2017 4.00 SURFAC CASING PUTB P RIH w/ 13-3/8", 68#, L-80, Hyd 563 2,401.0 3,044.0 12:00 16:00 casing from 2401' MD to 3010' MD. Make up casing hanger and landing joint. RIH and land casing with shoe @ 3044' 1/7/2017 1/7/2017 2.50 SURFAC CEMENT CIRC P Circulate and condition mud. Stage 3,044.0 3,044.0 16:00 18:30 rate up to 8 bpm @ 150 psi, 79% flow 1/7/2017 1/7/2017 1.00 SURFAC CEMENT CIRC P Blow down top drive and rig up 3,044.0 3,044.0 18:30 19:30 cement lines. Continue circulating at 8 bpm, 300 psi 1/7/2017 1/8/2017 4.50 SURFAC CEMENT CMNT P Pump 5 bbl CW100 and pressure test 3,044.0 3,044.0 19:30 00:00 lines to 4500 psi -good test. Pump additional 35 bbl CW100 followed by 72.7 bbl MudPush II. Drop bottom plug. Pump 624 bbl Lead cement with cemnet at 11.0 ppg. Pump 72.5 bbl Tail slurry at 12.0 ppg. Drop top plug and chase with 10 bbl water. Switch to rig pump 1/8/2017 1/8/2017 1.50 SURFAC CEMENT CMNT P Drop top plug and displace cement at 3,044.0 3,044.0 00:00 01:30 6.5 bpm @ 600 psi. At 4000 strokes, slow rate to 3.0 bpm at 550 psi. Bum plug at 4302 strokes. Pressure up to 1100 psi and hold for 5 minutes. Bleed pressure and check floats -good. 1/8/2017 1/8/2017 1.50 SURFAC CEMENT CIRC P Flush surface equipment with black- 3,044.0 3,044.0 01:30 03:00 water 1/8/2017 1/8/2017 2.00 SURFAC CEMENT NUND P Nipple down diverter line and knife 3,044.0 3,044.0 03:00 05:00 valve 1/8/2017 1/8/2017 3.00 SURFAC CEMENT WWWH T Vacuum fluid out of casing and 3,044.0 3,044.0 05:00 08:00 prepare to cut conductor and reweld landing ring. Clean and clear surface equipment from rig floor. 1/8/2017 1/8/2017 3.00 SURFAC CEMENT NUND T Cut landing ring off conductor. Sim- 3,044.0 3,044.0 08:00 11:00 ops utilize crane to remove diverter line and knife valve. Stage xmas tree behind rig 1/8/2017 1/8/2017 1.00 SURFAC CEMENT NUND T Prep landing ring and conductor for 3,044.0 3,044.0 11:00 12:00 welding 1/8/2017 1/8/2017 6.50 SURFAC CEMENT NUND T Weld landing ring on conductor. Load 3,044.0 3,044.0 12:00 18:30 additonal 5" drillpipe in the pipeshed and tally 1/8/2017 1/8/2017 1.25 SURFAC CEMENT NUND T Allow landing ring to cool. Install 3,044.0 0.0 18:30 19:45 emergency slips. Break landing joint and rough cut 13-3/8" casing 1/8/2017 1/8/2017 2.25 SURFAC CEMENT NUND P Nipple down annular, diverter tee and 0.0 0.0 19:45 22:00 diverter adapter. Sim -ops-- rig down Volant casing running tool and bale extensions 1/8/2017 1/9/2017 2.00 SURFAC CEMENT NUND T Make final cut on 13-3/8" casing and 0.0 0.0 22:00 00:00 prepare for welding. Install FMC transition adapter and begin welding out. Install mousehole and prepare to pick up 5" drillpipe 1/9/2017 1/9/2017 11.00 SURFAC CEMENT PULD P Pick up 125 stands (375 joints) of 5" 0.0 0.0 00:00 11:00 drillpipe from the pipeshed and rack back in derrick Page 6/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) k =:. 2M-38 Rig: DOYON 141 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) 1/9/2017 1/9/2017 0.50 SURFAC CEMENT RURD P Remove mousehole and clear rig floor 0.0 0.0 11:00 11:30 1/9/2017 1/9/2017 3.25 SURFAC CEMENT WAIT T Wait on transistion adapter to cool. 0.0 0.0 11:30 14:45 Test with N2 per FMC and found pinhole leak. Repaired leak and continued to wait for the transition to cool. Sim -ops --prepare to change drilling line spool. Work on preventative maintenance tasks and assignments. 1/9/2017 1/9/2017 0.50 SURFAC WHDBOP NUND P Nipple up casing head 0.0 0.0 14:45 15:15 1/9/2017 1/9/2017 1.75 SURFAC WHDBOP NUND P Nipple up blowout preventors 0.0 0.0 15:15 17:00 1/9/2017 1/9/2017 3.00 SURFAC WHDBOP MPDA P Install scaffolding around blowout 0.0 0.0 17:00 20:00 preventers for MPD operations. Install trip nipple and make up MPD lines. 1/9/2017 1/10/2017 4.00 SURFAC WHDBOP BOPE P Test BOPE to 250 psi low and 3500 0.0 0.0 20:00 00:00 psi high on all components except annular which was tested to 250 psi low and 2500 psi high. Tested utilizing a 5" test joint. 1/10/2017 1/10/2017 1.50 SURFAC WHDBOP BOPE T Finish testing BOPE equipment. 0.0 0.0 00:00 01:30 Tested accumulator. Tested blind rams -failed. Functioned blind rams and retested -passed. Tested PVT equippment and gas detectors. Witnessing of test waived by Chuck Scheve, AOGCC. 1/10/2017 1/10/2017 0.50 SURFAC WHDBOP RURD P Rig down test equipment and blow 0.0 0.0 01:30 02:00 down choke/kill lines and top drive system 1/10/2017 1/10/2017 2.50 SURFAC WHDBOP MPDA P Pull trip nipple. Set MPD test cap. 0.0 0.0 02:00 04:30 Test MPD unit to300 psi/1200 psi 1/10/2017 1/10/2017 0.25 SURFAC WHDBOP MPDA P Pull MPD test plug cap and install 0.0 0.0 04:30 04:45 riser. 1/10/2017 1/10/2017 0.50 SURFAC WHDBOP RURD P Install 12.375" wear bushing and blow 0.0 0.0 04:45 05:15 down kill line 1/10/2017 1/10/2017 2.50 SURFAC CEMENT SLPC P Slip on new spool of drilling line 0.0 0.0 05:15 07:45 1/10/2017 1/10/2017 0.50 SURFAC CEMENT SVRG P SErvice rig 0.0 0.0 07:45 08:15 1/10/2017 1/10/2017 3.25 SURFAC CEMENT BHAH P Mobilize BHA components to the rig 0.0 462.0 08:15 11:30 floor. Make up directional drillling BHA #3 1/10/2017 1/10/2017 0.50 SURFAC CEMENT TRIP P RIH with BHA #3 from 462' to 1580'. 462.0 1,580.0 11:30 12:00 1/10/2017 1/10/2017 1.00 SURFAC CEMENT TRIP P RIH from 1580' to 2940'. Tag plugs 1,580.0 2,940.0 12:00 13:00 1/10/2017 1/10/2017 0.75 SURFAC CEMENT CIRC P Pull up to 2883'. Circulate bottoms up 2,940.0 2,883.0 13:00 13:45 at 750 gpm, 1300 psi. 1/10/2017 1/10/2017 0.50 SURFAC CEMENT SFTY P Morale meeting with rig crew and 2,883.0 2,883.0 13:45 14:15 CPAI drilling and wells manager Shon Robinson. 1/10/2017 1/10/2017 1.75 SURFAC CEMENT PRTS P Pressure test 13-3/8" casing to 3500 2,883.0 2,883.0 14:15 16:00 psi for 30 minutes. Required 57 pump strokes.. Bled back 7.78 bbl. Good test. Rig down test equipment Page 7169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/10/2017 1/10/2017 0.25 SURFAC CEMENT CIRC P Obtain slow pump rates and establish 2,883.0 2,883.0 16:00 16:15 initial drilling parameters: P/U = 112k S/O = 75k Rot = 90k Top drive = 60 rpm Torque off bottom = 5-9 k ft -lbs Flow in = 400 gpm, SPP = 510 psi, SPR's @ 2883' MD, MW = 9.6 ppg, @ 16:00 hrs Pump #1 #2 30 spm 40 psi 100 psi 40 spm 40 psi 100 psi 1/10/2017 1/10/2017 3.60 SURFAC CEMENT DRLG P Drill float equipment and cement (shoe 2,883.0 3,054.0 16:15 19:51 track) from 2940' to 3054'. 1/10/2017 1/10/2017 0.15 SURFAC CEMENT DDRL P Drill 20' of new hole to 3074'.(2660.84' 3,054.0 3,074.0 19:51 20:00 TVD) P/U = 120k S/O = 75k Rot = 90k WOB = 5-25k Top drive = 60-70 rpm Torque on bottom = 5-10 k ft -lbs Torque off bottom = 5-8 k ft -lbs Flow in = 200-600 gpm, Strokes = 140 spm SPP = 200-510 psi, Flow out = 47% SPR's @ 2883' MD, MW = 9.6 ppg, @ 16:00 hrs Pump #1 #2 30 spm 40 psi 100 psi 40 spm 40 psi 100 psi 1/10/2017 1/10/2017 1.00 SURFAC CEMENT CIRC P Circulate bottoms up at 700 gpm, 3,074.0 3,074.0 20:00 21:00 1360 psi, 1/10/2017 1/10/2017 0.50 SURFAC CEMENT FIT P Perform FIT to 15.8 ppg EMW. 3,074.0 3,074.0 21:00 21:30 MW = 9.6 ppg, Pressure = 850 psi Pumped a total of 18 strokes (1.8 bbl) Pressure bled to 775 psi in 30 minutes Bled off pressure and recovered 1.53 bbl in trip tank 1/10/2017 1/10/2017 0.25 INTRM1 DRILL SFTY P Pre -job safety meeting to discuss mud 3,074.0 3,074.0 21:30 21:45 swap Page 8/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/10/2017 1/11/2017 2.25 INTRM1 DRILL DDRL P Directionally drill from 3074' to 3200'. 3,074.0 3,200.0 21:45 00:00 Swap mud on the fly ART = 1.51 hrs ADT = 1.51 hrs AST = 0 hrs Bit hrs = 1.51 hrs Total jar hours = 1.51 hrs P/U = 112k S/O = 75k Rot = 90k WOB = 7-10k Top drive = 105 rpm Torque on bottom = 5-10 k ft -lbs Torque off bottom = 5-6 k ft -lbs Flow in = 800 gpm, Strokes = 188 spm SPP = 1100 psi, Flow out = 55% ECD = 10.01 ppg Max gas = 0 units SPR's @ 3160' MD, TVD = 2715' MW = 9.6 ppg, @ 23.25 hrs Pump #1 #2 30 spm 100 psi 120 psi 40 spm 80 psi 120 psi 1/11/2017 1/11/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 3200' to 3816'. 3,200.0 3,816.0 00:00 06:00 (TVD = 2980') ART = 5.49 hrs ADT = 7 hrs AST = 0 hrs Bit hrs = 7 hrs Total jar hours = 7 hrs P/U = 125k S/O = 80k Rot = 95k WOB = 10-15k Top drive = 150 rpm Torque on bottom = 5-14 k ft -lbs Torque off bottom = 6-7 k ft -lbs Flow in = 814 gpm, Strokes = 190 spm SPP = 1310 psi, Flow out = 56% ECD = 10.21 ppg Max gas = 22 units Page 9169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) "= 2M-38 Rig: DOYON 141 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) 1/11/2017 1/11/2017 6.00 INTRMI DRILL DDRL P Directionally drill from 3816' to 4446'. 3,816.0 4,446.0 06:00 12:00 (TVD = 3153') ART = 4.43 hrs ADT = 11.43 hrs AST = 0 hrs Bit hrs = 11.43 hrs Total jar hours = 11.43 hrs P/U = 125k S/O = 81k Rot = 96k WOB = 8-115k Top drive = 110 rpm Torque on bottom = 8-11 k ft -lbs Torque off bottom= 4-11 k ft -lbs Flow in = 809 gpm, Strokes = 189 spm SPP = 1525 psi, Flow out = 55% ECD = 10.17 ppg Max gas = 88 units Slow pump rates taken at 4278' (3106' TVD) Time = 10:20 hrs Mud weight = 9.6 ppg Pump #1 #2 30 spm 100 psi 100 psi 40 spm 120 psi 120 psi 1/11/2017 1/11/2017 6.00 INTRMI DRILL DDRL P Directionally drill from 4446'to 5216'. 4,446.0 5,126.0 12:00 18:00 (TVD = 3346') ART = 4.83 hrs ADT = 16.26 hrs AST =0hrs Bit hrs = 16.26 hrs Total jar hours = 16.26 hrs P/U = 125k S/O = 80k Rot = 95k WOB = 7-12k Top drive = 120 rpm Torque on bottom = 8-12 k ft -lbs Torque off bottom = 5-10 k ft -lbs Flow in = 840 gpm, Strokes = 198 spm SPP = 1900 psi, Flow out = 55% ECD = 10.41 ppg Max gas= 41 units Page 10/69 Report Printed: 2/27/2017 "max- Operations Summary (with Timelog Depths) - >. 4 2M-38 Rig: DOYON 141 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) 1/11/2017 1/12/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 5216' to 5779'. 5,126.0 5,779.0 18:00 00:00 (TVD = 3531') ART = 4.59 hrs ADT = 20.85 hrs AST = 0 hrs Bit hrs = 20.85 hrs Total jar hours = 20.85 hrs P/U = 135k S/O = 83k Rot = 99k WOB = 7-12k Top drive = 120 rpm Torque on bottom = 8-12 k ft -lbs Torque off bottom = 5-10 k ft -lbs Flow in = 850 gpm, Strokes = 199 spm SPP = 2260 psi, Flow out = 57% ECD = 10.65 ppg Max gas = 64 units Slow pump rates taken at 5593' (3478' TVD) Time = 22:00 hrs Mud weight = 9.6 ppg Pump #1 #2 30 spm 220 psi 220 psi 40 spm 280 psi 280 psi 1/12/2017 1/12/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 5779' to 6470'. 5,779.0 6,470.0 00:00 06:00 (TVD = 3731') ART = 5.05 hrs ADT = 25.90 hrs AST = 0 hrs Bit hrs = 25.90 hrs Total jar hours = 25.90 hrs P/U = 152k S/O = 85k Rot = 108k WOB = 7-10k Top drive = 140 rpm Torque on bottom = 10-14 k ft -lbs Torque off bottom = 11-13 k ft -lbs Flow in = 851 gpm, Strokes = 199 spm SPP = 2390 psi, Flow Out = 57% ECD = 10.64 ppg Max gas = 63 units Page 11169 Report Printed: 2/27/2017 ; Y� Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth (ftKB) 1/12/2017 1/12/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 6470' to 7145'. 6,470.0 7,145.0 06:00 12:00 (TVD = 3925') ART= 4.41 hrs ADT = 30.31 hrs AST = 0 hrs Bit hrs = 30.31 hrs Total jar hours = 30.31 hrs P/U = 162k S/O = 85k Rot= 110k WOB = 9-115k Top drive = 140 rpm Torque on bottom = 12-17 k ft -lbs Torque off bottom = 6-17 k ft -lbs Flow in = 852 gpm, Strokes = 199 spm SPP = 2650 psi, Flow out = 57% ECD = 10.71 ppg Max gas= units Slow pump rates taken at 7086'(3907' TVD) Time = 11:12 hrs Mud weight = 9.7 ppg Pump #1 #2 30 spm 220 psi 220 psi 40 spm 260 psi 280 psi 1/12/2017 1/12/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 7145' to 7775'. 7,145.0 7,775.0 12:00 18:00 (TVD = 4107') ART = 4.49 hrs ADT = 34.80 hrs AST = 0 hrs Bit hrs = 34.80 hrs Total jar hours = 34.80 hrs P/U = 165k S/O = 90k Rot = 110k WOB = 11-15k Top drive = 140 rpm Torque on bottom = 14-16 k ft -lbs Torque off bottom = 13-14 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm SPP = 2850 psi, Flow out = 63% ECD = 10.83 ppg Max gas = 100 units Page 12/69 Report Printed: 2/27/2017 - Operations Summary (with Timelog Depths) b> 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth (ftKB) 1/12/2017 1/12/2017 4.50 INTRM1 DRILL DDRL P Directionally drill from 7775' to 8319'. 7,775.0 8,319.0 18:00 22:30 (TVD = 4258') Hole started packing off from 8206' to 8298' ART = 4.39 hrs ADT = 39.19 hrs AST = 0 hrs Bit hrs = 39.19 hrs Total jar hours = 39.19 hrs P/U = 175k S/O = 90k Rot= 113k WOB = 13-20k Top drive = 140 rpm Torque on bottom = 15-16 k ft -lbs Torque off bottom = 11-12 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm Slow pump rates taken at 8115'(4204' TVD) Time = 20:55 hrs Mud weight = 9.8 ppg Pump #1 #2 30 spm 200 psi 200 psi 40 spm 240 psi 240 psi SPP = 3000 psi, Flow out = 57% ECD = 11.33 ppg Max gas = 133 units 1/12/2017 1/12/2017 1.00 INTRM1 DRILL BKRM T Backream from 8298' to 8206' @ 8,319.0 8,298.0 22:30 23:30 1300 fph, 850 gpm, 130 rpm, 55% flow in. Ream down at 250 fph, 600 gpm, 2150 psi. Packed off with 200 psi increase in pump pressure. Pressure fell off and well started taking fluid. 1/12/2017 1/13/2017 0.50 INTRM1 DRILL CIRC T Circulate 30 bbl nut plug sweep at 2 8,298.0 8,298.0 23:30 00:00 bpm, and 300 psi. Build mud volume. Total losses to formation for tour: 260 bbl 1/13/2017 1/13/2017 7.75 INTRMI DRILL BKRM T Back ream out of the hole from 8298 8,298.0 7,276.0 00:00 07:45 to 7276'. Losing 100 bph. Rotating @ 80 rpm, Pumping at 2 bpm. Losses decreased and increased pumping rate to 3.5 bpm. 1/13/2017 1/13/2017 4.25 INTRM1 DRILL CIRC T Circulate and condition mud from 7,276.0 7,183.0 07:45 12:00 7276' to 7183'. Increase pump rate to 5 bpm and stage up to 12 bpm. 1/13/2017 1/13/2017 8.75 INTRM1 DRILL BKRM T Backream out of the hole from 7183' 7,183.0 3,130.0 12:00 20:45 to 3130'@ 20 bpm 2450 psi. Rotate at 130 rpm. 1/13/2017 1/13/2017 1.00 INTRM1 DRILL BKRM T Backream out of the hole from 3130' 3,130.0 2,886.0 20:45 21:45 to 2886' Circulate bottoms up 2 times. 1/13/2017 1/13/2017 0.25 INTRM1 DRILL OWFF T Allow well to breathe back and flow 2,886.0 2,886.0 21:45 22:00 I check -static Page 13/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) u 2M-38 Rig: DOYON 141 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) 1/13/2017 1/13/2017 0.75 INTRM1 DRILL MPDA T Pull trip nipple and install RCD 2,886.0 2,886.0 22:00 22:45 bearing. 1/13/2017 1/14/2017 1.25 INTRM1 DRILL FIT T Perform FIT. Pressure = 210 psi, Mud 2,886.0 2,886.0 22:45 00:00 weight = 9.65 ppg. Point of interest is 7985' MD / 4177' TVD. FIT = 10.61 ppg EMW. Rig down test equipment 1/14/2017 1/14/2017 1.50 INTRMI DRILL SVRG P Service rig and top drive 2,886.0 2,886.0 00:00 01:30 1/14/2017 1/14/2017 1.50 INTRM1 DRILL TRIP T RIH from 2886 to 4846' 2,886.0 4,846.0 01:30 03:00 1/14/2017 1/14/2017 1.50 INTRM1 DRILL CIRC T Circulate bottoms up. Stage pumping 4,846.0 4,846.0 03:00 04:30 rate up to 847 gpm and 2080 psi. Rotate at 140 rpm, P/U = 120k, S/O = 80 k, Rot = 80k, 1/14/2017 1/14/2017 1.50 INTRM1 DRILL TRIP T RIH from 4846' to 6715' 4,846.0 6,715.0 04:30 06:00 1/14/2017 1/14/2017 1.50 INTRM1 DRILL CIRC T Circulate bottoms up. Stage pumping 6,715.0 6,715.0 06:00 07:30 rate up to 853 gpm and 2540 psi. Rotate at 140 rpm, P/U = 125k, S/O = 80 k, Rot = 80k, 1/14/2017 1/14/2017 1.00 INTRM1 DRILL SFTY T Safety stand down to discuss recents 6,715.0 6,715.0 07:30 08:30 events and refocus 1/14/2017 1/14/2017 1.25 INTRM1 DRILL MPDA T Blow down top drive and replace RCD 6,715.0 6,715.0 08:30 09:45 bearing on MPD system 1/14/2017 1/14/2017 0.25 INTRM1 DRILL TRIP T RIH from 6715'to7089' 6,715.0 7,089.0 09:45 10:00 1/14/2017 1/14/2017 3.00 INTRM1 DRILL REAM T Wash and ream from 7089' to 8021'. 7,089.0 8,021.0 10:00 13:00 Rotate at 130 rpm, Pump at 850 gpm. 1/14/2017 1/14/2017 1.00 INTRM1 DRILL CIRC T CBU at 850 gpm 2800 psi. Rotate at 8,021.0 8,021.0 13:00 14:00 130 rpm, 1/14/2017 1/14/2017 0.50 INTRM1 DRILL SFTY T Continue circulating while holding 8,021.0 8,021.0 14:00 14:30 safety stand down with crew to discuss recent events and refocus 1/14/2017 1/14/2017 1.00 INTRM1 DRILL CIRC T Spot 25 bbl LCM pill at 8021' at 5 bpm 8,021.0 8,021.0 14:30 15:30 1/14/2017 1/14/2017 0.50 INTRM1 DRILL SMPD T Strip out of the hole utilizing MPD 8,021.0 7,881.0 15:30 16:00 system holding 120 psi back pressure from 8021' to7881'. Pipe started pulling 25-30k over normal up weight. 1/14/2017 1/14/2017 1.00 INTRM1 DRILL BKRM T Work pipe free with 40k overpulle. 7,881.0 7,648.0 16:00 17:00 Backream out of the hole from 7881' to7648' while circulating 850 gpm at 2800 psi. Rotate at 110 rpm 1/14/2017 1/14/2017 1.00 INTRM1 DRILL CIRC T CBU at 850 gpm 2700 psi. No losses- 7,648.0 7,648.0 17:00 18:00 static or dynamic 1/14/2017 1/14/2017 3.00 INTRM1 DRILL REAM T Ream from 7648' to 8319' at 850 gpm, 7,648.0 8,319.0 18:00 21:00 j I j 2800 psi, 110 rpm, Page 14/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/14/2017 1/15/2017 3.00 INTRMI DRILL DDRL P Directionally drill from 8319' to 8504'. 8,319.0 8,504.0 21:00 00:00 (TVD = 4313) Hole started packing off from 8206' to 8298' ART = 2.08 hrs ADT = 41.27 hrs AST = 0 hrs Bit hrs = 41.27 hrs Total jar hours = 41.27 hrs P/U = 162k S/O = 97k Rot = 120k WOB = 7-10k Top drive = 130 rpm Torque on bottom = 13-14 k ft -lbs Torque off bottom = 10-12 k ft -lbs Flow in = 800 gpm, Strokes = 190 spm Standpipe pressure= 2700 psi Max gas = 34 units Flow out = 87% ECD = 10.49 ppg Slow pump rates taken at 8296' (4254' TVD) Time = 21:00 hrs Mud weight = 9.6 ppg Pump #1 #2 30 spm 170 psi 170 psi 40 spm 240 psi 230 psi Page 15169 Report Printed: 2/2712017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/15/2017 1/15/2017 5.50 INTRM1 DRILL DDRL P Directionally drill from 8504' to 9045'. 8,504.0 9,045.0 00:00 05:30 (TVD = 4464') ART = 5.03 hrs ADT = 46.30 hrs AST = 0 hrs Bit hrs = 46.30 hrs Total jar hours = 46.30 hrs P/U = 161 k S/O = 101 k Rot = 122k WOB = 10-13k Top drive = 140 rpm Torque on bottom = 13-16 k ft -lbs Torque off bottom = 11 k ft -lbs Flow in = 823 gpm, Strokes = 192 spm Standpipe pressure= 2875 psi Max gas= 116 units Flow out = 88% ECD = 10.5 ppg Slow pump rates taken at 9045' (4464' TVD) Time = 05:30 hrs Mud weight = 9.7 ppg Pump #1 #2 30 spm 290 psi 280 psi 40 spm 350 psi 350 psi 1/15/2017 1/15/2017 5.50 INTRM1 DRILL DDRL P Directionally drill from 9045' to 9420'. 9,045.0 9,420.0 05:30 11:00 (TVD = 4572') ART = 4.32 hrs ADT = 50.62 hrs AST = 0 hrs Bit hrs = 50.62 hrs Total jar hours = 50.62 hrs P/U = 160k S/O = 105k Rot = 120k WOB = 10-14k Top drive = 160 rpm Torque on bottom = 14-17 k ft -lbs Torque off bottom = 13-15 k ft -lbs Flow in = 850 gpm, Strokes = 199 spm Standpipe pressure= 3190 psi Max gas = 150 units Flow out = 88% ECD = 11.01 ppg Page 16/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth (ftKB) 1/15/2017 1/15/2017 1.00 INTRMI DRILL DDRL P Directionally drill from 9420' to 9480'. 9,420.0 9,480.0 11:00 12:00 (TVD = 4589') Pumping through MPD choke ART = 0.4 hrs ADT = 51.02 hrs AST = 0 hrs Bit hrs = 51.02 hrs Total jar hours = 51.02 hrs P/U = 160k S/O = 105k Rot = 120k WOB = 10-14k Top drive = 160 rpm Torque on bottom = 14-17 k ft -lbs Torque off bottom = 13-15 k ft -lbs Flow in = 850 gpm, Strokes = 199 spm Standpipe pressure= 3190 psi Max gas = 150 units Flow out = 88% ECD = 11.01 ppg 1/15/2017 1/15/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 9480'to 9795'. 9,480.0 9,795.0 12:00 18:00 (TVD = 4678') ART= 3.11 hrs ADT = 54.13 hrs AST = 0 hrs Bit hrs = 54.13 hrs Total jar hours = 54.13 hrs P/U = 160k S/O = 98k Rot = 120k WOB = 2-20k Top drive = 160 rpm Torque on bottom = 14-16 k ft -lbs Torque off bottom = 14-15 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm Standpipe pressure= 3250 psi Max gas = 205 units Flow out = 75% ECD = 11.05 ppg Page 17169 Report Printed: 2/27/2017 fl'L operations Summary (with Timelog Uepths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/15/2017 1/16/2017 6.00 INTRM1 DRILL DDRL P Directionally drill from 9795' to 10380 9,795.0 10,380.0 18:00 00:00 '. (TVD = 4846') ART = 5.62 hrs ADT = 59.75 hrs AST = 0 hrs Bit hrs = 59.75 hrs Total jar hours = 59.75 hrs P/U = 170k S/O = 97k Rot= 115k WOB = 5-1 Ok Top drive = 160 rpm Torque on bottom = 14-18 k ft -lbs Torque off bottom = 12 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm Standpipe pressure= 3200 psi Max gas = 113 units Flow out = 89% ECD = 11.05 ppg Slow pump rates taken at 10168' (4784' TVD) Time =20:45 hrs Mud weight = 9.8 ppg Pump #1 #2 30 spm 265 psi 2860 psi 40 spm 310 psi 355 psi Page 18/69 Report Printed: 2/2712017 t Operations Summary (with Timelog Depths) :. 2M-38 Rig: DOYON 141 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) 1/16/2017 1/16/2017 2.00 INTRM1 DRILL DDRL P Directionally drill from 10380' to 10,380.0 10,545.0 00:00 02:00 10545'. (TVD = 4894') ART = 1.73 hrs ADT = 61.48 hrs AST = 0 hrs Bit hrs = 61.48 hrs Total jar hours = 61.48 hrs P/U = 165k S/O = 100k Rot = 120k WOB = 5-11k Top drive = 160 rpm Torque on bottom = 15-18 k ft -lbs Torque off bottom = 13 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm Standpipe pressure= 3320 psi Max gas = 120 units Flow out = 89% ECD = 10.97 ppg Slow pump rates taken at 10545' (4894' TVD) Time =02:00 hrs Mud weight = 9.8 ppg Pump #1 #2 30 spm 287 psi 283 psi 40 spm 310 psi 350 psi 1/16/2017 1/16/2017 10.00 INTRM1 DRILL BKRM P Back ream out of the hole from 10543' 10,545.0 8,021.0 02:00 12:00 to 8021'. Pump @ 850 gpm Top drive = 160 rpm Flow out = 88% 1/16/2017 1/16/2017 5.00 INTRM1 DRILL BKRM P Back ream out of the hole from 8021' 8,021.0 7,089.0 12:00 17:00 to 7089' Blow down top drive. Pump @ 850 gpm Top drive = 160 rpm Flow out = 88% 1/16/2017 1/16/2017 3.25 INTRM1 DRILL STRP P Strip in the hole with MPD from 7089' 7,089.0 10,545.0 17:00 20:15 to 10545' Stripping speed = 3000 fph Back pressure maintained by MPD = 155 psi. Page 19/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/16/2017 1/17/2017 3.75 INTRM1 DRILL DDRL P Directionally drill from 10545' to 10,545.0 10,825.0 20:15 00:00 10825'. (TVD = 4975') ART = 2.62 hrs ADT = 64.10 hrs AST = 0 hrs Bit hrs = 64.10 hrs Total jar hours = 64.10 hrs P/U = 175k S/O = 100k Rot = 120k WOB = 5-11k Top drive = 150 rpm Torque on bottom = 15-22 k ft -lbs Torque off bottom = 13 k ft -lbs Flow in = 850 gpm, Strokes = 200 spm Standpipe pressure= 3160 psi Max gas = 132 units Flow out = 89% ECD = 10.76 ppg Slow pump rates taken at 10542' (4894' TVD) Time =20:15 hrs Mud weight = 9.8 ppg Pump #1 #2 30 spm 287 psi 283 psi 40 spm 310 psi 350 psi 1/17/2017 1/17/2017 6.00 INTRMI DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 10,825.0 11,360.0 00:00 06:00 section f/ 10826- 11360' MD, 5125' TVD, ADT 5.10 hrs, Bit hrs 69.20, Jar hrs 69.20, PUW 171 k, SOW 99k, ROT 126k, Tq on 16-18k, Tq off 12-14k, ECD 10.86ppg, 90% F/0, WOB 10- 13k, 150 rpm, 850 gpm, 3270 psi, Max Gas 130 units, MW 9.8+ ppg. Hold 160 psi (10.4ppg EMW @ C-37) backpressure dynamically on connections with MPD. SPRs @ 11 107'MD, 5054' TVD, MW=9.8+ ppg, 03:00 hours MP#1: 30 spm=272 psi, 40 spm=315 psi. MP #2: 30 spm= 261 psi, 40 spm=319 psi. Page 20169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/17/2017 1/17/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 11,360.0 11,780.0 06:00 12:00 section f/ 11360' - 11780' MD, 5244' TVD, ADT 4.08 hrs, Bit hrs 73.28, Jar hrs 73.28, PUW 176k, SOW 100k, ROT 131 k, Tq on 18-21 k, Tq off 13- 16k, ECD 11.00ppg, 89% F/O, WOB 8 -13k, 150 rpm, 850 gpm, 3450 psi, Max Gas 165 units, MW 9.8+ ppg. Hold 160 psi (10.4ppg EMW @ C-37) backpressure dynamically on connections with MPD. SPRs @ 11735' MD, 5239' TVD, MW=9.9 ppg, 11:00 hours MP#1: 30 spm=330 psi, 40 spm=397 psi. MP #2: 30 spm= 309 psi, 40 spm=405 psi. Downhole losses from midnight to noon = 114 bbls 1/17/2017 1/17/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 11,780.0 12,200.0 12:00 18:00 section f/ 11780' - 12200' MD, 5380' TVD, ADT 4.72 hrs, Bit hrs 78.00, Jar hrs 78.00, PUW 185k, SOW 102k, ROT 135k, Tq on 18-21 k, Tq off 12- 16k, ECD 10.91 ppg, 85% F/O, WOB 8 -15k, 150 rpm, 850 gpm, 3500 psi, Max Gas 356 units, MW 9.9 ppg. Hold 160 psi (10.4ppg EMW @ C-37) backpressure dynamically on connections with MPD. 1/17/2017 1/18/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 12,200.0 12,646.0 18:00 00:00 section f/ 12200'- 12646' MD, 5562' TVD, ADT 4.52 hrs, Bit hrs 82.52, Jar hrs 82.52, PUW 191 k, SOW 106k, ROT 133k, Tq on 19-23k, Tq off 16- 17k, ECD 10.89ppg, 87% F/O, WOB 5 -13k, 150 rpm, 850 gpm, 3500 psi, Max Gas 411 units, MW 9.8+ ppg. Hold 160 psi (10.4ppg EMW @ C-37) backpressure dynamically on connections with MPD. SPRs @ 12405' MD, 5466' TVD, MW=9.9 ppg, 20:40 hours MP#1: 30 spm=305 psi, 40 spm=470 psi. MP #2: 30 spm= 340 psi, 40 spm=395 psi. Downhole losses from noon to midnight = 112 bbls Total losses for 24 hours = 226 bbls. Page 21/69 Report Printed: 2/27/2017 4 . Uperations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/18/2017 1/18/2017 6.00 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 12,646.0 12,968.0 00:00 06:00 section f/ 12646'- 12968' MD, 5687' TVD, ADT 4.59 hrs, Bit hrs 87.11, Jar hrs 87.11, PUW 190k, SOW 106k, ROT 145k, Tq on 20-25k, Tq off 22k, ECD 11.14ppg, 89% F/O, WOB 5-9k, 150 rpm, 850 gpm, 3590 psi, Max Gas 258 units, MW 10.1+ ppg. Hold 160 psi to 130 psi backpressure dynamically on connections with MPD as mud weight increased to maintain 10.4ppg EMW on C37. Observe increasing erratic torque from 12950' - 12968'. Geology seeing increasing shale concentration in formation. Note: Started adding in 14ppg LSND spike fluid into system to weight up system from 12910' MD onwards using 100 bbl increments on closed system, monitoring for any increase in losses as ECDs increased. No change in losses observed. Decreased target ROP to 50 ft/hr. 1/18/2017 1/18/2017 3.50 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 12,968.0 13,024.0 06:00 09:30 section f/ 12968'- 13024' MD, 5638' TVD, ADT 1.39 hrs, Bit hrs 88.50, Jar hrs 88.50, PUW 191k, SOW 108k, ROT 145k, Tq on 20-25k, Tq off 22k, ECD 11.21ppg, 88% F/O, WOB 5-9k, 150 rpm, 850 gpm, 3610 psi, Max Gas 286 units, MW 10.1 ppg. Hold 130 psi backpressure dynamically on connections with MPD as mud weight increased to maintain 10.4ppg EMW on C37. Continue to see erratic torque on bottom. Geology continues to see shale concentration increasing in formation. 1/18/2017 1/18/2017 1.75 INTRM1 DRILL BKRM T Backream OOH at drilling rate to 13,024.0 12,830.0 09:30 11:15 12830' MD w/ 850 gpm, 3620 psi, 150 rpm, 20-25k Tq, 87% F/O, 11.15ppg ECD, increasing lubes from 1.5% Lo- Torq to 2.0% Lo-Torq. 1/18/2017 1/18/2017 0.75 INTRM1 DRILL REAM T Wash / Ream back to bottom f/ 12830' 12,830.0 13,024.0 11:15 12:00 - 13024'w/ 835 gpm, 3550 psi, 11.14 ppg ECD, 80% F/O, 154 rpm, 16k Tq. SPRs @ 12869' MD, 5650' TVD, MW=10.1 ppg, 11:30 hours MP#1: 30 spm=295 psi, 40 spm=365 psi. MP #2: 30 spm= 315 psi, 40 spm=375 psi. Observe 49 bbl loss downhole from midnight to noon. Page 22169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/18/2017 1/18/2017 5.75 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate l 13,024.0 13,234.0 12:00 17:45 section f/ 13024'- 13234' MD, 5795' TVD, ADT 5.38 hrs, Bit hrs 93.88, Jar hrs 93.88, PUW 195k, SOW 115k, ROT 140k, Tq on 17-18k, Tq off 17k, ECD 11.40ppg, 89% F/O, WOB 6-10k, 150 rpm, 850 gpm, 3710 psi, Max Gas 246 units, MW 10.4 ppg. Increase lubes from 2.0% (Lo-Torq) to 2.5% with 776 lube. Note: Continue adding in 14ppg LSND spike fluid to weight up to KWM. Decrease MPD backpressure as mud weight increased to maintain 10.4ppg EMW on C37. Once at 10.4ppg MW, close chokes on connections and monitor for any pressure buildup. 1/18/2017 1/18/2017 0.25 INTRM1 DRILL CIRC T On stand # 137 at 13234' MD, observe 13,234.0 13,234.0 17:45 18:00 pump pressure decrease from 3710 psi to 2950 psi at 850 gpm over 12 minutes, with corresponding drop in MWD turbine rpm of 2812 to 2421 at same flow rate. Flow out percent did not change. Killed pump, closed MPD chokes, pressured up to 60 psi and observed pressure stabilize. Opened standpipe bleeder and observed backside pressure bleeding off. Inspect surface lines and equipment and confirm no issues at surface. Suspected washout downhole. Decision made to pump OOH to locate washout. Note: As pump pressure decreased, stroke rate increased on Totco but pump setpoint was not changed. 1/18/2017 1/18/2017 1.25 INTRM1 DRILL PMPO T Pump OOH f/ 13234'- 12775'w/ 2 13,234.0 12,775.0 18:00 19:15 bpm, 190 psi, 12% F/O, 600 ft/hr pulling speed. 1/18/2017 1/18/2017 1.00 INTRM1 DRILL PMPO T Continue pumping/backreaming OOH 12,775.0 12,587.0 19:15 20:15 f/ 12775'- 12587'w/ 2 bpm, 280 psi, working up rotary to 20-40 rpm after seeing 40k overpull with no breakover, PUW 185k, SOW 100k, ROT 136k. 1/18/2017 1/18/2017 3.25 INTRM1 DRILL PMPO T Continue pumping OOH f/ 12587'- 12,587.0 11,606.0 20:15 23:30 11606'w/ 4 bpm, 420 psi, 28% F/O. Observe dime -sized washout in pipe body of middle joint of stand #120, 1.75' down from box end. 1/18/2017 1/19/2017 0.50 INTRM1 DRILL PULD T Kill pump, Pull OOH slowly and layout 11,606.0 11,606.0 23:30 00:00 washout joint, 31.66'. Note: Observed 40k overpull with pumps off, PUW 175k. Engaged rotary to 25-30 rpm, 17-18k Tq and worked up high enough to lay out washout joint. Page 23/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/19/2017 1/19/2017 0.25 INTRM1 DRILL CIRC T Circulate / condition hole w/ 815 gpm, 11,606.0 11,606.0 00:00 00:15 3360 psi, 90% F/O, 135 rpm, 15-16k Tq. Observe large amount of cuttings coming out over shakers and mud weight at 10.5ppg in/out, started adding water to dilute back. Initial ECD of 11.73ppg fall to 11.66ppg. 1/19/2017 1/19/2017 0.50 INTRM1 DRILL CIRC T While circulating / conditioning hole 11,606.0 11,606.0 00:15 00:45 between 11521'- 11610', ECD suddenly climbed and well started losing at 11.82 ppg. Suspected loss zone at C50 formation at 7985' MD. Initial loss rate at 815 gpm, 3400 psi of 300 bbl/hr. Decreased pump rate down to 515 gpm, 1543 psi, 75% F/O, 11.50ppg ECD, 135 rpm, 15-16k Tq, and observed loss rate decrease to 100 bbl/hr. Continue decreasing pump rate to 100 gpm, 430 psi, 3% F/O, 75 rpm, 16k Tq and observed loss rate decrease to 15 bbl/hr. SIMOPS: Start adding LCM (Nut Plug Medium) to active at 1 sack / 2 minutes and start builiding 30 bbl LCM pill. 1/19/2017 1/19/2017 1.50 INTRM1 DRILL CIRC T Circulate well between 11521'- 11610' 11,606.0 11,606.0 00:45 02:15 w/ 100 gpm, ICP 430 psi, FCP 320 psi, 11 % F/O, 75 rpm, 16k Tq while building LCM pill and adding LCM to active. Observe loss rate decrease to zero. 1/19/2017 1/19/2017 2.75 INTRM1 DRILL CIRC T Pump 30 bbl LCM pill w/ 25ppb Nut 11,606.0 11,606.0 02:15 05:00 Plug Medium and circulate around to loss zone, working pump rate up slowly from 100 gpm, 320 psi, to 195 gpm, 574 psi. From 500 psi onward, observe loss rate start to increase significantly. Dropped flow rate to 158 gpm, 460 psi to maintain pump pressure under 500 psi and observe losses stop. Continue circulating and stage up to 243 gpm, 536psi once initial additions of LCM reached the C- 50 and observe loss rate remain at zero. MW in/out 10.4+/10.5-10.7 ppg. 1/19/2017 1/19/2017 1.00 INTRM1 DRILL CIRC T Stage up pumps in increments to 470 11,606.0 11,606.0 05:00 06:00 gpm as LCM pill crossed the C-50 loss zone to increase pump pressure and squeeze pill at 20 bbl/hr loss rate. Circulate at 470 gpm, ICP 1340 psi, FCP 1290 psi, 70% F/O, ECD decrease from 11.40ppg to 11.31 ppg, 75 rpm, 16k Tq with large amount of cuttings coming over shakers, loss rate of 20 bbl/hr decreasing to 2 bbl/hr. MW in/out 10.5/10.6. Page 24169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) ,r Y 2M-38 LLiL°b': Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 1/19/2017 1/19/2017 1.75 INTRM1 DRILL CIRC T Work up pump rate and rotary to 628 11,606.0 11,606.0 06:00 07:45 gpm, 2130 psi, 85% F/O, ECD 11.33ppg, 100 rpm, 16-17k Tq, loss rate of 20 bbl/hr decreasing to 10 bbl/hr. Observe large amount of cuttings and LCM coming over shakers. Continue adding LCM Nut Plug Medium to active at 6 sacks / hr. MW in/out 10.4+ Note: 192 bbls lost downhole from initial sign of losses to 7:45 am 1/19/2017 1/19/2017 1.50 INTRM1 DRILL CIRC T Add single to string (30.95') to replace 11,606.0 11,617.0 07:45 09:15 washout joint and continue circulating / conditioning well to 11617' w/ 621 gpm, 2080 psi, ECD 11.28 ppg, 80% F/O, 100 rpm, 16k Tq. MW in/out 10.5. Loss zone appears to be healed. 1/19/2017 1/19/2017 0.50 INTRM1 DRILL OWFF T Maintain rotation @ 15 rpm, 16k Tq, 11,617.0 11,617.0 09:15 09:45 close MPD chokes and observe slight wellbore breathing with initial pressure buildup of 54 psi decreasing to 39 psi. Line up to cellar and monitor well for flow - well static. 1/19/2017 1/19/2017 2.00 INTRMI DRILL MPDA T Blow down top drive, pull MPD 11,617.0 11,617.0 09:45 11:45 bearing, realign stack, and install trip nipple. 1/19/2017 1/19/2017 1.00 INTRMI DRILL TRIP T Trip in hole on elevators f/ 11617'- 11,617.0 12,549.0 11:45 12:45 12549' MD, SOW 100k, monitoring displacement on active system. Observe string start taking 15-25k weight at 12549' MD. Total downhole losses from midnight - noon = 222 bbls 1/19/2017 1/19/2017 0.50 INTRM1 DRILL OTHR T Make up to string to fill pipe and 12,549.0 12,549.0 12:45 13:15 observe lines pressure up quickly. Troubleshoot and observe IBOP frozen in place. Thaw out IBOP and confirm line clear. 1/19/2017 1/19/2017 0.25 INTRM1 DRILL WASH T Fill pipe and wash down f/ 12549'- 12,549.0 12,582.0 13:15 13:30 12582' MD w/ 186 gpm, 450 psi, 29% F/O, MW in/out 10.4" / 10.5. 1/19/2017 1/19/2017 0.25 INTRM1 DRILL TRIP T Trip in hole on elevators f/ 12582' - 12,582.0 12,675.0 13:30 13:45 12675' MD, SOW 110k. Observe string start taking —15k drag at bottom of stand. 1/19/2017 1/19/2017 0.50 INTRM1 DRILL WASH T Wash/trip in f/ 12675'- 12956' MD 12,675.0 12,956.0 13:45 14:15 staging up to 342 gpm, 820 psi, 41% F/O. 1/19/2017 1/19/2017 4.75 INTRMI DRILL REAM T Ream to bottom f/ 12768'- 13234' 12,768.0 13,234.0 14:15 19:00 MD, staging up to full drilling rate of 850 gpm, 3710 psi, 56% F/O, ECD 11.07ppg, 150 rpm, 16k Tq, circulating total of 3 bottoms up, conditioning mud until in/out 10.3+/10.4+ observed. Page 25/69 Report Printed: 212712017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/19/2017 1/19/2017 1.25 INTRM1 DRILL DDRL P Directionally drill 12-1/4" Intermediate 1 13,234.0 13,307.0 19:00 20:15 section f/ 13234' to TD of 13307' MD, 5821' TVD, ADT 0.99 hrs, Bit hrs 94.87, Jar hrs 94.87, PUW 198k, SOW 115k, ROT 145k, Tq on 20k, Tq off 15k, ECD 11.02ppg, 55% F/O, WOB 12-15k, 150 rpm, 850 gpm, 3700 psi, Max Gas 234 units, MW 10.4 ppg. Lubes at 2.5% Lo-Torq / 776 at TD. 1/19/2017 1/19/2017 0.25 INTRM1 CASING CIRC P Obtain final survey, parameters, and 13,307.0 13,299.0 20:15 20:30 SPR's. SPRs @ 13299' MD, 5818' TVD, MW=10.4 ppg, 20:28 hours MP#1: 30 spm=380 psi, 40 spm=440 psi. MP #2: 30 spm= 380 psi, 40 spm=440 psi. 1/19/2017 1/19/2017 2.50 INTRM1 CASING BKRM P Backream OOH f/ 13299'- 13054', 13,299.0 13,054.0 20:30 23:00 circulating 2 x bottoms up while racking back 3 x stands w/ 850 gpm, 3660 psi, 54% F/O, ECD 11.01 ppg, 150 rpm, 18-19k Tq. 1/19/2017 1/19/2017 0.75 INTRM1 CASING OWFF P Blow down top drive and monitor well 13,054.0 13,054.0 23:00 23:45 for flow - well breathing back initially but tapered off to static. 1/19/2017 1/20/2017 0.25 INTRM1 CASING BKRM P Backream OOH f/ 13054' - 12974'w/ 13,054.0 12,974.0 23:45 00:00 850 gpm, 3650 psi, 55% F/O, 150 rpm, 16-17k Tq, ECD 11.08ppg. 1/20/2017 1/20/2017 6.00 INTRM1 CASING BKRM P Backream OOH f/ 12974'- 11014'w/ 12,974.0 11,014.0 00:00 06:00 850 gpm, ICP 3650 psi, FCP 3350 psi, Initial ECD 11.07ppg, Final ECD 11.27ppg, 54% F/O, 140 rpm, 16k Tq. 1/20/2017 1/20/2017 6.00 INTRM1 CASING BKRM P Backream OOH f/ 11014'- 9237'w/ 11,014.0 9,237.0 06:00 12:00 850 gpm, ICP 3350 psi, FCP 3200 psi, Initial ECD 11.27ppg, Final ECD 11.18ppg, 53% F/O, 140 rpm, 16k Tq. Note: Observe hole unload @ 10000' MD. Total losses midnight - noon = 122 bbls 1/20/2017 1/20/2017 6.00 INTRM1 CASING BKRM P Backream OOH f/ 9237'- 7834'w/ 850 9,237.0 7,834.0 12:00 18:00 gpm, ICP 3200 psi, FCP 2777 psi, Initial ECD 11.18ppg, Final ECD 11.01 ppg, 53% F/O, 140 rpm, 12-14k Tq. Note: Hold safety stand down with incoming crew from 14:00 - 14:30 hrs. 1/20/2017 1/20/2017 0.25 INTRM1 CASING TRIP P Perform wiper trip f/ 7834' - 8115', 7,834.0 8,115.0 18:00 18:15 PUW 140k, SOW 90k - no issues observed. Page 26169 Report Printed: 2/27/2017 ' Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/20/2017 1/20/2017 4.00 INTRM1 CASING BKRM P Backream OOH f/ 811 5' - 7051 w/ 850 8,115.0 7,051.0 18:15 22:15 gpm, ICP 2850 psi, FCP 2470 psi, Initial ECD 11.00ppg, Final ECD 10.93ppg, 55% F/0, 140 rpm, 10-12k Tq. Note: Packoff tendencies observed at 7515', 7400', 7285'. Continue to decrease pulling speed —300 ft/hr 1/20/2017 1/21/2017 1.75 INTRM1 CASING BKRM P At 7051', observe hole try to packoff 7,051.0 7,045.0 22:15 00:00 and start taking losses. Work through section and continue slowly backream OOH f/ 7074'- 7045'w/ 850 gpm, 2500-2750 psi, 55% F/0, ECD 10.90 - 11.00 ppg, 140 rpm, 10-12k Tq, 1/21/2017 1/21/2017 4.50 INTRM1 CASING BKRM P Backream OOH f/ 7045'- 6992' MD, 7,045.0 6,992.0 00:00 04:30 working through section slowly as hole continued trying to packoff. 800-850 gpm, 2550 psi, 55% F/0, 10.95ppg ECD, varying rotary 120-140 rpm, 10- 12k Tq. Wipe section multiple times and observe no issues going down. 1/21/2017 1/21/2017 7.25 INTRMI CASING BKRM P Backream OOH f/ 6992'- 4940' MD w/ 6,992.0 4,940.0 04:30 11:45 850 gpm, ICP 2600 psi, FCP 2280 psi, ECD 11.15 ppg, 52% F/0, 140 rpm, 8- 11 k Tq 1/21/2017 1/21/2017 1.50 INTRMI CASING OWFF P Observe gain in active. Stop and 4,940.0 4,940.0 11:45 13:15 monitor well for flow - observe initial wellbore breathing taper off to static. Note: Discovered water line to centrifuge was dumping into active pit. Dump mud and roll new mud into active, MW in/out 10.4+ ppg 1/21/2017 1/21/2017 5.50 INTRMI CASING BKRM P Backream OOH f/ 4940' - 3387' MD w/ 4,940.0 3,387.0 13:15 18:45 850 gpm, 7700 psi, ECD 11.02ppg, 55% F/0, 140 rpm, 7-9k Tq. 1/21/2017 1/21/2017 0.50 INTRM1 CASING SVRG T Service rig. Repair failed coupling on 3,387.0 3,387.0 18:45 19:15 rod wash pump for mud pump #1 while circulating at 440 gpm, 530 psi 40% F/0, 100 rpm, 7.5k Tq with mud pump #2. 1/21/2017 1/21/2017 1.75 INTRM1 CASING BKRM P Backream OOH f/ 3387'- 2974'w/ 850 3,387.0 2,974.0 19:15 21:00 gpm, 1750 psi, 54% F/0, ECD 10.95 ppg, 140rpm, 7-8k Tq decreasing to 80 rpm, 7-8k Tq while pulling BHA up inside casing. 1/21/2017 1/21/2017 1.00 INTRMI CASING CIRC P Pump sweep and circulate 2 x 2,974.0 2,880.0 21:00 22:00 bottoms up until shakers cleaned up f/ 2974'- 2880'w/ 850 gpm, 1750 psi, 54% F/0, ECD 10.92ppg, 80 rpm, 6.5k Tq, MW in/out 10.4ppg. Blow down top drive. 1/21/2017 1/21/2017 0.50 INTRM1 CASING OWFF P Monitor well for flow - initial breathing 2,880.0 2,880.0 22:00 22:30 back tapered to static. 1/21/2017 1/22/2017 1.50 INTRMI CASING BKRM P Backream OOH f/ 2880'- 2233' MD w/ 2,880.0 2,233.0 22:30 00:00 850 gpm, 1850 psi, 54% F/0, ECD 10.97ppg, 80 rpm, 3-5k Tq. Page 27/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) „ X58 2M-38 , Rig: DOYON 141 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) 1/22/2017 1/22/2017 0.75 INTRM1 CASING BKRM P Backream OOH f/ 2233'- 2045' MD w/ 2,233.0 2,045.0 00:00 00:45 850 gpm, 1610 psi, 54% F/O, ECD 10.94 ppg, 80 rpm, 2-3k Tq, 1/22/2017 1/22/2017 0.25 INTRM1 CASING OWFF P Blow down top drive and monitor well 2,045.0 2,045.0 00:45 01:00 for flow - well static. 1/22/2017 1/22/2017 4.25 INTRM1 CASING PMPO P Drop 2.5" hollow rabbit and attempt to 2,045.0 462.0 01:00 05:15 pull OOH on elevators - observe well swabbing. Pump OOH f/ 2045'- 1115' MD w/ 4 bpm, 120 psi to offset swab, pulling 2000-3000 ft/hr. At 1115', bring on pumps after connection and observe pump pressure build to 320 psi and start taking losses. Backream stand f/ 1115'- 1020'w/ 520 gpm, 570 psi, 44% F/O, ECD 11.35ppg, 80 rpm, 3k Tq. Observe initial unloading at shakers and then hole cleaned up. Continue pumping/reaming OOH f/ 1115'- 462'w/ 4bpm, 140 psi, 30 rpm, 3k Tq. 1/22/2017 1/22/2017 0.75 INTRM1 CASING OWFF P Blow down top drive and monitor well 462.0 462.0 05:15 06:00 for flow at top of HWDP - well static. Note: Rabbit landed out on jars 1/22/2017 1/22/2017 1.00 INTRM1 CASING BHAH P Attempt to pull OOH on elevators w/ 5" 462.0 154.0 06:00 07:00 HWDP - observe well swabbing. Pump OOH f/ 462' - 154', racking back 3 x stands HWDP and laying out jars. Blow down top drive. Note: Dropped 2.5" rabbit through last two stands of HWDP prior to racking back. 1/22/2017 1/22/2017 3.00 INTRM1 CASING BHAH P Pull OOH f/ 154'- surface laying down 154.0 0.0 07:00 10:00 BHA. Observe large amount of clay packed around the bit. Bit graded 1 -1 - WT -A -X -0 -NO -TD. 1/22/2017 1/22/2017 0.75 INTRM1 CASING BHAH P Clear floor of BHA tools. 0.0 0.0 10:00 10:45 1/22/2017 1/22/2017 0.75 INTRM1 CASING RURD P Clean / clear rig floor 0.0 0.0 10:45 11:30 1/22/2017 1/22/2017 0.75 INTRMI WHDBOP WWWH P Make up stack washer and jet stack w/ 0.0 0.0 11:30 12:15 870 gpm, 35 psi, 57% F/O, 25 rpm, 3k Tq. 1/22/2017 1/22/2017 1.00 INTRM1 WHDBOP RURD P Blow down top drive and pull 0.0 0.0 12:15 13:15 wearbushing. 1/22/2017 1/22/2017 1.50 INTRM1 WHDBOP RURD P Change out upper 3-1/2" x 6" VBR's 0.0 0.0 13:15 14:45 for 9-5/8" solid body casing rams. SIMOPS Rig up BOPE test equipment. 1/22/2017 1/22/2017 1.25 INTRM1 WHDBOP BOPE P Rig up 9-5/8" handing equipment, 0.0 0.0 14:45 16:00 install test plug and 9-5/8" test joint. Flood stack, purge air out of lines, and perform shell test. Page 28169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/22/2017 1/22/2017 6.75 INTRM1 WHDBOP BOPE P Tested BOPE with 9-5/8" and 5" test 0.0 0.0 16:00 22:45 joint. 250/3500 psi and 250/2500 psi for annular, charted for 5 minutes each. Witnessed by AOGCC Rep. Jeff Jones. Install 9-5/8" Test Joint and test: Test #1 - Upper 9-5/8" Casing rams, CV#1, #12, #13, #14, and manual kill. Test #2 - HCR Kill, CV #9 and #11. Test #3 - Dart Valve, CV #5, #8, and #10. Test #4 - Floor Valve, CV #4, #6, and #7. Test #5 - CV #2. Test #6 - HCR choke, 4" Demco kill line valve. Test #7 - Manual choke valve and HCR kill. Test #8 - Blind rams and CV #3 Install 5" Test joint and test: Test #9 - Lower 3-1/2" x 6" VBR's Test #10 - Annular to 2500 psi Test #11 - Manual super choke and Hydraulic super choke to 1500 psi Perform Koomey draw down test. Observed initial system pressure at ACC - 2950 PSI. After Closure observed ACC - 1850 PSI, 200 PSI increase in 48 seconds w/ 1 x electric pump, full pressure at 174 seconds w/ 1 x electric pump and 2 x air pumps. Observed 5 nitrogen bottles with an average PSI of 1925 PSI. Tested all gas and PVT alarms, both audio and visual - good tests. Note: Unable to obtain test on upper IBOP. Although obtained initial passing test on CV#1, visible leak was observed downstream of CV#1 while testing CV#2. After completion of other tests, change out lower and upper IBOP as well as replace CV#1 with new valve and re -test. 1/22/2017 1/22/2017 0.50 INTRM1 WHDBOP RURD P Rig down test equipment and blow 0.0 0.0 22:45 23:15 down choke manifold. Pull test plug. 1/22/2017 1/23/2017 0.75 INTRM1 WHDBOP BOPE T Change out upper / lower IBOP. 0.0 0.0 23:15 00:00 SIMOPS Change out choke valve #1 on choke manifold. Note: Monitor well while performing repairs - fluid level constant. Page 29169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) r. 2M-38 r Rig: DOYON 141 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) 1/23/2017 1/23/2017 4.75 INTRM1 WHDBOP BOPE T PJSM. Change out upper/lower IBOP 0.0 0.0 00:00 04:45 and saver sub. Re -install test plug. SIMOPS: Change out choke valve #1 Note: Monitor well while performing repairs - fluid level constant. 1/23/2017 1/23/2017 1.25 INTRM1 WHDBOP RURD T Rig up to test BOPE. 0.0 0.0 04:45 06:00 1/23/2017 1/23/2017 1.50 INTRM1 WHDBOP BOPE T PJSM. Re -test upper IBOP, lower 0.0 0.0 06:00 07:30 IBOP, and choke valve #1 to 250 / 3500 psi 5/5 min - charted. Good test. 1/23/2017 1/23/2017 1.00 INTRM1 WHDBOP RURD P Rig down test equipment. Blow down 0.0 0.0 07:30 08:30 choke manifold and top drive. Pull test plug. 1/23/2017 1/23/2017 0.50 INTRMI CASING RURD P Install 12.375" ID wearbushing. 0.0 0.0 08:30 09:00 1/23/2017 1/23/2017 0.50 INTRM1 CASING RURD P Clean / clear rig floor. 0.0 0.0 09:00 09:30 1/23/2017 1/23/2017 1.50 INTRM1 CASING RURD P Mobilize casing tools to rig floor. 0.0 0.0 09:30 11:00 1/23/2017 1/23/2017 1.75 INTRM1 CASING RURD P PJSM. Rig up Volant CRT, single- 0.0 0.0 11:00 12:45 stack casing tongs, and handling tools to run 9-5/8" liner. 1/23/2017 1/23/2017 0.25 INTRMI CASING SFTY P Hold PJSM for running 9-5/8" liner. 0.0 0.0 12:45 13:00 1/23/2017 1/23/2017 1.50 INTRM1 CASING PUTB P Make up 9-5/8" 40# L-80 H563 shoe, 0.0 160.0 13:00 14:30 float collar, and landing collar, baker - locking connections. Circulate 45 bbls through shoe track and test floats - good test. Make up next joint, baker - locking connection and run in to 160'. 1/23/2017 1/23/2017 4.75 INTRM1 CASING PUTB P Run in hole with 9-5/8" 40# L-80 H563 160.0 1,778.0 14:30 19:15 liner f/ 160' - 1778', filling pipe on the fly and topping off every 5th joint with volant tool, installing 9-5/8" x 12" hydroform centralizers on each joint. Use Seal -Guard dope and torque connections with Volant tool to 13.5k Tq, no remakes/ no rejects. Monitor displacement on pit #5. Run in at -3300 ft/hr as per trip schedule. 1/23/2017 1/23/2017 1.75 INTRM1 CASING PUTB P Make up XO joint and continue 1,778.0 2,952.0 19:15 21:00 running in hole with 9-5/8" 40# L-80 BTC -m liner f/ 1778'- 2952' MD, filling pipe on the fly and topping off every 5th joint with volant tool, installing 9- 5/8" x 12" hydroform centralizers free floating on each joint up to #50 (2270' above float shoe). Use Run -n -Seal dope and torque connections with single -stack casing tongs to 8k Tq. Run in at -3300 ft/hr as per trip schedule. Total of 55 x centralizers run, including the 3 x on shoe track. Page 30/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) z 2M-38 ,.zk• Rig: DOYON 141 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) 1/23/2017 1/23/2017 1.00 INTRM1 CASING CIRC P Circulate / condition mud, staging up 2,952.0 2,952.0 21:00 22:00 pumps to 8 bpm, 200 psi, 35% F/O, MW in/out 10.4ppg, total of 396 bbls pumped. PUW 125k, SOW 105k 1/23/2017 1/23/2017 0.25 INTRM1 CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 2,952.0 3,073.0 22:00 22:15 m liner f/ 2952' - 3073'. 1/23/2017 1/23/2017 1.25 INTRM1 CASING WASH T Observe string take weight at 3073', 3,073.0 3,092.0 22:15 23:30 unable to trip through. Stage up pumps and observe hole packed off with no returns. Pull up into casing and work up rate to 3.5 bpm, 120 psi, 23% F/O. Wash down and tag up at 3073' and observe pump pressure increase to 200 psi. Work multiple times, stacking 25k on it and observe weight come back, pressure drop back to 120 psi, and continue running in to 3092'. 1/23/2017 1/24/2017 0.50 INTRM1 CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 3,092.0 3,456.0 23:30 00:00 m liner f/ 3092' - 3456' MD, filling pipe on the fly and topping off every 5th joint with volant tool. Use Run -n -Seal dope and torque connections with single -stack casing tongs to 8k Tq. SOW 110k. Running speed 2100 ft/hr 1/24/2017 1/24/2017 5.50 INTRM1 CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 3,456.0 5,458.0 00:00 05:30 m liner f/ 3456' - 5458' MD, filling pipe on the fly and topping off every 5th joint with volant tool. Use Run -n -Seal dope and torque connections with single -stack casing tongs to 8k Tq. SOW 115k. Running speed 2100 ft/hr per trip schedule. 1/24/2017 1/24/2017 1.50 INTRM1 CASING CIRC P Circulate 1.5 bottoms up at planned 5,458.0 5,458.0 05:30 07:00 circulation point, staging up pumps to 300 gpm, 130 psi, 34% F/O, MW 10.4ppg in/out. 1/24/2017 1/24/2017 3.50 INTRM1 CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 5,458.0 7,048.0 07:00 10:30 m liner f/ 5458'- 7048' MD, filling pipe on the fly and topping off every 5th joint with volant tool. Use Run -n -Seal dope and torque connections with single -stack casing tongs to 8k Tq. SOW 115k. Running speed 1500-900 ft/hr per trip schedule. 1/24/2017 1/24/2017 2.25 INTRM1 CASING CIRC P Circulate 1 x bottoms up at planned 7,048.0 7,048.0 10:30 12:45 circulation point, staging up pumps to 200 gpm, 160 psi, 30% F/O, MW in/out 10.4+/10.5+ 1/24/2017 1/25/2017 11.25 INTRMI CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 7,048.0 9,517.0 12:45 00:00 m liner f/ 7048'- 9517' MD, filling pipe on the fly and topping off every 5th joint with volant tool. Use Run -n -Seal dope and torque connections with single -stack casing tongs to 8k Tq. SOW 115k. Running speed 720 - 480 ft/hr per trip schedule. Note: Observe well breathing back initially and taper off to static. Page 31/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 1/25/2017 1/25/2017 3.75 INTRM1 CASING CIRC P Circulate 1 x bottoms up, staging up 9,517.0 9,517.0 00:00 03:45 pumps slowly while monitoring losses. Decrease rate on downstroke and increase on upstroke to compensate for surge. Observe initial loss rate of 6 bbl/hr @ 2.5 bpm increase to 17 bbl/hr at 3.5 bpm. After circulating 1/2 bottoms up, start observing 10.7ppg / 143 vis coming out, 10.5ppg / 58 vis going in. Continue staging up rate to 6 bpm, 320 psi on upstroke, 5 bpm, 320 psi on downstroke as loss rate decreased to zero. Total 28.6 bbls lost downhole throughout circulation and MW in/out 10.4+/10.5+ after 750 bbls pumped. Initial PUW 265k, Final PUW 235k. SOW 133k 1/25/2017 1/25/2017 5.50 INTRMI CASING PUTB P Run in hole with 9-5/8" 40# L-80 BTC- 9,517.0 11,191.0 03:45 09:15 m liner f/ 9517'- 11191' MD, filling pipe on the fly and topping off every 5th joint with volant tool. Use Run -n - Seal dope and torque connections with single -stack casing tongs to 8k Tq. SOW 133k. Running speed 480 - 600 ft/hr per trip schedule. Note: Observe well breathing back initially and taper off to static. 1/25/2017 1/25/2017 0.50 INTRM1 CASING RURD P Rig down volant and casing handling 11,191.0 11,191.0 09:15 09:45 tools. 1/25/2017 1/25/2017 1.50 INTRM1 CASING OTHR P Make up Baker HRD-E ZXP liner top 11,191.0 11,324.0 09:45 11:15 packer / Flex -Lock hanger assembly and fill tieback w/ ZamPlex-D. RIH w/ 1 x stand of HWDP to 11324', PUW 345k, SOW 130k. 1/25/2017 1/25/2017 5.00 INTRM1 CASING CIRC P Circulate 1 x liner volume, staging up 11,324.0 11,324.0 11:15 16:15 pumps slowly to 4.5 bpm, 480 psi, 29% F/O by 2700 strokes. Observe well start taking fluid at 40 bbl/hr. Decrease pump rate to 3 bpm / 300 psi , 27% F/O and continue circulating total of 868 bbls. Halfway through circulation, observed MW in/out 10.4 / 10.6 increasing to 10.7+. Final MW in/out 10.4 / 10.5+. Total downhole losses throughout circulation = 112 bbls. 1/25/2017 1/25/2017 4.00 INTRM1 CASING RUNL P Run 9-5/8" liner with 2 x remaining 11,324.0 12,642.0 16:15 20:15 stands 5" HWDP from derrick and then 37 x singles 5" HWDP from pipe shed f/ 11324'- 12642', SOW 150k. Note: Observe well breathing back initially and taper off to static. 1/25/2017 1/25/2017 1.75 INTRM1 CASING RUNL P Run 9-5/8" liner on 5" DP stands from 12,642.0 13,215.0 20:15 22:00 derrick f/ 12642' - 13215', filling on the fly and topping off every 5 x stands, SOW 140k Page 32/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/25/2017 1/25/2017 1.50 INTRM1 CASING WASH P Wash down f/ 13215'- 13277'w/ 2 13,215.0 13,305.0 22:00 23:30 bpm, 480 psi, 22% F/O. Observe string take 25k weight at 13277' with no pump pressure increase. Attempt to pick up but unable to move at 380k up. Stage rate up to 4bpm, 550 psi, 31 % F/O and wash through, setting down 85k before it broke over and continued down. Wash down and tag bottom at 13307' with 30k weight, 240 psi increase in pump pressure. Pick up to 365k and observe string travel, —2 ft. Note: From 13277' to bottom, observed erratic pump pressure and string taking 10-15k weight. 1/25/2017 1/26/2017 0.50 INTRM1 CEMENT CIRC P Circulate / condition mud for cement 13,305.0 13,305.0 23:30 00:00 job w/ 4 bpm, ICP 580 psi, FCP 440 psi, 31 % F/O. Attempt to reciprocate pipe but unable to move with 380k up. Note: Since started circulating to wash stand down, no losses observed. 1/26/2017 1/26/2017 3.25 INTRM1 CEMENT CIRC P Circulate / condition mud and 13,305.0 13,305.0 00:00 03:15 decrease yield point for cement job, staging up to 5.5 bpm, 520 psi, 28% F/O, observing mud coming out between 10.4+ to 10.6ppg. 1/26/2017 1/26/2017 9.25 INTRM1 CEMENT CIRC T After circulating 1400 bbls, observe 13,305.0 13,305.0 03:15 12:30 pressure start increasing at 5.5 bpm. Decrease rate to 3.5 bpm and pressure stabilized and started trending downard. At 1471 bbls pumped, hole tried to packoff. Drop rate to 0.5 bpm and slowly work rate up to 4.5 bpm, 400 psi, 27% F/O, MW in/out 10.4ppg. SIMOPS: Load / strap 7" casing in shed for tieback and liner strings. 1/26/2017 1/26/2017 0.50 INTRM1 CEMENT RURD P Blow down top drive. Rig up Baker 13,305.0 13,305.0 12:30 13:00 cement swivel, cement line, and 10' pup joint. 1/26/2017 1/26/2017 3.25 INTRM1 CEMENT CIRC P Slowly stage up pumps to 4.5 bpm, 13,305.0 13,305.0 13:00 16:15 400 psi, 26% F/O and continue circulating through cement swivel. Hold PJSM for cementing with crew. Page 33/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (WB) 1/26/2017 1/26/2017 2.00 INTRM1 CEMENT CMNT P Line up to Schlumberger and pump 9- 13,305.0 13,305.0 16:15 18:15 5/8" liner cement job. Pump 10 bbls CW100 and pressure test lines to 450 / 4500 psi - good test. Continue pumping additional 30.2 bbls 8.34ppg CW100 at 4.5 bpm, 655 psi. Batch up and pump 63.3 bbls 12.5ppg MudPush spacer at 4.5 bpm, 260 psi. Drop bottom wiper dart and mix cement. Cement wet at 17:10 hrs. Pump 166.5 bbls 15.8ppg Class G cement at 4.5 bpm, 373 psi. Drop top wiper dart. Kick out dart and clear SLB lines with 10.3 bbls freshwater. Note: Bottom wiper dart latched into plug at 23 bbls cement pumped, 1300 psi to release. 1/26/2017 1/26/2017 3.25 INTRM1 CEMENT CMNT P Line up to rig pumps and displace 13,305.0 13,305.0 18:15 21:30 cement with 10.4+ppg LSND, staging up to 4.5 bpm, ICP 213 psi, FCP 1150 psi, 26% F/O. Observe top dart latch after 20 strokes pumped (13.5 bbl early), 861 psi to release. Observe bottom plug land out at 6760 strokes (22 bbl early), 625 psi. Decrease rate at 8370 strokes to 3 bpm, 1000 psi, 24% F/O. Bump top plug at 8427 strokes (21 bbl early). Pressure up to 1500 psi and hold for 5 minutes. Bleed off pressure and check floats - floats holding. CIP @ 21:20 hrs. 1/26/2017 1/26/2017 0.75 INTRM1 CEMENT PACK P Pressure up to 2600 psi and slackoff 13,305.0 2,077.0 21:30 22:15 to 90k - confirm hanger set. Pressure up to 3800 psi, bleed off pressure, and pick up to 200k - running tool not released. Pressure up to 4000 psi and pick up to 105k to observe travel - confirm tool released. Liner top at 2077' MD. Shoe set at 13305' MD. 1/26/2017 1/26/2017 0.25 INTRM1 CEMENT RURD P Lay down cement swivel and blow 2,077.0 2,077.0 22:15 22:30 down cement line. 1/26/2017 1/26/2017 1.00 INTRM1 CEMENT CIRC P Pressure up to 500 psi and pick up to 2,077.0 2,045.0 22:30 23:30 release RS packoff. Pump at 2 bpm while pulling out of tieback. Once above tieback, stage up to 660 gpm, 965 psi, 49% F/O and circulate 2 x bottoms up. 1/26/2017 1/26/2017 0.25 INTRM1 CEMENT TRIP P Pull OOH and rack back 3 x stands 5" 2,045.0 1,781.0 23:30 23:45 DP and layout 15' pup joint f/ 2045' - 1781'. 1/26/2017 1/27/2017 0.25 INTRM1 CEMENT RURD P Blow down top drive and rig up to test 1,781.0 1,781.0 23:45 00:00 liner top packer. 1/27/2017 1/27/2017 1.00 INTRM1 CEMENT PRTS P PJSM, R/U testing lines. Pressure test 1,781.0 1,781.0 00:00 01:00 9-5/8" ZXP liner top packer to 1000 psi f/ 10 min on chart. Good test. 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT TRIP P POOH standing back 4 stands of 5" 1,781.0 1,472.0 01:00 01:30 j j DP to 1472' MD. Page 34/69 Report Printed: 2/27/2017 k Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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 (WS) 1/27/2017 1/27/2017 1.50 INTRM1 CEMENT SLPC P PJSM, Slip and cut 91'( 14 wraps) of 1,472.0 1,472.0 01:30 03:00 drilling line. Monitor well on trip tank. 1/27/2017 1/27/2017 1.00 INTRM1 CEMENT SVRG P Lubricate rig and service top drive. 1,472.0 1,472.0 03:00 04:00 1/27/2017 1/27/2017 2.00 INTRM1 CEMENT PULD P POOH laying down 5" HWDP (37 1,472.0 33.0 04:00 06:00 joints total ) stand back the last 3 stands of HWDP to be used on Inter 2. Calculated displacement= 29.5 bbls, Actual displacement= 30 bbls. 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT BHAH P Make service breaks and L/D Baker 33.0 0.0 06:00 06:30 running tool. Observed dog sub had sheared. 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT OTHR P Pick up Baker cement swivel and 0.0 0.0 06:30 07:00 remove 10' pups joints, lay back down. 1/27/2017 1/27/2017 0.75 INTRM1 CEMENT BOPE P Pull wear bushing and install test plug. 0.0 0.0 07:00 07:45 1/27/2017 1/27/2017 1.75 INTRM1 CEMENT BOPE P PJSM. Change out upper casing rams 0.0 0.0 07:45 09:30 to 3-1/2" x 6" VBRs. 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT BOPE P Rig up to test upper VBRs 0.0 0.0 09:30 10:00 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT BOPE P Test upper 3-1/2" x 6" VBRs 250/3500 0.0 0.0 10:00 10:30 psi 5/5 min w/ 5" test joint, charted - good test. 1/27/2017 1/27/2017 1.50 INTRM1 CEMENT BOPE P Rig down test equipment and blow 0.0 0.0 10:30 12:00 down lines. Pull test plug and install long wearbushing w/ 12.375" ID. Layout wearbushing running tool and install new stand pipe clamp. 1/27/2017 1/27/2017 0.50 INTRM1 CEMENT BHAH P Mobilize BHA to rig floor. SIMOPS: 0.0 0.0 12:00 12:30 Take on 1 x load new 10.5ppg LSND to pits. 1/27/2017 1/27/2017 1.50 INTRM1 CEMENT BHAH P PJSM. Make up BHA #4 per SLB with 0.0 110.0 12:30 14:00 8-1/2" Smith MDi516 PDC bit (4 x 14's and 1 x 15 jets), Powerdrive, PD sub, NM Flex collar, EcoScope, TeleScope, NMDC pony, 8-3/8" NM Stab w/ non - ported plunger, and NMDC pony to 110'. 1/27/2017 1/27/2017 0.25 INTRM1 CEMENT BHAH P PJSM. Pull up to EcoScope and load 110.0 110.0 14:00 14:15 nuclear source. Run in hole to 110'. 1/27/2017 1/27/2017 1.25 INTRM1 CEMENT BHAH P Continue making up BHA #4 per SLB 110.0 508.0 14:15 15:30 with Riptide Underreamer w/ 9-7/8" cutter blocks (2 x 8-3/2" nozzles), NMDC, 8-3/8" NM stab w/ non -ported flapper float, NMDC, Saver sub w/ non -ported flapper float, 6 x HWDP, 6-1/4" hydraulic jars, and 3 x HWDP to 508'. Note: Floats tested offline to 600 psi prior to picking up - good tests. 1/27/2017 1/27/2017 0.25 INTRM1 CEMENT TRIP P Run in hole f/ 508'- 1442' MD on 5" 508.0 1,442.0 15:30 15:45 DP stands. 1/27/2017 1/27/2017 0.25 INTRM1 CEMENT DHEQ P Shallow hole test MWD tools w/ 515 1,442.0 1,442.0 15:45 16:00 gpm, 950 psi, 42% F/O - good test. Blow down top drive. 1/27/2017 1/27/2017 6.50 INTRM1 CEMENT TRIP P Run in hole f/ 1442'- 12922' MD, filling 1,442.0 12,922.0 16:00 22:30 pipe every 20 x stands, SOW 65k. Calc Disp 108 bbls, Actual Disp 111 bbls. Page 35/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (W) End Depth (ftKB) 1/27/2017 1/28/2017 1.50 INTRM1 CEMENT CIRC P Fill pipe and wash down to 13011' w/ 12,922.0 13,011.0 22:30 00:00 126 gpm, 500 psi, SOW 70k. Stage up pumps to 500 gpm, 2250 psi and attempt to rotate string. Observe string stall out at 26k Tq while stationary or picking up, but observed rotation on downward stroke at 23-25k Tq. Increase rate to 610 gpm, 3100 psi, 47% F/O, and finish circulating bottoms up. Drop rate to 500 gpm, 2100 psi, 45% F/O, and attempt to rotate string - observe string stall out at 27k. Note: Make-up torque for the 5" NC50 DP at 28k. 1/28/2017 1/28/2017 0.50 INTRM1 CEMENT RURD P Blow down top drive and rig up for 13,011.0 13,011.0 00:00 00:30 casing test. 1/28/2017 1/28/2017 1.00 INTRM1 CEMENT PRTS P PJSM. Pressure test 9-5/8" x 13-3/8" 13,011.0 13,011.0 00:30 01:30 casing to 3500 psi / 30 min, charted - good test. Pump 13 bbls / bled back 13 bbls. Note: Conducted safety stand up with new crew. 1/28/2017 1/28/2017 0.25 INTRM1 CEMENT RURD P Rig down test equipment and blow 13,011.0 13,011.0 01:30 01:45 down lines. 1/28/2017 1/28/2017 5.00 INTRM1 CEMENT DISP P PJSM, Displace well to new 10.5 ppg 13,011.0 13,011.0 01:45 06:45 LSND mud treated with black products for shale stability as follows. Pump 30 bbls of high vis 10.5 ppg LSND followed by 1025 bbls of 10.5 ppg LSND mud. Pump @ 250 gpm w/ 800 psi, 27% FO, 60 rpm's w/ 25K - 28K Tq. Had to reduce pump rate to 2 bpm w/ 300 psi for 290 bbls due to 1 B unable to take fluids due to rig move, increased rate once had enough trucks to keep up with flow rate. Increased Lubes to 1.5% w/ Lo -Torg and lowered rotating torque to 22 Kft/lbs. 1/28/2017 1/28/2017 0.25 INTRMI CEMENT CIRC P Obtain post displacement parameters, 13,011.0 13,011.0 06:45 07:00 P/U= 230K, S/O= 90, ROT=145K @ 60 rpm's w/ 22K Tq. SPRs @ 13106' MD, 5818' TVD, MW=10.5 ppg, 06:45 hours MP#1: 30 spm=410 psi, 40 spm=500 psi. MP #2: 30 spm= 410 psi, 40 spm=490 psi. 1/28/2017 1/28/2017 0.50 INTRM1 CEMENT COCF P Wash down from 13011' MD to 13220' 13,011.0 13,220.0 07:00 07:30 MD, pump @ 500 gpm= 1900 psi, Rotate @ 60 rpm's w/ 22K Tq. Page 36/69 Report Printed: 2/27/2017 r' Operations Summary (with Timelog Depths) ' 2M-38 Rig: DOYON 141 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) 1/28/2017 1/28/2017 2.75 INTRM1 CEMENT DRLG P Tag top of plug @ 13220' MD. Drill 13,220.0 13,307.0 07:30 10:15 plugs @ 350 gpm=1130 psi, 40 rpm's w/ 17K -23K Tq, start w/ 5L WOB and increase to 10K. No progress in 20 min, P/U and increase rotary to 60 rpm's and pump to 500 gpm= 1830 psi. Slowly increase WOB U 12K and observed 22K Tq. Adjust WOB to maintain 22K Tq. Drilled cement, float collar and cement down to float collar at the same parameters. Reduced WOB at float shoe to 2-5K and drilled float shoe and rat hole to 13307' MD. 1/28/2017 1/28/2017 0.25 INTRM1 CEMENT DDRL P Drill 20' of new hole from 13307' MD 13,307.0 13,327.0 10:15 10:30 to 13327' MD TVD= 5829'. ADT= .23, Bit hours= .23, Total jar hours= 95.10. P/U= 230K, S/O= 90K, ROT= 145K, Pump @ 500 gpm= 1830 psi w/ 42% FO. Rotate @ 80 rpm's w/ 17K Tq off, 20Tq on. WOB= 5-1 OK. 1/28/2017 1/28/2017 2.00 INTRM1 CEMENT CIRC P Pull up into shoe to 13292' MD. Rack 13,327.0 13,292.0 10:30 12:30 back stand and circulate / condition mud for FIT f/ 13292'- 13205'w/ 500 gpm, 1840 psi, 42% F/O, 60 rpm, 18- 25k Tq. Increased lubes to 2% to lower torque w/ 776 lube. SPRs @ 13287' MD, 5829' TVD, MW=10.5 ppg, 12:30 hours MP#1: 30 spm=400 psi, 40 spm=480 psi. MP #2: 30 spm= 400 psi, 40 spm=480 psi. 1/28/2017 1/28/2017 0.25 INTRM1 CEMENT RURD P Blow down top drive and rig up for 13,292.0 13,292.0 12:30 12:45 FIT. 1/28/2017 1/28/2017 0.50 INTRM1 CEMENTFIT P Perform FIT to 16ppg EMW w/ 10.5 13,292.0 13,292.0 12:45 13:15 ppg LSND mud at 9-5/8" casing shoe, 13305' MD / 5821' TVD. Pumped 6.2 bbl's to reach 1660 psi, 3.8 bbl's bled back. 1/28/2017 1/28/2017 0.25 INTRM2 DRILL RURD P Rig down test equipment and blow 13,292.0 13,292.0 13:15 13:30 down lines. 1/28/2017 1/28/2017 1.25 INTRM2 DRILL MPDA P PJSM. Pull trip nipple and install MPD 13,292.0 13,292.0 13:30 14:45 bearing. 1/28/2017 1/28/2017 1.00 INTRM2 DRILL MPDA P Test MPD lines / chokes to 500 psi - 13,292.0 13,292.0 14:45 15:45 good test. Circulate through both chokes, stage up pumps to 500 gpm, 1900 psi, and calibrate MPD system. 1/28/2017 1/28/2017 0.25 INTRM2 DRILL REAM P Ream down to bottom f/ 13292'- 13,292.0 13,327.0 15:45 16:00 13327'w/ 500 gpm, 2000 psi, 60 rpm, 25k Tq. Page 37/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/28/2017 1/28/2017 1.75 INTRM2 DRILL DDRL P Directionally drill 8-1/2" Intermediate II 13,327.0 13,451.0 16:00 17:45 section f/ 13327'- 13451' MD, 5878' TVD, ADT 1.67 hrs, Bit hrs 1.90, Jar hrs 96.77, PUW 192k, SOW 95k, ROT 126k, Tq on 24k, Tq off 24k, ECD 12.20ppg, 80% F/O, WOB 10-15k, 120 rpm, 600 gpm, 2750 psi, Max Gas 54 units, MW 10.5ppg. Hold 310 psi MPD backpressure on connection. Increase lube concentration to 2.5% to lower torque w/ 776 lube, total of 1.5% Lo-torq and 1% 776 lube in system 1/28/2017 1/28/2017 2.00 INTRM2 DRILL CIRC P Open Riptide Underreamer per WFT 13,451.0 13,451.0 17:45 19:45 rep. Drop 6 x RFID tags and pump down at 600 gpm, 2600 psi, 80% F/O, 12.11 ppg ECD, 40 rpm, 16k Tq. Reduce rate to 250 gpm, 900 psi, 33% F/O f/ 1700 - 2800 strokes while tags passing through tool. Increase rate to 600 gpm, 2600 psi, 80% F/O, 12.04 ppg ECD, 40 rpm, 16.5k Tq f/ 2800 - 5450 strokes - no indications of tool opening. Cycle pumps and stage back up to 600 gpm, 2600 psi and increase rotary to 120 rpm, 16k Tq. After increasing rotary, observe pressure drop 200 psi and turbine rpm decrease from 3250 to 2775. Kill rotary and perform pull test into shoe w/ 15k overpull to confirm open. Increase flow and ream to bottom w/ 700 gpm, 3050 psi, 85% F/O, 12.19ppg ECD, 120 rpm, 23k Tq. Note: Top of 9-7/8" hole start from 13310' onward. Cutters 116' behind bit 1/28/2017 1/28/2017 1.25 INTRM2 DRILL CIRC T Troubleshoot mud pump #2. Come off 13,464.0 13,464.0 19:45 21:00 bottom and circulate with mud pump #1 at 414 gpm, 1300 psi, 57% F/O, 60 rpm, 16k Tq while changing out washed valve / seat on mud pump #2. 1/28/2017 1/28/2017 0.50 INTRM2 DRILL DDRL P Directionally drill 8-1/2" x 9-7/8" 13,451.0 13,464.0 21:00 21:30 Intermediate II section f/ 13451' - 13464' MD, 5884' TVD, ADT 0.33 hrs, Bit hrs 2.23, Jar hrs 97.10, PUW 215k, SOW 95k, ROT 129k, Tq on 22k, Tq off 22k, ECD 12.40 ppg, 80% F/O, WOB 13-15k, 120 rpm, 740 gpm, 3000 psi, Max Gas 40 units, MW 10.5ppg. Page 38/69 Report Printed: 2/27/2017 x Operations Summary (with Timelog Depths) 2M-38 fi< Rig: DOYON 141 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) 1/28/2017 1/29/2017 2.50 INTRM2 DRILL DDRL P Directionally drill 8-1/2" x 9-7/8" 13,464.0 13,573.0 21:30 00:00 Intermediate II section f/ 13464' - 13573' MD, 5926' TVD, ADT 1.49 hrs, Bit hrs 3.72, Jar hrs 98.59, PUW 190k, SOW 93k, ROT 125k, Tq on 21 k, Tq off 19k, ECD 12.66 ppg, 87% F/O, WOB 14-17k, 120 rpm, 740 gpm, 3300 psi, Max Gas 161 units, MW 10.5ppg. Hold 12ppg EMW backpressure on connections with MPD. 1/29/2017 1/29/2017 6.00 INTRM2 DRILL DDRL P Directionally drill 8-1/2" x 9-7/8" 13,573.0 13,910.0 00:00 06:00 Intermediate II section f/ 13573' to 13910, 6049' TVD, ADT 3.66 hrs, Bit hrs 7.38, Jar hrs 102.25, PUW 190k, SOW 93k, ROT 125k, Tq on 23k, Tq off 18k, ECD 12.66 ppg, 87% F/O, WOB 15-20k, 130 rpm, 785 gpm, 3750 psi, Max Gas 99 units, MW 10.5ppg. Hold 12ppg EMW backpressure on connections with MPD. SPR's @ 13756' MD, TVD=5998' MW= 10.5 ppg, 02:51 hours MP # 1: 30 spm=407 psi, 40 spm= 515 psi MP #2: 30 spm= 450 psi, 40 spm= 472 psi 1/29/2017 1/29/2017 4.00 INTRM2 DRILL DDRL P Directionally drill 8-1/2" x 9-7/8" 13,910.0 14,120.0 06:00 10:00 Intermediate II section f/ 13910' to TD of 14120' MD 6086' TVD, ADT 3.17 hrs, Bit hrs 10.55, Jar hrs 105.42, PUW 205k, SOW 90k, ROT 130k, Tq on 23k, Tq off 19k, ECD 12.54 ppg, 89% F/O, WOB 15-20k, 130 rpm, 760 gpm, 3669 psi, Max Gas 184 units, MW 10.5ppg. Hold 12ppg EMW backpressure on connections with MPD. 1/29/2017 1/29/2017 0.75 INTRM2 CASING CIRC P Close underreamer per WFT. Drop 6 x 14,120.0 14,117.0 10:00 10:45 RFID chips, obtain survey on bottom, and pump chips down at 600 gpm, 2600 psi, 79% F/O, 40 rpm, 16k Tq, Turbine rpm 2773. Reduce flow rate at 1900 strokes to 250 gpm, 1000 psi and circulate until 3000 strokes to pump chips through tool. Bleed off pressure and hold for 30 seconds. Increase pumps to 600 rpm, 2775 psi, Turbine rpm 3281 - confirm reamer successfully closed. 1/29/2017 1/29/2017 1.75 INTRM2 CASING CIRC P Circulate bottoms up at 660 gpm, 14,117.0 14,097.0 10:45 12:30 3150 psi, 83% VO, 80 rpm, 16k Tq while reciprocating from 14117' - 14035' MD, total 1330 bbls pumped. 1/29/2017 1/29/2017 0.50 INTRM2 CASING OWFF P Perform MPD drawdown to determine 14,097.0 14,097.0 12:30 13:00 kill weight mud. Drop pressure to 11.5 ppg EMW, shut in chokes, and monitor for pressure buildup - none observed. Well deemed static at 11 1.5ppg MW Page 39/69 Report Printed: 2/27/2017 k Operations Summary (with Timelog Depths) Y, 2M-38 Rig: DOYON 141 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) 1/29/2017 1/29/2017 5.50 INTRM2 CASING CIRC P Weight up mud system from 10.5ppg 14,097.0 13,947.0 13:00 18:30 to 11.8 ppg using 16ppg LSND spike fluid. Over first surface-to-surface circulation, weight up to 11.2 ppg, 650 gpm, 3050 psi, 12.43 - 12.69 ppg ECD. Reduce pump rate to 625 gpm, 3025 psi over second circulation and weight up to 11.8 ppg, racking back 1 x stand to 14040' MD. Reduce pump rate to 525 gpm, 2500 psi, ECD 13.18 ppg and circulate until even in/out 11.8ppg MW observed to 13947' MD. Total 4250 bbls pumped. SPR's @ 13969' MD,TVD= 6059' MW= 11.8 ppg, 18:25 hours MP # 1: 30 spm=480 psi, 40 spm= 580 psi MP #2: 30 spm= 480 psi, 40 spm= 600 psi 1/29/2017 1/29/2017 0.75 INTRM2 CASING OWFF P Blow down top drive and monitor well 13,947.0 13,947.0 18:30 19:15 for flow w/ 10 rpm, 22k Tq - well static. 1/29/2017 1/29/2017 1.75 INTRM2 CASING SMPD P Line up MPD and strip OOH f/ 13947'- 13,947.0 13,297.0 19:15 21:00 13297', holding 150 psi backpressure, observing 10-25k overpull throughout section. PUW 210k. See 40k overpull as upper stabilizer came into shoe, work down and continue up with no issues. Observe 26-27k overpull once inside casing. 1/29/2017 1/29/2017 1.25 INTRM2 CASING CIRC P Circulate 1 x bottoms up while 13,297.0 13,297.0 21:00 22:15 reciprocating stand, staging up to 550 gpm, ICP 1920 psi, FCP 1650 psi, 80% F/0, ECD 13.06 ppg, 60 rpm, 16k Tq. 1/29/2017 1/29/2017 0.25 INTRM2 CASING OWFF P Blow down top drive and monitor well 13,297.0 13,297.0 22:15 22:30 for flow - well static. Drop 2.50" hollow rabbit w/ 120' wire on stand #137. 1/29/2017 1/29/2017 0.50 INTRM2 CASING SMPD P Line up MPD and attempt to strip 13,297.0 13,193.0 22:30 23:00 OOH holding 150 psi - observe fluid flowing up drill pipe. Make up topdrive and pump out stand at 426 gpm, 1040 psi, 42% F/O to 13193'. At connection, line up MPD and slowly increase backpressure - observe fluid flowing up drill pipe. Note: Turbine rpm continually decreased while CBU at shoe, dropping 275rpm in last 30 minutes of circulating at 550 gpm, indicating washout 1/29/2017 1/30/2017 1.00 INTRM2 CASING SMPD P Continue pumping / stripping OOH f/ 13,193.0 12,829.0 23:00 00:00 13193' - 12829' looking for washout w/ 3 bpm, 360 psi, holding 100 psi MPD backpressure to offset swab. Page 40/69 Report Printed: 2/27/2017 1 a r 7* Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/30/2017 1/30/2017 2.00 INTRM2 CASING SMPD P Continue pumping / stripping OOH 12,829.0 12,022.0 00:00 02:00 from 12829' to 12022' MD looking for washout w/ 3 bpm, 350 psi, holding 100 psi MPD backpressure to offset swab. Observed washout in middle joint on stand # 124, wash out roughly -2" wide, 3-1/2;' below tool joint. Swap bad joint out with 30.88' replacement. 1/30/2017 1/30/2017 8.25 INTRM2 CASING SMPD P Continue to strip OOH from 12022' 12,022.0 2,000.0 02:00 10:15 MD to 2000' MD holding 150 psi on back side while pulling and 50 psi when in slips. 1/30/2017 1/30/2017 0.50 INTRM2 CASING OWFF P OWFF, slight flow decreasing to static. 2,000.0 2,000.0 10:15 10:45 1/30/2017 1/30/2017 0.75 INTRM2 CASING MPDA P Remove MPD bearing and install trip 2,000.0 2,000.0 10:45 11:30 nipple. 1/30/2017 1/30/2017 1.25 INTRM2 CASING TRIP P Pull OOH on elevators to top of 2,000.0 509.0 11:30 12:45 HWDP at 509', monitoring displacement on trip tank. Actual displacement 103 bbl, Calculated displacement 92 bbls. 1/30/2017 1/30/2017 0.25 INTRM2 CASING OWFF P Monitor well for flow at top of HWDP - 509.0 509.0 12:45 13:00 well static. 1/30/2017 1/30/2017 1.00 INTRM2 CASING BHAH P PJSM. Pull OOH on elevators to 199', 509.0 199.0 13:00 14:00 laying out jars and racking back HWDP, monitoring displacement on trip tank. 1/30/2017 1/30/2017 0.50 INTRM2 CASING BHAH P PJSM. Remove nuclear source from 199.0 199.0 14:00 14:30 EcoScope. 1/30/2017 1/30/2017 0.50 INTRM2 CASING BHAH P Pull OOH on elevators laying out BHA. 199.0 0.0 14:30 15:00 Observed several chipped teeth on bit. Bit Graded 2 -1 -CT -A -X -0 -NO -TD. Reamer graded 1 -1 -WT-G-X-1 -NO-TD 1/30/2017 1/30/2017 1.00 INTRM2 CASING BHAH P Clean / clear rig floor, L/D MPD 0.0 0.0 15:00 16:00 bearings and BHA tools. Pull wearbushing. 1/30/2017 1/30/2017 1.50 INTRM2 CASING BOPE P PJSM. Change out upper VBRs for 7" 0.0 0.0 16:00 17:30 solid body casing rams. 1/30/2017 1/30/2017 0.50 INTRM2 CASING BOPE P Install test plug, rig up test equipment, 0.0 0.0 17:30 18:00 and flood stack. 1/30/2017 1/30/2017 1.00 INTRM2 CASING BOPE P Test upper 7" casing rams to 250 / 0.0 0.0 18:00 19:00 3500 psi and annular to 250 / 2500 psi for 5/5 min with 7" test joint, charted - good test. 1/30/2017 1/30/2017 0.50 INTRM2 CASING BOPE P Rig down test equipment and blow 0.0 0.0 19:00 19:30 down lines. Install 12.375" wearbushing. 1/30/2017 1/30/2017 1.00 INTRM2 CASING RURD Rig up to run 7" liner with single -stack 0.0 0.0 19:30 20:30 1 IP tongs. Page 41/69 Report Printed: 2/27/2017 r{d Operations Summary (with Timelog Depths) � r Y 2M-38 Rig: DOYON 141 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) 1/30/2017 1/30/2017 2.25 INTRM2 CASING PUTB P PJSM. M/U shoe track, fill pipe, and 0.0 938.0 20:30 22:45 check floats - good test. Continue RIH W/ 7", 26# L-80 H563 doped liner to 938', filling each joint on the fly with fill -up hose and installing 7" x 8-1/2" hydroform centralizers free-floating on each joint. Total 4 x 7"x8-1/4" Weatherford Spiragliders, 8 x friction -set stop rings, and 19 x 7" x 8-1/2" Hydroform centralizers run in hole with liner. MUT of 9400 ft -lbs. Baker -lock first four connections. 1/30/2017 1/30/2017 0.75 INTRM2 CASING OTHR P Make up HRDE ZXP liner top packer/ 938.0 978.0 22:45 23:30 Flex -Lock hanger assembly w/ wiper darts and fill tieback sleeve per Baker. Rig down casing equipment. 1/30/2017 1/31/2017 0.50 INTRM2 CASING CIRC P Pick up one stand 5" DP and circulate 978.0 1,070.0 23:30 00:00 1 x liner volume at 5 bpm, 100 psi to 1070' MD. 1/31/2017 1/31/2017 8.50 INTRM2 CASING RUNL P Continue running in hole with 7" liner 1,070.0 13,295.0 00:00 08:30 one 5" drillpipe from 1070' to 13295'. Fill drillpipe every 10 stands. P/U = 210 kiips S/O = 90 kips Calculated displacement = 100 bbl. Actual displacement = 97 bbl. 1/31/2017 1/31/2017 1.50 INTRM2 CASING CIRC P Circulate and condition mud while 13,295.0 13,295.0 08:30 10:00 rotating and reciprocating liner and drillpipe Stage pump rate up to: Rate = 7 bpm Standpipe pressure = 940 psi. Flow out = 33% P/U = 210 kips S/O = 90 kips Rot = 130 kips 1/31/2017 1/31/2017 0.75 INTRM2 CASING RUNL P Continue running in hole with 7" liner 13,295.0 14,041.0 10:00 10:45 one 5" drillpipe from 13295' to 14041 @ 50 fpm. Fill drillpipe every 10 stands. 1/31/2017 1/31/2017 0.25 INTRM2 CASING WASH P Break circulation and wash liner down 14,041.0 14,110.0 10:45 11:00 from 14041' to 14120'. Tag bottom on depth. Pick up and put liner on depth with shoe at 14110' MD and liner top at 13137.72' Circulate at; rate = 2 bpm Stand pipe pressure = 550 psi Flow out = 28% Page 42/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) M 2M-38 Rig: DOYON 141 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) 1/31/2017 1/31/2017 3.25 INTRM2 CEMENT CIRC P Circulate and condition mud while 14,110.0 14,110.0 11:00 14:15 reciprocating liner and drillpipe Stage pump rate up to: Rate = 7 bpm Standpipe pressure = 834 psi. Flow out = 33% P/U = 210 kips S/O = 90 kips Rot = 130 kips Stroke = 80' 1/31/2017 1/31/2017 0.75 INTRM2 CEMENT RURD P Make up cementing head. 14,110.0 14,110.0 14:15 15:00 1/31/2017 1/31/2017 1.75 INTRM2 CEMENT CMNT P Cement liner as follows: 14,110.0 14,100.0 15:00 16:45 Pump 10 bbl CW100 Test cement lines to 4500 psi Pump 30 bbl CW100 Pump 40 bbl Mud Push @ 13.00 ppg Drop dart Mix and Pump 67 bbl slurry @ 15.80 ppg Drop 2nd dart Pump 10 bbl freshwater and switch to rig pump for displacement 1/31/2017 1/31/2017 0.75 INTRM2 CEMENT CMNT P Displace with rig pump at: 14,100.0 14,100.0 16:45 17:30 Initial Rate = 7 bpm Stand pipe pressure = 900 psi Final rate = 3pm Final stand pipe pressure = 900 psi Bump plug @ 2350 strokes Pressure up 1500 psi 1/31/2017 1/31/2017 0.75 INTRM2 CEMENT PACK P Set liner hanger by pressuring up to 14,100.0 13,136.0 17:30 18:15 2900 psi. Slack off 45 kips on weight indicator Pressure up to 4000 psi to release running tool Check floats -Good Pick up to 195 kips. Running tool free. Slack off and set liner top packer with 110 kips on weight indicator. Break off cement line. Pull running tool above TOL while keeping 500 psi on the drillpipe. 1/31/2017 1/31/2017 1.50 INTRM2 CEMENT CIRC P Circulate two bottoms up: 13,136.0 13,136.0 18:15 19:45 Rate = 800 gpm Stand pipe pressure = 3325 psi 1/31/2017 1/31/2017 0.50 INTRM2 CEMENT PULD P Lay down two joints of 5" drillpipe and 13,136.0 12,830.0 19:45 20:15 cement head. Lay down 9 joints of HWDP Page 43169 Report Printed: 2/27/2017 d. Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 1/31/2017 1/31/2017 1.00 INTRM2 CEMENT PRTS P Rig up and test casing, (liner top and 12,830.0 12,830.0 20:15 21:15 liner to 1000 psi for 10 minutes. Record test on chart. Rig down 1/31/2017 1/31/2017 1.50 INTRM2 CEMENT OTHR P Clear. rig floor. Mix hi -vis spacer. Off 12,830.0 12,830.0 21:15 22:45 load mud and rockwasher 1/31/2017 2/1/2017 1.25 INTRM2 CEMENT DISP P Displace well with fresh water. Pump 12,830.0 12,830.0 22:45 00:00 66 bbl viscous spacer ahead and displace at 8 bpm @ 1800 psi. 2/1/2017 2/1/2017 3.00 INTRM2 CEMENT DISP P Cont displacing well to fresh water, 12,830.0 12,920.0 00:00 03:00 pump at 8 bpm=1258 psi, 35% flow out. At 13952 stokes MW in 8.4 ppg, MW out 8,7 ppg. Shut down and haul more fresh water. 2/1/2017 2/1/2017 1.50 INTRM2 CEMENT SLPC P Slip and cut 59' of drilling line, 9 12,920.0 12,920.0 03:00 04:30 wraps. Clean and service draw works and adjust breaks. 2/1/2017 2/1/2017 1.50 INTRM2 CEMENT WAIT T Re -supply rig with fresh water. 12,920.0 12,920.0 04:30 06:00 Perform derrick inspection, service roughneck and 5" handling equipment. Complete MP2 and clean and clear rig floor. SIMOPS, monitoring well. Well static and not U -tubing. Decision made to pump dry job and POOH. 2/1/2017 2/1/2017 1.00 INTRM2 CEMENT CIRC P Mix 25 bbls of 9.3 ppg NaCl brine for 12,920.0 12,920.0 06:00 07:00 dry pump, pump @ 2 bpm=75 psi, 14% flow out. 2/1/2017 2/1/2017 7.75 INTRM2 CEMENT PULD P Laydown 5" drillpipe from 12920' to 12,920.0 3,418.0 07:00 14:45 3418 2/1/2017 2/1/2017 0.50 INTRM2 CEMENT TRIP P RIH with remaining 5" drillpipe from 3,418.0 4,572.0 14:45 15:15 derrick from 3418' to 4572' 2/1/2017 2/1/2017 2.75 INTRM2 CEMENT PULD P Laydown 5" drillpipe from 4572' to 4,572.0 0.0 15:15 18:00 surface 2/1/2017 2/1/2017 0.50 INTRM2 CEMENT BHAH P Lay down liner setting tool. Drain 0.0 0.0 18:00 18:30 stack and pull wear bushing 2/1/2017 2/1/2017 0.75 INTRM2 CEMENT RURD P Mobilize casing equipment to the rig 0.0 0.0 18:30 19:15 floor 2/1/2017 2/1/2017 1.25 INTRM2 CEMENT RURD P Ri up volant tool and casing tongs 0.0 0.0 19:15 20:30 2/1/2017 2/2/2017 3.50 INTRM2 CEMENT PUTB P RIH with 62 joints of 7" 26.0#, BTC -M 0.0 2,853.0 20:30 00:00 casing to 2853' P/U = 94 kips S/O = 84 kips 2/2/2017 2/2/2017 9.50 INTRM2 CEMENT PUTB P Continue running in the hole with 7" 2,853.0 13,078.0 00:00 09:30 26#, L-80 BTC -M casing from 2853' to10863'. Make up crossover and run in hole with 7" 26#, L-80 Hydril 563 casing to 13078' 2/2/2017 2/2/2017 1.00 INTRM2 CEMENT HOSO P Wash down to 13145' and observed 13,078.0 13,154.0 09:30 10:30 seals entering SBE. No-go @ 13156' Pick up to 13154'. P/U = 275 kips S/O = 90 kips. 2/2/2017 2/2/2017 0.25 INTRM2 CEMENT PRTS P Rig up and pressure test OA to 1000 13,154.0 13,154.0 10:30 10:45 psi for 10 minutes-- Good Test Page 44/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 4� t 2M-38 Rig: DOYON 141 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) 2/2/2017 2/2/2017 1.25 INTRM2 CEMENT HOSO P Lay down joint #309 and #308. Make 13,154.0 13,154.0 10:45 12:00 up 3.82' pup joint and joint #308. RIH to 13124.14'. Make up casing hanger and landing joint. RIH to 13154' and land hanger. 2/2/2017 2/2/2017 1.00 INTRM2 CEMENT RURD P Rig up to reverse circulate. Rig down 13,154.0 13,154.0 12:00 13:00 casing running equipment and clear rig floor 2/2/2017 2/2/2017 1.75 INTRM2 CEMENT CRIH P Pull seals above SBE and close 13,154.0 13,154.0 13:00 14:45 annular. Reverse circulate 325 bbl corrosion inhibitted water down OA at 5 bpm -300 psi. SI 2/2/2017 2/2/2017 3.25 INTRM2 CEMENT WAIT T Wait for truckload of Isotherm to arrive 13,154.0 13,154.0 14:45 18:00 from Dead Horse, Alaska. 2/2/2017 2/2/2017 1.50 INTRM2 CEMENT FRZP P Utilizing hot -oil truck freeze protect OA 13,154.0 13,154.0 18:00 19:30 by reversing in 215 bbl Isotherm at 3 bpm -750 psi 2/2/2017 2/2/2017 2.00 INTRM2 CEMENT HOSO P Strip through annular and land casing 13,154.0 13,154.0 19:30 21:30 hanger. Test OA to 1000 psi for 10 minutes to verify seals in SBE. Bleed pressure and drain stack. Open annular. 2/2/2017 2/2/2017 0.50 INTRM2 CEMENT OWFF P Observe well for flow ---Dead 13,154.0 0.0 21:30 22:00 Drain stack and lay down 7" landing joint 2/2/2017 2/2/2017 1.00 INTRM2 CEMENT WWSP P Install 7" packoffand RILDS. Test 0.0 0.0 22:00 23:00 void to 5000 psi for 10 minutes 2/2/2017 2/3/2017 1.00 INTRM2 CEMENT PRTS P Rig up and test OA to 2500 psi for 30 0.0 0.0 23:00 00:00 minutes. 2/3/2017 2/3/2017 0.75 INTRM2 CEMENT PRTS P Cont testing OA with LRS to 2500 psi 0.0 0.0 00:00 00:45 on chart for 30 min, good test. SimOps - C/O saver sub to 4" XT -39. 2/3/2017 2/3/2017 2.25 INTRM2 CEMENT BOPE P Continue swapping saver sub. 0.0 0.0 00:45 03:00 Change upper pipe rams from 7" casing rams to 3-1/2" x 6" VBR's 2/3/2017 2/3/2017 1.00 INTRM2 CEMENT RURD P Remove all casing handling 0.0 0.0 03:00 04:00 equipment and 5" handling equipment from the rig floor. Bring 4" handling equipment and TIW/dart valves to the rig floor 2/3/2017 2/3/2017 5.00 INTRM2 CEMENT PULD P Pick up 15 stands of 4" HWDP and 0.0 0.0 04:00 09:00 rack in derrick. Pick up 37 stands of 4" drillpipe and rack in derrick 2/3/2017 2/3/2017 0.50 INTRM2 CEMENT SVRG P Service rig and top drive 0.0 0.0 09:00 09:30 2/3/2017 2/3/2017 1.50 INTRM2 WHDBOP RURD P Rig up BOPE test equipment and 0.0 0.0 09:30 11:00 perform shell test 2/3/2017 2/3/2017 4.50 INTRM2 WHDBOP BOPE P BOPE test. Test all components to 0.0 0.0 11:00 15:30 250 psi low pressure test and 3500 psi high pressure test. Test Annular and both sets of pipe rams with 3-1/2" and 4-1/2" test joints 2/3/2017 2/3/2017 0.75 INTRM2 WHDBOP RURD P Rig down test equipment and install 0.0 0.0 15:30 16:15 wear ring (8.75" I.D., 13-3/8" O.D., and 13-1/4" length) 2/3/2017 2/3/2017 0.75 INTRM2 CEMENT BHAH P Mobilize BHA components to the rig 0.0 0.0 16:15 17:00 floor. Concurrent operation finalize 4" drillpipe tally 2/3/2017 2/3/2017 2.25 INTRM2 CEMENT BHAH P Make up BHA #5 0.0 337.0 17:00 9:15I 1 I I Page 45/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/3/2017 2/3/2017 1.75 INTRM2 CEMENT PULD P Pick up 4" drillpipe from the pipeshed 337.0 2,225.0 19:15 21:00 and RIH with BHA #5 to 2225' 2/3/2017 2/3/2017 0.50 INTRM2 CEMENT DHEQ P Perform shallow test of MWD 2,225.0 2,225.0 21:00 21:30 equipment in the hole @ 200 gpm, 800 psi, 2/3/2017 2/4/2017 2.50 INTRM2 CEMENTPULD P Continue picking up 4" drillpipe from 2,225.0 5,896.0 21:30 00:00 the pipeshed from 2225' to 5896' P/U = 100 kips S/0 = 65 kips 2/4/2017 2/4/2017 0.50 INTRM2 CEMENT SVRG P Service rig and roughneck. 5,896.0 5,896.0 00:00 00:30 2/4/2017 2/4/2017 6.00 INTRM2 CEMENT PULD P Continue to RIH picking up 4" drill pipe 5,896.0 12,784.0 00:30 06:30 from 5896' MD to 12784' MD, filling pipe every 20 stands. 2/4/2017 2/4/2017 0.50 INTRM2 CEMENT CIRC P Establish circulation @ 225 gpm= 12,784.0 12,784.0 06:30 07:00 1428 psi, 22 % flow out. Send down link to turn on Sonic tool for cement job evaluation. 2/4/2017 2/4/2017 3.00 INTRM2 CEMENT QEVL P Continue to RIH picking up 4" drill pipe 12,784.0 13,847.0 07:00 10:00 from 12784' MD to 13847' MD, Logging cement job with Sonic tool while RIH @ 750 fph. Observed cement stringer in 6.19" ID restriction below tie back sleeve @ 13154. Able to pick up and set 10K to pass through. Tagged up on stringers @ 13847' MD. Actual displacement= 89 bbls. Calculated displacement= 89 bbls. P/U= 205K, S/0=83K. 2/4/2017 2/4/2017 3.00 INTRM2 CEMENT DISP P PJSM, Displace well to 11.8 ppg used 13,847.0 13,875.0 10:00 13:00 LSND mud system. Pumped 30 bbls of high vis spacer followed by 463 bbls of 11.8 ppg LSND mud. Pumped @ 200 gpm=1275 psi, 18 % flow out, rotate @ 60 rpm's= 12K Tq. Once LSND turned the corner, reamed down through stringers to 13875' MD 2/4/2017 2/4/2017 2.00 INTRM2 CEMENT PRTS P Pressure test 7" casing to 3600 psi for 13,875.0 13,875.0 13:00 15:00 30 minutes. Pressure bled to 3450 psi. Test required 55 stokres. Bled back 5.44 bbl to the trip tank. Test recorded on a chart. 2/4/2017 2/4/2017 1.50 INTRM2 CEMENT SLPC P Cut and slipped 7 wraps (46') of 1-3/8" 13,875.0 13,875.0 15:00 16:30 drilling line. Serviced top drive and drawworks. Inspected brakes and linkage Page 46/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/4/2017 2/4/2017 1.50 INTRM2 CEMENT COCF P Washed and rotated cleaning out 13,875.0 14,019.0 16:30 18:00 cement stringers from 13875' and tagged landing collar at 10419'. Rotated @ 60 rpm Pumped at 200 gpm Standpipe pressure = 2350 psi Flow out = 28% WOB = 5-15 kips P/U = 250 kips S/O = 80 kips Rot = 105 kips Torque off bottom = 15 k -ft -lbs 2/4/2017 2/4/2017 3.75 INTRM2 CEMENT DRLG P Drilled shoe track from 10419' to 14,019.0 14,125.0 18:00 21:45 14125'. Tagged float collar at 14067'. Tagged shoe at 14115'. Clean out rathole to 14125'. Rotated @ 60 rpm Pumped at 200 gpm Standpipe pressure = 2350 psi Flow out = 28% WOB = 5-15 kips P/U = 250 kips S/O = 70 kips Rot = 105 kips Torque off bottom = 15 k -ft -lbs 2/4/2017 2/4/2017 0.50 INTRM2 CEMENT DDRL P Directionally drilled 20' of new 14,125.0 14,145.0 21:45 22:15 formation to 14145' (6089' TVD). Rotated @ 60 rpm Pumped at 200 gpm Standpipe pressure = 2350 psi Flow out = 28% WOB = 5-15 kips P/U = 250 kips S/O = 70 kips Rot = 105 kips Torque off bottom = 15 k -ft -lbs 2/4/2017 2/4/2017 1.25 INTRM2 CEMENT CIRC P Circulate and condition mud while 14,145.0 14,065.0 22:15 23:30 reciprocating. Rack back one stand. Rotated @ 60 rpm Pumped at 200 gpm Standpipe pressure = 2350 psi Flow out = 28% WOB = N/A kips P/U = 250 kips S/O = 70 kips Rot = 105 kips Torque off bottom = 15 k -ft -lbs Page 47/69 Report Printed: 2/2712017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/4/2017 2/5/2017 0.50 INTRM2 CEMENT FIT P Perform FIT to 14.5 ppg EMW. 14,065.0 14,065.0 23:30 00:00 Pressure = 950 psi Mud weight = 11.5 ppg TVD @ shoe = 6085' TVD Volume pumped = 26 strokes = 2.6 bbl Volume bled back =.8 bbl SI for 10 minutes: Starting pressure = 950 psi Finish pressure = 850 psi 2/5/2017 2/5/2017 0.50 INTRM2 CEMENT FIT P Rig down FIT test equipment and blow 14,065.0 14,065.0 00:00 00:30 down kill line 2/5/2017 2/5/2017 0.75 PROD1 DRILL MPDA P Pull trip nipple. Install RCD bearing 14,065.0 14,065.0 00:30 01:15 2/5/2017 2/5/2017 0.50 PROD1 DRILL MPDA P Establish injection rate through MPD 14,065.0 14,065.0 01:15 01:45 chokes @ 200 gpm--2850 psi. Calibrate chokes 2/5/2017 2/5/2017 1.75 PROD1 DRILL DDRL P Drill from 14145' to 14161' while 14,065.0 14,161.0 01:45 03:30 displacing the well to 10.5 ppg Flo -pro water-based drilling fluid. Pump 30 bbl hi -vis spacer followed by 500 bbl of 10.5 ppg mud @ 240 gpm, Obtain slow pump rates Slow pump rates: Depth 14161' MD Depth 6099' TVD Mud Weight = 10.5 ppg Time 03:00 hours 30 spm 40 spm Pump #1 1380 psi 1600 psi Pump #2 1392 psi 1775 psi OA pressure held by MPD system = 780 psi Page 48169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/5/2017 2/5/2017 4.25 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 14,161.0 14,445.0 03:30 07:45 from 14161' to 14445' (6099' TVD) ART = 2.67 hrs ADT = 2.67 hrs Bit hours = 2.67 hrs Total jar hours = 2.67 hrs P/U = 220 kips S/O = 50 kips Rot = 100 kips Top drive rpm = 80 rpm Torque on bottom = 17 kft-lbs Torque off bottom = 16 kft-lbs ECD = 13.2 ppg EMW Flow in = 240 gpm Total pump strokes = 57 spm Flow out = 25% Standpipe pressure = 3050 psi Max gas = 212 units 2/5/2017 2/5/2017 3.25 PROD1 DRILL MPDA T Trouble shoot and unplug MPD 14,445.0 14,445.0 07:45 11:00 chokes while reciprocating drillstring. Circulate and 200 gpm--2475 psi. 2/5/2017 2/5/2017 1.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 14,445.0 14,542.0 11:00 12:00 from 14445' to 14542' (6088' TVD) ART = 4.35 hrs ADT = 4.35 hrs Bit hours = 4.35 hrs Total jar hours = 4.35 hrs P/U = 220 kips S/O = 50 kips Rot = 100 kips WOB - 10-12 kips Top drive rpm = 80 rpm Torque on bottom = 17 kft-lbs Torque off bottom = 16 kft-lbs ECD = 13.08 ppg EMW Flow in = 240 gpm Total pump strokes = 57 spm Flow out = 33% Standpipe pressure = 3050 psi Max gas = 145 units Page 49/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 2/5/2017 2/5/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 14,542.0 14,893.0 12:00 18:00 from 14542' to 14893' (6062' TVD) ART = 4.08 hrs ADT = 8.43 hrs Bit hours = 8.43 hrs Total jar hours = 8.43 hrs P/U = 205 kips S/O = 50 kips Rot = 95 kips WOB - 8-14 kips Top drive rpm = 80 rpm Torque on bottom = 17 kft-lbs Torque off bottom = 16 kft-lbs ECD = 13.08 ppg EMW Flow in = 240 gpm Total pump strokes = 57 spm Flow out = 30% Standpipe pressure = 3100 psi Max gas = 484 units Page 50169 Report Printed: 2/27/2017 w' Operations Summary (with Timelog Depths) 2M-38 r i ♦ ' Rig: DOYON 141 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) 2/5/2017 2/6/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 14,893.0 15,297.0 18:00 00:00 from 14893' to 15297' (6063' TVD) ART = 4.17 hrs ADT = 12.6 hrs Bit hours = 12.6 hrs Total jar hours = 12.6 hrs P/U = 200 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 120 rpm Torque on bottom = 17 kft-lbs Torque off bottom = 16 kft-lbs ECD = 13.24 ppg EMW Flow in = 240 gpm Total pump strokes = 57 spm Flow out = 30% Standpipe pressure = 3200 psi Max gas = 469 units Slow pump rates: Depth 15202' MD Depth 6064' TVD Mud Weight = 10.5 ppg Time 22:00 hours 20 spm 30 spm Pump #1 840 psi 1240 psi Pump #2 820 psi 1220 psi OA pressure held by MPD system = 520 psi Page 51/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 A .. 1.0 •'r1 . Rig: DOYON 141 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) 2/6/2017 2/6/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 15,297.0 15,730.0 00:00 06:00 from 15297' to 15730' (6070' TVD) ART = 4.72 hrs ADT = 4.72 hrs Bit hours = 17.32 hrs Total jar hours = 17.32 hrs P/U = 202 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 130 rpm Torque on bottom = 18 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.24 ppg EMW Flow in = 250 gpm Total pump strokes = 59 spm Flow out = 33% Standpipe pressure = 3290 psi Max gas = 385 units OA pressure = 1100 psi Page 52/69 Report Printed: 2/27/2017 ,. Operations Summary (with Timelog Depths) t,F.wl 2M-38 Rig: DOYON 141 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) 2/6/2017 2/6/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 15,730.0 16,150.0 06:00 12:00 from 15730' to 16150 (6070' TVD) ART = 4.28 hrs ADT = 4.28 hrs Bit hours = 21.60 hrs Total jar hours = 21.0 hrs P/U = 205 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 120 rpm Torque on bottom = 18 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.29 ppg EMW Flow in = 250 gpm Total pump strokes = 59 spm Flow out = 33% Standpipe pressure = 3290 psi Max gas = 629 units Slow pump rates: Depth 16063' MD Depth 6077' TVD Mud Weight = 10.5 ppg Time 11:30 hours 20 spm 30 spm Pump #1 940 psi 1270 psi Pump #2 910 psi 1300 psi Page 53/69 Report Printed: 2/27/2017 ,- Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/6/2017 2/6/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 16,150.0 16,653.0 12:00 18:00 from 16150' to 16653' (6070' TVD) ART = 4.28 hrs ADT = 4.28 hrs Bit hours = 21.60 hrs Total jar hours = 21.60 hrs P/U = 205 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 120 rpm Torque on bottom = 19 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.43 ppg EMW Flow in = 247 gpm Total pump strokes = 58 spm Flow out = 33% Standpipe pressure = 3300 psi Max gas = 446 units Page 54/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/6/2017 2/7/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 16,653.0 17,000.0 18:00 00:00 from 16653' to 17000 (6108' TVD) ART = 4.28 hrs ADT = 4.28 hrs Bit hours = 30.56 hrs Total jar hours = 30.56 hrs P/U = 205 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 120 rpm Torque on bottom = 19 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.43 ppg EMW Flow in = 240 gpm Total pump strokes = 57 spm Flow out = 33% Standpipe pressure = 3200 psi Max gas = 343 units Slow pump rates: Depth 16840' MD Depth 6100' TVD Mud Weight = 10.5 ppg Time 22:18 hours 20 spm 30 spm Pump #1 825 psi 1155 psi Pump #2 790 psi 1165 psi Page 55/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/7/2017 2/7/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 17,000.0 17,474.0 00:00 06:00 from 17000' to 17474' (6068' TVD) ART = 4.75 hrs ADT = 4.75 hrs Bit hours = 35.30 hrs Total jar hours = 35.30 hrs P/U = 210 kips S/O = 0 kips Rot = 95 kips WOB - 5-10 kips Top drive rpm = 120 rpm Torque on bottom = 18-19 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.23 ppg EMW Flow in = 240 gpm Total pump strokes = 58 spm Flow out = 32% Standpipe pressure = 3190 psi Max gas = 569 units Page 56/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 160 2M-38 Ww Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Star! Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 2/7/2017 2/7/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 17,474.0 17,781.0 06:00 12:00 from 17474' to 17781 (6048' TVD) ART = 3.43 hrs ADT = 3.34 hrs Bit hours = 38.73 hrs Total jar hours = 38.73 hrs P/U = 220 kips S/O = 45 kips Rot = 105 kips WOB - 5-10 kips Top drive rpm = 120-140 rpm Torque on bottom = 18-20 kft-lbs Torque off bottom = 17 kft-lbs ECD = 13.32 ppg EMW Flow in = 240-260 gpm Total pump strokes = 59-61 spm Flow out = 32% Standpipe pressure = 3300 psi Max gas = 765 units Slow pump rates: Depth 17766' MD Depth 6051' TVD Mud Weight = 10.5 ppg Time 10:30 hours 20 spm 30 spm Pump #1 750 psi 1150 psi Pump #2 780 psi 1170 psi Page 57169 Report Printed: 2/27/2017 .T Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/7/2017 2/7/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 17,781.0 18,116.0 12:00 18:00 from 17781' to 18116' (6052' TVD) ART = 4.73 hrs ADT = 4.73 hrs Bit hours = 43.46 hrs Total jar hours = 43.46 hrs P/U = 210 kips S/O = 0 kips Rot = 103 kips WOB - 5-10 kips Top drive rpm = 140 rpm Torque on bottom = 19-20 kft-lbs Torque off bottom = 18 kft-lbs ECD = 13.30 ppg EMW Flow in = 247 gpm Total pump strokes = 58 spm Flow out = 32% Standpipe pressure = 3400 psi Max gas = 414 units Page 58169 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 46 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 2/7/2017 2/8/2017 6.00 PROD1 DRILL DDRL P Directionally 6-1/8" production hole 18,116.0 18,483.0 18:00 00:00 from 18116' to 18483' (6050' TVD) ART = 4.47 hrs ADT = 4.47 hrs Bit hours = 48.20 hrs Total jar hours = 48.20 hrs P/U = 215 kips S/O = 0 kips Rot = 109 kips WOB - 5-10 kips Top drive rpm = 140 rpm Torque on bottom = 19-20 kft-lbs Torque off bottom = 19 kft-lbs ECD = 13.53 ppg EMW Flow in = 249 gpm Total pump strokes = 58 spm Flow out = 32% Standpipe pressure = 3400 psi Max gas = 663 units Slow pump rates: Depth 18391' MD Depth 6053' TVD Mud Weight = 10.5 ppg Time 22:15 hours 20 spm 30 spm Pump #1 780 psi 1230 psi Pump #2 800 psi 1170 psi 2/8/2017 2/8/2017 1.25 PROD1 CASING CIRC P CBU, Downlink and shoot final survey. 18,483.0 18,483.0 00:00 01:15 4300 stks total. 250 GPM 140 RPM 18-20 kft-Ib TQ 3400 psi SPP 2/8/2017 2/8/2017 0.50 PROD1 CASING OWFF P Perform MPD no -flow test by trapping 18,483.0 18,483.0 01:15 01:45 310 psi (11.5 ppg EMW). Pressure bled down to 130 psi (10.9 ppg EMW) over 20 minutes. 2/8/2017 2/8/2017 1.00 PROD1 CASING CIRC P CBU, 18,483.0 18,483.0 01:45 02:45 250 GPM 140 RPM 18-20 kft-Ib TQ 3400 psi SPP Page 59169 Report Printed: 2/27/2017 M Kms'' Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/8/2017 2/8/2017 9.25 PROD1 CASING BKRM P BROOH f/ 18,483' MD U 16,500' MD. 18,483.0 16,500.0 02:45 12:00 240 GPM 140 RPM 17-19 kft-Ib TQ 500-1000 FPH Flow out 32 % 2/8/2017 2/8/2017 7.50 PROD1 CASING BKRM P BROOH f/ 16500' MD to 14068' MD. 16,500.0 14,068.0 12:00 19:30 240 GPM 140 RPM 17-19 kft-Ib TQ 500-1000 FPH Flow out 32 % 2/8/2017 2/9/2017 4.50 PROD1 CASING CIRC P Circulate at 240 gpm and 2700 psi 14,068.0 14,068.0 19:30 00:00 while rotating and reciprocating. Flow out = 58%. S/O = 100 kips P/U = 175 kips Torque = 15 kft-lbs 2/9/2017 2/9/2017 1.00 PROD1 CASING CIRC P Continue circulating at 240 gpm--2700 14,068.0 14,068.0 00:00 01:00 psi Flow out = 58% P/U = 75 kips S/O = 100 kips Rotate @ 120 rpm Torque = 15 Kft-lbs 2/9/2017 2/9/2017 0.75 PROD1 CASING DISP P Displace well to kill weight brine. 14,068.0 14,068.0 01:00 01:45 Pump 60 bbl hi -vis pill followed by 600 bbl brine at 230 gpm, Spot 30 bbl brine in annulus and leave 30 bbl brine in drillpipe. 2/9/2017 2/9/2017 0.75 PROD1 CASING SMPD P Strip out of the hole 6 stands from 14,068.0 13,500.0 01:45 02:30 14068' to 13500' holding 400 psi on annulus when in slips and 350 psi on annulus while pulling 1000 fph. P/U = 180 kips S/O = 70 kips 2/9/2017 2/9/2017 1.25 PROD1 CASING DISP P Finish displacing well to 11.8 ppg 13,500.0 13,500.0 02:30 03:45 brine 2/9/2017 2/9/2017 0.50 PROD1 CASING OWFF P Monitor well for flow for 30 minutes --- 13,500.0 13,500.0 03:45 04:15 Dead 2/9/2017 2/9/2017 0.50 PROD1 CASING MPDA P Flush MPD system with fleshwater 13,500.0 13,500.0 04:15 04:45 and blow down 2/9/2017 2/9/2017 0.75 PROD1 CASING MPDA P Remove RCD bearing and install trip 13,500.0 13,500.0 04:45 05:30 nipple 2/9/2017 2/9/2017 6.50 PROD1 CASING TRIP P Drop 2" hollow rabbit on stand #139. 13,500.0 1,474.0 05:30 12:00 POOH from 13500' to 1474' Losses during trip = 14 bbl 2/9/2017 2/9/2017 0.50 PROD1 CASING TRIP P Continue POOH from 1474' to 474' 1,474.0 474.0 12:00 12:30 Page 60/69 Report Printed: 2/27/2017 Y Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 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) 2/9/2017 2/9/2017 0.50 PROD1 CASING OWFF P Monitor well for losses or gains-- slight 474.0 474.0 12:30 13:00 Posses. 2/9/2017 2/9/2017 1.50 PROD1 CASING BHAH P Lay down BHA 474.0 0.0 13:00 14:30 2/9/2017 2/9/2017 0.50 COMPZN CASING OWFF P Monitor well while clearing rig floor 0.0 0.0 14:30 15:00 2/9/2017 2/9/2017 1.00 COMPZN CASING RURD P Rig up casing tongs, slips and 0.0 0.0 15:00 16:00 elevators 2/9/2017 2/9/2017 4.50 COMPZN CASING PUTB P Pick up 4-1/2" 12.6# L-80 TXP blank 0.0 4,892.0 16:00 20:30 and perforated liner. Make up 7400 ft- lbs 2/9/2017 2/9/2017 1.50 COMPZN CASING OTHR P Make up 7" x 4-1/2" liner hanger. Fill 4,892.0 4,892.0 20:30 22:00 top of liner hanger with Pal-Mix. Circulate through liner at 3 bpm @ 150 psi. P/U = 72 kips S/O = 62 kips Rot = 65 kips Torque = 3 Kft-lbs 2/9/2017 2/9/2017 0.50 COMPZN CASING RURD P Rig down casing tongs, slips and 4,892.0 4,892.0 22:00 22:30 elevators. Prep to run drillpipe 2/9/2017 2/9/2017 1.00 COMPZN CASING SVRG P Service rig, top drive, drawworks, 4,892.0 4,892.0 22:30 23:30 ironroughneck. 2/9/2017 2/10/2017 0.50 COMPZN CASING RUNL P Continue RIH with 4-1/2" liner on 4" 4,892.0 5,554.7 23:30 00:00 drillpipe from 4892' to 5554.7' P/U = 75 kips S/O = 65 kips 2/10/2017 2/10/2017 3.75 COMPZN CASING RUNL P Continue running in the hole with 41/2" 5,554.7 14,080.0 00:00 03:45 liner on 4" drillpipe from 5554' to 14080' 2/10/2017 2/10/2017 0.50 COMPZN CASING CIRC P Circulate 950 strokes at 4 bpm @ 690 14,080.0 14,080.0 03:45 04:15 psi. P/U = 168 kips S/O = 83 kips ROT = 105 kips @ 20 rpm Torque = 9 Kft-lbs 2/10/2017 2/10/2017 4.00 COMPZN CASING RUNL P Continue running in the hole with 41/2" 14,080.0 18,483.0 04:15 08:15 liner on 4" drillpipe from 14080' to 18483' 2/10/2017 2/10/2017 1.75 COMPZN CASING CIRC P Circulate 3542 strokes at 4 bpm @ 18,483.0 18,483.0 08:15 10:00 900 psi. P/U = 190 kips S/O = 71 kips 2/10/2017 2/10/2017 1.00 COMPZN CASING PACK P Drop 1.62" setting ball. Pick up to set 18,483.0 13,589.0 10:00 11:00 liner on depth at 18473'. Pump down at 4 bpm and slow down to 2 bpm until ball on seat. Pressure up to 2300 psi to set liner hanger. Increase pressure to 3500 psi to release running tool. Pick up to expose dogs. Set down to 40 kips and rotate at 10 rpm to set liner top packer. Page 61/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 am Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 2/10/2017 2/10/2017 0.50 COMPZN CASING PRTS P Pressure test Liner Top Packer to 13,589.0 13,589.0 11:00 11:30 3500 psi for 10 minutes. Recorded test on chart. Good test 2/10/2017 2/10/2017 0.50 COMPZN WELLPR RURD P Blow down top drive and kill line. 13,589.0 13,440.0 11:30 12:00 POOH to 13440' 2/10/2017 2/10/2017 0.50 COMPZN WELLPR OWFF P Monitor well for 30 minutes. Static 13,440.0 13,440.0 12:00 12:30 losses = 2 bph 2/10/2017 2/10/2017 1.00 COMPZN WELLPR SLPC P Cut and slip 52' of 1-3/8" drilling line 13,440.0 13,440.0 12:30 13:30 2/10/2017 2/10/2017 4.50 COMPZN WELLPR PULD P Lay down 4" drill pipe from 13440' to 13,440.0 7,600.0 13:30 18:00 7600' 2/10/2017 2/10/2017 0.50 COMPZN WELLPR SVRG P Service top drive and iron roughneck 7,600.0 7,600.0 18:00 18:30 2/10/2017 2/10/2017 4.50 COMPZN WELLPR PULD P Continue laying down 4" drillpipe from 7,600.0 0.0 18:30 23:00 7600' to surface. Lay down liner running tool 2/10/2017 2/10/2017 0.50 COMPZN WELLPR RURD P Clear rig floor 0.0 0.0 23:00 23:30 2/10/2017 2/11/2017 0.50 COMPZN WELLPR TRIP P RIH with 9 stand of HWDP from 0.0 840.0 23:30 00:00 derrick 2/11/2017 2/11/2017 1.50 COMPZN WELLPR TRIP P Continue running in hole with 840.0 3,506.0 00:00 01:30 remaining 4" drillpipe and HWDP from derrick 2/11/2017 2/11/2017 3.75 COMPZN WELLPR PULD P Lay down 4" drillpipe and HWDP from 3,506.0 0.0 01:30 05:15 the derrick 2/11/2017 2/11/2017 1.25 COMPZN WELLPR PULD P Rig up mousehole and lay down 0.0 0.0 05:15 06:30 remaining 2 stands of 4" HWDP. Remove trapped rabbits and rig down mousehole 2/11/2017 2/11/2017 0.50 COMPZN RPCOMP RURD P Pull wear ring and flush stack. 0.0 0.0 06:30 07:00 2/11/2017 2/11/2017 1.00 COMPZN RPCOMP RURD P Clear rig floor and rig up to run 3-1/2" 0.0 0.0 07:00 08:00 completion string 2/11/2017 2/11/2017 4.00 COMPZN RPCOMP PUTB P Run 3-1/2" 9.3#, L-80 EUE-mod tubing 0.0 2,045.0 08:00 12:00 to 2045' 2/11/2017 2/11/2017 9.50 COMPZN RPCOMP PUTB P Run 3-1/2" 9.3#, L-80 EUE-mod tubing 2,045.0 13,590.0 12:00 21:30 from 2045' to 13590'. P/U = 102 kips S/O = 62 kips 2/11/2017 2/12/2017 2.50 COMPZN RPCOMP HOSO P RIH and tag at 13582'. Rotate 1/2 turn 13,590.0 13,643.5 21:30 00:00 and work torque down. Continue to RIH to 13634' with charge pump on. Bleed off pressure and tag at 13643.5' (6' high). Attempt to pressure up on IA and had communication to tubing. Drop ball/rod and allow to fall for 15 minutes. Presssure up on tubing to 2000 psi with slight bleed off 2/12/2017 2/12/2017 1.00 COMPZN RPCOMP PRTS T Pressure up on tubing to 2000 psi. 13,643.5 13,643.5 00:00 01:00 Had returns up the IA.. Pressure up on IA. Tubing pressure and IA pressure equalized. 2/12/2017 2/12/2017 0.50 COMPZN RPCOMP PRTS T Pressure up tubing and IA 13,643.5 13,643.5 01:00 01:30 simultaneously to 2500 psi. Pressure held for 10 minutes Page 62/69 Report Printed: 2/27/2017 Operations Summary (with Timelog Depths) 2M-38 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Activity Code Time P -LX Operation (ftKB) End Depth (ftKB) 2/12/2017 2/12/2017 2.00 COMPZN RPCOMP HOSO P Slack off to no-go at 13662.54', 19.5' 13,643.5 13,662.5 01:30 03:30 in on joint #426. Lay down 3 joints. Make up space out pups (8.17', 8.12', 2.27'). crossover, one joint of 4-1/2" IBT tubing and tubing hanger. Seal locator located 6.23' above fully located position. Make up landing joint 2/12/2017 2/12/2017 0.25 COMPZN RPCOMP THGR P Drain BOP stack and blow down lines 13,662.5 13,662.5 03:30 03:45 2/12/2017 2/12/2017 0.75 COMPZN RPCOMP THGR P Land tubing hanger and RILDS 13,662.5 13,662.5 03:45 04:30 2/12/2017 2/12/2017 0.75 COMPZN RPCOMP PRTS P Pressure test tubing and annulus 13,662.5 13,662.5 04:30 05:15 simultaneously to 3500 psi for 30 minutes. Bled off tubing in see if SOV would shear. IA pressure bled off slowly -10 minutess 2/12/2017 2/12/2017 0.50 COMPZN RPCOMP OWFF P Monitor well for 30 minutes -dead 13,662.5 13,662.5 05:15 05:45 2/12/2017 2/12/2017 0.50 COMPZN RPCOMP RURD P Lay down landing joint and blow down 13,662.5 0.0 05:45 06:15 lines 2/12/2017 2/12/2017 0.50 COMPZN WHDBOP MPSP P Set Type H BPV with dry rod. Test IA 0.0 0.0 06:15 06:45 to 2500 psi to verify BPV holding in direction of potential flow 2/12/2017 2/12/2017 5.25 COMPZN WHDBOP SVRG P Open BOP Ram doors and remove 0.0 0.0 06:45 12:00 rams. Grease wear plates. Remove MPD lines. 2/12/2017 2/12/2017 4.50 COMPZN WHDBOP MPDA P Remove MPD equipment and 0.0 0.0 12:00 16:30 scaffolding. Set stack back on stump 2/12/2017 2/12/2017 1.75 COMPZN WHDBOP NUND P Prep wellhead. Install tubing head 0.0 0.0 16:30 18:15 adapter and test to 250/5000 psi. 2/12/2017 2/12/2017 2.25 COMPZN WHDBOP NUND P Nipple up Xmas tree. Pull BPV and 0.0 0.0 18:15 20:30 install two-way check. Pressure test tree to 250/5000 psi. Pull two-way check 2/12/2017 2/12/2017 0.50 COMPZN WHDBOP FRZP P Rig up lines to freeze protect 0.0 0.0 20:30 21:00 2/12/2017 2/12/2017 1.50 COMPZN WHDBOP FRZP P Pressure test lines to 2500 psi. Pump 0.0 0.0 21:00 22:30 75 bbl diesel down IA. Initial rate of 2 bpm @ 1400 psi. Reduced rate to 1 bpm @ 1100 psi. FCP = - 1100 psi. Pumped 75 bbl had returns of 73.5 bbl brine 2/12/2017 2/12/2017 1.00 COMPZN WHDBOP FRZP P Put tubing and IA into communication 0.0 0.0 22:30 23:30 at surface. Allow diesel to equalize between tubing and IA. Final pressures: TP = 450 psi. IA = 450 psi 2/12/2017 2/13/2017 1.00 COMPZN WHDBOP FRZP P Rig down freeze protect lines and 0.0 0.0 23:30 00:30 blow down 2/13/2017 2/13/2017 1.00 COMPZN WHDBOP NUND P Install gauges and flanges on Xmas 0.0 0.0 00:00 01:00 tree 2/13/2017 2/13/2017 1.00 COMPZN WHDBOP MPSP P Install BPV. Tubing pressure = 450 0.0 0.0 01:00 02:00 psi. IA = 450 psi. Secure tree. Release rig at 02:00 hours on 2/13/2017 Page 63/69 Report Printed: 2/27/2017 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-38 2M-38 Definitive Survey Report 27 February, 2017 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 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 2M-38 Well Position +N/ -S 0.00 usft Northing: 5,948,986.00 usft Latitude: 70° 16'18.587 N +E/ -W 0.00 usft Easting: 488,364.41 usft Longitude: 150° 5'38.782 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-38 Magnetics Model Name Sample Date Declination Dip Angle Field Strength MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing BG GM2016 1/20/2017 17.67 80.88 57,533 (°) (I (usft) (usft) (usft) (usft) (ft) Design 2M-38 (ft) Survey Tool Name 29.57 0.00 0.00 Audit Notes: -101.30 0.00 0.00 5,948,986.00 488,364.41 Version: 1.0 Phase: ACTUAL Tie On Depth: 29.57 95.41 74.39 Vertical Section: Depth From (TVD) +N1 -S +E1 -W Direction 488,364.60 1.09 -0.18 GYD-GC-SS (1) (usft) (usft) (usft) (°) 110.00 -20.87 -0.04 29.57 0.00 0.00 260.00 0.24 -0.45 GYD-GC-SS (1) 30" x 20" Survey Program Date 166.39 0.27 From To 35.52 -0.05 0.80 5,948,985.95 (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 74.39 809.01 2M-38 Srvy 1 - SLB_GWD70 (2M-38) GYD-GC-SS Gyrodata gyro single shots 1/3/2017 9:35:0 847.52 2,952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/3/2017 9:37:0 3,005.44 3,005.44 2M-38 Srvy 3 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 1/10/2017 9:26: 3,098.07 13,236.61 2M-38 Srvy 4 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/10/2017 9:27: 13,314.99 13,314.99 2M-38 Srvy 5 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer+ known azi trend 1/28/2017 9:48: 13,408.66 14,047.29 2M-38 Srvy 6 - SLB _MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/28/2017 9:49: 14,095.43 14,095.43 2M-38 Srvy 7 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 2/5/2017 3:00:0 14,192.33 18,423.35 2M-38 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2017 3:24:0 Survey M712017 Z'W48PM Page 2 COMPASS 5000 1 Budd 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E1 -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 29.57 0.00 0.00 29.57 -101.30 0.00 0.00 5,948,986.00 488,364.41 0.00 0.00 UNDEFINED 74.39 0.49 95.41 74.39 -56.48 -0.02 0.19 5,948,985.98 488,364.60 1.09 -0.18 GYD-GC-SS (1) 110.00 0.40 93.46 110.00 -20.87 -0.04 0.47 5,948,985.96 488,364.87 0.24 -0.45 GYD-GC-SS (1) 30" x 20" 166.39 0.27 87.83 166.39 35.52 -0.05 0.80 5,948,985.95 488,365.21 0.24 -0.78 GYD-GC-SS (1) 260.70 2.18 158.80 260.67 129.80 -1.71 1.67 5,948,984.29 488,366.07 2.23 -1.35 GYD-GC-SS (1) 350.18 3.32 159.75 350.05 219.18 -5.73 3.18 5,948,980.27 488,367.58 1.28 -2.14 GYD-GC-SS (1) 444.01 5.98 165.98 443.56 312.69 -13.02 5.31 5,948,972.97 488,369.69 2.88 -2.97 GYD-GC-SS (1) M712017 Z'W48PM Page 2 COMPASS 5000 1 Budd 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting OLS Section (tuft) r) (1) (usft) (usft) (usft) (usft) (ft) (ft) ('/100•) (ft) Survey Tool Name 535.02 6.18 173.63 534.06 403.19 -22.49 7.00 5,948,963.50 488,371.37 0.92 -2.99 GYD-GC-SS(1) 626.51 6.81 180.04 624.97 494.10 -32.81 7.54 5,948,953.18 488,371.90 1.05 -1.73 GYD-GC-SS(1) 718.62 4.71 178.70 716.61 585.74 -42.05 7.62 5,948,943.94 488,371.97 2.28 -0.21 GYD-GC-SS (1) 809.01 6.55 179.77 806.56 675.69 -50.92 7.73 5,948,935.08 488,372.06 2.04 1.23 GYD-GC-SS(1) 847.52 7.60 181.94 844.77 713.90 -55.66 7.65 5,948,930.34 488,371.97 2.81 2.13 MWD+IFR-AK-CAZ-SC (2) 940.13 10.47 185.54 936.22 805.35 -70.16 6.63 5,948,915.84 488,370.93 3.16 5.65 MWD+IFR-AK-CAZ-SC (2) 1,034.52 11.93 184.22 1,028.81 897.94 -88.42 5.09 5,948,897.58 488,369.36 1.57 10.35 MWD+IFR-AK-CAZ-SC (2) 1,127.77 13.34 182.66 1,119.80 988.93 -108.78 3.88 5,948,877.22 488,368.12 1.56 15.07 MWD+IFR-AK-CAZ-SC (2) 1,221.58 18.99 178.84 1,209.87 1,079.00 -134.88 3.68 5,948,851.13 488,367.88 6.13 19.79 MWD+IFR-AK-CAZ-SC (2) 1,315.01 22.92 177.26 1,297.10 1,166.23 -168.26 4.86 5,948,817.75 488,369.01 4.25 24.43 MWD+IFR-AK-CAZ-SC (2) 1,407.64 23.11 178.16 1,382.36 1,251.49 -204.45 6.31 5,948,781.57 488,370.40 0.43 29.29 MWD+IFR-AK-CAZ-SC (2) 1,500.06 22.58 178.66 1,467.53 1,336.66 -240.31 7.30 5,948,745.70 488,371.34 0.61 34.54 MWD+IFR-AK-CAZ-SC (2) 1,593.04 27.05 185.87 1,551.93 1,421.06 -279.22 5.56 5,948,706.80 488,369.53 5.80 43.01 MWD+IFR-AK-CAZ-SC (2) 1,687.70 26.42 193.25 1,636.49 1,505.62 -321.14 -1.47 5,948,664.89 488,362.44 3.57 57.21 MWD+IFR-AK-CAZ-SC (2) 1,779.53 27.50 199.10 1,718.35 1,587.48 -361.07 -13.09 5,948,624.99 488,350.76 3.12 75.59 MWD+IFR-AK-CAZ-SC (2) 1,872.17 28.34 207.74 1,800.24 1,669.37 -400.76 -30.33 5,948,585.33 488,333.46 4.46 99.46 MWD+IFR-AK-CAZ-SC (2) 1,965.74 26.51 216.65 1,883.33 1,752.46 437.19 -53.15 5,948,548.94 488,310.59 4.80 128.26 MWD+IFR-AK-CAZ-SC (2) 2,059.09 28.63 223.46 1,966.09 1,835.22 470.15 -80.98 5,948,516.03 488,282.71 4.07 161.39 MWD+IFR-AK-CAZ-SC (2) 2,150.45 30.57 228.86 2,045.54 1,914.67 -501.33 -113.54 5,948,484.90 488,250.10 3.61 198.87 MWD+IFR-AK-CAZ-SC (2) 2,242.21 33.31 234.74 2,123.42 1,992.55 -531.24 -151.70 5,948,455.05 488,211.90 4.51 241.65 MWD+IFR-AK-CAZ-SC (2) 2,336.09 37.44 238.74 2,199.96 2,069.09 -560.94 -197.17 5,948,425.42 488,166.39 5.04 291.58 MWD+IFR-AK-CAZ-SC (2) 2,430.23 41.42 241.73 2,272.67 2,141.80 -590.56 -249.08 5,948,395.89 488,114.44 4.68 347.85 MWD+IFR-AK-CAZ-SC (2) 2,521.66 44.56 242.74 2,339.54 2,208.67 -619.58 -304.25 5,948,366.95 488,059.23 3.52 407.21 MWD+IFR-AK-CAZ-SC (2) 2,617.38 46.68 246.74 2,406.50 2,275.63 -648.72 -366.11 5,948,337.91 487,997.33 3.72 473.20 MWD+IFR-AK-CAZ-SC (2) 2,710.86 49.33 249.13 2,469.04 2,338.17 -674.79 -430.49 5,948,311.95 487,932.92 3.41 541.13 MWD+IFR-AK-CAZ-SC (2) 2,803.36 51.01 250.40 2,528.29 2,397.42 -699.34 497.14 5,948,287.50 487,866.23 2.10 611.03 MWD+IFR-AK-CAZ-SC (2) 2,896.07 55.95 251.20 2,583.44 2,452.57 -723.82 -567.49 5,948,263.13 487,795.86 5.37 684.56 MWD+IFR-AK-CAZ-SC (2) 2,952.69 61.15 253.71 2,612.98 2,482.11 -738.35 -613.53 5,948,248.67 487,749.80 9.93 732.42 MWD+IFR-AK-CAZ-SC (2) 3,005.44 60.08 253.98 2,638.86 2,507.99 -751.14 -657.68 5,948,235.95 487,705.64 2.08 778.12 INC+TREND (3) 3,044.00 60.45 254.18 2,657.99 2,527.12 -760.32 -689.88 5,948,226.82 487,673.43 1.07 811.42 MWD+IFR-AK-CAZ-SC (4) 13 3/8" x 16" 3,098.07 60.98 254.46 2,684.43 2,553.56 -773.07 -735.28 5,948,214.15 487,628.00 1.07 858.35 MWD+IFR-AK-CAZ-SC (4) 3,192.17 61.75 254.76 2,729.53 2,598.66 -794.99 -814.91 5,948,192.36 487,548.35 0.86 940.58 MWD+IFR-AK-CAZ-SC (4) 3,286.28 63.19 257.18 2,773.03 2,642.16 -815.20 -895.87 5,948,172.26 487,467.37 2.75 1,023.81 MWD+IFR-AK-CAZ-SC (4) 3,379.73 64.50 261.19 2,814.24 2,683.37 -830.92 -978.24 5,948,156.68 487,384.99 4.10 1,107.66 MWD+IFR-AK-CAZ-SC (4) 3,472.76 65.69 264.63 2,853.42 2,722.55 -841.32 -1,061.95 5,948,146.41 487,301.26 3.59 1,191.91 MWD+IFR-AK-CAZ-SC (4) 3,565.38 66.85 265.41 2,890.69 2,759.82 -848.68 -1,146.42 5,948,139.18 487,216.79 1.47 1,276.37 MWD+IFR-AK-CAZ-SC (4) 3,659.05 70.41 266.50 2,924.82 2,793.95 -854.82 -1,233.42 5,948,133.17 487,129.79 3.95 1,363.12 MWD+IFR-AK-CAZ-SC (4) 3,750.72 71.88 268.51 2,954.45 2,823.58 -858.59 -1,320.08 5,948,129.54 487,043.14 2.62 1,449.12 MWD+IFR-AK-CAZ-SC (4) 3,845.19 72.85 270.01 2,983.07 2,852.20 -859.75 -1,410.10 5,948,128.52 486,953.12 1.83 1,537.97 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 2.50:49PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey Map Map Vertical MO Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting OLS Section (usft) 0 (°l (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,939.25 74.42 271.16 3,009.57 2,878.70 -858.83 -1,500.34 5,948,129.58 486,862.89 2.04 1,626.68 MWD+IFR-AK-CAZ-SC (4) 4,031.95 72.86 272.34 3,035.68 2,904.81 -856.11 -1,589.24 5,948,132.43 486,774.01 2.08 1,713.76 MWD+IFR-AK-CAZ-SC (4) 4,125.21 73.43 271.19 3,062.72 2,931.85 -853.37 -1,678.45 5,948,135.32 486,684.81 1.33 1,801.13 MWD+IFR-AK-CAZ-SC (4) 4,218.27 74.05 269.76 3,088.78 2,957.91 -852.63 -1,767.78 5,948,136.19 486,595.49 1.62 1,888.98 MWD+IFR-AK-CAZ-SC (4) 4,311.58 73.60 266.71 3,114.78 2,983.91 -855.38 -1,857.34 5,948,133.57 486,505.93 3.18 1,977.66 MWD+IFR-AK-CAZ-SC (4) 4,404.26 73.36 263.71 3,141.14 3,010.27 -862.80 -1,945.87 5,948,126.29 486,417.40 3.11 2,066.13 MWD+IFR-AK-CAZ-SC (4) 4,498.05 73.18 264.69 3,168.14 3,037.27 -871.88 -2,035.23 5,948,117.36 486,328.03 1.02 2,155.71 MWD+IFR-AK-CAZ-SC (4) 4,591.59 73.12 264.19 3,195.25 3,064.38 -880.55 -2,124.33 5,948,108.82 486,238.93 0.52 2,244.97 MWD+IFR-AK-CAZ-SC (4) 4,685.34 73.43 263.88 3,222.23 3,091.36 -889.88 -2,213.63 5,948,099.63 486,149.62 0.46 2,334.53 MWD+IFR-AK-CAZ-SC (4) 4,779.30 73.56 264.03 3,248.93 3,118.06 -899.37 -2,303.22 5,948,090.28 486,060.03 0.21 2,424.40 MWD+IFR-AK-CAZ-SC (4) 4,873.44 73.86 261.26 3,275.34 3,144.47 -910.94 -2,392.83 5,948,078.85 485,970.42 2.84 2,514.66 MWD+IFR-AK-CAZ-SC (4) 4,966.25 73.97 262.19 3,301.05 3,170.18 -923.77 -2,481.07 5,948,066.16 485,882.16 0.97 2,603.79 MWD+IFR-AK-CAZ-SC (4) 5,058.86 73.66 261.75 3,326.87 3,196.00 -936.20 -2,569.14 5,948,053.87 485,794.08 0.57 2,692.68 MWD+IFR-AK-CAZ-SC (4) 5,153.15 73.45 262.38 3,353.56 3,222.69 -948.68 -2,658.71 5,948,041.53 485,704.50 0.68 2,783.05 MWD+IFR-AK-CAZ-SC (4) 5,247.73 73.77 262.60 3,380.25 3,249.38 -960.54 -2,748.66 5,948,029.81 485,614.54 0.41 2,873.70 MWD+IFR-AK-CAZ-SC (4) 5,341.64 73.77 262.50 3,406.50 3,275.63 -972.23 -2,838.07 5,948,018.26 485,525.12 0.10 2,963.78 MWD+IFR-AK-CAZ-SC (4) 5,435.06 73.27 261.76 3,433.00 3,302.13 -984.50 -2,926.81 5,948,006.13 485,436.37 0.93 3,053.30 MWD+IFR-AK-CAZ-SC (4) 5,527.19 73.27 262.65 3,459.52 3,328.65 -996.46 -3,014.22 5,947,994.30 485,348.95 0.93 3,141.46 MWD+IFR-AK-CAZ-SC (4) 5,621.72 73.44 261.34 3,486.60 3,355.73 -1,009.07 -3,103.91 5,947,981.83 485,259.25 1.34 3,231.97 MWD+IFR-AK-CAZ-SC (4) 5,714.13 73.27 260.89 3,513.07 3,382.20 -1,022.75 -3,191.38 5,947,968.29 485,171.77 0.50 3,320.50 MWD+IFR-AK-CAZ-SC (4) 5,807.31 73.47 261.05 3,539.73 3,408.86 -1,036.76 -3,279.56 5,947,954.41 485,083.58 0.27 3,409.77 MWD+IFR-AK-CAZ-SC (4) 5,900.82 73.34 261.37 3,566.44 3,435.57 -1,050.46 -3,368.12 5,947,940.86 484,995.00 0.36 3,499.36 MWD+IFR-AK-CAZ-SC (4) 5,993.80 73.35 261.46 3,593.09 3,462.22 -1,063.75 -3,456.20 5,947,927.70 484,906.91 0.09 3,588.41 MWD+IFR-AK-CAZ-SC (4) 6,086.10 73.21 261.86 3,619.64 3,488.77 -1,076.58 -3,543.66 5,947,915.01 484,819.44 0.44 3,676.77 MWD+IFR-AK-CAZ-SC (4) 6,182.26 73.44 261.21 3,647.24 3,516.37 -1,090.14 -3,634.78 5,947,901.59 484,728.31 0.69 3,768.86 MWD+IFR-AK-CAZ-SC (4) 6,276.14 73.31 261.82 3,674.10 3,543.23 -1,103.41 -3,723.75 5,947,888.46 484,639.33 0.64 3,858.78 MWD+IFR-AK-CAZ-SC (4) 6,368.62 73.25 262.36 3,700.70 3,569.83 -1,115.60 -3,811.47 5,947,876.41 484,551.59 0.56 3,947.29 MWD+IFR-AK-CAZ-SC (4) 6,461.24 73.31 261.94 3,727.35 3,596.48 -1,127.71 -3,899.35 5,947,864.43 484,463.71 0.44 4,035.93 MWD+IFR-AK-CAZ-SC (4) 6,553.86 73.19 262.45 3,754.04 3,623.17 -1,139.76 -3,987.21 5,947,852.52 484,375.83 0.54 4,124.56 MWD+IFR-AK-CAZ-SC (4) 6,648.06 73.25 263.40 3,781.24 3,650.37 -1,150.87 14,076.73 5,947,841.55 484,286.31 0.97 4,214.65 MWD+IFR-AK-CAZ-SC (4) 6,741.43 73.09 262.96 3,808.27 3,677.40 -1,161.48 -4,165.45 5,947,831.08 484,197.58 0.48 4,303.86 MWD+IFR-AK-CAZ-SC (4) 6,835.33 73.29 264.22 3,835.43 3,704.56 -1,171.51 3,254.78 5,947,821.18 484,108.25 1.30 4,393.57 MWD+IFR-AK-CAZ-SC (4) 6,929.47 73.22 264.59 3,862.55 3,731.68 -1,180.30 -4,344.50 5,947,812.53 484,018.53 0.38 4,483.45 MWD+IFR-AK-CAZ-SC (4) 7,022.21 73.22 264.97 3,889.33 3,758.46 -1,188.38 -4,432.92 5,947,804.59 483,930.10 0.39 4,571.93 MWD+IFR-AK-CAZ-SC (4) 7,116.38 73.25 264.23 3,916.49 3,785.62 -1,196.87 -4,522.68 5,947,796.25 483,840.33 0.75 4,661.81 MWD+IFR-AK-CAZ-SC (4) 7,208.32 73.36 265.06 3,942.90 3,812.03 -1,205.08 14,610.36 5,947,788.17 483,752.65 0.87 4,749.58 MWD+IFR-AK-CAZ-SC (4) 7,301.34 73.34 264.53 3,969.55 3,838.68 -1,213.17 -4,699.12 5,947,780.22 483,663.89 0.55 4,838.39 MWD+IFR-AK-CAZ-SC (4) 7,394.54 73.27 262.42 3,996.33 3,865.46 -1,223.31 11,787.80 5,947,770.21 483,575.20 2.17 4,927.49 MWD+IFR-AK-CAZ-SC (4) 7,488.18 73.41 261.80 4,023.18 3,892.31 -1,235.63 -4;876.66 5,947,758.04 483,486.33 0.65 5,017.14 MWD+IFR-AK-CAZ-SC (4) 7,581.60 73.12 261.68 4,050.08 3,919.21 -1,248.48 -4,965.20 5,947,745.32 483,397.78 0.33 5,106.56 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 2:50.,49PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°11001) (ft) Survey Tool Name 7,673.37 73.35 261.79 4,076.55 3,945.68 -1,261.11 -5,052.15 5,947,732.83 483,310.81 0.28 5,194.39 MWD+IFR-AK-CAZ-SC (4) 7,767.11 73.13 261.64 4,103.58 3,972.71 -1,274.05 -5,140.98 5,947,720.03 483,221.98 0.28 5,284.11 MWD+IFR-AK-CAZ-SC (4) 7,859.59 73.31 261.60 4,130.28 3,999.41 -1,286.95 -5,228.57 5,947,707.26 483,134.37 0.20 5,372.62 MWD+IFR-AK-CAZ-SC (4) 7,952.95 73.61 262.65 4,156.86 4,025.99 -1,299.21 -5,317.22 5,947,695.14 483,045.71 1.13 5,462.05 MWD+IFR-AK-CAZ-SC (4) 8,047.09 73.26 262.58 4,183.70 4,052.83 -1,310.81 -5,406.71 5,947,683.68 482,956.22 0.38 5,552.19 MWD+IFR-AK-CAZ-SC (4) 8,140.76 73.64 263.04 4,210.38 4,079.51 -1,322.05 -5,495.79 5,947,672.58 482,867.13 0.62 5,641.87 MWD+IFR-AK-CAZ-SC (4) 8,232.78 73.78 263.36 4,236.19 4,105.32 -1,332.50 -5,583.50 5,947,662.26 482,779.42 0.37 5,730.06 MWD+IFR-AK-CAZ-SC (4) 8,326.46 74.10 264.09 4,262.11 4,131.24 -1,342.34 -5,672.98 5,947,652.56 482,689.93 0.82 5,819.89 MWD+IFR-AK-CAZ-SC (4) 8,420.57 73.83 264.65 4,288.10 4,157.23 -1,351.22 -5,762.99 5,947,643.83 482,599.91 0.64 5,910.07 MWD+IFR-AK-CAZ-SC (4) 8,512.73 74.03 265.02 4,313.61 4,182.74 -1,359.19 -5,851.19 5,947,635.99 482,511.71 0.44 5,998.32 MWD+IFR-AK-CAZ-SC (4) 8,606.38 74.10 265.43 4,339.32 4,208.45 -1,366.69 -5,940.93 5,947,628.64 482,421.97 0.43 6,087.99 MWD+IFR-AK-CAZ-SC (4) 8,700.38 73.75 265.54 4,365.35 4,234.48 -1,373.80 -6,030.97 5,947,621.67 482,331.92 0.39 6,177.91 MWD+IFR-AK-CAZ-SC (4) 8,792.78 73.64 264.92 4,391.29 4,260.42 -1,381.17 -6,119.35 5,947,614.43 482,243.54 0.65 6,266.22 MWD+IFR-AK-CAZ-SC (4) 8,888.08 73.33 264.04 4,418.38 4,287.51 -1,389.96 -6,210.29 5,947,605.78 482,152.59 0.94 6,357.31 MWD+IFR-AK-CAZ-SC (4) 8,980.80 73.47 264.17 4,444.87 4,314.00 -1,399.08 -6,298.68 5,947,596.79 482,064.20 0.20 6,445.94 MWD+IFR-AK-CAZ-SC (4) 9,074.16 73.12 264.06 4,471.71 4,340.84 -1,408.25 -6,387.63 5,947,587.76 481,975.25 0.39 6,535.12 MWD+IFR-AK-CAZ-SC (4) 9,169.42 73.12 262.90 4,499.37 4,368.50 -1,418.60 -6,478.19 5,947,577.56 481,884.68 1.17 6,626.11 MWD+IFR-AK-CAZ-SC (4) 9,261.89 73.37 263.85 4,526.03 4,395.16 -1,428.82 -6,566.14 5,947,567.48 481,796.72 1.02 6,714.50 MWD+IFR-AK-CAZ-SC (4) 9,355.29 73.48 262.86 4,552.67 4,421.80 -1,439.18 -6,655.06 5,947,557.26 481,707.80 1.02 6,803.86 MWD+IFR-AK-CAZ-SC (4) 9,449.25 73.49 263.43 4,579.38 4,448.51 -1,449.93 -6,744.50 5,947,546.64 481,618.35 0.58 6,893.81 MWD+IFR-AK-CAZ-SC (4) 9,541.68 73.55 262.12 4,605.61 4,474.74 -1,461.08 -6,832.43 5,947,535.63 481,530.41 1.36 6,982.34 MWD+IFR-AK-CAZ-SC (4) 9,636.38 73.55 263.16 4,632.42 4,501.55 -1,472.71 -6,922.50 5,947,524.14 481,440.33 1.05 7,073.06 MWD+IFR-AK-CAZ-SC (4) 9,730.46 73.58 262.46 4,659.04 4,528.17 -1,484.00 -7,012.03 5,947,512.99 481,350.80 0.71 7,163.19 MWD+IFR-AK-CAZ-SC (4) 9,822.97 73.36 262.92 4,685.36 4,554.49 -1,495.29 -7,099.99 5,947,501.84 481,262.82 0.53 7,251.78 MWD+IFR-AK-CAZ-SC (4) 9,915.77 73.43 262.97 4,711.88 4,581.01 -1,506.21 -7,188.25 5,947,491.05 481,174.56 0.09 7,340.59 MWD+IFR-AK-CAZ-SC (4) 10,010.19 73.64 263.68 4,738.64 4,607.77 -1,516.74 -7,278.18 5,947,480.67 481,084.62 0.75 7,430.99 MWD+IFR-AK-CAZ-SC (4) 10,103.41 73.49 262.53 4,765.02 4,634.15 -1,527.47 -7,366.94 5,947,470.07 480,995.85 1.19 7,520.27 MWD+IFR-AK-CAZ-SC (4) 10,197.02 73.28 263.40 4,791.79 4,660.92 -1,538.46 -7,455.97 5,947,459.23 480,906.81 0.92 7,609.85 MWD+IFR-AK-CAZ-SC (4) 10,291.59 73.20 263.77 4,819.06 4,688.19 -1,548.57 -7,545.95 5,947,449.25 480,816.82 0.38 7,700.22 MWD+IFR-AK-CAZ-SC (4) 10,384.94 72.90 262.42 4,846.27 4,715.40 -1,559.31 -7,634.60 5,947,438.65 480,728.17 1.42 7,789.38 MWD+IFR-AK-CAZ-SC (4) 10,480.08 73.07 263.39 4,874.11 4,743.24 -1,570.54 -7,724.88 5,947,427.56 480,637.88 0.99 7,880.24 MWD+IFR-AK-CAZ-SC (4) 10,573.68 73.35 264.46 4,901.15 4,770.28 -1,580.03 -7,813.98 5,947,418.21 480,548.77 1.13 7,969.64 MWD+IFR-AK-CAZ-SC (4) 10,666.32 72.98 264.72 4,927.98 4,797.11 -1,588.39 -7,902.26 5,947,409.99 480,460.49 0.48 8,058.02 MWD+IFR-AK-CAZ-SC (4) 10,760.20 73.12 264.56 4,955.35 4,824.48 -1,596.78 -7,991.67 5,947,401.74 480,371.08 0.22 8,147.53 MWD+IFR-AK-CAZ-SC (4) 10,854.04 73.50 264.33 4,982.30 4,851.43 -1,605.48 -8,081.13 5,947,393.18 480,281.61 0.47 8,237.15 MWD+IFR-AK-CAZ-SC (4) 10,947.19 73.55 264.82 5,008.72 4,877.85 -1,613.92 -8,170.06 5,947,384.87 480,192.68 0.51 8,326.19 MWD+IFR-AK-CAZ-SC (4) 11,039.89 73.42 264.40 5,035.07 4,904.20 -1,622.27 -8,258.54 5,947,376.66 480,104.20 0.46 8,414.78 MWD+IFR-AK-CAZ-SC (4) 11,133.42 73.61 265.02 5,061.61 4,930.74 -1,630.54 -8,347.84 5,947,368.53 480,014.89 0.67 8,504.16 MWD+IFR-AK-CAZ-SC (4) 11,224.58 73.64 264.74 5,087.31 4,956.44 -1,638.34 -8,434.95 5,947,360.86 479,927.77 0.30 8,591.30 MWD+IFR-AK-CAZ-SC (4) 11,319.87 73.55 265.69 5,114.22 4,983.35 -1,645.97 -8,526.04 5,947,353.38 479,836.68 0.96 8,682.33 MWD+IFR-AK-CAZ-SC (4) M712017 2 50-4gPM page 5 COMFIIASS 5000.1 Budd 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method`. Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,413.10 73.39 265.78 5,140.75 5,009.88 -1,652.62 -8,615.17 5,947,346.87 479,747.55 0.19 8,771.26 MWD+IFR-AK-CAZ-SC (4) 11,507.22 73.55 264.79 5,167.53 5,036.66 -1,660.03 -8,705.10 5,947,339.59 479,657.62 1.02 8,861.11 MWD+IFR-AK-CAZ-SC (4) 11,600.65 73.46 264.68 5,194.06 5,063.19 -1,668.25 -8,794.30 5,947,331.51 479,568.41 0.15 8,950.39 MWD+IFR-AK-CAZ-SC (4) 11,692.44 73.62 263.01 5,220.07 5,089.20 -1,677.69 -8,881.82 5,947,322.21 479,480.89 1.75 9,038.21 MWD+IFR-AK-CAZ-SC (4) 11,785.91 73.55 262.65 5,246.48 5,115.61 -1,688.88 -8,970.78 5,947,311.16 479,391.92 0.38 9,127.77 MWD+IFR-AK-CAZ-SC (4) 11,878.02 73.50 263.11 5,272.60 5,141.73 -1,699.83 -9,058.43 5,947,300.34 479,304.27 0.48 9,215.98 MWD+IFR-AK-CAZ-SC (4) 11,970.46 71.73 263.68 5,300.22 5,169.35 -1,709.98 -9,146.05 5,947,290.33 479,216.63 2.00 9,304.04 MWD+IFR-AK-CAZ-SC (4) 12,064.20 69.47 265.54 5,331.36 5,200.49 -1,718.29 -9,234.07 5,947,282.16 479,128.61 3.05 9,392.16 MWD+IFR-AK-CAZ-SC (4) 12,156.29 66.90 264.16 5,365.58 5,234.71 -1,725.96 -9,319.21 5,947,274.62 479,043.47 3.12 9,477.34 MWD+IFR-AK-CAZ-SC (4) 12,250.13 66.50 265.40 5,402.70 5,271.83 -1,733.80 -9,405.04 5,947,266.91 478,957.64 1.29 9,563.23 MWD+IFR-AK-CAZ-SC (4) 12,344.54 66.67 265.48 5,440.22 5,309.35 -1,740.69 -9,491.40 5,947,260.16 478,871.28 0.20 9,649.47 MWD+IFR-AK-CAZ-SC (4) 12,438.03 66.60 264.24 5,477.29 5,346.42 -1,748.38 -9,576.88 5,947,252.61 478,785.80 1.22 9,734.98 MWD+IFR-AK-CAZ-SC (4) 12,530.88 66.63 264.59 5,514.15 5,383.28 -1,756.67 -9,661.69 5,947,244.44 478,700.97 0.35 9,819.95 MWD+IFR-AK-CAZ-SC (4) 12,624.47 66.61 264.49 5,551.29 5,420.42 -1,764.85 -9,747.21 5,947,236.40 478,615.45 0.10 9,905.59 MWD+IFR-AK-CAZ-SC (4) 12,715.53 66.54 265.15 5,587.49 5,456.62 -1,772.39 -9,830.42 5,947,228.99 478,532.24 0.67 9,988.85 MWD+IFR-AK-CAZ-SC (4) 12,808.41 66.51 265.43 5,624.49 5,493.62 -1,779.38 -9,915.33 5,947,222.12 478,447.33 0.28 10,073.68 MWD+IFR-AK-CAZ-SC (4) 12,903.72 66.69 265.28 5,662.34 5,531.47 -1,786.47 -10,002.51 5,947,215.18 478,360.14 0.24 10,160.77 MWD+IFR-AK-CAZ-SC (4) 12,996.07 66.80 266.00 5,698.80 5,567.93 -1,792.92 -10,087.11 5,947,208.86 478,275.54 0.73 10,245.20 MWD+IFR-AK-CAZ-SC (4) 13,090.27 66.63 265.85 5,736.04 5,605.17 -1,799.07 -10,173.42 5,947,202.84 478,189.23 0.23 10,331.27 MWD+IFR-AK-CAZ-SC (4) 13,183.28 66.72 267.60 5,772.87 5,642.00 -1,803.95 -10,258.69 5,947,198.10 478,103.97 1.73 10,416.09 MWD+IFR-AK-CAZ-SC (4) 13,236.61 66.90 267.44 5,793.87 5,663.00 -1,806.07 -10,307.66 5,947,196.05 478,055.00 0.44 10,464.68 MWD+IFR-AK-CAZ-SC (4) 13,305.00 66.35 268.16 5,821.00 5,690.13 -1,808.48 -10,370.39 5,947,193.74 477,992.27 1.25 10,526.88 INC+TREND (5) 9 SM" x 12114" 13,314.99 66.27 268.26 5,825.02 5,694.15 -1,808.77 -10,379.53 5,947,193.46 477,983.12 1.25 10,535.94 INC+TREND (5) 13,408.66 66.96 269.24 5,862.19 5,731.32 -1,810.64 -10,465.49 5,947,191.72 477,897.18 1.21 10,620.91 MWD+IFR-AK-CAZ-SC (6) 13,441.65 67.06 269.29 5,875.08 5,744.21 -1,811.03 -10,495.86 5,947,191.38 477,866.81 0.33 10,650.88 MWD+IFR-AK-CAZ-SC (6) 13,475.29 66.93 269.98 5,888.23 5,757.36 -1,811.23 -10,526.82 5,947,191.23 477,835.85 1.93 10,681.41 MWD+IFR-AK-CAZ-SC (6) 13,499.93 66.86 269.98 5,897.90 5,767.03 -1,811.23 -10,549.48 5,947,191.26 477,813.19 0.28 10,703.73 MWD+IFR-AK-CAZ-SC (6) 13,535.14 66.84 270.40 5,911.74 5,780.87 -1,811.13 -10,581.86 5,947,191.42 477,780.82 1.10 10,735.59 MWD+IFR-AK-CAZ-SC (6) 13,567.45 66.77 271.30 5,924.46 5,793.59 -1,810.69 -10,611.55 5,947,191.90 477,751.13 2.57 10,764.76 MWD+IFR-AK-CAZ-SC (6) 13,593.44 66.80 271.29 5,934.71 5,803.84 -1,810.15 -10,635.43 5,947,192.48 477,727.25 0.12 10,788.18 MWD+IFR-AK-CAZ-SC (6) 13,687.73 67.65 270.67 5,971.21 5,840.34 -1,808.66 -10,722.36 5,947,194.10 477,640.34 1.09 10,873.53 MWD+IFR-AK-CAZ-SC (6) 13,780.26 69.88 271.09 6,004.72 5,873.85 -1,807.33 -10,808.59 5,947,195.56 477,554.12 2.45 10,958.22 MWD+IFR-AK-CAZ-SC (6) 13,873.77 72.87 270.40 6,034.58 5,903.71 -1,806.19 -10,897.18 5,947,196.84 477,465.53 3.27 11,045.27 MWD+IFR-AK-CAZ-SC (6) 13,966.96 76.86 270.55 6,058.91 5,928.04 -1,805.44 -10,987.12 5,947,197.73 477,375.61 4.28 11,133.71 MWD+IFR-AK-CAZ-SC (6) 14,047.29 79.58 271.11 6,075.31 5,944.44 -1,804.30 -11,065.74 5,947,198.99 477,297.00 3.45 11,210.94 MWD+IFR-AK-CAZ-SC (6) 14,095.43 81.92 270.63 6,083.05 5,952.18 -1,803.58 -11,113.25 5,947,199.78 477,249.50 4.96 11,257.60 INC+TREND (7) 14,110.00 82.50 270.49 6,085.02 5,954.15 -1,803.44 -11,127.68 5,947,199.95 477,235.06 4.07 11,271.79 MWD+IFR-AK-CAZ-SC (8) 7" x 8.112" 14,192.33 85.75 269.69 6,093.45 5,962.58 -1,803.31 -11,209.57 5,947,200.20 477,153.19 4.07 11,352.41 MWD+IFR-AK-CAZ-SC (8) 14,288.68 89.66 268.98 6,097.31 5,966.44 -1,804.43 -11,305.81 5,947,199.23 477,056.95 4.12 11,447.39 MWD+IFR-AK-CAZ-SC (8) 227f2017 2:50-49PM Page 6 CESS WW. 1 Bui&174 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDM P2 Survey Map Map Vertical MO Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (q) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,380.85 93.42 268.60 6,094.83 5,963.96 -1,806.38 -11,397.91 5,947,197.43 476,964.85 4.10 11,538.43 MWD+IFR-AK-CAZ-SC (8) 14,477.92 93.98 270.59 6,088.57 5,957.70 -1,807.06 -11,494.77 5,947,196.89 476,868.00 2.13 11,633.93 MWD+IFR-AK-CAZ-SC (8) 14,573.51 94.23 270.42 6,081.72 5,950.85 -1,806.22 -11,590.11 5,947,197.88 476,772.67 0.32 11,727.68 MWD+IFR-AK-CAZ-SC (8) 14,668.43 94.15 270.89 6,074.79 5,943.92 -1,805.14 -11,684.77 5,947,199.11 476,678.02 0.50 11,820.71 MWD+IFR-AK-CAZ-SC (8) 14,762.22 92.99 273.48 6,068.95 5,938.08 -1,801.57 -11,778.30 5,947,202.82 476,584.51 3.02 11,912.20 MWD+IFR-AK-CAZ-SC (8) 14,857.50 90.99 274.39 6,065.64 5,934.77 -1,795.03 -11,873.30 5,947,209.50 476,489.54 2.31 12,004.62 MWD+IFR-AK-CAZ-SC (8) 14,951.56 90.35 273.33 6,064.54 5,933.67 -1,788.70 -11,967.13 5,947,215.98 476,395.72 1.32 12,095.93 MWD+IFR-AK-CAZ-SC (8) 15,043.96 90.04 269.55 6,064.22 5,933.35 -1,786.38 -12,059.49 5,947,218.44 476,303.38 4.10 12,186.48 MWD+IFR-AK-CAZ-SC (8) 15,141.14 90.21 266.08 6,064.01 5,933.14 -1,790.09 -12,156.58 5,947,214.89 476,206.29 3.57 12,282.74 MWD+IFR-AK-CAZ-SC (8) 15,236.32 89.45 264.99 6,064.29 5,933.42 -1,797.49 -12,251.47 5,947,207.63 476,111.40 1.40 12,377.47 MWD+IFR-AK-CAZ-SC (8) 15,329.21 88.56 262.19 6,065.91 5,935.04 -1,807.86 -12,343.76 5,947,197.40 476,019.10 3.16 12,470.16 MWD+IFR-AK-CAZ-SC (8) 15,423.16 88.80 261.99 6,068.07 5,937.20 -1,820.79 -12,436.79 5,947,184.62 475,926.06 0.33 12,564.02 MWD+IFR-AK-CAZ-SC (8) 15,475.88 89.25 268.32 6,068.97 5,938.10 -1,825.24 -12,489.28 5,947,180.25 475,873.56 12.04 12,616.49 MWD+IFR-AK-CAZ-SC (8) 15,519.09 89.69 270.73 6,069.37 5,938.50 -1,825.60 -12,532.49 5,947,179.96 475,830.36 5.67 12,659.10 MWD+IFR-AK-CAZ-SC (8) 15,563.59 90.40 274.82 6,069.33 5,938.46 -1,823.44 -12,576.93 5,947,182.19 475,785.93 9.33 12,702.49 MWD+IFR-AK-CAZ-SC (8) 15,611.93 89.52 273.80 6,069.37 5,938.50 -1,819.81 -12,625.13 5,947,185.89 475,737.74 2.79 12,749.33 MWD+IFR-AK-CAZ-SC (8) 15,708.55 88.94 275.66 6,070.67 5,939.80 -1,811.84 -12,721.41 5,947,194.01 475,641.49 2.02 12,842.76 MWD+IFR-AK-CAZ-SC (8) 15,801.55 89.42 279.11 6,072.00 5,941.13 -1,799.89 -12,813.61 5,947,206.10 475,549.31 3.75 12,931.49 MWD+IFR-AK-CAZ-SC (8) 15,897.96 88.80 283.58 6,073.50 5,942.63 -1,780.93 -12,908.10 5,947,225.20 475,454.86 4.68 13,021.25 MWD+IFR-AK-CAZ-SC (8) 15,992.15 88.32 285.64 6,075.86 5,944.99 -1,757.18 -12,999.21 5,947,249.09 475,363.79 2.24 13,106.86 MWD+IFR-AK-CAZ-SC (8) 16,088.03 88.63 285.14 6,078.42 5,947.55 -1,731.75 -13,091.62 5,947,274.67 475,271.43 0.61 13,193.44 MWD+IFR-AK-CAZ-SC (8) 16,182.07 88.90 284.19 6,080.44 5,949.57 -1,707.95 -13,182.57 5,947,298.61 475,180.52 1.05 13,278.88 MWD+IFR-AK-CAZ-SC (8) 16,277.53 88.84 282.00 6,082.33 5,951.46 -1,686.32 -13,275.53 5,947,320.37 475,087.61 2.29 13,366.67 MWD+IFR-AK-CAZ-SC (8) 16,370.84 88.53 278.58 6,084.47 5,953.60 -1,669.66 -13,367.30 5,947,337.17 474,995.88 3.68 13,454.15 MWD+IFR-AK-CAZ-SC (8) 16,465.94 88.08 274.04 6,087.28 5,956.41 -1,659.22 -13,461.76 5,947,347.76 474,901.45 4.80 13,545.36 MWD+IFR-AK-CAZ-SC (8) 16,560.45 88.29 274.54 6,090.28 5,959.41 -1,652.15 -13,555.95 5,947,354.97 474,807.27 0.57 13,636.90 MWD+IFR-AK-CAZ-SC (8) 16,655.41 87.81 276.96 6,093.51 5,962.64 -1,642.64 -13,650.37 5,947,364.63 474,712.87 2.60 13,728.24 MWD+IFR-AK-CAZ-SC (8) 16,749.18 87.88 279.13 6,097.03 5,966.16 -1,629.53 -13,743.15 5,947,377.88 474,620.13 2.31 13,817.33 MWD+IFR-AK-CAZ-SC (8) 16,844.19 87.32 281.59 6,101.01 5,970.14 -1,612.46 -13,836.52 5,947,395.09 474,526.79 2.65 13,906.31 MWD+IFR-AK-CAZ-SC (8) 16,939.58 88.06 281.76 6,104.86 5,973.99 -1,593.17 -13,929.86 5,947,414.52 474,433.49 0.80 13,994.89 MWD+IFR-AK-CAZ-SC (8) 17,033.26 91.65 278.84 6,105.09 5,974.22 -1,576.43 -14,022.01 5,947,431.41 474,341.38 4.94 14,082.72 MWD+IFR-AK-CAZ-SC (8) 17,128.30 96.52 278.41 6,098.33 5,967.46 -1,562.22 -14,115.70 5,947,445.76 474,247.71 5.14 14,172.53 MWD+IFR-AK-CAZ-SC (8) 17,223.64 96.19 278.74 6,087.77 5,956.90 -1,548.09 -14,209.40 5,947,460.04 474,154.05 0.49 14,262.35 MWD+IFR-AK-CAZ-SC (8) 17,317.61 95.68 278.12 6,078.06 5,947.19 -1,534.39 -14,301.85 5,947,473.88 474,061.63 0.85 14,351.02 MWD+IFR-AK-CAZ-SC (8) 17,408.22 93.00 279.06 6,071.20 5,940.33 -1,520.89 -14,391.18 5,947,487.51 473,972.33 3.13 14,436.65 MWD+IFR-AK-CAZ-SC (8) 17,500.78 92.49 278.98 6,066.77 5,935.90 -1,506.40 -14,482.49 5,947,502.15 473,881.05 0.56 14,524.05 MWD+IFR-AK-CAZ-SC (8) 17,592.72 93.30 278.20 6,062.12 5,931.25 -1,492.68 -14,573.28 5,947,516.00 473,790.29 1.22 14,611.08 MWD+IFR-AK-CAZ-SC (8) 17,686.79 94.68 277.74 6,055.58 5,924.71 -1,479.67 -14,666.22 5,947,529.15 473,697.39 1.55 14,700.35 MWD+IFR-AK-CAZ-SC (8) 17,778.18 91.22 278.22 6,050.88 5,920.01 -1,467.00 -14,756.59 5,947,541.96 473,607.04 3.82 14,787.14 MWD+IFR-AK-CAZ-SC (8) 17,870.42 89.75 278.26 6,050.09 5,919.22 -1,453.78 -14,847.87 5,947,555.32 473,515.79 1.59 14,874.74 MWD+IFR-AK-CAZ-SC (8) 2272017 2:50:49PM Page 7 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey MD Inc Azt TVD TVDSS (usft) (°) V) (usft) (usft) 17,962.58 89.73 277.56 6,050.51 5,919.64 18,054.86 88.34 277.08 6,052.07 5,921.20 18,146.24 89.21 275.76 6,054.02 5,923.15 18,238.04 90.45 274.08 6,054.29 5,923.42 18,330.25 91.29 272.59 6,052.89 5,922.02 18,423.35 89.54 270.59 6,052.22 5,921.35 18,483.00 89.54 270.59 6,052.70 5,921.83 4-112" x 6-1/8" 1.85 15,316.56 MWD+IFR-AK-CAZ-SC (8) -1,403.31 2/2712017 2.50.49PM Page 8 COMPASS 5000. 1 Build 74 Map Map Vertical +N/ -S +E1 -W Northing Easting DLS Section (usft) (usft) (ft) (ft) (%100') (ft) Survey Tool Name -1,441.10 -14,939.15 5,947,568.14 473,424.54 0.76 14,962.44 MWD+IFR-AK-CAZ-SC (8) -1,429.34 -15,030.66 5,947,580.04 473,333.05 1.59 15,050.52 MWD+IFR-AK-CAZ-SC (8) -1,419.13 -15,121.45 5,947,590.39 473,242.29 1.73 15,138.15 MWD+IFR-AK-CAZ-SC (8) -1,411.26 -15,212.90 5,947,598.41 473,150.86 2.27 15,226.85 MWD+IFR-AK-CAZ-SC (8) -1,405.89 -15,304.94 5,947,603.91 473,058.84 1.85 15,316.56 MWD+IFR-AK-CAZ-SC (8) -1,403.31 -15,398.00 5,947,606.64 472,965.80 2.85 15,407.75 MWD+IFR-AK-CAZ-SC (8) -1,402.69 -15,457.64 5,947,607.34 472,906.16 0.00 15,466.38 PROJECTED to TO 2/2712017 2.50.49PM Page 8 COMPASS 5000. 1 Build 74 Cement Detail Report 2M-38 String: 13-3/8" SURFACE CEMENT JOB Job: DRILLING ORIGINAL, 1/1/2017 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 13-3/8" SURFACE CEMENT JOB 1/7/20172( 1/8/2017 01:09 2M-38 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 13-3/8" SURFACE29.0 3,044.0 Yes 334.0 Yes Yes CEMENTJOB Q Pump [nit (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi)Rec[p? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 6 550.0 1,100 . 01 Yes 10.001 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement surface casing to surface Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) CW 100 0.0 0.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) MudPush II 0.0 0.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 0.0 0.0 46 Litecrete 15.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.84 6.14 1 1.0 Additives Additive Type Concentration Cone Unit label D177 0.015 gal/sx Additive Type Concentration Cone Unit label D185 0.04 gal/sx Additive Type Concentration Cone Unit label D46 0.5 %BWOC Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement w/ 0.0 2,544.0 1,859 Litecrete 609.1 cemNet Yield (W/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.84 6.14 11.0 Additives Additive Type Concentration Cone Unit label Cemnet 1.0 lbs/bbl Additive Type Concentration Cone Unit label D177 0.015 gal/sx Additive Type Concentration Cone Unit label D185 0.04 gal/sx Additive Type Concentration Cone Unit label D46 0.2 %BWOC Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,544.0 3,044.0 247 Litecrete 72.5 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.65 5.45 12.0 1 1 Page 1/2 Report Printed: 2/8/2017 Cement Detail Report 2M-38 String: 13-3/8" SURFACE CEMENT JOB Job: DRILLING ORIGINAL, 1/1/2017 18:00 Additives Additive Type Concentration I Conc Unit label Page 2/2 Report Printed: 2/8/2017 Cement Detail Report 2M-38 String: 9-5/8" INTRM 1 CEMENT JOB Job: DRILLING ORIGINAL, 1/1/2017 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name 9-5/8" INTRM 1 CEMENT JOB 1/26/2017 15:30 1/26/2017 21:50 2M-38 Comment Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? 9-5/8" INTRM 1 CEMENT 111,100- Cement 9-5/8 liner to 11,100.0 13,305.0 No Yes Yes JOB MD Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 1 5 5 1,000.0 1,500.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up to Schlumberger and pump 9-5/8" liner cement job. Pump 10 bbls CW100 and pressure test lines to 450 / 4500 psi - good test. Continue pumping additional 30.2 bbls 8.34ppg CW100 at 4.5 bpm, 655 psi. Batch up and pump 63.3 bbls 12.5ppg MudPush spacer at 4.5 bpm, 260 psi. Drop bottom wiper dart and mix cement. Cement wet at 17:10 hrs. Pump 166.5 bbls 15.8ppg Class G cement at 4.5 bpm, 373 psi. Drop top wiper dart. Kick out dart and clear SLB lines with 10.3 bbls freshwater. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Pre Flush 9,721.0 11,100.0 0 Mud Push II 63.3 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 12.50 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.25 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D165 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder ID177 1 0.04 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 11,100.0 13,305.0 806 G 1.2 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.00 5.06 15.80 125.0 0.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/8/2017 NNW Cement Detail Report 2M-38 String: 7" Intermediate 2 Cement Job Job: Cement Details Description 7' Intermediate 2 Cement Job Cementing Start Date 1/31/2017 15:00 Cementing End Date 1/31/2017 17:32 Wellbore Name 2M-38 Comment Cement Stages Stage # 1 Description 7' Intermediate 2 Cement Job Objective Top Depth (ftKB) 13,137.7 Bottom Depth (ftKB) 14,110.0 Full Return? No Vol Cement... Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 7 Q Pump Final (bbl/... 3 Q Pump Avg (bbl/... 6 P Pump Final (psi) 600.0 P Plug Bump (psi) 1,100.0 Recip? Yes Stroke (ft) 80.00 Rotated? No 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 Pre Flush 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 (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Spacer 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 (ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 13,137.7 Est Btm (ftKB) Amount 14,110.0 (sacks) 324 Class G Volume Pumped (bbl) 67.0 Yield (ft /sack) 1.16 Mix H2O Ratio (gal/sa... 5.06 Free Water (%) Density (Ib/gal) Plastic 15.80 Viscosity (Pa -s) 103.2 Thickening Time (hr) CmprStr 317.00 1 (psi) Additives Additive D046 Type Concentration 0.2 Cone Unit label %BWOC Additive D065 Type Concentration 0.25 Cone Unit label %BWOC Additive D167 Type Concentration 0.4 Cone Unit label %BWOC Additive D177 Type Concentration I 0.04 Cone Unit label gal/sx Page 1/1 Report Printed: 2/8/2017 REC,,EIVE[ Schlumberger AOGr Drilling & Measurements MWD/LWD Log Product Delivery Customer: Conoco Phillips Alaska Dispatched To: Well No: 2M-38 Date Dispatched: Job#: 16AKA0119 Dispatched By: 21 60 83 280, Transmittal #: 17MAR17-SP01 DATA LOGGED 3 80/2011 ,A K BENDEF AOGCC: Makana Bender 17 -Mar -17 Stephanie Pacillo Well / Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service VISION*Service 2" TVD VMD _ x x x x VISION*Service 5" ND 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: Tom.Osterkamp(a�conocophillips.com Alaska PTS PrintCenter(cDslb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: RECEIVED MAR 16 2017 A FINAL NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-38 2M-38 Definitive Survey Report 27 February, 2017 NAD 27 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 roject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Jell 2M-38 Tie On Depth: +N/ -S lell Position +N/ -S 0.00 usft Northing: 5,948,986.00 usft Latitude: 70° 16' 18.587 +E/ -W 0.00 usft Easting: 488,364.41 usft Longitude: 150° 5'38.782 osition Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 us Wellbore 2M-38 Magnetics Model Name Sample Date BGGM2016 1/20/2017 Design 2M-38 Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVD) (usft) 29.57 Declination Dip Angle (1) (°) 17.67 ACTUAL Tie On Depth: +N/ -S +E/ -W (usft) (usft) 0.00 0.00 Field Strength (nT) 80.88 57.533 Survey Program Date From To Map Vertical MD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 74.39 809.01 2M-38 Srvy 1 - SLB _GWD70 (2M-38) GYD-GC-SS Gyrodata gyro single shots 1/3/2017 9:35:0 847.52 2,952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/3/2017 9:37:0 3,005.44 3,005.44 2M-38 Srvy 3 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 1/10/2017 9:26: 3,098.07 13,236.61 2M-38 Srvy 4 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/10/2017 9:27: 13,314.99 13,314.99 2M-38 Srvy 5 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 1/28/2017 9:48: 13,408.66 14,047.29 2M-38 Srvy 6 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/28/2017 9:49: 14,095.43 14,095.43 2M-38 Srvy 7 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 2/5/2017 3:00:0 14,192.33 18,423.35 2M-38 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2017 3:24:0 Survey 2/27/2017 2.50.49PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 29.57 0.00 0.00 29.57 -101.30 0.00 0.00 5,948,986.00 488,364.41 0.00 0.00 UNDEFINED 74.39 0.49 95.41 74.39 -56.48 -0.02 0.19 5,948,985.98 488,364.60 1.09 -0.18 GYD-GC-SS (1) 110.00 0.40 93.46 110.00 -20.87 -0.04 0.47 5,948,985.96 488,364.87 0.24 -0.45 NOT an Actual Survey 30" x 20" 166.39 0.27 87.83 166.39 35.52 -0.05 0.80 5,948,985.95 488,365.21 0.24 -0.78 GYD-GC-SS (1) 260.70 2.18 158.80 260.67 129.80 -1.71 1.67 5,948,984.29 488,366.07 2.23 -1.35 GYD-GC-SS(1) 350.18 3.32 159.75 350.05 219.18 -5.73 3.18 5,948,980.27 488,367.58 1.28 -2.14 GYD-GC-SS (1) 444.01 5.98 165.98 443.56 312.69 -13.02 5.31 5,948,972.97 488,369.69 2.88 -2.97 GYD-GC-SS (1) 2/27/2017 2.50.49PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey 2/27/2017 2.50:49PM Page 3 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 535.02 6.18 173.63 534.06 403.19 -22.49 7.00 5,948,963.50 488,371.37 0.92 -2.99 GYD-GC-SS (1) 626.51 6.81 180.04 624.97 494.10 -32.81 7.54 5,948,953.18 488,371.90 1.05 -1.73 GYD-GC-SS(1) 718.62 4.71 178.70 716.61 585.74 -42.05 7.62 5,948,943.94 488,371.97 2.28 -0.21 GYD-GC-SS (1) 809.01 6.55 179.77 806.56 675.69 -50.92 7.73 5,948,935.08 488,372.06 2.04 1.23 GYD-GC-SS (1) 847.52 7.60 181.94 844.77 713.90 -55.66 7.65 5,948,930.34 488,371.97 2.81 2.13 MWD+IFR-AK-CAZ-SC (2) 940.13 10.47 185.54 936.22 805.35 -70.16 6.63 5,948,915.84 488,370.93 3.16 5.65 MWD+IFR-AK-CAZ-SC (2) 1,034.52 11.93 184.22 1,028.81 897.94 -88.42 5.09 5,948,897.58 488,369.36 1.57 10.35 MWD+IFR-AK-CAZ-SC (2) 1,127.77 13.34 182.66 1,119.80 988.93 -108.78 3.88 5,948,877.22 488,368.12 1.56 15.07 MWD+IFR-AK-CAZ-SC (2) 1,221.58 18.99 178.84 1,209.87 1,079.00 -134.88 3.68 5,948,851.13 488,367.88 6.13 19.79 MWD+IFR-AK-CAZ-SC (2) 1,315.01 22.92 177.26 1,297.10 1,166.23 -168.26 4.86 5,948,817.75 488,369.01 4.25 24.43 MWD+IFR-AK-CAZ-SC (2) 1,407.64 23.11 178.16 1,382.36 1,251.49 -204.45 6.31 5,948,781.57 488,370.40 0.43 29.29 MWD+IFR-AK-CAZ-SC (2) 1,500.06 22.58 178.66 1,467.53 1,336.66 -240.31 7.30 5,948,745.70 488,371.34 0.61 34.54 MWD+IFR-AK-CAZ-SC (2) 1,593.04 27.05 185.87 1,551.93 1,421.06 -279.22 5.56 5,948,706.80 488,369.53 5.80 43.01 MWD+IFR-AK-CAZ-SC (2) 1,687.70 26.42 193.25 1,636.49 1,505.62 -321.14 -1.47 5,948,664.89 488,362.44 3.57 57.21 MWD+IFR-AK-CAZ-SC (2) 1,779.53 27.50 199.10 1,718.35 1,587.48 -361.07 -13.09 5,948,624.99 488,350.76 3.12 75.59 MWD+IFR-AK-CAZ-SC (2) 1,872.17 28.34 207.74 1,800.24 1,669.37 -400.76 -30.33 5,948,585.33 488,333.46 4.46 99.46 MWD+IFR-AK-CAZ-SC (2) 1,965.74 26.51 216.65 1,883.33 1,752.46 -437.19 -53.15 5,948,548.94 488,310.59 4.80 128.26 MWD+IFR-AK-CAZ-SC (2) 2,059.09 28.63 223.46 1,966.09 1,835.22 -470.15 -80.98 5,948,516.03 488,282.71 4.07 161.39 MWD+IFR-AK-CAZ-SC (2) 2,150.45 30.57 228.86 2,045.54 1,914.67 -501.33 -113.54 5,948,484.90 488,250.10 3.61 198.87 MWD+IFR-AK-CAZ-SC (2) 2,242.21 33.31 234.74 2,123.42 1,992.55 -531.24 -151.70 5,948,455.05 488,211.90 4.51 241.65 MWD+IFR-AK-CAZ-SC (2) 2,336.09 37.44 238.74 2,199.96 2,069.09 -560.94 -197.17 5,948,425.42 488,166.39 5.04 291.58 MWD+IFR-AK-CAZ-SC(2) 2,430.23 41.42 241.73 2,272.67 2,141.80 -590.56 -249.08 5,948,395.89 488,114.44 4.68 347.85 MWD+IFR-AK-CAZ-SC (2) 2,521.66 44.56 242.74 2,339.54 2,208.67 -619.58 -304.25 5,948,366.95 488,059.23 3.52 407.21 MWD+IFR-AK-CAZ-SC (2) 2,617.38 46.68 246.74 2,406.50 2,275.63 -648.72 -366.11 5,948,337.91 487,997.33 3.72 473.20 MWD+IFR-AK-CAZ-SC (2) 2,710.86 49.33 249.13 2,469.04 2,338.17 -674.79 -430.49 5,948,311.95 487,932.92 3.41 541.13 MWD+IFR-AK-CAZ-SC (2) 2,803.36 51.01 250.40 2,528.29 2,397.42 -699.34 -497.14 5,948,287.50 487,866.23 2.10 611.03 MWD+IFR-AK-CAZ-SC (2) 2,896.07 55.95 251.20 2,583.44 2,452.57 -723.82 -567.49 5,948,263.13 487,795.86 5.37 684.56 MWD+IFR-AK-CAZ-SC (2) 2,952.69 61.15 253.71 2,612.98 2,482.11 -738.35 -613.53 5,948,248.67 487,749.80 9.93 732.42 MWD+IFR-AK-CAZ-SC (2) 3,005.44 60.08 253.98 2,638.86 2,507.99 -751.14 -657.68 5,948,235.95 487,705.64 2.08 778.12 INC+TREND (3) 3,044.00 60.45 254.18 2,657.99 2,527.12 -760.32 -689.88 5,948,226.82 487,673.43 1.07 811.42 NOT an Actual Survey ) 13 3/8" x 16" 3,098.07 60.98 254.46 2,684.43 2,553.56 -773.07 -735.28 5,948,214.15 487,628.00 1.07 858.35 MWD+IFR-AK-CAZ-SC (4) 3,192.17 61.75 254.76 2,729.53 2,598.66 -794.99 -814.91 5,948,192.36 487,548.35 0.86 940.58 MWD+IFR-AK-CAZ-SC (4) 3,286.28 63.19 257.18 2,773.03 2,642.16 -815.20 -895.87 5,948,172.26 487,467.37 2.75 1,023.81 MWD+IFR-AK-CAZ-SC (4) 3,379.73 64.50 261.19 2,814.24 2,683.37 -830.92 -978.24 5,948,156.68 487,384.99 4.10 1,107.66 MWD+IFR-AK-CAZ-SC (4) 3,472.76 65.69 264.63 2,853.42 2,722.55 -841.32 -1,061.95 5,948,146.41 487,301.26 3.59 1,191.91 MWD+IFR-AK-CAZ-SC (4) 3,565.38 66.85 265.41 2,890.69 2,759.82 -848.68 -1,146.42 5,948,139.18 487,216.79 1.47 1,276.37 MWD+IFR-AK-CAZ-SC (4) 3,659.05 70.41 266.50 2,924.82 2,793.95 -854.82 -1,233.42 5,948,133.17 487,129.79 3.95 1,363.12 MWD+IFR-AK-CAZ-SC (4) 3,750.72 71.88 268.51 2,954.45 2,823.58 -858.59 -1,320.08 5,948,129.54 487,043.14 2.62 1,449.12 MWD+IFR-AK-CAZ-SC (4) 3,845.19 72.85 270.01 2,983.07 2,852.20 -859.75 -1,410.10 5,948,128.52 486,953.12 1.83 1,537.97 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 2.50:49PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,939.25 74.42 271.16 3,009.57 2,878.70 -858.83 -1,500.34 5,948,129.58 486,862.89 2.04 1,626.68 MWD+IFR-AK-CAZ-SC (4) 4,031.95 72.86 272.34 3,035.68 2,904.81 -856.11 -1,589.24 5,948,132.43 486,774.01 2.08 1,713.76 MWD+IFR-AK-CAZ-SC (4) 4,125.21 73.43 271.19 3,062.72 2,931.85 -853.37 -1,678.45 5,948,135.32 486,684.81 1.33 1,801.13 MWD+IFR-AK-CAZ-SC (4) 4,218.27 74.05 269.76 3,088.78 2,957.91 -852.63 -1,767.78 5,948,136.19 486,595.49 1.62 1,888.98 MWD+IFR-AK-CAZ-SC (4) 4,311.58 73.60 266.71 3,114.78 2,983.91 -855.38 -1,857.34 5,948,133.57 486,505.93 3.18 1,977.66 MWD+IFR-AK-CAZ-SC (4) 4,404.26 73.36 263.71 3,141.14 3,010.27 -862.80 -1,945.87 5,948,126.29 486,417.40 3.11 2,066.13 MWD+IFR-AK-CAZ-SC (4) 4,498.05 73.18 264.69 3,168.14 3,037.27 -871.88 -21035.23 5,948,117.36 486,328.03 1.02 2,155.71 MWD+IFR-AK-CAZ-SC (4) 4,591.59 73.12 264.19 3,195.25 3,064.38 -880.55 -2,124.33 5,948,108.82 486,238.93 0.52 2,244.97 MWD+IFR-AK-CAZ-SC (4) 4,685.34 73.43 263.88 3,222.23 3,091.36 -889.88 -2,213.63 5,948,099.63 486,149.62 0.46 2,334.53 MWD+IFR-AK-CAZ-SC (4) 4,779.30 73.56 264.03 3,248.93 3,118.06 -899.37 -2,303.22 5,948,090.28 486,060.03 0.21 2,424.40 MWD+IFR-AK-CAZ-SC (4) 4,873.44 73.86 261.26 3,275.34 3,144.47 -910.94 -2,392.83 5,948,078.85 485,970.42 2.84 2,514.66 MWD+IFR-AK-CAZ-SC (4) 4,966.25 73.97 262.19 3,301.05 3,170.18 -923.77 -2,481.07 5,948,066.16 485,882.16 0.97 2,603.79 MWD+IFR-AK-CAZ-SC (4) 5,058.86 73.66 261.75 3,326.87 3,196.00 -936.20 -2,569.14 5,948,053.87 485,794.08 0.57 2,692.68 MWD+IFR-AK-CAZ-SC (4) 5,153.15 73.45 262.38 3,353.56 3,222.69 -948.68 -2,658.71 5,948,041.53 485,704.50 0.68 2,783.05 MWD+IFR-AK-CAZ-SC (4) 5,247.73 73.77 262.60 3,380.25 3,249.38 -960.54 -2,748.66 5,948,029.81 485,614.54 0.41 2,873.70 MWD+IFR-AK-CAZ-SC (4) 5,341.64 73.77 262.50 3,406.50 3,275.63 -972.23 -2,838.07 5,948,018.26 485,525.12 0.10 2,963.78 MWD+IFR-AK-CAZ-SC (4) 5,435.06 73.27 261.76 3,433.00 3,302.13 -984.50 -2,926.81 5,948,006.13 485,436.37 0.93 3,053.30 MWD+IFR-AK-CAZ-SC (4) 5,527.19 73.27 262.65 3,459.52 3,328.65 -996.46 -3,014.22 5,947,994.30 485,348.95 0.93 3,141.46 MWD+IFR-AK-CAZ-SC (4) 5,621.72 73.44 261.34 3,486.60 3,355.73 -1,009.07 -3,103.91 5,947,981.83 485,259.25 1.34 3,231.97 MWD+IFR-AK-CAZ-SC (4) 5,714.13 73.27 260.89 3,513.07 3,382.20 -1,022.75 -3,191.38 5,947,968.29 485,171.77 0.50 3,320.50 MWD+IFR-AK-CAZ-SC (4) 5,807.31 73.47 261.05 3,539.73 3,408.86 -1,036.76 -3,279.56 5,947,954.41 485,083.58 0.27 3,409.77 MWD+IFR-AK-CAZ-SC (4) 5,900.82 73.34 261.37 3,566.44 3,435.57 -1,050.46 -3,368.12 5,947,940.86 484,995.00 0.36 3,499.36 MWD+IFR-AK-CAZ-SC (4) 5,993.80 73.35 261.46 3,593.09 3,462.22 -1,063.75 -3,456.20 5,947,927.70 484,906.91 0.09 3,588.41 MWD+IFR-AK-CAZ-SC (4) 6,086.10 73.21 261.86 3,619.64 3,488.77 -1,076.58 -3,543.66 5,947,915.01 484,819.44 0.44 3,676.77 MWD+IFR-AK-CAZ-SC (4) 6,182.26 73.44 261.21 3,647.24 3,516.37 -1,090.14 -3,634.78 5,947,901.59 484,728.31 0.69 3,768.86 MWD+IFR-AK-CAZ-SC (4) 6,276.14 73.31 261.82 3,674.10 3,543.23 -1,103.41 -3,723.75 5,947,888.46 484,639.33 0.64 3,858.78 MWD+IFR-AK-CAZ-SC (4) 6,368.62 73.25 262.36 3,700.70 3,569.83 -1,115.60 -3,811.47 5,947,876.41 484,551.59 0.56 3,947.29 MWD+IFR-AK-CAZ-SC (4) 61461.24 73.31 261.94 3,727.35 3,596.48 -1,127.71 -3,899.35 5,947,864.43 484,463.71 0.44 4,035.93 MWD+IFR-AK-CAZ-SC (4) 6,553.86 73.19 262.45 3,754.04 3,623.17 -1,139.76 -3,987.21 5,947,852.52 484,375.83 0.54 4,124.56 MWD+IFR-AK-CAZ-SC (4) 6,648.08 73.25 263.40 3,781.24 3,650.37 -1,150.87 -4,076.73 5,947,841.55 484,286.31 0.97 4,214.65 MWD+IFR-AK-CAZ-SC (4) 6,741.43 73.09 262.96 3,808.27 3,677.40 -1,161.48 -4,165.45 5,947,831.08 484,197.58 0.48 4,303.86 MWD+IFR-AK-CAZ-SC (4) 6,835.33 73.29 264.22 3,835.43 3,704.56 -1,171.51 -4,254.78 5,947,821.18 484,108.25 1.30 4,393.57 MWD+IFR-AK-CAZ-SC (4) 6,929.47 73.22 264.59 3,862.55 3,731.68 -1,180.30 -4,344.50 5,947,812.53 484,018.53 0.38 4,483.45 MWD+IFR-AK-CAZ-SC (4) 7,022.21 73.22 264.97 3,889.33 3,758.46 -1,188.38 -4,432.92 5,947,804.59 483,930.10 0.39 4,571.93 MWD+IFR-AK-CAZ-SC (4) 7,116.38 73.25 264.23 3,916.49 3,785.62 -1,196.87 -4,522.68 5,947,796.25 483,840.33 0.75 4,661.81 MWD+IFR-AK-CAZ-SC (4) 7,208.32 73.36 265.06 3,942.90 3,812.03 -1,205.08 -4,610.36 5,947,788.17 483,752.65 0.87 4,749.58 MWD+IFR-AK-CAZ-SC (4) 7,301.34 73.34 264.53 3,969.55 3,838.68 -1,213.17 -4,699.12 5,947,780.22 483,663.89 0.55 4,838.39 MWD+IFR-AK-CAZ-SC (4) 7,394.54 73.27 262.42 3,996.33 3,865.46 -1,223.31 -4,787.80 5,947,770.21 483,575.20 2.17 4,927.49 MWD+IFR-AK-CAZ-SC (4) 7,488.18 73.41 261.80 4,023.18 3,892.31 -1,235.63 -4,876.66 5,947,758.04 483,486.33 0.65 5,017.14 MWD+IFR-AK-CAZ-SC (4) 7,581.60 73.12 261.68 4,050.08 3,919.21 -1,248.48 -4,965.20 5,947,745.32 483,397.78 0.33 5,106.56 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 2:50:49PM Page 4 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey 2,27/2017 2:50-49PM Page 5 COMPASS 5000 1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,673.37 73.35 261.79 4,076.55 3,945.68 -1,261.11 -5,052.15 5,947,732.83 483,310.81 0.28 5,194.39 MWD+IFR-AK-CAZ-SC (4) 7,767.11 73.13 261.64 4,103.58 3,972.71 -1,274.05 -5,140.98 5,947,720.03 483,221.98 0.28 5,284.11 MWD+IFR-AK-CAZ-SC (4) 7,859.59 73.31 261.60 4,130.28 3,999.41 -1,286.95 -5,228.57 5,947,707.26 483,134.37 0.20 5,372.62 MWD+IFR-AK-CAZ-SC (4) 7.,952.95 73.61 262.65 4,156.86 4,025.99 -1,299.21 -5,317.22 5,947,695.14 483,045.71 1.13 5,462.05 MWD+IFR-AK-CAZ-SC (4) 8,047.09 73.26 262.58 4,183.70 4,052.83 -1,310.81 -5,406.71 5,947,683.68 482,956.22 0.38 5,552.19 MWD+IFR-AK-CAZ-SC (4) 8,140.76 73.64 263.04 4,210.38 4,079.51 -1,322.05 -5,495.79 5,947,672.58 482,867.13 0.62 5,641.87 MWD+IFR-AK-CAZ-SC (4) 8,232.78 73.78 263.36 4,236.19 4,105.32 -1,332.50 -5,583.50 5,947,662.26 482,779.42 0.37 5,730.06 MWD+IFR-AK-CAZ-SC (4) 8,326.46 74.10 264.09 4,262.11 4,131.24 -1,342.34 -5,672.98 5,947,652.56 482,689.93 0.82 5,819.89 MWD+IFR-AK-CAZ-SC (4) 8,420.57 73.83 264.65 4,288.10 4,157.23 -1,351.22 -5,762.99 5,947,643.83 482,599.91 0.64 5,910.07 MWD+IFR-AK-CAZ-SC (4) 8,512.73 74.03 265.02 4,313.61 4,182.74 -1,359.19 -5,851.19 5,947,635.99 482,511.71 0.44 5,998.32 MWD+IFR-AK-CAZ-SC (4) 8,606.38 74.10 265.43 4,339.32 4,208.45 -1,366.69 -5,940.93 5,947,628.64 482,421.97 0.43 6,087.99 MWD+IFR-AK-CAZ-SC (4) 8,700.38 73.75 265.54 4,365.35 4,234.48 -1,373.80 -6,030.97 5,947,621.67 482,331.92 0.39 6,177.91 MWD+IFR-AK-CAZ-SC (4) 8,792.78 73.64 264.92 4,391.29 4,260.42 -1,381.17 -6,119.35 5,947,614.43 482,243.54 0.65 6,266.22 MWD+IFR-AK-CAZ-SC (4) 8,888.08 73.33 264.04 4,418.38 4,287.51 -1,389.96 -6,210.29 5,947,605.78 482,152.59 0.94 6,357.31 MWD+IFR-AK-CAZ-SC (4) 8,980.80 73.47 264.17 4,444.87 4,314.00 -1,399.08 -6,298.68 5,947,596.79 482,064.20 0.20 6,445.94 MWD+IFR-AK-CAZ-SC (4) 9,074.16 73.12 264.06 4,471.71 4,340.84 -1,408.25 -6,387.63 5,947,587.76 481,975.25 0.39 6,535.12 MWD+IFR-AK-CAZ-SC (4) 9,169.42 73.12 262.90 4,499.37 4,368.50 -1,418.60 -6,478.19 5,947,577.56 481,884.68 1.17 6,626.11 MWD+IFR-AK-CAZ-SC (4) 9,261.89 73.37 263.85 4,526.03 4,395.16 -1,428.82 -6,566.14 5,947,567.48 481,796.72 1.02 6,714.50 MWD+IFR-AK-CAZ-SC (4) 9,355.29 73.48 262.86 4,552.67 4,421.80 -1,439.18 -6,655.06 5,947,557.26 481,707.80 1.02 6,803.86 MWD+IFR-AK-CAZ-SC (4) 9,449.25 73.49 263.43 4,579.38 4,448.51 -1,449.93 -6,744.50 5,947,546.64 481,618.35 0.58 6,893.81 MWD+IFR-AK-CAZ-SC (4) 9,541.68 73.55 262.12 4,605.61 4,474.74 -1,461.08 -6,832.43 5,947,535.63 481,530.41 1.36 6,982.34 MWD+IFR-AK-CAZ-SC (4) 9,636.38 73.55 263.16 4,632.42 4,501.55 -1,472.71 -6,922.50 5,947,524.14 481,440.33 1.05 7,073.06 MWD+IFR-AK-CAZ-SC (4) 9,730.46 73.58 262.46 4,659.04 4,528.17 -1,484.00 -7,012.03 5,947,512.99 481,350.80 0.71 7,163.19 MWD+IFR-AK-CAZ-SC (4) 9,822.97 73.36 262.92 4,685.36 4,554.49 -1,495.29 -7,099.99 5,947,501.84 481,262.82 0.53 7,251.78 MWD+IFR-AK-CAZ-SC (4) 9,915.77 73.43 262.97 4,711.88 4,581.01 -1,506.21 -7,188.25 5,947,491.05 481,174.56 0.09 7,340.59 MWD+IFR-AK-CAZ-SC (4) 10,010.19 73.64 263.68 4,738.64 4,607.77 -1,516.74 -7,278.18 5,947,480.67 481,084.62 0.75 7,430.99 MWD+IFR-AK-CAZ-SC (4) 10,103.41 73.49 262.53 4,765.02 4,634.15 -1,527.47 -7,366.94 5,947,470.07 480,995.85 1.19 7,520.27 MWD+IFR-AK-CAZ-SC (4) 10,197.02 73.28 263.40 4,791.79 4,660.92 -1,538.46 -7,455.97 5,947,459.23 480,906.81 0.92 7,609.85 MWD+IFR-AK-CAZ-SC (4) 10,291.59 73.20 263.77 4,819.06 4,688.19 -1,548.57 -7,545.95 5,947,449.25 480,816.82 0.38 7,700.22 MWD+IFR-AK-CAZ-SC (4) 10,384.94 72.90 262.42 4,846.27 4,715.40 -1,559.31 -7,634.60 5,947,438.65 480,728.17 1.42 7,789.38 MWD+IFR-AK-CAZ-SC (4) 10,480.08 73.07 263.39 4,874.11 4,743.24 -1,570.54 -7,724.88 5,947,427.56 480,637.88 0.99 7,880.24 MWD+IFR-AK-CAZ-SC (4) 10,573.68 73.35 264.46 4,901.15 4,770.28 -1,580.03 -7,813.98 5,947,418.21 480,548.77 1.13 7,969.64 MWD+IFR-AK-CAZ-SC (4) 10,666.32 72.98 264.72 4,927.98 4,797.11 -1,588.39 -7,902.26 5,947,409.99 480,460.49 0.48 8,058.02 MWD+IFR-AK-CAZ-SC (4) 10,760.20 73.12 264.56 4,955.35 4,824.48 -1,596.78 -7,991.67 5,947,401.74 480,371.08 0.22 8,147.53 MWD+IFR-AK-CAZ-SC (4) 10,854.04 73.50 264.33 4,982.30 4,851.43 -1,605.48 -8,081.13 5,947,393.18 480,281.61 0.47 8,237.15 MWD+IFR-AK-CAZ-SC (4) 10,947.19 73.55 264.82 5,008.72 4,877.85 -1,613.92 -8,170.06 5,947,384.87 480,192.68 0.51 8,326.19 MWD+IFR-AK-CAZ-SC (4) 11,039.89 73.42 264.40 5,035.07 4,904.20 -1,622.27 -8,258.54 5,947,376.66 480,104.20 0.46 8,414.78 MWD+IFR-AK-CAZ-SC (4) 11,133.42 73.61 265.02 5,061.61 4,930.74 -1,630.54 -8,347.84 5,947,368.53 480,014.89 0.67 8,504.16 MWD+IFR-AK-CAZ-SC (4) 11,224.58 73.64 264.74 5,087.31 4,956.44 -1,638.34 -8,434.95 5,947,360.86 479,927.77 0.30 8,591.30 MWD+IFR-AK-CAZ-SC (4) 11,319.87 73.55 265.69 5,114.22 4,983.35 -1,645.97 -8,526.04 5,947,353.38 479,836.68 0.96 8,682.33 MWD+IFR-AK-CAZ-SC (4) 2,27/2017 2:50-49PM Page 5 COMPASS 5000 1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,413.10 73.39 265.78 5,140.75 5,009.88 -1,652.62 -8,615.17 5,947,346.87 479,747.55 0.19 8,771.26 MWD+IFR-AK-CAZ-SC (4) 11,507.22 73.55 264.79 5,167.53 5,036.66 -1,660.03 -8,705.10 5,947,339.59 479,657.62 1.02 8,861.11 MWD+IFR-AK-CAZ-SC (4) 11,600.65 73.46 264.68 5,194.06 5,063.19 -1,668.25 -8,794.30 5,947,331.51 479,568.41 0.15 8,950.39 MWD+IFR-AK-CAZ-SC (4) 11,692.44 73.62 263.01 5,220.07 5,089.20 -1,677.69 -8,881.82 5,947,322.21 479,480.89 1.75 9,038.21 MWD+IFR-AK-CAZ-SC (4) 11,785.91 73.55 262.65 5,246.48 5,115.61 -1,688.88 -8,970.78 5,947,311.16 479,391.92 0.38 9,127.77 MWD+IFR-AK-CAZ-SC (4) 11,878.02 73.50 263.11 5,272.60 5,141.73 -1,699.83 -9,058.43 5,947,300.34 479,304.27 0.48 9,215.98 MWD+IFR-AK-CAZ-SC (4) 11,970.46 71.73 263.68 5,300.22 5,169.35 -1,709.98 -9,146.05 5,947,290.33 479,216.63 2.00 9,304.04 MWD+IFR-AK-CAZ-SC (4) 12,064.20 69.47 265.54 5,331.36 5,200.49 -1,718.29 -9,234.07 5,947,282.16 479,128.61 3.05 9,392.16 MWD+IFR-AK-CAZ-SC (4) 12,156.29 66.90 264.16 5,365.58 5,234.71 -1,725.96 -9,319.21 5,947,274.62 479,043.47 3.12 9,477.34 MWD+IFR-AK-CAZ-SC (4) 12,250.13 66.50 265.40 5,402.70 5,271.83 -1,733.80 -9,405.04 5,947,266.91 478,957.64 1.29 9,563.23 MWD+IFR-AK-CAZ-SC (4) 12,344.54 66.67 265.48 5,440.22 5,309.35 -1,740.69 -9,491.40 5,947,260.16 478,871.28 0.20 9,649.47 MWD+IFR-AK-CAZ-SC (4) 12,438.03 66.60 264.24 5,477.29 5,346.42 -1,748.38 -9,576.88 5,947,252.61 478,785.80 1.22 9,734.98 MWD+IFR-AK-CAZ-SC (4) 12,530.88 66.63 264.59 5,514.15 5,383.28 -1,756.67 -9,661.69 5,947,244.44 478,700.97 0.35 9,819.95 MWD+IFR-AK-CAZ-SC (4) 12,624.47 66.61 264.49 5,551.29 5,420.42 -1,764.85 -9,747.21 5,947,236.40 478,615.45 0.10 9,905.59 MWD+IFR-AK-CAZ-SC (4) 12,715.53 66.54 265.15 5,587.49 5,456.62 -1,772.39 -9,830.42 5,947,228.99 478,532.24 0.67 9,988.85 MWD+IFR-AK-CAZ-SC (4) 12,808.41 66.51 265.43 5,624.49 5,493.62 -1,779.38 -9,915.33 5,947,222.12 478,447.33 0.28 10,073.68 MWD+IFR-AK-CAZ-SC (4) 12,903.72 66.69 265.28 5,662.34 5,531.47 -1,786.47 -10,002.51 5,947,215.18 478,360.14 0.24 10,160.77 MWD+IFR-AK-CAZ-SC (4) 12,996.07 66.80 266.00 5,698.80 5,567.93 -1,792.92 -10,087.11 5,947,208.86 478,275.54 0.73 10,245.20 MWD+IFR-AK-CAZ-SC (4) 13,090.27 66.63 265.85 5,736.04 5,605.17 -1,799.07 -10,173.42 5,947,202.84 478,189.23 0.23 10,331.27 MWD+IFR-AK-CAZ-SC (4) 13,183.28 66.72 267.60 5,772.87 5,642.00 -1,803.95 -10,258.69 5,947,198.10 478,103.97 1.73 10,416.09 MWD+IFR-AK-CAZ-SC (4) 13,236.61 66.90 267.44 5,793.87 5,663.00 -1,806.07 -10,307.66 5,947,196.05 478,055.00 0.44 10,464.68 MWD+IFR-AK-CAZ-SC (4) 13,305.00 66.35 268.16 5,821.00 5,690.13 -1,808.48 -10,370.39 5,947,193.74 477,992.27 1.25 10,526.88 NOT an Actual Suryey 9 6/8" x 12 1/4" 13,314.99 66.27 268.26 5,825.02 5,694.15 -1,808.77 -10,379.53 5,947,193.46 477,983.12 1.25 10,535.94 INC+TREND (5) 13,408.66 66.96 269.24 5,862.19 5,731.32 -1,810.64 -10,465.49 5,947,191.72 477,897.18 1.21 10,620.91 MWD+IFR-AK-CAZ-SC (6) 13,441.65 67.06 269.29 5,875.08 5,744.21 -1,811.03 -10,495.86 5,947,191.38 477,866.81 0.33 10,650.88 MWD+IFR-AK-CAZ-SC (6) 13,475.29 66.93 269.98 5,888.23 5,757.36 -1,811.23 -10,526.82 5,947,191.23 477,835.85 1.93 10,681.41 MWD+IFR-AK-CAZ-SC (6) 13,499.93 66.86 269.98 5,897.90 5,767.03 -1,811.23 -10,549.48 5,947,191.26 477,813.19 0.28 10,703.73 MWD+IFR-AK-CAZ-SC (6) 13,535.14 66.84 270.40 5,911.74 5,780.87 -1,811.13 -10,581.86 5,947,191.42 477,780.82 1.10 10,735.59 MWD+IFR-AK-CAZ-SC (6) 13,567.45 66.77 271.30 5,924.46 5,793.59 -1,810.69 -10,611.55 5,947,191.90 477,751.13 2.57 10,764.76 MWD+IFR-AK-CAZ-SC (6) 13,593.44 66.80 271.29 5,934.71 5,803.84 -1,810.15 -10,635.43 5,947,192.48 477,727.25 0.12 10,788.18 MWD+IFR-AK-CAZ-SC (6) 13,687.73 67.65 270.67 5,971.21 5,840.34 -1,808.66 -10,722.36 5,947,194.10 477,640.34 1.09 10,873.53 MWD+IFR-AK-CAZ-SC (6) 13,780.26 69.88 271.09 6,004.72 5,873.85 -1,807.33 -10,808.59 5,947,195.56 477,554.12 2.45 10,958.22 MWD+IFR-AK-CAZ-SC (6) 13,873.77 72.87 270.40 6,034.58 5,903.71 -1,806.19 -10,897.18 5,947,196.84 477,465.53 3.27 11,045.27 MWD+IFR-AK-CAZ-SC (6) 13,966.96 76.86 270.55 6,058.91 5,928.04 -1,805.44 -10,987.12 5,947,197.73 477,375.61 4.28 11,133.71 MWD+IFR-AK-CAZ-SC (6) 14,047.29 79.58 271.11 6,075.31 5,944.44 -1,804.30 -11,065.74 5,947,198.99 477,297.00 3.45 11,210.94 MWD+IFR-AK-CAZ-SC (6) 14,095.43 81.92 270.63 6,083.05 5,952.18 -1,803.58 -11,113.25 5,947,199.78 477,249.50 4.96 11,257.60 INC+TREND (7) 14,110.00 82.50 270.49 6,085.02 5,954.15 -1,803.44 -11,127.68 5,947,199.95 477,235.06 4.07 11,271.79 NOT an Actual Survey ) 7" x 8-1/2" 14,192.33 85.75 269.69 6,093.45 5,962.58 -1,803.31 -11,209.57 5,947,200.20 477,153.19 4.07 11,352.41 MWD+IFR-AK-CAZ-SC (8) 14,288.68 89.66 268.98 6,097.31 5,966.44 -1,804.43 -11,305.81 5,947,199.23 477,056.95 4.12 11,447.39 MWD+IFR-AK-CAZ-SC (8) 2/27/2017 2:50.49PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,380.85 93.42 268.60 6,094.83 5,963.96 -1,806.38 -11,397.91 5,947,197.43 476,964.85 4.10 11,538.43 MWD+IFR-AK-CAZ-SC (8) 14,477.92 93.98 270.59 6,088.57 5,957.70 -1,807.06 -11,494.77 5,947,196.89 476,868.00 2.13 11,633.93 MWD+IFR-AK-CAZ-SC (8) 14,573.51 94.23 270.42 6,081.72 5,950.85 -1,806.22 -11,590.11 5,947,197.88 476,772.67 0.32 11,727.68 MWD+IFR-AK-CAZ-SC (8) 14,668.43 94.15 270.89 6,074.79 5,943.92 -1,805.14 -11,684.77 5,947,199.11 476,678.02 0.50 11,820.71 MWD+IFR-AK-CAZ-SC (8) 14,762.22 92.99 273.48 6,068.95 5,938.08 -1,801.57 -11,778.30 5,947,202.82 476,584.51 3.02 11,912.20 MWD+IFR-AK-CAZ-SC (8) 14,857.50 90.99 274.39 6,065.64 5,934.77 -1,795.03 -11,873.30 5,947,209.50 476,489.54 2.31 12,004.62 MWD+IFR-AK-CAZ-SC (8) 14,951.56 90.35 273.33 6,064.54 5,933.67 -1,788.70 -11,967.13 5,947,215.98 476,395.72 1.32 12,095.93 MWD+IFR-AK-CAZ-SC (8) 15,043.96 90.04 269.55 6,064.22 5,933.35 -1,786.38 -12,059.49 5,947,218.44 476,303.38 4.10 12,186.48 MWD+IFR-AK-CAZ-SC (8) 15,141.14 90.21 266.08 6,064.01 5,933.14 -1,790.09 -12,156.58 5,947,214.89 476,206.29 3.57 12,282.74 MWD+IFR-AK-CAZ-SC (8) 15,236.32 89.45 264.99 6,064.29 5,933.42 -1,797.49 -12,251.47 5,947,207.63 476,111.40 1.40 12,377.47 MWD+IFR-AK-CAZ-SC (8) 15,329.21 88.56 262.19 6,065.91 5,935.04 -1,807.86 -12,343.76 5,947,197.40 476,019.10 3.16 12,470.16 MWD+IFR-AK-CAZ-SC (8) 15,423.16 88.80 261.99 6,068.07 5,937.20 -1,820.79 -12,436.79 5,947,184.62 475,926.06 0.33 12,564.02 MWD+IFR-AK-CAZ-SC (8) 15,475.88 89.25 268.32 6,068.97 5,938.10 -1,825.24 -12,489.28 5,947,180.25 475,873.56 12.04 12,616.49 MWD+IFR-AK-CAZ-SC (8) 15,519.09 89.69 270.73 6,069.37 5,938.50 -1,825.60 -12,532.49 5,947,179.96 475,830.36 5.67 12,659.10 MWD+IFR-AK-CAZ-SC (8) 15,563.59 90.40 274.82 6,069.33 5,938.46 -1,823.44 -12,576.93 5,947,182.19 475,785.93 9.33 12,702.49 MWD+IFR-AK-CAZ-SC (8) 15,611.93 89.52 273.80 6,069.37 5,938.50 -1,819.81 -12,625.13 5,947,185.89 475,737.74 2.79 12,749.33 MWD+IFR-AK-CAZ-SC (8) 15,708.55 88.94 275.66 6,070.67 5,939.80 -1,811.84 -12,721.41 5,947,194.01 475,641.49 2.02 12,842.76 MWD+IFR-AK-CAZ-SC (8) 15,801.55 89.42 279.11 6,072.00 5,941.13 -1,799.89 -12,813.61 5,947,206.10 475,549.31 3.75 12,931.49 MWD+IFR-AK-CAZ-SC (8) 15,897.96 88.80 283.58 6,073.50 5,942.63 -1,780.93 -12,908.10 5,947,225.20 475,454.86 4.68 13,021.25 MWD+IFR-AK-CAZ-SC (8) 15,992.15 88.32 285.64 6,075.86 5,944.99 -1,757.18 -12,999.21 5,947,249.09 475,363.79 2.24 13,106.86 MWD+IFR-AK-CAZ-SC (8) 16,088.03 88.63 285.14 6,078.42 5,947.55 -1,731.75 -13,091.62 5,947,274.67 475,271.43 0.61 13,193.44 MWD+IFR-AK-CAZ-SC (8) 16,182.07 88.90 284.19 6,080.44 5,949.57 -1,707.95 -13,182.57 5,947,298.61 475,180.52 1.05 13,278.88 MWD+IFR-AK-CAZ-SC (8) 16,277.53 88.84 282.00 6,082.33 5,951.46 -1,686.32 -13,275.53 5,947,320.37 475,087.61 2.29 13,366.67 MWD+IFR-AK-CAZ-SC (8) 16,370.84 88.53 278.58 6,084.47 5,953.60 -1,669.66 -13,367.30 5,947,337.17 474,995.88 3.68 13,454.15 MWD+IFR-AK-CAZ-SC (8) 16,465.94 88.08 274.04 6,087.28 5,956.41 -1,659.22 -13,461.76 5,947,347.76 474,901.45 4.80 13,545.36 MWD+IFR-AK-CAZ-SC (8) 16,560.45 88.29 274.54 6,090.28 5,959.41 -1,652.15 -13,555.95 5,947,354.97 474,807.27 0.57 13,636.90 MWD+IFR-AK-CAZ-SC (8) 16,655.41 87.81 276.96 6,093.51 5,962.64 -1,642.64 -13,650.37 5,947,364.63 474,712.87 2.60 13,728.24 MWD+IFR-AK-CAZ-SC (8) 16,749.18 87.88 279.13 6,097.03 5,966.16 -1,629.53 -13,743.15 5,947,377.88 474,620.13 2.31 13,817.33 MWD+IFR-AK-CAZ-SC (8) 16,844.19 87.32 281.59 6,101.01 5,970.14 -1,612.46 -13,836.52 5,947,395.09 474,526.79 2.65 13,906.31 MWD+IFR-AK-CAZ-SC (8) 16,939.58 88.06 281.76 6,104.86 5,973.99 -1,593.17 -13,929.86 5,947,414.52 474,433.49 0.80 13,994.89 MWD+IFR-AK-CAZ-SC (8) 17,033.26 91.65 278.84 6,105.09 5,974.22 -1,576.43 -14,022.01 5,947,431.41 474,341.38 4.94 14,082.72 MWD+IFR-AK-CAZ-SC (8) 17,128.30 96.52 278.41 6,098.33 5,967.46 -1,562.22 -14,115.70 5,947,445.76 474,247.71 5.14 14,172.53 MWD+IFR-AK-CAZ-SC (8) 17,223.64 96.19 278.74 6,087.77 5,956.90 -1,548.09 -14,209.40 5,947,460.04 474,154.05 0.49 14,262.35 MWD+IFR-AK-CAZ-SC (8) 17,317.61 95.68 278.12 6,078.06 5,947.19 -1,534.39 -14,301.85 5,947,473.88 474,061.63 0.85 14,351.02 MWD+IFR-AK-CAZ-SC (8) 17,408.22 93.00 279.06 6,071.20 5,940.33 -1,520.89 -14,391.18 5,947,487.51 473,972.33 3.13 14,436.65 MWD+IFR-AK-CAZ-SC (8) 17,500.78 92.49 278.98 6,066.77 5,935.90 -1,506.40 -14,482.49 5,947,502.15 473,881.05 0.56 14,524.05 MWD+IFR-AK-CAZ-SC (8) 17,592.72 93.30 278.20 6,062.12 5,931.25 -1,492.68 -14,573.28 5,947,516.00 473,790.29 1.22 14,611.08 MWD+IFR-AK-CAZ-SC (8) 17,686.79 94.68 277.74 6,055.58 5,924.71 -1,479.67 -14,666.22 5,947,529.15 473,697.39 1.55 14,700.35 MWD+IFR-AK-CAZ-SC (8) 17,778.18 91.22 278.22 6,050.88 5,920.01 -1,467.00 -14,756.59 5,947,541.96 473,607.04 3.82 14,787.14 MWD+IFR-AK-CAZ-SC (8) 17,870.42 89.75 278.26 6,050.09 5,919.22 -1,453.78 -14,847.87 5,947,555.32 473,515.79 1.59 14,874.74 MWD+IFR-AK-CAZ-SC (8) 2/27/2017 2:50:49PM Page 7 COMPASS 5000.1 Build 74 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-38 actual @ 130.87usft (Doyon 141) Well: 2M-38 North Reference: True Wellbore: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38 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) (°/100') (ft) Survey Tool Name 17,962.58 89.73 277.56 6,050.51 5,919.64 -1,441.10 -14,939.15 5,947,568.14 473,424.54 0.76 14,962.44 MWD+IFR-AK-CAZ-SC (8) 18,054.86 88.34 277.08 6,052.07 5,921.20 -1,429.34 -15,030.66 5,947,580.04 473,333.05 1.59 15,050.52 MWD+IFR-AK-CAZ-SC (8) 18,146.24 89.21 275.76 6,054.02 5,923.15 -1,419.13 -15,121.45 5,947,590.39 473,242.29 1.73 15,138.15 MWD+IFR-AK-CAZ-SC (8) 18,238.04 90.45 274.08 6,054.29 5,923.42 -1,411.26 -15,212.90 5,947,598.41 473,150.86 2.27 15,226.85 MWD+IFR-AK-CAZ-SC (8) 18,330.25 91.29 272.59 6,052.89 5,922.02 -1,405.89 -15,304.94 5,947,603.91 473,058.84 1.85 15,316.56 MWD+IFR-AK-CAZ-SC (8) 18,423.35 89.54 270.59 6,052.22 5,921.35 -1,403.31 -15,398.00 5,947,606.64 472,965.80 2.85 15,407.75 MWD+IFR-AK-CAZ-SC (8) 18,483.00 89.54 270.59 6,052.70 5,921.83 -1,402.69 -15,457.64 5,947,607.34 472,906.16 0.00 15,466.38 PROJECTED to TD 4-1/2" x 6-1/8" 2/27/2017 2:50:49PM Page 8 COMPASS 5000.1 Build 74 RECEIVED MAR 16 2017 AOGCC FINAL ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-38 2M-38 Definitive Survey Report 27 February, 2017 NAD 83 1 0083 28075 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-38 Wellbore: 2M-38 Design: 2M-38 Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature 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 2M-38 ACTUAL Tie On Depth: 29.57 Depth From (TVD) Well Position +N/ -S 0.00 usft Northing: 5,948,736.09 usft Latitude: 70° 16' 17.482 N +EI -W 0.00 usft Easting: 1,628,397.28 usft Longitude: 150° 5'49.966 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore 2M-38 Magnetics Model Name BGGM2016 Design Audit Notes: Version: Vertical Section: 2M-38 1.0 Sample Date Declination 1/20/2017 17.67 Dip Angle Field Strength (°) (nT) 80.88 57,533 Phase: ACTUAL Tie On Depth: 29.57 Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 29.57 0 00 0.00 260.00 Survey Program Date 2/27/2017 From To Map Vertical MD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 74.39 809.01 2M-38 Srvy 1 - SLB_GWD70 (2M-38) GYD-GC-SS Gyrodata gyro single shots 1/3/2017 9:35:0 847.52 2,952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/3/2017 9:37:3 3,005.44 3,005.44 2M-38 Srvy 3 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 1/10/2017 9:26:. 3,098.07 13,236.61 2M-38 Srvy 4 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1/10/2017 9:27:. 13,314.99 13,314.99 2M-38 Srvy 5 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 1/28/2017 9:48: 13,408.66 14,047.29 2M-38 Srvy 6 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1128/2017 9:49: 14,095.43 14,095.43 2M-38 Srvy 7 - SLB_INC+Filler (2M-38) INC+TREND Inclinometer + known azi trend 2/5/2017 3:00:3 14,192.33 18,423.35 2M-38 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2/5/2017 3:24:4 Survey 2/27/2017 12:33:25PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (`) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 29.57 0.00 0.00 29.57 -101.30 0.00 0.00 5,948,736.09 1,628,397.26 0.00 0.00 UNDEFINED 74.39 0.49 95.41 74.39 -56.48 -0.02 0.19 5,948,736.08 1,628,397.47 1.09 -0.18 GYD-GC-SS(1) 110.00 0.40 93.46 110.00 -20.87 -0.04 0.47 5,948,736.05 1,628,397.75 0.24 -0.45 NOT an Actual Survey 30" x 20" 166.39 0.27 87.83 166.39 35.52 -0.05 0.80 5,948,736.05 1,628,398.08 0.24 -0.78 GYD-GC-SS (1) 260.70 2.18 158.80 260.67 129.80 -1.71 1.67 5,948,734.38 1,628,398.95 2.23 -1.35 GYD-GC-SS(1) 350.18 3.32 159.75 350.05 219.18 -5.73 3.18 5,948,730.36 1,628,400.45 1.28 -2.14 GYD-GC-SS (1) 444.01 5.98 165.98 443.56 312.69 -13.02 5.31 5,948,723.07 1,628,402.57 2.88 -2.97 GYD-GC-SS (1) 2/27/2017 12:33:25PM Page 2 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 2M-38 North Reference: Wellbore: 2M-38 Survey Calculation Method: Design: 2M-38 Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 535.02 6.18 173.63 534.06 403.19 -22.49 7.00 5,948,713.60 1,628,404.24 0.92 -2.99 GYD-GC-SS (1) 626.51 6.81 180.04 624.97 494.10 -32.81 7.54 5,948,703.28 1,628,404.77 1.05 -1.73 GYD-GC-SS (1) 718.62 4.71 178.70 716.61 585.74 -42.05 7.62 5,948,694.04 1,628,404.84 2.28 -0.21 GYD-GC-SS (1) 809.01 6.55 179.77 806.56 675.69 -50.92 7.73 5,948,685.17 1,628,404.93 2.04 1.23 GYD-GC-SS (1) 847.52 7.60 181.94 844.77 713.90 -55.66 7.65 5,948,680.43 1,628,404.84 2.81 2.13 MWD+IFR-AK-CAZ-SC (2) 940.13 10.47 185.54 936.22 805.35 -70.16 6.63 5,948,665.93 1,628,403.80 3.16 5.65 MWD+IFR-AK-CAZ-SC (2) 1,034.52 11.93 184.22 1,028.81 897.94 -88.42 5.09 5,948,647.67 1,628,402.22 1.57 10.35 MWD+IFR-AK-CAZ-SC (2) 1,127.77 13.34 182.66 1,119.80 988.93 -108.78 3.88 5,948,627.31 1,628,400.98 1.56 15.07 MWD+IFR-AK-CAZ-SC (2) 1,221.58 18.99 178.84 1,209.87 1,079.00 -134.88 3.68 5,948,601.23 1,628,400.75 6.13 19.79 MWD+IFR-AK-CAZ-SC (2) 1,315.01 22.92 177.26 1,297.10 1,166.23 -168.26 4.86 5,948,567.84 1,628,401.87 4.25 24.43 MWD+IFR-AK-CAZ-SC (2) 1,407.64 23.11 178.16 1,382.36 1,251.49 -204.45 6.31 5,948,531.66 1,628,403.26 0.43 29.29 MWD+IFR-AK-CAZ-SC (2) 1,500.06 22.58 178.66 1,467.53 1,336.66 -240.31 7.30 5,948,495.79 1,628,404.20 0.61 34.54 MWD+IFR-AK-CAZ-SC (2) 1,593.04 27.05 185.87 1,551.93 1,421.06 -279.22 5.56 5,948,456.89 1,628,402.39 5.80 43.01 MWD+IFR-AK-CAZ-SC (2) 1,687.70 26.42 193.25 1,636.49 1,505.62 -321.14 -1.47 5,948,414.99 1,628,395.30 3.57 57.21 MWD+IFR-AK-CAZ-SC (2) 1,779.53 27.50 199.10 1,718.35 1,587.48 -361.07 -13.09 5,948,375.08 1,628,383.61 3.12 75.59 MWD+IFR-AK-CAZ-SC (2) 1,872.17 28.34 207.74 1,800.24 1,669.37 -400.76 -30.33 5,948,335.42 1,628,366.31 4.46 99.46 MWD+IFR-AK-CAZ-SC (2) 1,965.74 26.51 216.65 1,883.33 1,752.46 -437.19 -53.15 5,948,299.04 1,628,343.44 4.80 128.26 MWD+IFR-AK-CAZ-SC (2) 2,059.09 28.63 223.46 1,966.09 1,835.22 -470.15 -80.98 5,948,266.12 1,628,315.56 4.07 161.39 MWD+IFR-AK-CAZ-SC (2) 2,150.45 30.57 228.86 2,045.54 1,914.67 -501.33 -113.54 5,948,235.00 1,628,282.95 3.61 198.87 MWD+IFR-AK-CAZ-SC (2) 2,242.21 33.31 234.74 2,123.42 1,992.55 -531.24 -151.70 5,948,205.15 1,628,244.74 4.51 241.65 MWD+IFR-AK-CAZ-SC (2) 2,336.09 37.44 238.74 2,199.96 2,069.09 -560.94 -197.17 5,948,175.52 1,628,199.23 5.04 291.58 MWD+IFR-AK-CAZ-SC (2) 2,430.23 41.42 241.73 2,272.67 2,141.80 -590.56 -249.08 5,948,145.99 1,628,147.28 4.68 347.85 MWD+IFR-AK-CAZ-SC (2) 2,521.66 44.56 242.74 2,339.54 2,208.67 -619.58 -304.25 5,948,117.06 1,628,092.07 3.52 407.21 MWD+IFR-AK-CAZ-SC (2) 2,617.38 46.68 246.74 2,406.50 2,275.63 -648.72 -366.11 5,948,088.02 1,628,030.17 3.72 473.20 MWD+IFR-AK-CAZ-SC (2) 2,710.86 49.33 249.13 2,469.04 2,338.17 -674.79 -430.49 5,948,062.06 1,627,965.75 3.41 541.13 MWD+IFR-AK-CAZ-SC (2) 2,803.36 51.01 250.40 2,528.29 2,397.42 -699.34 -497.14 5,948,037.61 1,627,899.07 2.10 611.03 MWD+IFR-AK-CAZ-SC (2) 2,896.07 55.95 251.20 2,583.44 2,452.57 -723.82 -567.49 5,948,013.25 1,627,828.70 5.37 684.56 MWD+IFR-AK-CAZ-SC (2) 2,952.69 61.15 253.71 2,612.98 2,482.11 -738.35 -613.53 5,947,998.80 1,627,782.63 9.93 732.42 MWD+IFR-AK-CAZ-SC (2) 3,005.44 60.08 253.98 2,638.86 2,507.99 -751.14 -657.68 5,947,986.08 1,627,738.47 2.08 778.12 INC+TREND (3) 3,044.00 60.45 254.18 2,657.99 2,527.12 -760.32 -689.88 5,947,976.95 1,627,706.26 1.07 811.42 1 NOT an Actual Survey (4) 13 3/8" x 16" 3,098.07 60.98 254.46 2,684.43 2,553.56 -773.07 -735.28 5,947,964.28 1,627,660.84 1.07 858.35 MWD+IFR-AK-CAZ-SC (4) 3,192.17 61.75 254.76 2,729.53 2,598.66 -794.99 -814.91 5,947,942.49 1,627,581.18 0.86 940.58 MWD+IFR-AK-CAZ-SC (4) 3,286.28 63.19 257.18 2,773.03 2,642.16 -815.20 -895.87 5,947,922.40 1,627,500.20 2.75 1,023.81 MWD+IFR-AK-CAZ-SC (4) 3,379.73 64.50 261.19 2,814.24 2,683.37 -830.92 -978.24 5,947,906.82 1,627,417.82 4.10 1,107.66 MWD+IFR-AK-CAZ-SC (4) 3,472.76 65.69 264.63 2,853.42 2,722.55 -841.32 -1,061.95 5,947,896.55 1,627,334.09 3.59 1,191.91 MWD+IFR-AK-CAZ-SC (4) 3,565.38 66.85 265.41 2,890.69 2,759.82 -848.68 -1,146.42 5,947,889.33 1,627,249.62 1.47 1,276.37 MWD+IFR-AK-CAZ-SC (4) 3,659.05 70.41 266.50 2,924.82 2,793.95 -854.82 -1,233.42 5,947,883.33 1,627,162.62 3.95 1,363.12 MWD+IFR-AK-CAZ-SC (4) 3,750.72 71.88 268.51 2,954.45 2,823.58 -858.59 -1,320.08 5,947,879.70 1,627,075.96 2.62 1,449.12 MWD+IFR-AK-CAZ-SC (4) 3,845.19 72.85 270.01 2,983.07 2,852.20 -859.75 -1,410.10 5,947,878.68 1,626,985.95 1.83 1,537.97 MWD+IFR-AK-CAZ-SC (4) 212 71201 7 12:33:25PM Page 3 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 2M-38 North Reference: Wellbore: 2M-38 Survey Calculation Method: Design: 2M-38 Database: Survey Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 Vertical Section (ft) Survey Tool Name 1,626.68 MWD+IFR-AK-CAZ-SC (4) 1,713.76 MWD+IFR-AK-CAZ-SC (4) 1,801.13 MWD+IFR-AK-CAZ-SC (4) 1,888.98 MWD+IFR-AK-CAZ-SC (4) 1,977.66 MWD+IFR-AK-CAZ-SC (4) 2,066.13 MWD+IFR-AK-CAZ-SC (4) 2,155.71 MWD+IFR-AK-CAZ-SC (4) 2,244.97 MWD+IFR-AK-CAZ-SC (4) 2,334.53 MWD+IFR-AK-CAZ-SC (4) 21424.40 MWD+IFR-AK-CAZ-SC (4) 2,514.66 MWD+IFR-AK-CAZ-SC (4) 2,603.79 MWD+IFR-AK-CAZ-SC (4) 2,692.68 MWD+IFR-AK-CAZ-SC (4) 2,783.05 MWD+IFR-AK-CAZ-SC (4) 2,873.70 MWD+IFR-AK-CAZ-SC (4) 2,963.78 MWD+IFR-AK-CAZ-SC (4) 3,053.30 MWD+IFR-AK-CAZ-SC (4) 3,141.46 MWD+IFR-AK-CAZ-SC (4) 3,231.97 MWD+IFR-AK-CAZ-SC (4) 3,320.50 MWD+IFR-AK-CAZ-SC (4) 3,409.77 MWD+IFR-AK-CAZ-SC (4) 3,499.36 MWD+IFR-AK-CAZ-SC (4) 3,588.41 MWD+IFR-AK-CAZ-SC (4) 3,676.77 MWD+IFR-AK-CAZ-SC (4) 3,768.86 MWD+IFR-AK-CAZ-SC (4) 3,858.78 MWD+IFR-AK-CAZ-SC (4) 3,947.29 MWD+IFR-AK-CAZ-SC (4) 4,035.93 MWD+IFR-AK-CAZ-SC (4) 4,124.56 MWD+IFR-AK-CAZ-SC (4) 4,214.65 MWD+IFR-AK-CAZ-SC (4) 4,303.86 MWD+IFR-AK-CAZ-SC (4) 4,393.57 MWD+IFR-AK-CAZ-SC (4) 4,483.45 MWD+IFR-AK-CAZ-SC (4) 4,571.93 MWD+IFR-AK-CAZ-SC (4) 4,661.81 MWD+IFR-AK-CAZ-SC (4) 4,749.58 MWD+IFR-AK-CAZ-SC (4) 4.838.39 MWD+IFR-AK-CAZ-SC (4) 4,927.49 MWD+IFR-AK-CAZ-SC (4) 5,017.14 MWD+IFR-AK-CAZ-SC (4) 5,106.56 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 12:33:25PM Page 4 COMPASS 5000.1 Build 74 Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (I V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 3,939.25 74.42 271.16 3,009.57 2,878.70 -858.83 -1,500.34 5,947,879.75 1,626,895.72 2.04 4,031.95 72.86 272.34 3,035.68 2,904.81 -856.11 -1,589.24 5,947,882.61 1,626,806.84 2.08 4,125.21 73.43 271.19 3,062.72 2,931.85 -853.37 -1,678.45 5,947,885.50 1,626,717.64 1.33 4,218.27 74.05 269.76 3,088.78 2,957.91 -852.63 -1,767.78 5,947,886.38 1,626,628.32 1.62 4,311.58 73.60 266.71 3,114.78 2,983.91 -855.38 -1,857.34 5,947,883.76 1,626,538.76 3.18 4,404.26 73.36 263.71 3,141.14 3,010.27 -862.80 -1,945.87 5,947,876.49 1,626,450.23 3.11 4,498.05 73.18 264.69 3,168.14 3,037.27 -871.88 -2,035.23 5,947,867.55 1,626,360.86 1.02 4,591.59 73.12 264.19 3,195.25 3,064.38 -880.55 -2,124.33 5,947,859.02 1,626,271.75 0.52 4,685.34 73.43 263.88 3,222.23 3,091.36 -889.88 -2,213.63 5,947,849.84 1,626,182.45 0.46 4,779.30 73.56 264.03 3,248.93 3,118.06 -899.37 -2,303.22 5,947,840.49 1,626,092.86 0.21 4,873.44 73.86 261.26 3,275.34 3,144.47 -910.94 -2,392.83 5,947,829.07 1,626,003.24 2.84 4,966.25 73.97 262.19 3,301.05 3,170.18 -923.77 -2,481.07 5,947,816.38 1,625,914.98 0.97 5,058.86 73.66 261.75 3,326.87 3,196.00 -936.20 -2,569.14 5,947,804.10 1,625,826.90 0.57 5,153.15 73.45 262.38 3,353.56 3,222.69 -948.68 -21658.71 5,947,791.76 1,625,737.33 0.68 5,247.73 73.77 262.60 3,380.25 3,249.38 -960.54 -2,748.66 5,947,780.04 1,625,647.36 0.41 5,341.64 73.77 262.50 3,406.50 3,275.63 -972.23 -2,838.07 5,947,768.49 1,625,557.94 0.10 5,435.06 73.27 261.76 3,433.00 3,302.13 -984.50 -2,926.81 5,947,756.37 1,625,469.20 0.93 5,527.19 73.27 262.65 3,459.52 3,328.65 -996.46 -3,014.22 5,947,744.55 1,625,381.77 0.93 5,621.72 73.44 261.34 3,486.60 3,355.73 -1,009.07 -3,103.91 5,947,732.08 1,625,292.08 1.34 5,714.13 73.27 260.89 3,513.07 3,382.20 -1,022.75 -3,191.38 5,947,718.54 1,625,204.59 0.50 5,807.31 73.47 261.05 3,539.73 3,408.86 -1,036.76 -3,279.56 5,947,704.67 1,625,116.40 0.27 5,900.82 73.34 261.37 3,566.44 3,435.57 -1,050.46 -3,368.12 5,947,691.12 1,625,027.82 0.36 5,993.80 73.35 261.46 3,593.09 3,462.22 -1,063.75 -3,456.20 5,947,677.97 1,624,939.73 0.09 6,086.10 73.21 261.86 3,619.64 3,488.77 -1,076.58 -3,543.66 5,947,665.29 1,624,852.26 0.44 6,182.26 73.44 261.21 3,647.24 3,516.37 -1,090.14 -3,634.78 5,947,651.87 1,624,761.13 0.69 6,276.14 73.31 261.82 3,674.10 3,543.23 -1,103.41 -3,723.75 5,947,638.74 1,624,672.15 0.64 6,368.62 73.25 262.36 3,700.70 3,569.83 -1,115.60 -3,811.47 5,947,626.70 1,624,584.41 0.56 6,461.24 73.31 261.94 3,727.35 3,596.48 -1,127.71 -3,899.35 5,947,614.72 1,624,496.53 0.44 6,553.86 73.19 262.45 3,754.04 3,623.17 -1,139.76 -3,987.21 5,947,602.82 1,624,408.65 0.54 6,648.08 73.25 263.40 3,781.24 3,650.37 -1,150.87 -4,076.73 5,947,591.85 1,624,319.12 0.97 6,741.43 73.09 262.96 3,808.27 3,677.40 -1,161.48 -4,165.45 5,947,581.38 1,624,230.39 0.48 6,835.33 73.29 264.22 3,835.43 3,704.56 -1,171.51 -4,254.78 5,947,571.49 1,624,141.06 1.30 6,929.47 73.22 264.59 3,862.55 3,731.68 -1,180.30 -4,344.50 5,947,562.85 1,624,051.34 0.38 7,022.21 73.22 264.97 3,889.33 3,758.46 -1,188.38 -4,432.92 5,947,554.91 1,623,962.91 0.39 7,116.38 73.25 264.23 3,916.49 3,785.62 -1,196.87 -4,522.68 5,947,546.57 1,623,873.14 0.75 7,208.32 73.36 265.06 3,942.90 3,812.03 -1,205.08 -4,610.36 5,947,538.49 1,623,785.46 0.87 7,301.34 73.34 264.53 3,969.55 3,838.68 -1,213.17 -4,699.12 5,947,530.55 1,623,696.70 0.55 7,394.54 73.27 262.42 3,996.33 3,865.46 -1,223.31 -4,787.80 5,947,520.55 1,623,608.01 2.17 7,488.18 73.41 261.80 4,023.18 3,892.31 -1,235.63 -4,876.66 5,947,508.38 1,623,519.14 0.65 7,581.60 73.12 261.68 4,050.08 3,919.21 -1,248.48 -4,965.20 5,947,495.67 1,623,430.59 0.33 Vertical Section (ft) Survey Tool Name 1,626.68 MWD+IFR-AK-CAZ-SC (4) 1,713.76 MWD+IFR-AK-CAZ-SC (4) 1,801.13 MWD+IFR-AK-CAZ-SC (4) 1,888.98 MWD+IFR-AK-CAZ-SC (4) 1,977.66 MWD+IFR-AK-CAZ-SC (4) 2,066.13 MWD+IFR-AK-CAZ-SC (4) 2,155.71 MWD+IFR-AK-CAZ-SC (4) 2,244.97 MWD+IFR-AK-CAZ-SC (4) 2,334.53 MWD+IFR-AK-CAZ-SC (4) 21424.40 MWD+IFR-AK-CAZ-SC (4) 2,514.66 MWD+IFR-AK-CAZ-SC (4) 2,603.79 MWD+IFR-AK-CAZ-SC (4) 2,692.68 MWD+IFR-AK-CAZ-SC (4) 2,783.05 MWD+IFR-AK-CAZ-SC (4) 2,873.70 MWD+IFR-AK-CAZ-SC (4) 2,963.78 MWD+IFR-AK-CAZ-SC (4) 3,053.30 MWD+IFR-AK-CAZ-SC (4) 3,141.46 MWD+IFR-AK-CAZ-SC (4) 3,231.97 MWD+IFR-AK-CAZ-SC (4) 3,320.50 MWD+IFR-AK-CAZ-SC (4) 3,409.77 MWD+IFR-AK-CAZ-SC (4) 3,499.36 MWD+IFR-AK-CAZ-SC (4) 3,588.41 MWD+IFR-AK-CAZ-SC (4) 3,676.77 MWD+IFR-AK-CAZ-SC (4) 3,768.86 MWD+IFR-AK-CAZ-SC (4) 3,858.78 MWD+IFR-AK-CAZ-SC (4) 3,947.29 MWD+IFR-AK-CAZ-SC (4) 4,035.93 MWD+IFR-AK-CAZ-SC (4) 4,124.56 MWD+IFR-AK-CAZ-SC (4) 4,214.65 MWD+IFR-AK-CAZ-SC (4) 4,303.86 MWD+IFR-AK-CAZ-SC (4) 4,393.57 MWD+IFR-AK-CAZ-SC (4) 4,483.45 MWD+IFR-AK-CAZ-SC (4) 4,571.93 MWD+IFR-AK-CAZ-SC (4) 4,661.81 MWD+IFR-AK-CAZ-SC (4) 4,749.58 MWD+IFR-AK-CAZ-SC (4) 4.838.39 MWD+IFR-AK-CAZ-SC (4) 4,927.49 MWD+IFR-AK-CAZ-SC (4) 5,017.14 MWD+IFR-AK-CAZ-SC (4) 5,106.56 MWD+IFR-AK-CAZ-SC (4) 2/27/2017 12:33:25PM Page 4 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-38 Wellbore: 2M-38 Design: 2M-38 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 Vertical Section (ft) Survey Tool Name 5,194.39 MWD+IFR-AK-CAZ-SC (4) 5,284.11 MWD+IFR-AK-CAZ-SC (4) 5,372.62 MWD+IFR-AK-CAZ-SC (4) 5,462.05 MWD+IFR-AK-CAZ-SC (4) 5,552.19 MWD+IFR-AK-CAZ-SC (4) 5,641.87 MWD+IFR-AK-CAZ-SC (4) 5,730.06 MWD+IFR-AK-CAZ-SC (4) 5,819.89 MWD+IFR-AK-CAZ-SC (4) 5,910.07 MWD+IFR-AK-CAZ-SC (4) 5,998.32 MWD+IFR-AK-CAZ-SC (4) 6,087.99 MWD+IFR-AK-CAZ-SC (4) 6,177.91 MWD+IFR-AK-CAZ-SC (4) 6,266.22 MWD+IFR-AK-CAZ-SC (4) 6,357.31 MWD+IFR-AK-CAZ-SC (4) 6,445.94 MWD+IFR-AK-CAZ-SC (4) 6,535.12 MWD+IFR-AK-CAZ-SC (4) 6,626.11 MWD+IFR-AK-CAZ-SC (4) 6,714.50 MWD+IFR-AK-CAZ-SC (4) 6,803.86 MWD+IFR-AK-CAZ-SC (4) 6,893.81 MWD+IFR-AK-CAZ-SC (4) 6,982.34 MWD+IFR-AK-CAZ-SC (4) 7,073.06 MWD+IFR-AK-CAZ-SC (4) 7,163.19 MWD+IFR-AK-CAZ-SC (4) 7,251.78 MWD+IFR-AK-CAZ-SC (4) 7,340.59 MWD+IFR-AK-CAZ-SC (4) 7,430.99 MWD+IFR-AK-CAZ-SC (4) 7,520.27 MWD+IFR-AK-CAZ-SC (4) 7,609.85 MWD+IFR-AK-CAZ-SC (4) 7,700.22 MWD+IFR-AK-CAZ-SC (4) 7,789.38 MWD+IFR-AK-CAZ-SC (4) 7,880.24 MWD+IFR-AK-CAZ-SC (4) 7,969.64 MWD+IFR-AK-CAZ-SC (4) 8,058.02 MWD+IFR-AK-CAZ-SC (4) 8,147.53 MWD+IFR-AK-CAZ-SC (4) 8,237.15 MWD+IFR-AK-CAZ-SC (4) 8,326.19 MWD+IFR-AK-CAZ-SC (4) 8,414.78 MWD+IFR-AK-CAZ-SC (4) 8,504.16 MWD+IFR-AK-CAZ-SC (4) 8,591.30 MWD+IFR-AK-CAZ-SC (4) 8,682.33 MWD+IFR-AK-CAZ-SC (4) 212712017 12:33:25PM Page 5 COMPASS 5000.1 Build 74 Map Map MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS (usft) (I (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') 7,673.37 73.35 261.79 4,076.55 3,945.68 -1,261.11 -5,052.15 5,947,483.18 1,623,343.62 0.28 7,767.11 73.13 261.64 4,103.58 3,972.71 -1,274.05 -5,140.98 5,947,470.39 1,623,254.79 0.28 7,859.59 73.31 261.60 4,130.28 3,999.41 -1,286.95 -5,228.57 5,947,457.62 1,623,167.18 0.20 7,952.95 73.61 262.65 4,156.86 4,025.99 -1,299.21 -5,317.22 5,947,445.51 1,623,078.52 1.13 8,047.09 73.26 262.58 4,183.70 4,052.83 -1,310.81 -5,406.71 5,947,434.05 1,622,989.03 0.38 8,140.76 73.64 263.04 4,210.38 4,079.51 -1,322.05 -5,495.79 5,947,422.96 1,622,899.93 0.62 8,232.78 73.78 263.36 4,236.19 4,105.32 -1,332.50 -5,583.50 5,947,412.64 1,622,812.22 0.37 8,326.46 74.10 264.09 4,262.11 4,131.24 -1,342.34 -5,672.98 5,947,402.95 1,622,722.73 0.82 8,420.57 73.83 264.65 4,288.10 4,157.23 -1,351.22 -5,762.99 5,947,394.22 1,622,632.71 0.64 8,512.73 74.03 265.02 4,313.61 4,182.74 -1,359.19 -5,851.19 5,947,386.39 1,622,544.51 0.44 8,606.38 74.10 265.43 4,339.32 4,208.45 -1,366.69 -5,940.93 5,947,379.03 1,622,454.77 0.43 8,700.38 73.75. 265.54 4,365.35 4,234.48 -1,373.80 -6,030.97 5,947,372.07 1,622,364.72 0.39 8,792.78 73.64 264.92 4,391.29 4,260.42 -1,381.17 -6,119.35 5,947,364.84 1,622,276.34 0.65 8,888.08 73.33 264.04 4,418.38 4,287.51 -1,389.96 -6,210.29 5,947,356.19 1,622,185.40 0.94 8,980.80 73.47 264.17 4,444.87 4,314.00 -1,399.08 -6,298.68 5,947,347.21 1,622,097.00 0.20 9,074.16 73.12 264.06 4,471.71 4,340.84 -1,408.25 -6,387.63 5,947,338.18 1,622,008.05 0.39 9,169.42 73.12 262.90 4,499.37 4,368.50 -1,418.60 -6,478.19 5,947,327.98 1,621,917.48 1.17 9,261.89 73.37 263.85 4,526.03 4,395.16 -1,428.82 -6,566.14 5,947,317.91 1,621,829.52 1.02 9,355.29 73.48 262.86 4,552.67 4,421.80 -1,439.18 -6,655.06 5,947,307.69 1,621,740.60 1.02 9,449.25 73.49 263.43 4,579.38 4,448.51 -1,449.93 -6,744.50 5,947,297.08 1,621,651.15 0.58 9,541.68 73.55 262.12 4,605.61 4,474.74 -1,461.08 -6,832.43 5,947,286.08 1,621,563.21 1.36 9,636.38 73.55 263.16 4,632.42 4,501.55 -1,472.71 -6,922.50 5,947,274.59 1,621,473.13 1.05 9,730.46 73.58 262.46 4,659.04 4,528.17 -1,484.00 -7,012.03 5,947,263.44 1,621,383.59 0.71 9,822.97 73.36 262.92 4,685.36 4,554.49 -1,495.29 -7,099.99 5,947,252.29 1,621,295.62 0.53 9,915.77 73.43 262.97 4,711.88 4,581.01 -1,506.21 -7,188.25 5,947,241.51 1,621,207.35 0.09 10,010.19 73.64 263.68 4,738.64 4,607.77 -1,516.74 -7,278.18 5,947,231.13 1,621,117.41 0.75 10,103.41 73.49 262.53 4,765.02 4,634.15 -1,527.47 -7,366.94 5,947,220.54 1,621,028.64 1.19 10,197.02 73.28 263.40 4,791.79 4,660.92 -1,538.46 -7,455.97 5,947,209.70 1,620,939.61 0.92 10,291.59 73.20 263.77 4,819.06 4,688.19 -1,548.57 -7,545.95 5,947,199.73 1,620,849.62 0.38 10,384.94 72.90 262.42 4,846.27 4,715.40 -1,559.31 -7,634.60 5,947,189.14 1,620,760.96 1.42 10,480.08 73.07 263.39 4,874.11 4,743.24 -1,570.54 -7,724.88 5,947,178.04 1,620,670.68 0.99 10,573.68 73.35 264.46 4,901.15 4,770.28 -1,580.03 -7,813.98 5,947,168.71 1,620,581.56 1.13 10,666.32 72.98 264.72 4,927.98 4,797.11 -1,588.39 -7,902.26 5,947,160.49 1,620,493.29 0.48 10,760.20 73.12 264.56 4,955.35 4,824.48 -1,596.78 -7,991.67 5,947,152.24 1,620,403.87 0.22 10,854.04 73.50 264.33 4,982.30 4,851.43 -1,605.48 -8,081.13 5,947,143.68 1,620,314.40 0.47 10,947.19 73.55 264.82 5,008.72 4,877.85 -1,613.92 -8,170.06 5,947,135.38 1,620,225.47 0.51 11,039.89 73.42 264.40 5,035.07 4,904.20 -1,622.27 -8,258.54 5,947,127.18 1,620,136.99 0.46 11,133.42 73.61 265.02 5,061.61 4,930.74 -1,630.54 -8,347.84 5,947,119.05 1,620,047.68 0.67 11,224.58 73.64 264.74 5,087.31 4,956.44 -1,638.34 -8,434.95 5,947,111.39 1,619,960.56 0.30 11,319.87 73.55 265.69 5,114.22 4,983.35 -1,645.97 -8,526.04 5,947,103.91 1,619,869.47 0.96 Vertical Section (ft) Survey Tool Name 5,194.39 MWD+IFR-AK-CAZ-SC (4) 5,284.11 MWD+IFR-AK-CAZ-SC (4) 5,372.62 MWD+IFR-AK-CAZ-SC (4) 5,462.05 MWD+IFR-AK-CAZ-SC (4) 5,552.19 MWD+IFR-AK-CAZ-SC (4) 5,641.87 MWD+IFR-AK-CAZ-SC (4) 5,730.06 MWD+IFR-AK-CAZ-SC (4) 5,819.89 MWD+IFR-AK-CAZ-SC (4) 5,910.07 MWD+IFR-AK-CAZ-SC (4) 5,998.32 MWD+IFR-AK-CAZ-SC (4) 6,087.99 MWD+IFR-AK-CAZ-SC (4) 6,177.91 MWD+IFR-AK-CAZ-SC (4) 6,266.22 MWD+IFR-AK-CAZ-SC (4) 6,357.31 MWD+IFR-AK-CAZ-SC (4) 6,445.94 MWD+IFR-AK-CAZ-SC (4) 6,535.12 MWD+IFR-AK-CAZ-SC (4) 6,626.11 MWD+IFR-AK-CAZ-SC (4) 6,714.50 MWD+IFR-AK-CAZ-SC (4) 6,803.86 MWD+IFR-AK-CAZ-SC (4) 6,893.81 MWD+IFR-AK-CAZ-SC (4) 6,982.34 MWD+IFR-AK-CAZ-SC (4) 7,073.06 MWD+IFR-AK-CAZ-SC (4) 7,163.19 MWD+IFR-AK-CAZ-SC (4) 7,251.78 MWD+IFR-AK-CAZ-SC (4) 7,340.59 MWD+IFR-AK-CAZ-SC (4) 7,430.99 MWD+IFR-AK-CAZ-SC (4) 7,520.27 MWD+IFR-AK-CAZ-SC (4) 7,609.85 MWD+IFR-AK-CAZ-SC (4) 7,700.22 MWD+IFR-AK-CAZ-SC (4) 7,789.38 MWD+IFR-AK-CAZ-SC (4) 7,880.24 MWD+IFR-AK-CAZ-SC (4) 7,969.64 MWD+IFR-AK-CAZ-SC (4) 8,058.02 MWD+IFR-AK-CAZ-SC (4) 8,147.53 MWD+IFR-AK-CAZ-SC (4) 8,237.15 MWD+IFR-AK-CAZ-SC (4) 8,326.19 MWD+IFR-AK-CAZ-SC (4) 8,414.78 MWD+IFR-AK-CAZ-SC (4) 8,504.16 MWD+IFR-AK-CAZ-SC (4) 8,591.30 MWD+IFR-AK-CAZ-SC (4) 8,682.33 MWD+IFR-AK-CAZ-SC (4) 212712017 12:33:25PM Page 5 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-38 Wellbore: 2M-38 Design: 2M-38 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 2/27/2017 12:33.25PM Page 6 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,413.10 73.39 265.78 5,140.75 5,009.88 -1,652.62 -8,615.17 5,947,097.40 1,619,780.34 0.19 8,771.26 MWD+IFR-AK-CAZ-SC (4) 11,507.22 73.55 264.79 5,167.53 5,036.66 -1,660.03 -8,705.10 5,947,090.13 1,619,690.41 1.02 8,861.11 MWD+IFR-AK-CAZ-SC (4) 11,600.65 73.46 264.68 5,194.06 5,063.19 -1,668.25 -8,794.30 5,947,082.05 1,619,601.20 0.15 8,950.39 MWD+IFR-AK-CAZ-SC (4) 11,692.44 73.62 263.01 5,220.07 5,089.20 -1,677.69 -8,881.82 5,947,072.76 1,619,513.68 1.75 9,038.21 MWD+IFR-AK-CAZ-SC (4) 11,785.91 73.55 262.65 5,246.48 5,115.61 -1,688.88 -8,970.78 5,947,061.71 1,619,424.71 0.38 9,127.77 MWD+IFR-AK-CAZ-SC (4) 11,878.02 73.50 263.11 5,272.60 5,141.73 -1,699.83 -9,058.43 5,947,050.90 1,619,337.05 0.48 9,215.98 MWD+IFR-AK-CAZ-SC (4) 11,970.46 71.73 263.68 5,300.22 5,169.35 -1,709.98 -9,146.05 5,947,040.89 1,619,249.42 2.00 9,304.04 MWD+IFR-AK-CAZ-SC (4) 12,064.20 69.47 265.54 5,331.36 5,200.49 -1,718.29 -9,234.07 5,947,032.72 1,619,161.40 3.05 9,392.16 MWD+IFR-AK-CAZ-SC (4) 12,156.29 66.90 264.16 5,365.58 5,234.71 -1,725.96 -9,319.21 5,947,025.19 1,619,076.25 3.12 9,477.34 MWD+IFR-AK-CAZ-SC (4) 12,250.13 66.50 265.40 5,402.70 5,271.83 -1,733.80 -9,405.04 5,947,017.49 1,618,990.42 1.29 9,563.23 MWD+IFR-AK-CAZ-SC (4) 12,344.54 66.67 265.48 5,440.22 5,309.35 -1,740.69 -9,491.40 5,947,010.74 1,618,904.06 0.20 9,649.47 MWD+IFR-AK-CAZ-SC (4) 12,438.03 66.60 264.24 5,477.29 5,346.42 -1,748.38 -9,576.88 5,947,003.19 1,618,818.58 1.22 9,734.98 MWD+IFR-AK-CAZ-SC (4) 12,530.88 66.63 264.59 5,514.15 5,383.28 -1,756.67 -9,661.69 5,946,995.03 1,618,733.76 0.35 9,819.95 MWD+IFR-AK-CAZ-SC (4) 12,624.47 66.61 264.49 5,551.29 5,420.42 -1,764.85 -9,747.21 5,946,986.99 1,618,648.24 0.10 9,905.59 MWD+IFR-AK-CAZ-SC (4) 12,715.53 66.54 265.15 5,587.49 5,456.62 -1,772.39 -9,830.42 5,946,979.58 1,618,565.02 0.67 9,988.85 MWD+IFR-AK-CAZ-SC (4) 12,808.41 66.51 265.43 5,624.49 5,493.62 -1,779.38 -9,915.33 5,946,972.72 1,618,480.11 0.28 10,073.68 MWD+IFR-AK-CAZ-SC (4) 12,903.72 66.69 265.28 5,662.34 5,531.47 -1,786.47 -10,002.51 5,946,965.78 1,618,392.93 0.24 10,160.77 MWD+IFR-AK-CAZ-SC (4) 12,996.07 66.80 266.00 5,698.80 5,567.93 -1,792.92 -10,087.11 5,946,959.47 1,618,308.32 0.73 10,245.20 MWD+IFR-AK-CAZ-SC (4) 13,090.27 66.63 265.85 5,736.04 5,605.17 -1,799.07 -10,173.42 5,946,953.46 1,618,222.01 0.23 10,331.27 MWD+IFR-AK-CAZ-SC (4) 13,183.28 66.72 267.60 5,772.87 5,642.00 -1,803.95 -10,258.69 5,946,948.71 1,618,136.75 1.73 10,416.09 MWD+IFR-AK-CAZ-SC (4) 13,236.61 66.90 267.44 5,793.87 5,663.00 -1,806.07 -10,307.66 5,946,946.67 1,618,087.78 0.44 10,464.68 MWD+IFR-AK-CAZ-SC (4) 13,305.00 66.35 268.16 5,821.00 5,690.13 -1,808.48 -10,370.39 5,946,944.36 1,618,025.05 1.25 10,526.88 NOT an Actual Survey 9 5/8" x 12 1/4" 13,314.99 66.27 268.26 5,825.02 5,694.15 -1,808.77 -10,379.53 5,946,944.09 1,618,015.91 1.25 10,535.94 INC+TREND (5) 13,408.66 66.96 269.24 5,862.19 5,731.32 -1,810.64 -10,465.49 5,946,942.35 1,617,929.96 1.21 10,620.91 MWD+IFR-AK-CAZ-SC (6) 13,441.65 67.06 269.29 5,875.08 5,744.21 -1,811.03 -10,495.86 5,946,942.01 1,617,899.59 0.33 10,650.88 MWD+IFR-AK-CAZ-SC (6) 13,475.29 66.93 269.98 5,888.23 5,757.36 -1,811.23 -10,526.82 5,946,941.86 1,617,868.63 1.93 10,681.41 MWD+IFR-AK-CAZ-SC (6) 13,499.93 66.86 269.98 5,897.90 5,767.03 -1,811.23 -10,549.48 5,946,941.89 1,617,845.97 0.28 10,703.73 MWD+IFR-AK-CAZ-SC (6) 13,535.14 66.84 270.40 5,911.74 5,780.87 -1,811.13 -10,581.86 5,946,942.05 1,617,813.60 1.10 10,735.59 MWD+IFR-AK-CAZ-SC (6) 13,567.45 66.77 271.30 5,924.46 5,793.59 -1,810.69 -10,611.55 5,946,942.54 1,617,783.91 2.57 10,764.76 MWD+IFR-AK-CAZ-SC (6) 13,593.44 66.80 271.29 5,934.71 5,803.84 -1,810.15 -10,635.43 5,946,943.11 1,617,760.03 0.12 10,788.18 MWD+IFR-AK-CAZ-SC (6) 13,687.73 67.65 270.67 5,971.21 5,840.34 -1,808.66 -10,722.36 5,946,944.74 1,617,673.12 1.09 10,873.53 MWD+IFR-AK-CAZ-SC (6) 13,780.26 69.88 271.09 6,004.72 5,873.85 -1,807.33 -10,808.59 5,946,946.20 1,617,586.90 2.45 10,958.22 MWD+IFR-AK-CAZ-SC (6) 13,873.77 72.87 270.40 6,034.58 5,903.71 -1,806.19 -10,897.18 5,946,947.49 1,617,498.32 3.27 11,045.27 MWD+IFR-AK-CAZ-SC (6) 13,966.96 76.86 270.55 6,058.91 5,928.04 -1,805.44 -10,987.12 5,946,948.38 1,617,408.39 4.28 11,133.71 MWD+IFR-AK-CAZ-SC (6) 14,047.29 79.58 271.11 6,075.31 5,944.44 -1,804.30 -11,065.74 5,946,949.65 1,617,329.78 3.45 11,210.94 MWD+IFR-AK-CAZ-SC (6) 14,095.43 81.92 270.63 6,083.05 5,952.18 -1,803.58 -11,113.25 5,946,950.44 1,617,282.28 4.96 11,257.60 INC+TREND (7) 14,110.00 82.50 270.49 6,085.02 5,954.15 -1,803.44 -11,127.68 5,946,950.61 1,617,267.84 4.07 11,271.79 NOT an Actual Suryey (8) 7" x 8-1/2" 14,192.33 85.75 269.69 6,093.45 5,962.58 -1,803.31 -11,209.57 5,946,950.86 1,617,185.97 4.07 11,352,41 MWD+IFR-AK-CAZ-SC (8) 14,288.68 89.66 268.98 6,097.31 5,966.44 -1,804.43 -11,305.81 5,946,949.90 1,617,089.73 4.12 11,447.39 MWD+IFR-AK-CAZ-SC (8) 2/27/2017 12:33.25PM Page 6 COMPASS 5000.1 Build 74 Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 2M-38 North Reference: Wellbore: 2M-38 Survey Calculation Method: Design: 2M-38 Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) (I (usft) (usft) (usft) (usft) IN (ft) (°/100') (ft) Survey Tool Name 14,380.85 93.42 268.60 6,094.83 5,963.96 -1,806.38 -11,397.91 5,946,948.10 1,616,997.64 4.10 11,538.43 MWD+IFR-AK-CAZ-SC (8) 14,477.92 93.98 270.59 6,088.57 5,957.70 -1,807.06 -11,494.77 5,946,947.57 1,616,900.78 2.13 11,633.93 MWD+IFR-AK-CAZ-SC (8) 14,573.51 94.23 270.42 6,081.72 5,950.85 -1,806.22 -11,590.11 5,946,948.56 1,616,805.45 0.32 11,727.68 MWD+IFR-AK-CAZ-SC (8) 14,668.43 94.15 270.89 6,074.79 5,943.92 -1,805.14 -11,684.77 5,946,949.80 1,616,710.81 0.50 11,820.71 MWD+IFR-AK-CAZ-SC (8) 14,762.22 92.99 273.48 6,068.95 5,938.08 -1,801.57 -11,778.30 5,946,953.52 1,616,617.29 3.02 11,912.20 MWD+IFR-AK-CAZ-SC (8) 14,857.50 90.99 274.39 6,065.64 5,934.77 -1,795.03 -11,873.30 5,946,960.20 1,616,522.32 2.31 12,004.62 MWD+IFR-AK-CAZ-SC (8) 14,951.56 90.35 273.33 6,064.54 5,933.67 -1,788.70 -11,967.13 5,946,966.68 1,616,428.50 1.32 12,095.93 MWD+IFR-AK-CAZ-SC (8) 15,043.96 90.04 269.55 6,064.22 5,933.35 -1,786.38 -12,059.49 5,946,969.15 1,616,336.16 4.10 12,186.48 MWD+IFR-AK-CAZ-SC (8) 15,141.14 90.21 266.08 6,064.01 5,933.14 -1,790.09 -12,156.58 5,946,965.60 1,616,239.07 3.57 12,282.74 MWD+IFR-AK-CAZ-SC (8) 15,236.32 89.45 264.99 6,064.29 5,933.42 -1,797.49 -12,251.47 5,946,958.35 1,616,144.18 1.40 12,377.47 MWD+IFR-AK-CAZ-SC (8) 15,329.21 88.56 262.19 6,065.91 5,935.04 -1,807.86 -12,343.76 5,946,948.13 1,616,051.89 3.16 12,470.16 MWD+IFR-AK-CAZ-SC (8) 15,423.16 88.80 261.99 6,068.07 5,937.20 -1,820.79 -12,436.79 5,946,935.35 1,615,958.84 0.33 12,564.02 MWD+IFR-AK-CAZ-SC (8) 15,475.88 89.25 268.32 6,068.97 5,938.10 -1,825.24 -12,489.28 5,946,930.99 1,615,906.34 12.04 12,616.49 MWD+IFR-AK-CAZ-SC (8) 15,519.09 89.69 270.73 6,069.37 5,938.50 -1,825.60 -12,532.49 5,946,930.70 1,615,863.14 5.67 12,659.10 MWD+IFR-AK-CAZ-SC (8) 15,563.59 90.40 274.82 6,069.33 5,938.46 -1,823.44 -12,576.93 5,946,932.92 1,615,818.71 9.33 12,702.49 MWD+IFR-AK-CAZ-SC (8) 15,611.93 89.52 273.80 6,069.37 5,938.50 -1,819.81 -12,625.13 5,946.936.63 1,615,770.52 2.79 12,749.33 MWD+IFR-AK-CAZ-SC (8) 15,708.55 88.94 275.66 6,070.67 5,939.80 -1,811.84 -12,721.41 5,946,944.75 1,615,674.27 2.02 12,842.76 MWD+IFR-AK-CAZ-SC (8) 15,801.55 89.42 279.11 6,072.00 5,941.13 -1,799.89 -12,813.61 5,946,956.85 1,615,582.09 3.75 12,931.49 MWD+IFR-AK-CAZ-SC (8) 15,897.96 88.80 283.58 6,073.50 5,942.63 -1,780.93 -12,908.10 5,946,975.95 1,615,487.64 4.68 13,021.25 MWD+IFR-AK-CAZ-SC (8) 15,992.15 88.32 285.64 6,075.86 5,944.99 -1,757.18 -12,999.21 5,946,999.85 1,615,396.58 2.24 13,106.86 MWD+IFR-AK-CAZ-SC (8) 16,088.03 88.63 285.14 6,078.42 5,947.55 -1,731.75 -13,091.62 5,947,025.43 1,615,304.22 0.61 13,193.44 MWD+IFR-AK-CAZ-SC (8) 16,182.07 88.90 284.19 6,080.44 5,949.57 -1,707.95 -13,182.57 5,947,049.37 1,615,213.31 1.05 13,278.88 MWD+IFR-AK-CAZ-SC (8) 16,277.53 88.84 282.00 6,082.33 5,951.46 -1,686.32 -13,275.53 5,947,071.14 1,615,120.40 2.29 13,366.67 MWD+IFR-AK-CAZ-SC (8) 16,370.84 88.53 278.58 6,084.47 5,953.60 -1,669.66 -13,367.30 5,947,087.95 1,615,028.67 3.68 13,454.15 MWD+IFR-AK-CAZ-SC (8) 16,465.94 88.08 274.04 6,087.28 5,956.41 -1,659.22 -13,461.76 5,947,098.54 1,614,934.24 4.80 13,545.36 MWD+IFR-AK-CAZ-SC (8) 16,560.45 88.29 274.54 6,090.28 5,959.41 -1,652.15 -13,555.95 5,947,105.76 1,614,840.06 0.57 13,636.90 MWD+IFR-AK-CAZ-SC (8) 16,655.41 87.81 276.96 6,093.51 5,962.64 -1,642.64 -13,650.37 5,947,115.42 1,614,745.66 2.60 13,728.24 MWD+IFR-AK-CAZ-SC (8) 16,749.18 87.88 279.13 6,097.03 5,966.16 -1,629.53 -13,743.15 5,947,128.68 1,614,652.92 2.31 13,817.33 MWD+IFR-AK-CAZ-SC (8) 16,844.19 87.32 281.59 6,101.01 5,970.14 -1,612.46 -13,836.52 5,947,145.89 1,614,559.58 2.65 13,906.31 MWD+IFR-AK-CAZ-SC (8) 16,939.58 88.06 281.76 6,104.86 5,973.99 -1,593.17 -13,929.86 5,947,165.33 1,614,466.28 0.80 13,994.89 MWD+IFR-AK-CAZ-SC (8) 17,033.26 91.65 278.84 6,105.09 5,974.22 -1,576.43 -14,022.01 5,947,182.22 1,614,374.17 4.94 14,082.72 MWD+IFR-AK-CAZ-SC (8) 17,128.30 96.52 278.41 6,098.33 5,967.46 -1,562.22 -14,115.70 5,947,196.58 1,614,280.51 5.14 14,172.53 MWD+IFR-AK-CAZ-SC (8) 17,223.64 96.19 278.74 6,087.77 5,956.90 -1,548.09 -14,209.40 5,947,210.85 1,614,186.85 0.49 14,262.35 MWD+IFR-AK-CAZ-SC (8) 17,317.61 95.68 278.12 6,078.06 5,947.19 -1,534.39 -14,301.85 5,947,224.70 1,614,094.42 0.85 14,351.02 MWD+IFR-AK-CAZ-SC (8) 17,408.22 93.00 279.06 6,071.20 5,940.33 -1,520.89 -14,391.18 5,947,238.34 1,614,005.12 3.13 14,436.65 MWD+IFR-AK-CAZ-SC (8) 17,500.78 92.49 278.98 6,066.77 5,935.90 -1,506.40 -14,482.49 5,947,252.98 1,613,913.85 0.56 14,524.05 MWD+IFR-AK-CAZ-SC (8) 17,592.72 93.30 278.20 6,062.12 5,931.25 -1,492.68 -14,573.28 5,947,266.84 1,613,823.09 1.22 14,611.08 MWD+IFR-AK-CAZ-SC (8) 17,686.79 94.68 277.74 6,055.58 5,924.71 -1,479.67 -14,666.22 5,947,280.00 1,613,730.18 1.55 14,700.35 MWD+IFR-AK-CAZ-SC (8) 17,778.18 91.22 278.22 6,050.88 5,920.01 -1,467.00 -14,756.59 5,947,292.81 1,613,639.84 3.82 14,787.14 MWD+IFR-AK-CAZ-SC (8) 17,870.42 89.75 278.26 6,050.09 5,919.22 -1,453.78 -14,847.87 5,947,306.17 1,613,548.59 1.59 14,874.74 MWD+IFR-AK-CAZ-SC (8) 2/27/2017 12: 33 25P Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-38 Wellbore: 2M-38 Design: 2M-38 Survey Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-38 2M-38 actual @ 130.87usft (Doyon 141) 2M-38 actual @ 130.87usft (Doyon 141) True Minimum Curvature OAKEDMP2 2127/2017 12:33:25PM Page 8 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 17,962.58 89.73 277.56 6,050.51 5,919.64 -1,441.10 -14,939.15 5,947,319.00 1,613,457.34 0.76 14,962.44 MWD+IFR-AK-CAZ-SC (8) 18,054.86 88.34 277.08 6,052.07 5,921.20 -1,429.34 -15,030.66 5,947,330.90 1,613,365.85 1.59 15,050.52 MWD+IFR-AK-CAZ-SC (8) 18,146.24 89.21 275.76 6,054.02 5,923.15 -1,419.13 -15,121.45 5,947,341.26 1,613,275.10 1.73 15,138.15 MWD+IFR-AK-CAZ-SC (8) 18,238.04 90.45 274.08 6,054.29 5,923.42 -1,411.26 -15,212.90 5,947,349.28 1,613,183.66 2.27 15,226.85 MWD+IFR-AK-CAZ-SC (8) 18,330.25 91.29 272.59 6,052.89 51922.02 -1,405.89 -15,304.94 5,947,354.79 1,613,091.64 1.85 15,316.56 MWD+IFR-AK-CAZ-SC (8) 18,423.35 89.54 270.59 6,052.22 5,921.35 -1,403.31 -15,398.00 5,947,357.52 1,612,998.60 2.85 15,407.75 MWD+IFR-AK-CAZ-SC (8) 18,483.00 89.54 270.59 6,052.70 5,921.83 -1,402.69 -15,457.64 5,947,358.23 1,612,938.96 0.00 15,466.38 PROJECTED to TD 4-1/2" x 6-1/8" 2127/2017 12:33:25PM Page 8 COMPASS 5000.1 Build 74 PT -0 214-09-5 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, February 09, 20171:38 PM To: Klem, Adam Subject: RE: 2M-38 PTD: 216-083 Change 4 1/2" LTP depth Adam, Approval is granted to change the 4 %" LTP depth to -13550' as outlined below. This approved change should be included with the approved PTD. 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. Loepp(a)alaska. pov 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 From: Klem, Adam [mailto:Adam.Klem@conocophillips.com] Sent: Thursday, February 09, 2017 11:35 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: 2M-38 PTD: 216-083 Victoria, I am writing you to make sure a small change to our completion is ok and within the regs. I want to move up our 4.5" liner top packer to -560' of overlap with our 7" liner in order to be able to set a ball and rod in the RHC plug body in the lower nipple with slickline, eliminating the need for a costly tractor if it was at a higher angle. We had a good cement job indicating the TOC is at the top of the 7" liner. Here are the depths: • 7" liner: 13,137'-14,110' MD Proposed 4 %" liner top: 13,551' Proposed 2.813" nipple with RHC plug: -13,500' (67 degrees) Is this plan ok with you? Adam Klem Senior Completions Engineer Greater Kuparuk Area ConocoPhillips Alaska 700 G St ATO 1586 Anchorage, AK 99510 907-263-4529 Office 970-317-0300 Cell Adam.Klem@conocophiIlips.com vrass Koots Horizo„tai -L” lana Nroaucer ConOCOPhillipS Proposed Wellbore Sci..--matic (4 -String) (WP22) 1(-'Vei Regg, James B (DOA) From: Regg, James B (DOA) "�4 I i Sent: Friday, January 20, 2017 9:36 AM ( j To: Rig 141; DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay; Herbert, Frederick 0; Hill, Larry G.; Michael Worthy; Michael.L.Kneale@contractor.conocophillips.com; n1334 @conocophillips.com; Brooks, Phoebe L (DOA); Whitlock, Guy D. Subject: RE: Doyon 141 BOP Test KRU 2M-38 1-10-2017 Report was due to AOGCC by 1/15/17 (within 5 days of completing the test). Refer to 20 AAC 25.035(e)(10(G). Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Rig 141[mailto:rig141@doyondrilling.com] Sent: Thursday, January 19, 2017 3:51 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.gov>; Herbert, Frederick 0 <Frederick.O.Herbert@conocophillips.com>; Hill, Larry G. <Larry.G.Hill@contractor.conocophillips.com>; Regg, James B (DOA) <jim.regg@alaska.gov>; Michael Worthy <Michael.S.Worthy@conocophillips.com>; Michael. L.Kneale@contractor.conocophillips.com; n1334@conocophillips.com; Brooks, Phoebe L (DOA) <phoebe.brooks@alaska.gov>; Whitlock, Guy D. <Guy.D.Whitlock@contractor.conocophillips.com> Subject: Doyon 141 BOP Test KRU 2M-38 1-10-2017 Please note the correction made to test finish date THE STATE 01 L S GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-38 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-083 - Revised Surface Location: 5165' FNL, 4756' FEL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 1281' FNL, 4391' FEL, Sec. 31, Tl 1N, R8E, 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. 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. ncerely, Frs Chai DATED this Q)4'�Jay of January, 2017. STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMM. )N REVISED PERMIT TO DRILL 20 AAC 25.005 HECEIVED JAN 12 2017 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone ❑✓ • Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 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 2M-38 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18483 ' TVD: 6102 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 5165 FNL 4756 FEL, Sec. 27 Twn 11 N Rng 8E, UM ADL025586, ADL025585 Kuparuk Oil Pool ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1743 FNL 150 FEL, Sec. 31 Twn 11N Rng 8E, UM 931894000, 931893000 1/1/2017 9. Acres in Property: 14. Distance to Nearest Propertv: Total Depth: 1281 FNL 4391 FEL, Sec. 31 Twn 11N Rng 8E, UM 2560, 2491 530 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 132 15. Distance to Nearest Well Open Surface: x- 488363.9 Y- 5948985.8 Zone- 4 GL Elevation above MSL (ft): 101.3 to Same Pool: 215 16. Deviated wells: Kickoff depth: 275 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92.89 degrees ' Downhole: 3821 psi ' Surface: 3216 psi ' 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# H-40 Welded 80 28 28 121.5 121.5 cement in place 16" 13.375" 68# L-80 Hydril 563 3006 28 28 3034 2656 1487 sx 11 ppg DeepCRETE, 246sx 12 ppg Class 'G' 12.25" 9.625" 40# L-80 Hydril 563 11214 2000 1915 13214 5789 780 sx 15.8ppg Class 'G' 8.75" 7" 26# L-80 Hydril 563 14088 39 39 14116 6064 246 sx 15.8ppg Class'G' 6.125" 4.5" 12.6# L-80 IBTM 5540 12943 5670 18483 6102 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): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch Drilling Program ❑ Time v. Depth Plot ❑ ❑ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jacob Voss @ 907-265-6935 Email 'ake.voss COP.00M Printed Name G. Alvord Title Alaska Drilling Manager r � Signature ` , �. Phone 265-6120 Date r 1 [ (2 t? Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: r`m 50-16-3- 2.o-1g4e - o o -G C7 Date: -7-7-1 requirements. ,e CL Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane gas hydrates, or gas contained in shales: Other: i3G P -�-z'$ f- if -3 �/J p s r Samples req'd: Yes ❑ No[� Mud log req'd: Yes ❑ No X r�t/� y rl �`v t Sf f -v 2 �Ul,��Ip easures: Yes [� No❑ Directional svy req'd: Yes No Spacing exc tion req'd: Yes ❑ Nod Inclination -only svy req'd: Yes ❑ No V Post initial injection MIT req'd: Yes ❑ No APPROVED BY Approved by: 442,�lIiCOMMISSIONER THE COMMISSION Date: 1-13-17 Q(R L i 2 / J J /'� Ri-&[N-A4 Submit Form a fd ForKo-4o1'(j;vviseQ� 1/ 015 'vIh onths from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 RECEIVED Phone (907) 263-4180 SNI 2 2017 January 11, 2017 AOGCC Alaska Oil and Gas Conservation Commission 333 West 71' Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2M-38 ConocoPhilfi S Re: Application for amendment to approved Permit to Drill (216-083) Well KRU 2M-38, a Kuparuk C Sand Producer d Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Amended permit to drill an onshore grassroots producer well from the 2M pad. Doyon 141 spudded the well on January Is' 2017. Currently the rig is drilling the 12-1/4" Intermediate 1 hole at 7,000' MD. Latest estimate to begin drilling the production lateral is 1/28/2017. 2M-38 is planned to be a horizontal well in the Kuparuk C sand. The surface section will be drilled with 16" bit and run 13-3/8" casing to +/-3,034'MD / 2,656' TVD. The intermediate section (I) will be drilled with 12-1/4" bit and run 9-5/8" casing to 13,214'MD / 5,789' TVD. The intermediate section (II) will be drilled with 8-3/4" bit with 9-7/8" under reamer and run 7" casing to 14,116'MD / 6,064'TVD. The production hole will be drilled with 6-1/8" bit and run 4-1/2" perforated liner to +/- 18,483'MD / 6,102' TVD. Please note: the amendedTD is to cover the updated directional plan (from well plan 13 to well plan 22) for the orientation of the lateral. The upper completion will be run with 3- 1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Jacob Voss at 265-6935 Oake.voss@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord /4'� - Drilling Manager Application for Permit to Drill, Well 2M-38 Permit It - Kuparuk Well 21VI-38 Application for Permit to Drill Document Table of Contents 1. Well Name.................................................................................................................. 3 Requirements of 20 AAC 25.005(0........................................................................................................ 3 2. Location Summary..................................................................................................... 3 Requirements of 20 AAC 25.005(c)(2)................................................................................................... 3 Requirements of 20 AAC 25.050(b)........................................................................................................ 3 3. Blowout Prevention Equipment Information............................................................... 3 Requirements of 20 AAC 25.005(c)(3)................................................................................................... 3 4. Drilling Hazards Information..................................................................................... 4 Requirements of 20 AAC 25.005 (c)(4)........................................................................................................ 4 Requirements of 20 AAC 25.005 (c)(5)........................................................................................................ 4 5. Casing and Cementing Program................................................................................. 5 Requirements of 20 AAC 25.005(c)(6)................................................................................................... 5 6. Diverter System Information...................................................................................... 5 Requirements of 20 AAC 25.005(c)(7)................................................................................................... 5 7. Drilling Fluid Program............................................................................................... 5 Requirements of 20 AAC 25.005(c)(8)................................................................................................... 5 8. Abnormally Pressured Formation Information........................................................... 6 Requirements of 20 AAC 25.005 (c)(9).................................................................................................. 6 9. Seismic Analysis......................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10)................................................................................................ 6 10. Seabed Condition Analysis.......................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11)................................................................................................ 6 11. Evidence of Bonding................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12)................................................................................................ 6 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............................................................................................................... 8 Attachment1 Directional Plan............................................................................................................... 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Program Summary ............................................................................................. 8 Attachment4 Well Schematic................................................................................................................ 8 Attachment 5 Pad with diverter schematic............................................................................................. 8 ration for Permit to Drill, Well 2M-38 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 tivell by the commission. The well for which this Application is submitted will be designated as 2M-38 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 Top of Productive 1743 FNL 150 FEL, Sec. 31 Twn 11N Rng 8E, UM Location at Surface 1 5165 FNL 4756 FEL, Sec. 27 Twn 11N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates Northings 5,948,985.83 Eastings: 488,363.9 RKB Elevation 132' AMSL Pad Elevation 1 101.3 AMSL Location at Top of Productive 1743 FNL 150 FEL, Sec. 31 Twn 11N Rng 8E, UM Interval (Ku aruk "C" Sand) Total Vertical Depth, RKB: 6,102' ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 14,116' Total Vertical Depth, RKB: 6,071' Northings: 5,947,153.29 Eastings: 477,132.14 Total Vertical Depth, SS: 5,928' Location at Total Depth 1 1281 FNL 4391 FEL, Sec. 31 Twn 11N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates Northings: 5,946,262.2 Eastings: 472,789.68 Measured Depth, RKB: 18,483' Total Vertical Depth, RKB: 6,102' Total Vertical Depth, SS: 5,970' and (D) other information required by 20 AAC 25.050(b); 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: Directional Plan 2M-38 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 fiurnished 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 Heins, 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 (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. ation for Permit to Drill, Well 2M-38 4. 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 potential surface pressure (MPSP) while drilling 2M-38 is calculated using an estimated maximum reservoir pressure of 3,822 psi (12.1 ppg, based on nearby 2M wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,064' TVD (WP21): C4 Sand Estimated. BHP = 3,821 psi C4 Sand estimated depth (WP21) = 6,064' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 606 psi (6,064' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,216 psi (3,821 psi — 606 psi) (B) data on potential gas zones: The well bore is not expected to penetrate any shallow 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; See attached 2M-38 Drilling Hazards Summary 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 AAC 25.0300; A procedure is on file with the commission for performing LOT'S. ration for Permit to Drill, Well 2M-38 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 ivith the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casing and Cementing Program Surface 16" Hole 13-3/8" Casing See also Attachment 3: Cement Summa Intermediate 8-3/4 x 9-7/8" Hole 7" Casing Csg/Tbg Hole Size weight Grade Conn. Length Top MDvTVD Btm MD/TVD Cement Program OD (in) 10.5-12.5 (lb/ft) 30-50 10-20 (ft) (ft) (ft) 40-80 20 42 94 H-40 Welded 80 Surf 121.5 / 121.5 Cement in place 13-3/8 16 68 L-80 Hydril 3006 Surf 3,034' / 2,656 1487 sx 11 ppg DeepCRETE, 246 sx 12 API Filtrate NC < 6 < 6 563 HTHP Fluid Loss at 160 F N/A < 10 ppg LiteCrete 9-5/8 12-1/4 40 L-80 BTC -M 11214 2,000 / 1,915 13214 / 5,789 780 sx 15.8ppg Class 'G' with TOC to 12,100' MD 7 8-3/4 26 L-80 Hyd563 14,088 Surf 14,116 / 6,064 246 sx 15.8ppg Class 'G' with TOC to /BTC -M 13,214' MD 41/2 6-1/8 12.6 L-80 TXP 5,590 13,934 / 6,046 18,483 / 6,102 No Cement 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, exceptfor 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 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematics on file for Doyon 142. 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 follotiving 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 AAC 25.033; Mud Program Summary Surface 16" Hole 13-3/8" Casing Intermediate 12-1/4" Hole 9-5/8" Casing Intermediate 8-3/4 x 9-7/8" Hole 7" Casing Production 6-1/8" Hole 4-1/2" Liner Mud System Spud mud (WBM) LSND (WBM) LSND (WBM) FLO-PRO NT (WBM) Density 8.6-9.5 9.2 - 10.5 10.5-12.5 10.5-12.5 PV 30-50 10-20 10-20 10-20 YP 40-80 16-24 17-28 16-24 Funnel Viscosity 200-300 N/A N/A N/A Initial Gel 30-50 10-12 11-15 5-8 10 minute Gel 30-50 10-18 12-22 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 < 10 pH 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 ration for Permit to Drill. Well 2M-38 Diagram of Doyon 141 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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 25.0330; 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 ivith 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. IO.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: (1 l) 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 AAC 25.061(b); Not applicable: Application is not for an offshore well. I I.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" conductor to t 121' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/-3034' MD / 2656' TVD as per directional plan. (LWD Program: GR/RES) 4. Run and cement 13-3/8", 68#, L80, 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 13-5/8" x 5,000 psi BOP'S to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 8" drilling assembly, with MWD. Run in hole, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and 20' of new hole. Perform formation integrity test to minimum 12.5ppg EMW, recording results. ration for Permit to Drill, Well 2M-38 8. Directionally drill 12-1/4" hole to casing point at +/-13,214 MD / 5,789' TVD in the HRZ. (LWD Program: GR/RES/PWD). 9. Circulate wellbore clean and pull out of the hole. 10. Run 9-5/8", 40# L80, liner and liner top packer. Top of cement to be +/-12,100' MD /5388' TVD which is +/- 1,100' MD and 400' TVD above the intermediate casing shoe. 11. PU 8-1/2" x 9-7/8" rotary steerable system and under reamer. RIH, clean out cement to top of float equipment and test casing to 3000 psi. 12. Drill out cement and 20' of new hole. Perform formation integrity test to a minimum of 13.5ppg EMW, recording results. 13. Directionally drill 8-3/4" x 9-7/8" hole to casing point at 14,116' MD / 6064' TVD in the Kuparuk C sand. (LWD Program: GR/RES/NEU/DEN/PWD) 14. Circulate well clean and pull out of hole. 15. Run 7", 26# L80 liner and liner top packer. Top of cement to be at the liner top packer. 16. Run 7", 26# L80 tie -back. Prior to stinging into the seal bore extension displace 7" x 9-5/8" x 13-3/8" annulus to corrosion inhibited brine and freeze protect. 17. PU 6-1/8" PDC Bit and drilling assembly, with MWD and LWD logging tools. RIH and clean out cement to top of float equipment. Test casing to 3500 psi. 18. Drill out cement and 20' of new hole. Perform formation integrity test to a minimum of 13.5ppg EMW, recording results. Displace hole to lateral drilling system. 19. Directionally drill 6-1/8" hole into the Kuparuk C sand and to TD at +/-18,483' MD / 6102' TVD as per directional plan. (LWD Program: GR/RES/NEU/DEN/PWD) 20. Pull out of hole. 21. PU and run 4-1/2", 12.6# L80 lower completion with perforated pups. 22. PU and run 3-1/2", 9.3# L80 EUE tubing upper completion, circulate around with kill weight brine 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 3.5" x 7" annulus, taking returns from tubing and allowing to equalize. 26. Set BPV, secure well and move rig off. 27. No fractured stimulation is planned on 2M-38 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 authorisation 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 hauled 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 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. ration for Permit to Drill, Well 2M-38 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Pad with diverter schematic 2M-38 Grass Roots Horizontal "C" Sand Producer Proposed Wellbore Schematic (4 -String) (WP22) Spud mud 8.6-9.6 PPG WestSak '!D WBM 9.5-10.5 PPG LSND WBM 10.5-12.0 PPG Top: 14,022' MD / 6,054" TVD FloPro WBM 10.5 —11 PPG Conductor To Be Installed: 20" set @ +/-110' ration for Permit to Drill, Well 2M-38 ConocoPhillips Last Update: 01/11/17 - JBV 16" Surface Hole 9 5/8" x 13 3/8" Liner hanger: ± 2,000' MD/1,923' TVD Surface Casing: Below West Sak 13-3/8" 68# L-80 Hydril 563 ±3,334' MD / 2,656' TVD 12-1/4" Intermediate Hole Tubing: ± J.3,950'3 -X" 9.3# L-80 EUE 8RD TOC @ ± 12,100' MD 9 5/8" x 7" liner hanger @ ± 13,060' MD Intermediate 1: 9 5/8" 40#, L80,Hydril 563 @ ± 13,214' MD / 5,789' TVD 8-1/2" x 9-7/8" Intermediate Hole 7" x 4-1/2, UP Liner Top Packer± 13,934' MD 6-1/8" Production Hole 7" x 4-%" Baker Flex Lock Liner hanger Intermediate 2: 7" 26#, L80, HydriIS63 Production To: @ ± 14,116'MD / 6,064'TVD @ ± 18,483'MD / 6,102'TVD Production Liner: 4-1/2" 12.6# L-80 IBTM 5.75" x 4-%" Swell Packer for fault Perforated Joints 12,934' —18,483' MD/6,102' TVD isolation 2M-38 )rilling Hazards S nmary 16" Hole / 13-3/8" Casing Interval Hazard T Risk Level I Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Gas Hydrates Low Monitor well at base of permafrost, controlled drilling rates, low mud temperatures. Additions of Lecithin. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced sever mud lost. Monitor real time equivalent circulating density (ECD) to below Lost Circulation Moderate expected formation fracture gradient. Prepare enough lost Lost Circulation Low circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of Hole swabbing on trips Moderate hole if necessary. Monitor real time surveys closely, shut in nearby wells Anti -Collision Low that we have collision concerns with, run gyro survey to eliminate magnetic interference from nearby wells when needed Washouts / Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize circulating time when possible 12-1/4" Hole - 9-5/8" Liner Interval Hazard Risk Level Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and torque/drag real time The Iceberg formation pressure is estimated to be Abnormal Reservoir Pressure Moderate 10.1ppg. Weight up mud to 10.4-10.5ppg before drill into Iceberg formation. Monitor ECD to below expected formation fracture Lost Circulation Low gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary Attachment 2 - 2M-38 Drilling Hazards Summary. docx 1/1212017 11:05:16 AM 8-1/2"x9-7/8" INTRM2 Section -7" Liner w/ Tieback Hazard Risk Level Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and Abnormal Reservoir Pressure Moderate torque/drag real time The intermediate II section is penetrating into the reservoir of Kuparuk C, which is estimated to be 12.1 - Abnormal Reservoir Pressure Moderate 12.3 ppg. Utilize MPD for shale stability and pore pressure management. Shut in nearby injectors to prevent Lost Circulation Moderate pore pressure rise. Monitor real time equivalent circulating density (ECD) to Lost Circulation Moderate below expected formation fracture gradient. Prepare Getting Liner to bottom Moderate enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary 6-1/8" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy The reservoir pore pressure of Kuparuk C is estimated to Abnormal Reservoir Pressure Moderate be 12.1-12.3 ppg. Utilize MPD pore pressure management to ensure wellbore overbalance. Shut in nearby injectors to prevent pore pressure rise. Stuck Pipe Low Keep good hole cleaning practices, use PWD tools monitoring and analysis, stabilized BHA Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program, control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly clean hole prior to pulling out of hole to run liner. Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use of trip sheets), pumping backreaming out if necessary Attachment 2 - 2M-38 Drilling Hazards Summary.docx 1/12/2017 11:05:16 AM 2M-38 Cement Calculations Surface Cement: Surface to 3,034' MD Hole Size ft (TOC) ft (Bottom) OD ID ppf Conductor Depth: 1.84 ft3/ sx of 11.0 ppg DeepCRETE 28 110 20 19.14 94 Surface Casing Depth: 16 28 3034 13.375 12.415 68 Intermediate #1 Casing Depth: 12.25 11100 13214 9.625 8.8325 40 Intermediate #2 Casing Depth: 8.75 13216 14116 7 6.276 26 Surface Cement: Surface to 3,034' MD Capacities Lead 1.84 ft3/ sx of 11.0 ppg DeepCRETE OH 0.248689 Tail 1.64 ft3/ sx of 12.0 DeepCRETE Permafrost (PF) depth 1501 ft 16"x13-3/8" 0.074907 XS% Above PF 250% 20"x13-3/8" 0.182095 XS% Below PF 50% 13-3/8" 0.14973 Tail Cement Length 500 ft 500 x 0.07490711 x 1.5 56.1803296 Shoe Track 80.78 ft 80.78 x 0.14973016 x 1 12.0952022 Open Hole 10 x 0.24868856 x 1.5 3.73032835 Total 72 bbl 404 ft3 246 sx Lead Top Tail Cement to Permafrost 1033 ft 1033 x 0.07490711 x 1.4 108.330657 bbl Permafrost to 20" Casing 1391 ft 1391 x 0.07490711 x 3.5 364.685246 bbl Conductor Length 80 ft 80 x 0.18209537 14.5676297 bbl Total: 488 bbl 2737 ft3 1488 sx Intermediate #1 Cement: Cement from 13,210' MD to 11,100' MD SI r i Capacities: 15.8ppg Class G yielding 1.16ft"3/sk 12-1/4" x 9-5/8" 0.055782 XS%for open hole and annulus: 30% 12-1/4" OH 0.145777 9-5/8" ST 0.075785 Annulus Cement 2114 x 0.05578189 x 1.3 = 153.2998 bbis Rathole Cement 10 x 0.14577667 x 1.3 = 1.895097 bbis Shoe Track 80 x 0.07578498 x 1 = 6.062798 bbls Total 161 bbis 905 ft3 780 sx Intermediate #2 Cement: Cement from 14116' MD to Liner Top (13214' MD) Capacities: Hole Size: 9.875 9.875" x 7" 0.04713 %XS 30 Open Hole 10 ft 9.625"x7" 0.028184 Length from shoe to TD: 900 ft 7" ST 0.038263 900 x 0.04713 x 1.5 63.6255039 bbl 250 Overlap of Liner 150 x 0.02818443 4.22766508 bbl Shoe Track 80 x 0.03826324 3.06105895 bbl Open Hole 5 x 0.09473055 x 1 0.47365273 bbl Total: 71 bbl 401 ft3 246 sx To DS2L 2M-38wp22 7.076 Plan Summary C-35 Top Kuparuk C Fault 2 - 25' DTW Top HRZ K1 \ ' S Base Iceberg / Growler Base HRZ/Top,Kalubik Deepest' possible Kuparuk C 5 \ a p SS C-37 /Top Iceberg` \ Fail[ 4 -40-4� DTE U � , m 0 0 0 ,3500 7000 10500 14000 17500 Measured 9-5/8" x 12-1/4" o Geodetic Datum: Depth Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Rig: Doyon141 _. 0 0 ( 0 N h N n O O ^ w w \° OO 00 O O �I ro 3000 4500 6000 7500 9000 10500 12000 13500 515000 16500 Horizontal Departure 3000 4500 6000 7500 9000 10500 12000 13500 240120 �'' ' -� �'� -- - _ 10190 - 7137 11370 - 125 SURVEY PROGRAM Sec MD Inc Azi TVD +W -S +E/ -W Dleg TFace VSect Target Annotation 1 2952.69 61.15 253.71 Surface Location North / Y: 0.00 9 12560 - 137 - epth From Depth To Survey/Plan Tool 74.39 809.01 2M-38 Srvy 1 - SLB_GWD70 (Rig: 2M-38) GYD-GC-SS East / X Pad 210 -- ---+,, Iso 13740 1493 847.52 2952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (Ri1,g1W JER-AK-CAZ-SC Elevation: 101.30 253.71 2671.03 -767.91 -714.67 14930 1611 2952.69 4452.69 2M-38wp22 (Rig: 2M-38) MWD 4 3856.44 73.29 180 16110 -�' 1730 2953.69 13200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC CASING DETAILS - 17300 - 18482- 13200.00 14200.00 2M-38wp22 (Rig: 2M-38) MWD TVD MD Name 6 12088.73 13200.00 14200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC 113.20 113.20 20" x 42" Magnetic Model: BGGM2a16 T 14200.00 15700.00 2M-38wp22 (Rig: 2M-38) MWD 2661.38 3053.00 13-3/8" x 16" Magnetic Model Date: 20 -Jan -17 Hold for 778.55' 14200.00 18482.67 2M-38wp22 (Rig: 21M-38) MWD+IFR-AK-CAZ-SC 5782.74 13200.00 9-5/8" x 12-1/4" Magnetic Declination: 17.67' Start 11100' DLS, -147.25° TF, for 10.64' 1912.0 9 13045.95 66.55 6071.88 14200.00 7" x 8-1/2" by 9-7/8" To convert a Magnetic Direction to a True Direction, Add 17.67' East SECTION DETAILS 4314 T-3 Sand Sec MD Inc Azi TVD +W -S +E/ -W Dleg TFace VSect Target Annotation 1 2952.69 61.15 253.71 2612.98 -738.35 -613.52 0.00 0.00 732.43 Adjust TF to 0°, for 100.31' 58 2 3053.00 61.15 253.71 2661.38 -762.99 -697.86 0.00 0.00 819.76 Adjust TF to 0°, for 20' 3 3073.00 61.15 253.71 2671.03 -767.91 -714.67 0.00 0.00 837.17 Start 21100' DLS, 41.54°TF, for 783.44' K-15 Marker 4 3856.44 73.29 264.49 2974.56 -901.02 -1421.86 2.00 41.54 1556.73 Hold for 8067.23' 5 11923.68 73.29 264.49 5294.03 -1643.38 -9112.72 0.00 0.00 9259.65 Start 21100' DLS, 175.5° TF, for 165.05' 6 12088.73 70.00 264.76 5346.00 -1658.05 -9268.66 2.00 175.50 9415.78 2M-38 1.C35 051716 JC Adjust TF to 179.99°, for 168.03' 1482.0 7 12256.76 66.64 264.76 5408.06 -1672.30 -9424.13 2.00 179.99 9571.35 Hold for 778.55' Base permafrost 8 13035.31 66.64 264.76 5716.77 -1737.55 -10135.88 0.00 0.0010283.62 Start 11100' DLS, -147.25° TF, for 10.64' 1912.0 9 13045.95 66.55 264.70 5721.00 -1738.44 -10145.60 1.00 -147.2510293.35 2M-38 2. Top HRZ 051716 JC Adjust TF to -167.84°, for 19.28' 10 13065.23 66.36 264.66 5728.70 -1740.08 -10163.20 1.00 -167.8410310.97 Hold for 362.37' lop W Sak (W Sak 11 13427.60 66.36 264.66 5874.00 -1771.00 -10493.72 0.00 0.0010641.84 2M-38 3. Faults 051716 JC Start 2.5%100' DLS, 179.7° TF, for 40.05' 2572.0 12 13467.66 65.36 264.66 5890.38 -1774.40 -10530.11 2.50 179.7010678.27 Hold for 30.27 Base W Sak 13 13497.93 65.36 264.66 5903.00 -1776.96 -10557.51 0.00 0.0010705.69 2M-38 4. Base HRZrrop Kuparuk 051716 JC Start 3.51100' DLS, -2.15° TF, for 74.08' 2917,0 14 13572.01 67.90 264.56 5932.38 -1783.35 -10625.21 3.50 -2.1510773.48 Hold for 34.2' 15 13606.22 67.90 264.56 5945.25 -1786.36 -10656.76 0.00 0.0010805.07 Start 3.51100' DLS, -6.25°TF, for 87.62' 16 13693.84 71.00 264.20 5976.00 -1794.39 -10738.40 3.50 -6.2510886.86 2M-38 5. K-1 051716 JC Adjust TF to 19.85°, for 56.84' 17 13750.68 72.87 264.91 5993.63 -1799.52 -10792.20 3.50 19.8510940.73 Hold for 17.62' Camp SS 18 13768.30 72.87 264.91 5998.81 -1801.02 -10808.97 0.00 0.0010957.51 Start 3.5%100' DLS,-13.54'TF, for 355.91' 19 14124.21 85.00 262.00 6067.00 -1840.94 -11155.28 3.50 -13.5411305.49 2M-38 6. Top C 051716 JC Adjust TF to 8.99°, for 180.19 20 14304.36 91.23 262.98 6072.93 -1864.46 -11333.70 3.50 8.9911485.28 Hold for 33.92' 4177.0 21 14338.28 91.23 262.98 6072.20 -1868.60 -11367.36 0.00 0.0011519.15 Start 3.5 /100' DLS, -170.39° TF, for 10.96' C-50 22 14349.25 90.85 262.92 6072.00 -1869.94 -11378.23 3.50 -170.3911530.10 210-38 7. Landing 051716 JC Start 3.221100' DLS, 96.52° TF, for 798.06' 23 15147.30 87.95 288.43 6080.52 -1791.74 -12165.72 3.22 96.5212292.03 Hold for 1.2' 4692.0 24 15148.51 87.95 288.43 6080.57 -1791.36 -12166.86 0.00 0.0012293.09 Start 3.22/100' DLS, -87.31 ° TF, for 372.53' C-37 / Top Iceberg 25 15521.04 88.55 276.46 6092.00 -1711.28 -12529.80 3.22 -87.3112636.62 2M-38wp21 Tgt Prof KEH 6Jan17 Hold for 1184.22' 5092.0 26 16705.26 88.55 276.46 6122.00 -1578.14 -13706.14 0.00 0.0013771.96 2M-38wp21 Tgt Pro2 KEH Wan17 Start 31100' DLS, 10.71' TF, for 147.28' Base Iceberg / Gro 27 16852.54 92.89 277.28 6120.15 -1560.54-13852.31 3.00 10.71 13912.85 Hold for 488.07' 5392.0 28 17340.61 92.89 277.28 6095.55 -1498.78 -14335.83 0.00 0.0014378.30 Start 2%100' DLS, -122.31 ° TF, for 83.15' C-35 29 17423.75 92.00 275.87 6092.00 -1489.27 -14418.35 2.00 -122.3114457.92 2M-38wp21 Tgt Pro3 KEH 6Jan17 Adjust TF to 180°, for 135.76' @ 30 17559.51 89.28 275.87 6090.48 -1475.38 -14553.37 2.00 180.0014588.48 Hold for 923.17' B ^�iW ®� 31 18482.68 89.28 275.87 6102.00 -1380.94 A 5471.63 0.00 0.0015476.39 2M-38wp21 Tgt Pro4 KEH 6Jan17 TD: 18482.67' MD, 6102' TVD p st possible Kuparuk C r• By szg this i a a w.dedpe ma t Hare o mionnm m ai dsxa,M.- ma tha rice m oma, --ftiara and alt. -M, - . as,g, t. d,aw uo -and i apo,wa ma. and m'loion avoidarce pan as setoNh miea e. Ms ...--hl 1- was pan and-Wie drawings. lalso xknawle69-L amass Wi- aherwisa, 61 WWM nave a 1M 1W gcerL Prepared by: Checked by: Accepted by: i Approved by: B. Temple N. Beck E. Sterk J. Voss Spider View L13:42, January 11 2017 1 Easting (3000 usft/in) 2M-13 - -20 A��T9A 2A�27 2M-21 2M-06 2 -11 2M-19 2A-05 2M 18 2M-20 2M-05 - 0 2H-16 M-36 17 2M-16 - 2M-23 -15 KUparuk 2M PajX 2M-25 0 is N 7 5 O c i -38 w - 22 -28 M-27 2M-26 2M-24 2H-13 0 t 2H -14A w c 2H-14 1 Z M-31 2M-22 2M-17 2H-14 2M-02 2M-14 1-01 2M-33 2M 04 2K-29 2 M -3 2 L 1PB1 M-08 2M-09-08APB1 `L 3l -34 AK 15 K-06 2S-14 2M -32L1 PB2 - 2M 2 ZW13@e1 2M-35 -.. 11 1- Fasting (3000 usft/in) Plan View 2M-38wp22 Plan View 4000- 000 - 2000 2000- 4-1 /2" 7" x 8-1/2 x 6-1/8" " by 9-7/8" 9-5/8" x 12-1/4" 13-3/8" x 16" ' 20" x 42" c 0 0- c) o 1000 c" -T, CO o 0 v o 0 0 0 b° �' 000 T 0 rd CDO d o0 0 0 O X000 o d o OCD L N O O O 00 O O Q O O 0 1 3 CO co M Z -4000 N -6000 -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 West( -)/East(+) (2000 usft/in) Section View 2M-38wp22 Section View -2000- 20" x 42" 0- 13-3/8" x 16" 1000 o 6 2000 ® 0 o, '0 9-5/8" x 12-1/4" 7" x 8-1/2" by 9-7/8" 4-1/2" x 6-1/8" Camp SS C) � 00 0 '• 4000- 000 C-50 C-50 - -- -- - ---�-Ile,a -- --- > = c a) C-37 / Top Iceberg- o �O,^co o o P— Iceberg / Growler -- -- --- - OD, w C-35-- - 6000 — — — — 'Deepest — — — — — — — — — — possible Kuparuk C 0 0 N 8000 3 ao a? N 0 2000 4000 6000 8000 10000 12000 14000 16000 Vertical Section at 260.00 ° (2000 usft/in) Plan Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Rig: 2M-38 Rig: 2M-38 Plan: 2M-38wp22 Standard Proposal Report 11 January, 2017 Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.10 ° Rig: 2M-38 Position +N/ -S 0.00 usft Northing: Latitude: +E/ -W 0.01 usft Easting: Longitude: ion Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.3C Wellbore Rig: 2M-38 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) BGG M2016 1/20/2017 17.67 80.88 57,533 Design 2M-38wp22 Audit Notes: Version: Phase: PLAN Tie On Depth: 2,952.69 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (°) 30.70 0.00 0.01 260.00 1/11/2017 12:46:52PM Page 2 COMPASS 5000.1 Build 74 Database: r OAKEDMP2 Local Co-ordinate Reference: vVell Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 Depth Inclination Design: 2M-38wp22 System +Ni -S Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +Ni -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°I100usft) r/100usft) (°) 2,952.69 61.15 253.71 2,612.98 2,480.98 -738.35 -613.52 0.00 0.00 0.00 0.00 3,053.00 61.15 253.71 2,661.38 2,529.38 -762.99 -697.86 0.00 0.00 0.00 0.00 3,073.00 61.15 253.71 2,671.03 2,539.03 -767.91 -714.67 0.00 0.00 0.00 0.00 3,856.44 73.29 264.49 2,974.56 2,842.56 -901.02 -1,421.86 2.00 1.55 1.38 41.54 11,923.68 73.29 264.49 5,294.03 5,162.03 -1,643.38 -9,112.72 0.00 0.00 0.00 0.00 12,088.73 70.00 264.76 5,346.00 5,214.00 -1,658.05 -9,268.66 2.00 -1.99 0.17 175.50 12,256.76 66.64 264.76 5,408.06 5,276.06 -1,672.30 -9,424.13 2.00 -2.00 0.00 179.99 13,035.31 66.64 264.76 5,716.77 5,584.77 -1,737.55 -10,135.88 0.00 0.00 0.00 0.00 13,045.95 66.55 264.70 5,721.00 5,589.00 -1,738.44 -10,145.60 1.00 -0.84 -0.59 -147.25 13,065.23 66.36 264.66 5,728.70 5,596.70 -1,740.08 -10,163.20 1.00 -0.98 -0.23 -167.84 13,427.60 66.36 264.66 5,874.00 5,742.00 -1,771.00 -10,493.72 0.00 0.00 0.00 0.00 13,467.66 65.36 264.66 5,890.38 5,758.38 -1,774.40 -10,530.11 2.50 -2.50 0.01 179.70 13,497.93 65.36 264.66 5,903.00 5,771.00 -1,776.96 -10,557.51 0.00 0.00 0.00 0.00 13,572.01 67.90 264.56 5,932.38 5,800.38 -1,783.35 -10,625.21 3.50 3.43 -0.14 -2.15 13,606.22 67.90 264.56 5,945.25 5,813.25 -1,786.36 -10,656.76 0.00 0.00 0.00 0.00 13,693.84 71.00 264.20 5,976.00 5,844.00 -1,794.39 -10,738.40 3.50 3.53 -0.41 -6.25 13,750.68 72.87 264.91 5,993.63 5,861.63 -1,799.52 -10,792.20 3.50 3.29 1.24 19.85 13,768.30 72.87 264.91 5,998.81 5,866.81 -1,801.02 -10,808.97 0.00 0.00 0.00 0.00 14,124.21 85.00 262.00 6,067.00 5,935.00 -1,840.94 -11,155.28 3.50 3.41 -0.82 -13.54 14,304.36 91.23 262.98 6,072.93 5,940.93 -1,864.46 -11,333.70 3.50 3.46 0.55 8.99 14,338.28 91.23 262.98 6,072.20 5,940.20 -1,868.60 -11,367.36 0.00 0.00 0.00 0.00 14,349.25 90.85 262.92 6,072.00 5,940.00 -1,869.94 -11,378.23 3.50 -3.45 -0.58 -170.39 15,147.30 87.95 288.43 6,080.52 5,948.52 -1,791.74 -12,165.72 3.22 -0.36 3.20 96.52 15,148.51 87.95 288.43 6,080.57 5,948.57 -1,791.36 -12,166.86 0.00 0.00 0.00 0.00 15,521.04 88.55 276.46 6,092.00 5,960.00 -1,711.28 -12,529.80 3.22 0.16 -3.21 -87.31 16,705.26 88.55 276.46 6,122.00 5,990.00 -1,578.14 -13,706.14 0.00 0.00 0.00 0.00 16,852.54 92.89 277.28 6,120.15 5,988.15 -1,560.54 -13,852.31 3.00 2.95 0.56 10.71 17,340.61 92.89 277.28 6,095.55 5,963.55 -1,498.78 -14,335.83 0.00 0.00 0.00 0.00 17,423.75 92.00 275.87 6,092.00 5,960.00 -1,489.27 -14,418.35 2.00 -1.07 -1.69 -122.31 17,559.51 89.28 275.87 6,090.48 5,958.48 -1,475.38 -14,553.37 2.00 -2.00 0.00 180.00 18,482.68 89.28 275.87 6,102.00 5,970.00 -1,380.94 -15,471.63 0.00 0.00 0.00 0.00 1/11/2017 12:46:52PM Page 3 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 Depth Inclination Design: 2M-38wp22 TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 2,480.98 2,952.69 61.15 253.71 2,612.98 2,480.98 -738.35 -613.52 5,947,998.80 1,627,782.63 0.00 732.43 Adjust TF to 0°, for 100.31' 3,000.00 61.15 253.71 2,635.81 2,503.81 -749.97 -653.30 5,947,987.24 1,627,742.84 0.00 773.61 3,053.00 61.15 253.71 2,661.38 2,529.38 -762.99 -697.86 5,947,974.29 1,627,698.27 0.00 819.76 Adjust TF to 0°, for 20' -13-3/8" x 16" 3,073.00 61.15 253.71 2,671.03 2,539.03 -767.91 -714.67 5,947,969.41 1,627,681.44 0.00 837.17 Start 2°/100' DLS, 41.54° TF, for 783.44' 3,100.00 61.55 254.12 2,683.98 2,551.98 -774.47 -737.44 5,947,962.88 1,627,658.67 2.00 860.73 3,200.00 63.06 255.60 2,730.45 2,598.45 -797.59 -822.91 5,947,939.90 1,627,573.17 2.00 948.92 3,300.00 64.59 257.04 2,774.55 2,642.55 -818.81 -910.10 5,947,918.82 1,627,485.95 2.00 1,038.47 3,400.00 66.13 258.45 2,816.25 2,684.25 -838.10 -998.92 5,947,899.68 1,627,397.11 2.00 1,129.29 3,500.00 67.68 259.82 2,855.48 2,723.48 -855.43 -1,089.25 5,947,882.49 1,627,306.76 2.00 1,221.26 3,600.00 69.24 261.16 2,892.20 2,760.20 -870.79 -1,180.99 5,947,867.28 1,627,215.01 2.00 1,314.26 3,671.85 70.37 262.11 2,917.00 2,785.00 -880.59 -1,247.70 5,947,857.58 1,627,148.29 2.00 1,381.67 Camp SS 3,700.00 70.81 262.48 2,926.35 2,794.35 -884.15 -1,274.01 5,947,854.07 1,627,121.98 2.00 1,408.20 3,800.00 72.39 263.77 2,957.91 2,825.91 -895.51 -1,368.21 5,947,842.86 1,627,027.77 2.00 1,502.94 3,856.44 73.29 264.49 2,974.56 2,842.56 -901.02 -1,421.86 5,947,837.43 1,626,974.12 2.00 1,556.72 Hold for 8067.23' 3,900.00 73.29 264.49 2,987.09 2,855.09 -905.03 -1,463.38 5,947,833.49 1,626,932.59 0.00 1,598.32 4,000.00 73.29 264.49 3,015.84 2,883.84 -914.23 -1,558.72 5,947,824.44 1,626,837.25 0.00 1,693.80 4,100.00 73.29 264.49 3,044.59 2,912.59 -923.44 -1,654.05 5,947,815.39 1,626,741.91 0.00 1,789.29 4,200.00 73.29 264.49 3,073.34 2,941.34 -932.64 -1,749.39 5,947,806.34 1,626,646.57 0.00 1,884.77 4,300.00 73.29 264.49 3,102.09 2,970.09 -941.84 -1,844.72 5,947,797.29 1,626,551.23 0.00 1,980.26 4,400.00 73.29 264.49 3,130.85 2,998.85 -951.04 -1,940.06 5,947,788.25 1,626,455.89 0.00 2,075.74 4,500.00 73.29 264.49 3,159.60 3,027.60 -960.25 -2,035.39 5,947,779.20 1,626,360.55 0.00 2,171.22 4,600.00 73.29 264.49 3,188.35 3,056.35 -969.45 -2,130.73 5,947,770.15 1,626,265.21 0.00 2,266.71 4,700.00 73.29 264.49 3,217.10 3,085.10 -978.65 -2,226.06 5,947,761.10 1,626,169.87 0.00 2,362.19 4,800.00 73.29 264.49 3,245.85 3,113.85 -987.85 -2,321.39 5,947,752.05 1,626,074.53 0.00 2,457.68 4,900.00 73.29 264.49 3,274.60 3,142.60 -997.05 -2,416.73 5,947,743.00 1,625,979.19 0.00 2,553.16 5,000.00 73.29 264.49 3,303.36 3,171.36 -1,006.26 -2,512.06 5,947,733.95 1,625,883.85 0.00 2,648.64 5,100.00 73.29 264.49 3,332.11 3,200.11 -1,015.46 -2,607.40 5,947,724.90 1,625,788.51 0.00 2,744.13 5,200.00 73.29 264.49 3,360.86 3,228.86 -1,024.66 -2,702.73 5,947,715.85 1,625,693.17 0.00 2,839.61 5,300.00 73.29 264.49 3,389.61 3,257.61 -1,033.86 -2,798.07 5,947,706.81 1,625,597.84 0.00 2,935.10 5,400.00 73.29 264.49 3,418.36 3,286.36 -1,043.06 -2,893.40 5,947,697.76 1,625,502.50 0.00 3,030.58 5,500.00 73.29 264.49 3,447.11 3,315.11 -1,052.27 -2,988.74 5,947,688.71 1,625,407.16 0.00 3,126.06 5,600.00 73.29 264.49 3,475.87 3,343.87 -1,061.47 -3,084.07 5,947,679.66 1,625,311.82 0.00 3,221.55 5,700.00 73.29 264.49 3,504.62 3,372.62 -1,070.67 -3,179.40 5,947,670.61 1,625,216.48 0.00 3,317.03 5,800.00 73.29 264.49 3,533.37 3,401.37 -1,079.87 -3,274.74 5,947,661.56 1,625,121.14 0.00 3,412.52 5,900.00 73.29 264.49 3,562.12 3,430.12 -1,089.07 -3,370.07 5,947,652.51 1,625,025.80 0.00 3,508.00 6,000.00 73.29 264.49 3,590.87 3,458.87 -1,098.28 -3,465.41 5,947,643.46 1,624,930.46 0.00 3,603.48 6,100.00 73.29 264.49 3,619.62 3,487.62 -1,107.48 -3,560.74 5,947,634.41 1,624,835.12 0.00 3,698.97 6,200.00 73.29 264.49 3,648.38 3,516.38 -1,116.68 -3,656.08 5,947,625.37 1,624,739.78 0.00 3,794.45 6,300.00 73.29 264.49 3,677.13 3,545.13 -1,125.88 -3,751.41 5,947,616.32 1,624,644.44 0.00 3,889.94 6,400.00 73.29 264.49 3,705.88 3,573.88 -1,135.08 -3,846.75 5,947,607.27 1,624,549.10 0.00 3,985.42 1/11/2017 12:46:52PM Page 4 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E! -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,602.63 6,500.00 73.29 264.49 3,734.63 3,602.63 -1,144.29 -3,942.08 5,947,598.22 1,624,453.76 0.00 4,080.90 6,600.00 73.29 264.49 3,763.38 3,631.38 -1,153.49 -4,037.42 5,947,589.17 1,624,358.42 0.00 4,176.39 6,700.00 73.29 264.49 3,792.14 3,660.14 -1,162.69 -4,132.75 5,947,580.12 1,624,263.08 0.00 4,271.87 6,800.00 73.29 264.49 3,820.89 3,688.89 -1,171.89 -4,228.08 5,947,571.07 1,624,167.74 0.00 4,367.36 6,900.00 73.29 264.49 3,849.64 3,717.64 -1,181.09 -4,323.42 5,947,562.02 1,624,072.40 0.00 4,462.84 7,000.00 73.29 264.49 3,878.39 3,746.39 -1,190.30 -4,418.75 5,947,552.97 1,623,977.06 0.00 4,558.32 7,100.00 73.29 264.49 3,907.14 3,775.14 -1,199.50 -4,514.09 5,947,543.93 1,623,881.72 0.00 4,653.81 7,200.00 73.29 264.49 3,935.89 3,803.89 -1,208.70 -4,609.42 5,947,534.88 1,623,786.38 0.00 4,749.29 7,300.00 73.29 264.49 3,964.65 3,832.65 -1,217.90 -4,704.76 5,947,525.83 1,623,691.04 0.00 4,844.78 7,400.00 73.29 264.49 3,993.40 3,861.40 -1,227.10 -4,800.09 5,947,516.78 1,623,595.71 0.00 4,940.26 7,500.00 73.29 264.49 4,022.15 3,890.15 -1,236.31 -4,895.43 5,947,507.73 1,623,500.37 0.00 5,035.74 7,600.00 73.29 264.49 4,050.90 3,918.90 -1,245.51 -4,990.76 5,947,498.68 1,623,405.03 0.00 5,131.23 7,700.00 73.29 264.49 4,079.65 3,947.65 -1,254.71 -5,086.09 5,947,489.63 1,623,309.69 0.00 5,226.71 7,800.00 73.29 264.49 4,108.40 3,976.40 -1,263.91 -5,181.43 5,947,480.58 1,623,214.35 0.00 5,322.20 7,900.00 73.29 264.49 4,137.16 4,005.16 -1,273.11 -5,276.76 5,947,471.53 1,623,119.01 0.00 5,417.68 8,000.00 73.29 264.49 4,165.91 4,033.91 -1,282.32 -5,372.10 5,947,462.49 1,623,023.67 0.00 5,513.16 8,038.58 73.29 264.49 4,177.00 4,045.00 -1,285.87 -5,408.88 5,947,458.99 1,622,986.89 0.00 5,550.00 C-50 8,100.00 73.29 264.49 4,194.66 4,062.66 -1,291.52 -5,467.43 5,947,453.44 1,622,928.33 0.00 5,608.65 8,200.00 73.29 264.49 4,223.41 4,091.41 -1,300.72 -5,562.77 5,947,444.39 1,622,832.99 0.00 5,704.13 8,300.00 73.29 264.49 4,252.16 4,120.16 -1,309.92 -5,658.10 5,947,435.34 1,622,737.65 0.00 5,799.62 8,400.00 73.29 264.49 4,280.91 4,148.91 -1,319.13 -5,753.44 5,947,426.29 1,622,642.31 0.00 5,895.10 8,500.00 73.29 264.49 4,309.67 4,177.67 -1,328.33 -5,848.77 5,947,417.24 1,622,546.97 0.00 5,990.59 8,600.00 73.29 264.49 4,338.42 4,206.42 -1,337.53 -5,944.10 5,947,408.19 1,622,451.63 0.00 6,086.07 8,700.00 73.29 264.49 4,367.17 4,235.17 -1,346.73 -6,039.44 5,947,399.14 1,622,356.29 0.00 6,181.55 8,800.00 73.29 264.49 4,395.92 4,263.92 -1,355.93 -6,134.77 5,947,390.09 1,622,260.95 0.00 6,277.04 8,900.00 73.29 264.49 4,424.67 4,292.67 -1,365.14 -6,230.11 5,947,381.05 1,622,165.61 0.00 6,372.52 9,000.00 73.29 264.49 4,453.42 4,321.42 -1,374.34 -6,325.44 5,947,372.00 1,622,070.27 0.00 6,468.01 9,100.00 73.29 264.49 4,482.18 4,350.18 -1,383.54 -6,420.78 5,947,362.95 1,621,974.93 0.00 6,563.49 9,200.00 73.29 264.49 4,510.93 4,378.93 -1,392.74 -6,516.11 5,947,353.90 1,621,879.59 0.00 6,658.97 9,300.00 73.29 264.49 4,539.68 4,407.68 -1,401.94 -6,611.45 5,947,344.85 1,621,784.25 0.00 6,754.46 9,400.00 73.29 264.49 4,568.43 4,436.43 -1,411.15 -6,706.78 5,947,335.80 1,621,688.91 0.00 6,849.94 9,500.00 73.29 264.49 4,597.18 4,465.18 -1,420.35 -6,802.11 5,947,326.75 1,621,593.58 0.00 6,945.43 9,600.00 73.29 264.49 4,625.94 4,493.94 -1,429.55 -6,897.45 5,947,317.70 1,621,498.24 0.00 7,040.91 9,700.00 73.29 264.49 4,654.69 4,522.69 -1,438.75 -6,992.78 5,947,308.65 1,621,402.90 0.00 7,136.39 9,800.00 73.29 264.49 4,683.44 4,551.44 -1,447.95 -7,088.12 5,947,299.61 1,621,307.56 0.00 7,231.88 9,829.78 73.29 264.49 4,692.00 4,560.00 -1,450.69 -7,116.51 5,947,296.91 1,621,279.17 0.00 7,260.31 C-37 / Top Iceberg 9,900.00 73.29 264.49 4,712.19 4,580.19 -1,457.16 -7,183.45 5,947,290.56 1,621,212.22 0.00 7,327.36 10,000.00 73.29 264.49 4,740.94 4,608.94 -1,466.36 -7,278.79 5,947,281.51 1,621,116.88 0.00 7,422.85 10,100.00 73.29 264.49 4,769.69 4,637.69 -1,475.56 -7,374.12 5,947,272.46 1,621,021.54 0.00 7,518.33 10,200.00 73.29 264.49 4,798.45 4,666.45 -1,484.76 -7,469.46 5,947,263.41 1,620,926.20 0.00 7,613.81 10,300.00 73.29 264.49 4,827.20 4,695.20 -1,493.96 -7,564.79 5,947,254.36 1,620,830.86 0.00 7,709.30 10,400.00 73.29 264.49 4,855.95 4,723.95 -1,503.17 -7,660.12 5,947,245.31 1,620,735.52 0.00 7,804.78 10,500.00 73.29 264.49 4,884.70 4,752.70 -1,512.37 -7,755.46 5,947,236.26 1,620,640.18 0.00 7,900.27 1/11/2017 12:46:52PM Page 5 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.O0usft (Doyonl41) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.O0usft (Doyonl41) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 (usft) (1) Design: 2M-38wp22 usft (usft) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +Nl-S +E/ -W Northing Easting DLS Vert Section (usft) (1) C) (usft) usft (usft) (usft) (usft) (usft) 4,781.45 10,600.00 73.29 264.49 4,913.45 4,781.45 -1,521.57 -7,850.79 5,947,227.21 1,620,544.84 0.00 7,995.75 10,700.00 73.29 264.49 4,942.20 4,810.20 -1,530.77 -7,946.13 5,947,218.17 1,620,449.50 0.00 8,091.23 10,800.00 73.29 264.49 4,970.96 4,838.96 -1,539.97 -8,041.46 5,947,209.12 1,620,354.16 0.00 8,186.72 10,900.00 73.29 264.49 4,999.71 4,867.71 -1,549.18 -8,136.80 5,947,200.07 1,620,258.82 0.00 8,282.20 11,000.00 73.29 264.49 5,028.46 4,896.46 -1,558.38 -8,232.13 5,947,191.02 1,620,163.48 0.00 8,377.69 11,100.00 73.29 264.49 5,057.21 4,925.21 -1,567.58 -8,327.47 5,947,181.97 1,620,068.14 0.00 8,473.17 11,200.00 73.29 264.49 5,085.96 4,953.96 -1,576.78 -8,422.80 5,947,172.92 1,619,972.80 0.00 8,568.65 11,221.00 73.29 264.49 5,092.00 4,960.00 -1,578.71 -8,442.82 5,947,171.02 1,619,952.78 0.00 8,588.70 Base Iceberg / Growler 11,300.00 73.29 264.49 5,114.71 4,982.71 -1,585.98 -8,518.14 5,947,163.87 1,619,877.46 0.00 8,664.14 11,400.00 73.29 264.49 5,143.47 5,011.47 -1,595.19 -8,613.47 5,947,154.82 1,619,782.12 0.00 8,759.62 11,500.00 73.29 264.49 5,172.22 5,040.22 -1,604.39 -8,708.80 5,947,145.77 1,619,686.78 0.00 8,855.11 11,600.00 73.29 264.49 5,200.97 5,068.97 -1,613.59 -8,804.14 5,947,136.73 1,619,591.45 0.00 8,950.59 11,700.00 73.29 264.49 5,229.72 5,097.72 -1,622.79 -8,899.47 5,947,127.68 1,619,496.11 0.00 9,046.07 11,800.00 73.29 264.49 5,258.47 5,126.47 -1,631.99 -8,994.81 5,947,118.63 1,619,400.77 0.00 9,141.56 11,900.00 73.29 264.49 5,287.22 5,155.22 -1,641.20 -9,090.14 5,947,109.58 1,619,305.43 0.00 9,237.04 11,923.67 73.29 264.49 5,294.03 5,162.03 -1,643.38 -9,112.71 5,947,107.44 1,619,282.86 0.00 9,259.65 Start 2°/100' DLS, 175.5° TF, for 165.05' 11,923.68 73.29 264.49 5,294.03 5,162.03 -1,643.38 -9,112.72 5,947,107.44 1,619,282.85 0.00 9,259.65 12,000.00 71.77 264.61 5,316.94 5,184.94 -1,650.29 -9,185.19 5,947,100.64 1,619,210.38 2.00 9,332.22 12,088.72 70.00 264.76 5,346.00 5,214.00 -1,658.05 -9,268.65 5,947,093.01 1,619,126.91 2.00 9,415.77 Adjust TF to 179.99°, for 168.03' 12,088.73 70.00 264.76 5,346.00 5,214.00 -1,658.05 -9,268.66 5,947,093.01 1,619,126.90 2.00 9,415.78 12,100.00 69.77 264.76 5,349.88 5,217.88 -1,659.02 -9,279.20 5,947,092.06 1,619,116.36 2.00 9,426.32 12,200.00 67.77 264.76 5,386.08 5,254.08 -1,667.53 -9,372.02 5,947,083.70 1,619,023.53 2.00 9,519.21 12,215.56 67.46 264.76 5,392.00 5,260.00 -1,668.84 -9,386.34 5,947,082.41 1,619,009.21 2.00 9,533.54 C-35 12,256.75 66.64 264.76 5,408.06 5,276.06 -1,672.30 -9,424.12 5,947,079.01 1,618,971.44 2.00 9,571.35 Hold for 778.55' 12,256.76 66.64 264.76 5,408.06 5,276.06 -1,672.30 -9,424.13 5,947,079.01 1,618,971.43 2.00 9,571.35 12,300.00 66.64 264.76 5,425.21 5,293.21 -1,675.93 -9,463.66 5,947,075.45 1,618,931.89 0.00 9,610.92 12,400.00 66.64 264.76 5,464.86 5,332.86 -1,684.31 -9,555.08 5,947,067.22 1,618,840.47 0.00 9,702.40 12,500.00 66.64 264.76 5,504.51 5,372.51 -1,692.69 -9,646.50 5,947,058.98 1,618,749.05 0.00 9,793.89 12,600.00 66.64 264.76 5,544.17 5,412.17 -1,701.07 -9,737.92 5,947,050.75 1,618,657.62 0.00 9,885.37 12,700.00 66.64 264.76 5,583.82 5,451.82 -1,709.45 -9,829.34 5,947,042.52 1,618,566.20 0.00 9,976.86 12,800.00 66.64 264.76 5,623.47 5,491.47 -1,717.83 -9,920.76 5,947,034.28 1,618,474.77 0.00 10,068.34 12,900.00 66.64 264.76 5,663.12 5,531.12 -1,726.21 -10,012.18 5,947,026.05 1,618,383.35 0.00 10,159.83 13,000.00 66.64 264.76 5,702.77 5,570.77 -1,734.59 -10,103.60 5,947,017.82 1,618,291.93 0.00 10,251.32 13,035.30 66.64 264.76 5,716.77 5,584.77 -1,737.54 -10,135.87 5,947,014.91 1,618,259.65 0.00 10,283.61 Start 1°/100' DLS, -147.25° TF, for 10.64' 13,035.31 66.64 264.76 5,716.77 5,584.77 -1,737.55 -10,135.88 5,947,014.91 1,618,259.64 0.00 10,283.62 13,045.94 66.55 264.70 5,721.00 5,589.00 -1,738.44 -10,145.59 5,947,014.03 1,618,249.93 1.00 10,293.34 Adjust TF to -167.84°, for 19.28' 13,045.95 66.55 264.70 5,721.00 5,589.00 -1,738.44 -10,145.60 5,947,014.03 1,618,249.92 1.00 10,293.35 1/11/2017 12:46:52PM Page 6 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) MD Reference: 2M-38:101.3+30.7 @ 132.00usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature 1/1112017 12:46:52PM Page 7 COMPASS 5000.1 Build 74 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +El -W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,596.70 13,065.22 66.36 264.66 5,728.70 5,596.70 -1,740.08 -10,163.19 5,947,012.42 1,618,232.33 1.00 10,310.96 Hold for 362.37' 13,065.23 66.36 264.66 5,728.70 5,596.70 -1,740.08 -10,163.20 5,947,012.42 1,618,232.32 1.00 10,310.97 13,100.00 66.36 264.66 5,742.64 5,610.64 -1,743.05 -10,194.91 5,947,009.50 1,618,200.61 0.00 10,342.71 13,200.00 66.36 264.66 5,782.74 5,650.74 -1,751.58 -10,286.12 5,947,001.12 1,618,109.39 0.00 10,434.02 9-5/8" x 12-1/4" 13,223.10 66.36 264.66 5,792.00 5,660.00 -1,753.55 -10,307.19 5,946,999.18 1,618,088.32 0.00 10,455.11 Top HRZ 13,300.00 66.36 264.66 5,822.84 5,690.84 -1,760.11 -10,377.33 5,946,992.73 1,618,018.17 0.00 10,525.33 13,400.00 66.36 264.66 5,862.93 5,730.93 -1,768.65 -10,468.55 5,946,984.34 1,617,926.96 0.00 10,616.64 13,427.59 66.36 264.66 5,874.00 5,742.00 -1,771.00 -10,493.71 5,946,982.03 1,617,901.79 0.00 10,641.83 Start 2.5°/100' DLS, 179.7° TF, for 40.05' 13,427.60 66.36 264.66 5,874.00 5,742.00 -1,771.00 -10,493.72 5,946,982.03 1,617,901.78 0.00 10,641.84 13,467.65 65.36 264.66 5,890.38 5,758.38 -1,774.40 -10,530.11 5,946,978.69 1,617,865.40 2.50 10,678.26 Hold for 30.27' 13,467.66 65.36 264.66 5,890.38 5,758.38 -1,774.40 -10,530.11 5,946,978.69 1,617,865.39 2.50 10,678.27 13,493.13 65.36 264.66 5,901.00 5,769.00 -1,776.56 -10,553.17 5,946,976.57 1,617,842.33 0.00 10,701.35 Fault 1 -40-45' DTE 13,495.53 65.36 264.66 5,902.00 5,770.00 -1,776.76 -10,555.34 5,946,976.37 1,617,840.16 0.00 10,703.52 Base HRZ/Top Kalubik 13,497.92 65.36 264.66 5,903.00 5,771.00 -1,776.96 -10,557.50 5,946,976.17 1,617,838.00 0.00 10,705.69 Start 3.5°/100' DLS, -2.15° TF, for 74.08' 13,497.93 65.36 264.66 5,903.00 5,771.00 -1,776.96 -10,557.51 5,946,976.17 1,617,837.99 0.00 10,705.69 13,500.00 65.43 264.66 5,903.86 5,771.86 -1,777.14 -10,559.39 5,946,976.00 1,617,836.11 3.50 10,707.57 13,572.00 67.90 264.56 5,932.38 5,800.38 -1,783.35 -10,625.20 5,946,969.89 1,617,770.29 3.43 10,773.47 Hold for 34.2' 13,572.01 67.90 264.56 5,932.38 5,800.38 -1,783.35 -10,625.21 5,946,969.89 1,617,770.29 3.43 10,773.48 13,600.00 67.90 264.56 5,942.91 5,810.91 -1,785.81 -10,651.03 5,946,967.47 1,617,744.47 0.00 10,799.33 13,606.21 67.90 264.56 5,945.25 5,813.25 -1,786.36 -10,656.75 5,946,966.94 1,617,738.74 0.00 10,805.06 Start 3.5°/100" DLS, -6.25° TF, for 87.62' 13,606.22 67.90 264.56 5,945.25 5,813.25 -1,786.36 -10,656.76 5,946,966.94 1,617,738.73 0.00 10,805.07 13,693.83 71.00 264.20 5,976.00 5,844.00 -1,794.39 -10,738.39 5,946,959.03 1,617,657.10 3.56 10,886.85 Adjust TF to 19.85°, for 56.84' 13,693.84 71.00 264.20 5,976.00 5,844.00 -1,794.39 -10,738.40 5,946,959.03 1,617,657.09 3.56 10,886.86 13,700.00 71.20 264.28 5,978.00 5,846.00 -1,794.98 -10,744.20 5,946,958.45 1,617,651.29 3.50 10,892.68 13,745.19 72.69 264.84 5,992.00 5,860.00 -1,799.05 -10,786.97 5,946,954.45 1,617,608.52 3.50 10,935.51 K1 13,750.67 72.87 264.91 5,993.62 5,861.62 -1,799.52 -10,792.19 5,946,953.99 1,617,603.30 3.50 10,940.72 Hold for 17.62' 13,750.68 72.87 264.91 5,993.63 5,861.63 -1,799.52 -10,792.20 5,946,953.99 1,617,603.29 3.50 10,940.73 13,768.29 72.87 264.91 5,998.81 5,866.81 -1,801.02 -10,808.96 5,946,952.52 1,617,586.53 0.00 10,957.50 Start 3.5°/100' DLS, -13.54° TF, for 355.91' 13,768.30 72.87 264.91 5,998.81 5,866.81 -1,801.02 -10,808.97 5,946,952.52 1,617,586.52 0.00 10,957.51 13,779.23 73.24 264.81 6,002.00 5,870.00 -1,801.95 -10,819.38 5,946,951.60 1,617,576.10 3.50 10,967.93 Fault 2 - 25' DTW 13,800.00 73.95 264.64 6,007.86 5,875.86 -1,803.79 -10,839.22 5,946,949.80 1,617,556.26 3.50 10,987.78 1/1112017 12:46:52PM Page 7 COMPASS 5000.1 Build 74 Database: I OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: 1 Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) MD Reference: 2M-38: 101.3+30.7 @ 132.O0usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 5,900.64 13,900.00 77.36 263.80 6,032.64 5,900.64 -1,813.55 -10,935.59 5,946,940.19 1,617,459.89 3.50 11,084.39 14,000.00 80.76 262.99 6,051.61 5,919.61 -1,824.84 -11,033.11 5,946,929.05 1,617,362.36 3.50 11,182.38 14,035.93 81.99 262.70 6,057.00 5,925.00 -1,829.27 -11,068.36 5,946,924.69 1,617,327.11 3.50 11,217.87 Top Kuparuk C 14,100.00 84.17 262.19 6,064.72 5,932.72 -1,837.63 -11,131.40 5,946,916.43 1,617,264.06 3.50 11,281.40 14,124.20 85.00 262.00 6,067.00 5,935.00 -1,840.94 -11,155.27 5,946,913.15 1,617,240.19 3.50 11,305.48 Adjust TF to 8.99°, for 180.15' 14,124.21 85.00 262.00 6,067.00 5,935.00 -1,840.94 -11,155.28 5,946,913.15 1,617,240.18 3.50 11,305.49 14,200.00 87.62 262.41 6,071.88 5,939.88 -1,851.20 -11,230.20 5,946,903.02 1,617,165.24 3.50 11,381.06 7" x 8-1/2" by 9-7/8" 14,300.00 91.08 262.96 6,073.01 5,941.01 -1,863.92 -11,329.37 5,946,890.45 1,617,066.07 3.50 11,480.93 14,304.35 91.23 262.98 6,072.93 5,940.93 -1,864.46 -11,333.69 5,946,889.93 1,617,061.75 3.50 11,485.28 Hold for 33.92' 14,304.36 91.23 262.98 6,072.93 5,940.93 -1,864.46 -11,333.70 5,946,889.93 1,617,061.74 3.50 11,485.28 14,338.28 91.23 262.98 6,072.20 5,940.20 -1,868.60 -11,367.35 5,946,885.84 1,617,028.09 0.00 11,519.14 Start 3.5°/100' DLS, -170.39° TF, for 10.96' 14,338.28 91.23 262.98 6,072.20 5,940.20 -1,868.60 -11,367.36 5,946,885.84 1,617,028.08 0.01 11,519.15 14,349.24 90.85 262.92 6,072.00 5,940.00 -1,869.94 -11,378.23 5,946,884.51 1,617,017.21 3.50 11,530.09 Start 3.22°/100' DLS, 96.52° TF, for 798.06' 14,349.25 90.85 262.92 6,072.00 5,940.00 -1,869.94 -11,378.23 5,946,884.51 1,617,017.20 3.50 11,530.10 14,400.00 90.66 264.54 6,071.33 5,939.33 -1,875.49 -11,428.68 5,946,879.05 1,616,966.75 3.22 11,580.74 14,500.00 90.30 267.74 6,070.49 5,938.49 -1,882.22 -11,528.44 5,946,872.48 1,616,866.99 3.22 11,680.15 14,600.00 89.93 270.93 6,070.29 5,938.29 -1,883.38 -11,628.42 5,946,871.48 1,616,767.02 3.22 11,778.81 14,700.00 89.56 274.13 6,070.74 5,938.74 -1,878.96 -11,728.30 5,946,876.05 1,616,667.15 3.22 11,876.41 14,800.00 89.19 277.32 6,071.83 5,939.83 -1,868.98 -11,827.79 5,946,886.19 1,616,567.69 3.22 11,972.65 14,900.00 88.83 280.52 6,073.55 5,941.55 -1,853.48 -11,926.55 5,946,901.85 1,616,468.97 3.22 12,067.22 15,000.00 88.47 283.72 6,075.91 5,943.91 -1,832.49 -12,024.28 5,946,922.99 1,616,371.28 3.22 12,159.82 15,038.94 88.33 284.96 6,077.00 5,945.00 -1,822.85 -12,061.99 5,946,932.69 1,616,333.58 3.22 12,195.29 Deepest possible Kuparuk C 15,100.00 88.11 286.92 6,078.90 5,946.90 -1,806.09 -12,120.67 5,946,949.54 1,616,274.94 3.22 12,250.17 15,147.30 87.95 288.43 6,080.52 5,948.52 -1,791.74 -12,165.71 5,946,963.96 1,616,229.93 3.22 12,292.02 Hold for 1.2' 15,147.30 87.95 288.43 6,080.52 5,948.52 -1,791.74 -12,165.72 5,946,963.96 1,616,229.92 3.22 12,292.03 15,148.50 87.95 288.43 6,080.56 5,948.56 -1,791.36 -12,166.85 5,946,964.34 1,616,228.79 0.00 12,293.08 Start 3.22°/100' DLS, -87.31° TF, for 372.53' 15,148.51 87.95 288.43 6,080.57 5,948.57 -1,791.36 -12,166.86 5,946,964.35 1,616,228.78 0.00 12,293.09 15,200.00 88.02 286.77 6,082.38 5,950.38 -1,775.80 -12,215.91 5,946,979.99 1,616,179.76 3.22 12,338.69 15,300.00 88.18 283.56 6,085.69 5,953.69 -1,749.65 -12,312.36 5,947,006.28 1,616,083.36 3.22 12,429.14 15,400.00 88.34 280.35 6,088.72 5,956.72 -1,728.95 -12,410.13 5,947,027.14 1,615,985.63 3.22 12,521.83 15,500.00 88.51 277.13 6,091.46 5,959.46 -1,713.77 -12,508.92 5,947,042.48 1,615,886.88 3.22 12,616.48 15,521.03 88.55 276.46 6,092.00 5,960.00 -1,711.28 -12,529.80 5,947,045.00 1,615,866.01 3.22 12,636.61 Hold for 1184.22' 15,521.04 88.55 276.46 6,092.00 5,960.00 -1,711.28 -12,529.80 5,947,045.00 1,615,866.00 3.22 12,636.62 15,600.00 88.55 276.46 6,094.00 5,962.00 -1,702.40 -12,608.24 5,947,054.00 1,615,787.59 0.00 12,712.32 15,700.00 88.55 276.46 6,096.53 5,964.53 -1,691.16 -12,707.57 5,947,065.40 1,615,688.28 0.00 12,808.19 1/11/2017 12:46:52PM Page 8 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 Depth Inclination Design: 2M-38wp22 TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) (usft) (usft) 5,967.07 15,800.00 88.55 276.46 6,099.07 5,967.07 -1,679.91 -12,806.91 5,947,076.80 1,615,588.98 0.00 12,904.06 15,900.00 88.55 276.46 6,101.60 5,969.60 -1,668.67 -12,906.24 5,947,088.20 1,615,489.67 0.00 12,999.94 16,000.00 88.55 276.46 6,104.13 5,972.13 -1,657.43 -13,005.57 5,947,099.60 1,615,390.36 0.00 13,095.81 16,100.00 88.55 276.46 6,106.67 5,974.67 -1,646.19 -13,104.91 5,947,111.00 1,615,291.06 0.00 13,191.68 16,200.00 88.55 276.46 6,109.20 5,977.20 -1,634.95 -13,204.24 5,947,122.40 1,615,191.75 0.00 13,287.55 16,300.00 88.55 276.46 6,111.73 5,979.73 -1,623.70 -13,303.58 5,947,133.80 1,615,092.45 0.00 13,383.43 16,400.00 88.55 276.46 6,114.27 5,982.27 -1,612.46 -13,402.91 5,947,145.20 1,614,993.14 0.00 13,479.30 16,500.00 88.55 276.46 6,116.80 5,984.80 -1,601.22 -13,502.24 5,947,156.60 1,614,893.84 0.00 13,575.17 16,600.00 88.55 276.46 6,119.33 5,987.33 -1,589.98 -13,601.58 5,947,168.00 1,614,794.53 0.00 13,671.04 16,700.00 88.55 276.46 6,121.87 5,989.87 -1,578.73 -13,700.91 5,947,179.40 1,614,695.22 0.00 13,766.92 16,705.25 88.55 276.46 6,122.00 5,990.00 -1,578.14 -13,706.13 5,947,180.00 1,614,690.01 0.00 13,771.95 Start 3°/100' DLS, 10.71° TF, for 147.28' 16,705.26 88.55 276.46 6,122.00 5,990.00 -1,578.14 -13,706.14 5,947,180.00 1,614,690.00 0.00 13,771.96 16,800.00 91.34 276.99 6,122.09 5,990.09 -1,567.05 -13,800.21 5,947,191.24 1,614,595.95 3.00 13,862.68 16,852.53 92.89 277.28 6,120.15 5,988.15 -1,560.54 -13,852.30 5,947,197.84 1,614,543.88 3.00 13,912.85 Hold for 488.07' 16,852.54 92.89 277.28 6,120.15 5,988.15 -1,560.54 -13,852.31 5,947,197.84 1,614,543.87 3.00 13,912.85 16,900.00 92.89 277.28 6,117.76 5,985.76 -1,554.53 -13,899.33 5,947,203.92 1,614,496.86 0.00 13,958.12 17,000.00 92.89 277.28 6,112.72 5,980.72 -1,541.88 -13,998.40 5,947,216.73 1,614,397.83 0.00 14,053.48 17,100.00 92.89 277.28 6,107.68 5,975.68 -1,529.23 -14,097.46 5,947,229.54 1,614,298.79 0.00 14,148.85 17,200.00 92.89 277.28 6,102.64 5,970.64 -1,516.57 -14,196.53 5,947,242.35 1,614,199.75 0.00 14,244.22 17,300.00 92.89 277.28 6,097.59 5,965.59 -1,503.92 -14,295.60 5,947,255.16 1,614,100.71 0.00 14,339.58 17,340.60 92.89 277.28 6,095.55 5,963.55 -1,498.78 -14,335.82 5,947,260.36 1,614,060.51 0.00 14,378.30 Start 2°/100' DLS, -122.31° TF, for 83.15' 17,340.61 92.89 277.28 6,095.55 5,963.55 -1,498.78 -14,335.83 5,947,260.36 1,614,060.50 0.00 14,378.30 17,400.00 92.25 276.27 6,092.88 5,960.88 -1,491.78 -14,394.75 5,947,267.45 1,614,001.60 2.00 14,435.11 17,423.74 92.00 275.87 6,092.00 5,960.00 -1,489.27 -14,418.34 5,947,270.00 1,613,978.01 2.00 14,457.91 Adjust TF to 180°, for 135.76' 17,423.75 92.00 275.87 6,092.00 5,960.00 -1,489.27 -14,418.35 5,947,270.00 1,613,978.00 2.00 14,457.92 17,500.00 90.48 275.87 6,090.35 5,958.35 -1,481.47 -14,494.18 5,947,277.92 1,613,902.19 2.00 14,531.24 17,559.50 89.29 275.87 6,090.48 5,958.48 -1,475.38 -14,553.36 5,947,284.10 1,613,843.02 2.00 14,588.47 Hold for 923.17' 17,559.51 89.28 275.87 6,090.48 5,958.48 -1,475.38 -14,553.37 5,947,284.10 1,613,843.01 2.00 14,588.48 17,600.00 89.28 275.87 6,090.98 5,958.98 -1,471.24 -14,593.65 5,947,288.31 1,613,802.75 0.00 14,627.43 17,700.00 89.28 275.87 6,092.23 5,960.23 -1,461.01 -14,693.12 5,947,298.70 1,613,703.31 0.00 14,723.61 17,800.00 89.28 275.87 6,093.48 5,961.48 -1,450.78 -14,792.58 5,947,309.08 1,613,603.87 0.00 14,819.79 17,900.00 89.28 275.87 6,094.73 5,962.73 -1,440.55 -14,892.05 5,947,319.47 1,613,504.42 0.00 14,915.97 18,000.00 89.28 275.87 6,095.98 5,963.98 -1,430.32 -14,991.52 5,947,329.86 1,613,404.98 0.00 15,012.15 18,100.00 89.28 275.87 6,097.22 5,965.22 -1,420.09 -15,090.99 5,947,340.25 1,613,305.54 0.00 15,108.33 18,200.00 89.28 275.87 6,098.47 5,966.47 -1,409.86 -15,190.45 5,947,350.64 1,613,206.10 0.00 15,204.51 18,300.00 89.28 275.87 6,099.72 5,967.72 -1,399.63 -15,289.92 5,947,361.02 1,613,106.66 0.00 15,300.69 18,400.00 89.28 275.87 6,100.97 5,968.97 -1,389.40 -15,389.39 5,947,371.41 1,613,007.22 0.00 15,396.87 18,482.67 89.28 275.87 6,102.00 5,970.00 -1,380.94 -15,471.62 5,947,380.00 1,612,925.01 0.00 15,476.38 TD: 18482.67' MD, 6102' TVD - 4-1/2" x 6-1/8" 18,482.68 89.28 275.87 6,102.00 5,970.00 -1,380.94 -15,471.63 5,947,380.00 1,612,925.00 0.00 15,476.39 1/11/2017 12:46:52PM Page 9 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 Design: 2M-38wp22 1/11/2017 12.46.52PM Page 10 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 Design: 2M-38wp22 Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (°) (usft) (usft) (usft) (usft) (usft) 2M-38 10. TD 051716 JC 0.00 0.00 6,067.00 -2,749.29 -15,571.58 5,946,011.95 1,612,822.87 - plan misses target center by 1371.83usft at 18441.68usft MD (6101.49 TVD, -1385.14 N, -15430.85 E) - Circle (radius 100.00) 21VI-38 5. K-1 051716 JC 0.00 0.00 5,976.00 -1,794.39 -10,738.40 5,946,959.03 1,617,657.09 plan hits target center Circle (radius 100.00) 2M-38 6. Top C 051716 JC 0.00 0.00 6,067.00 -1,840.94 -11,155.28 5,946,913.15 1,617,240.18 plan hits target center Circle (radius 100.00) 2M-382.1-anding 111214 BP 0.00 0.00 6,092.00 -1,798.47 -11,071.75 5,946,955.49 1,617,323.77 plan misses target center by 46.56usft at 14039.46usft MD (6057.49 TVD, -1829.71 N, -11071.83 E) Circle (radius 100.00) 2M-38 2.1-anding 012815 BP 0.00 0.00 6,077.00 -1,858.47 -11,424.15 5,946,896.06 1,616,971.31 plan misses target center by 17.43usft at 14393.56usft MD (6071.41 TVD, -1874.86 N, -11422.27 E) Circle (radius 100.00) 2M-38 4.T2 112014 JC 0.00 0.00 6,087.00 -2,245.25 -13,734.07 5,946,513.00 1,614,661.00 plan misses target center by 666.88usft at 16657.13usft MD (6120.78 TVD, -1583.55 N, -13658.32 E) Circle (radius 100.00) 2M-38332103114BP 0.00 0.00 6,102.00 -2,244.90 -13,733.57 5,946,513.35 1,614,661.50 - plan misses target center by 665.88usft at 16657.05usft MD (6120.78 TVD, -1583.56 N, -13658.25 E) - Circle (radius 100.00) 2M-38 3. Faultl 051716 JC 0.00 0.00 5,874.00 -1,771.00 -10,493.72 5,946,982.03 1,617,901.78 plan hits target center Circle (radius 100.00) 2M-38 1.C35 051716 JC 0.00 0.00 5,346.00 -1,658.05 -9,268.66 5,947,093.01 1,619,126.90 plan hits target center Circle (radius 100.00) 2M-3821anding112014 JC 0.00 0.00 6,082.00 -1,902.95 -11,685.41 5,946,852.00 1,616,710.00 - plan misses target center by 24.30usft at 14656.14usft MD (6070.47 TVD, -1881.58 N, -11684.52 E) -Circle (radius 100.00) 2M-38 21anding 103114 BP 0.00 0.00 6,092.00 -1,604.73 -10,876.81 5,947,148.90 1,617,519.00 plan misses target center by 215.70usft at 13837.65usft MD (6017.87 TVD, -1807.28 N, -10875.34 E) Circle (radius 100.00) 2M-38 7. Landing 051716 JC 0.00 0.00 6,072.00 -1,869.94 -11,378.23 5,946,884.51 1,617,017.20 plan hits target center Circle (radius 100.00) 2M-38 1.1ceberg 102414 JC 0.00 0.00 5,277.00 -1,642.80 -9,105.57 5,947,108.00 1,619,290.00 plan misses target center by 14.25usft at 11911.91 usft MD (5290.65 TVD, -1642.29 N, -9101.50 E) - Circle (radius 100.00) 2M-38 2. Top HRZ 051716 JC 0.00 0.00 5,721.00 -1,738.44 -10,145.60 5,947,014.03 1,618,249.92 - plan hits target center - Circle (radius 100.00) 2M-383.T2102414JC 0.00 0.00 6,102.00 -1,958.37 -13,822.54 5,946,800.00 1,614,573.00 plan misses target center by 391.69usft at 16776.35usft MD (6122.50 TVD, -1569.90 N, -13776.74 E) Circle (radius 100.00) 2M-38 10. TD 051716 JC -Circle 0.00 0.00 6,067.00 -2,749.29 -15,571.58 5,946,011.95 1,612,822.87 plan misses target center by 1371.83usft at 18441.68usft MD (6101.49 TVD, -1385.14 N, -15430.85 E) Circle (radius 1,320.00) 2M-38 8. - QM 0.00 0.00 6,062.00 -2,020.69 -12,417.24 5,946,735.44 1,615,978.06 Ian misses target center by 288.67usft at 15345.74usft MD (6087.11 TVD -1739.50 N -12356.93 E) 1/19/2017 12:46:52PM Page 11 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Local Co-ordinate Reference: Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 - Circle (radius 25.00) Design: 2M-38wp22 - plan misses target center by 789.71 usft at 16963.83usft MD (6114.54 TVD, -1546.46 N, -13962.56 E) - Circle (radius 1,320.00) -11,424.15 5,946,896.06 1,616,971.31 - plan misses target center by 22.37usft at 14393.44usft MD (6071.41 TVD, -1874.85 N, -11422.15 E) 2M-387. landing 051716JC_Circle 0.00 0.00 6,072.00 -1,869.94 -11,378.23 5,946,884.51 1,617,017.20 plan hits target center Circle (radius 1,320.00) Circle (radius 1,320.00) -12,417.24 5,946,735.44 1,615,978.06 plan misses target center by 288.67usft at 15345.74usft MD (6087.11 TVD, -1739.50 N, -12356.93 E) 21VI-38 4. Base HRZ/Top Kuparuk 051716 JC 0.00 0.00 5,903.00 -1,776.96 -10,557.51 5,946,976.17 1,617,837.99 plan hits target center - Circle (radius 25.00) Circle (radius 100.00) -14,061.97 5,946,429.00 1,614,333.00 - plan misses target center by 789.71 usft at 16963.83usft MD (6114.54 TVD, -1546.46 N, -13962.56 E) 2M-381.1ceberg 103114 BP 0.00 0.00 5,277.00 -1,547.29 -9,135.22 5,947,203.55 1,619,260.50 - plan misses target center by 99.85usft at 11931.23usft MD (5296.21 TVD, -1644.07 N, -9119.91 E) - Circle (radius 100.00) -Circle (radius 100.00) -10,576.58 5,947,026.00 1,617,819.00 plan misses target center by 80.07usft at 13485.54usft MD (5897.84 TVD, -1775.92 N, -10546.30 E) 2M-38wp21 Tgt Pro4 KEH 6Jan17 0.00 0.00 6,102.00 -1,380.94 -15,471.63 5,947,380.00 1,612,925.00 plan hits target center Circle (radius 100.00) Circle (radius 25.00) -14,039.55 5,946,435.32 1,614,355.43 plan misses target center by 780.59usft at 16942.42usft MD (6115.62 TVD, -1549.16 N, -13941.35 E) 21VI-38 7.Climbing Point 021915 JC 0.00 0.00 6,067.00 -2,749.26 -15,047.02 5,946,011.14 1,613,347.38 plan misses target center by 1318.00usft at 17919.92usft MD (6094.98 TVD, -1438.51 N, -14911.86 E) Circle (radius 100.00) - Circle (radius 100.00) 2M-381.C35112014JC 0.00 0.00 5,277.00 -1,642.80 -9,105.57 5,947,108.00 1,619,290.00 - plan misses target center by 14.25usft at 11911.91 usft MD (5290.65 TVD, -1642.29 N, -9101.50 E) - Circle (radius 100.00) 2M-38wp21 Tgt Pro2 KEH 6Jan17 0.00 0.00 6,122.00 -1,578.14 -13,706.14 5,947,180.00 1,614,690.00 plan hits target center Circle (radius 25.00) Interp @ 6056.80 (Plan: 2M-38 Plan: 21VI-38 2M -38H 0.00 0.00 6,060.00 -1,833.39 -11,089.07 5,946,920.60 1,617,306.40 plan misses target center by 1.43usft at 14057.21 usft MD (6059.83 TVD, -1831.98 N, -11089.27 E) Point 21VI-38 2.1-anding 112414 BP 0.00 0.00 6,086.50 -1,858.47 -11,424.15 5,946,896.06 1,616,971.31 - plan misses target center by 22.37usft at 14393.44usft MD (6071.41 TVD, -1874.85 N, -11422.15 E) -Circle (radius 100.00) 2M-38 6. T3TD 021915 JC Circle 0.00 0.00 6,067.00 -2,749.24 -15,572.45 5,946,012.00 1,612,822.00 plan misses target center by 1371.87usft at 18442.55usft MD (6101.50 TVD, -1385.05 N, -15431.72 E) Circle (radius 1,320.00) 2M-38 8. Crest 051716 JC 0.00 0.00 6,062.00 -2,020.69 -12,417.24 5,946,735.44 1,615,978.06 plan misses target center by 288.67usft at 15345.74usft MD (6087.11 TVD, -1739.50 N, -12356.93 E) Circle (radius 100.00) 2M-38wp21 Tgt Pro3 KEH 6Jan17 0.00 0.00 6,092.00 -1,489.27 -14,418.35 5,947,270.00 1,613,978.00 plan hits target center - Circle (radius 25.00) 2M-38 5.Fault2 112014 JC 0.00 0.00 6,102.00 -2,329.79 -14,061.97 5,946,429.00 1,614,333.00 - plan misses target center by 789.71 usft at 16963.83usft MD (6114.54 TVD, -1546.46 N, -13962.56 E) -Circle (radius 100.00) 2M-38 2x.Landing 012615 JC 0.00 0.00 6,077.00 -1,902.95 -11,685.41 5,946,852.00 1,616,710.00 - plan misses target center by 22.36usft at 14656.11usft MD (6070.47 TVD, -1881.58 N, -11684.50 E) - Circle (radius 100.00) 2M-38 x.Faultl 112014 JC 0.00 0.00 5,842.00 -1,727.16 -10,576.58 5,947,026.00 1,617,819.00 plan misses target center by 80.07usft at 13485.54usft MD (5897.84 TVD, -1775.92 N, -10546.30 E) Circle (radius 100.00) 21VI-38 6.T3TD 021915 JC 0.00 0.00 6,067.00 -2,749.24 -15,572.45 5,946,012.00 1,612,822.00 plan misses target center by 1371.87usft at 18442.55usft MD (6101.50 TVD, -1385.05 N, -15431.72 E) Circle (radius 100.00) 2M-38 9. Fault 2 051716 JC 0.00 0.00 6,102.00 -2,323.43 -14,039.55 5,946,435.32 1,614,355.43 plan misses target center by 780.59usft at 16942.42usft MD (6115.62 TVD, -1549.16 N, -13941.35 E) Circle (radius 100.00) 2M-382. Landing 051316 JC 0.00 0.00 6,057.00 -1,836.87 -11,015.45 5,946,917.00 1,617,380.00 plan misses target center by 16.17usft at 13985.16usft MD (6049.17 TVD, -1823.07 N, -11018.58 E) Circle (radius 100.00) 1/11/2017 12:46.52PM Page 12 COMPASS 5000.1 Build 74 Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: 1 Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) North Reference: True Survey Calculation Method: Minimum Curvature 2M-38 1. - QM 0.00 0.00 5,346.00 -1,658.05 -9,268.66 5,947,093.01 1,619,126.90 plan hits target center 42 (usft) (usft) Circle (radius 1,320.00) 113.20 113.20 20" x 42" 2M-38wp21 Tgt Prot KEH 6Jan17 0.00 0.00 6,092.00 -1,711.28 -12,529.80 5,947,045.00 1,615,866.00 plan hits target center 7" x 8-1/2" by 9-7/8" 18,482.67 6,102.00 - Circle (radius 25.00) 3,053.00 2,661.38 13-3/8" x 16" 2M-38 10. TD - QM 0.00 0.00 6,072.00 -2,486.05 -15,472.86 5,946,275.00 1,612,922.00 plan misses target center by 1099.81 usft at 18370.48usft MD (6100.60 TVD, -1392.42 N, -15360.03 E) Circle (radius 1,320.00) 2M-38 10. TD 121416 KEH 0.00 0.00 6,067.90 -2,495.21 -15,571.36 5,946,266.00 1,612,823.50 plan misses target center by 1119.14usft at 18467.46usft MD (6101.81 TVD, -1382.50 N, -15456.49 E) Circle (radius 100.00) 2M-382. Landing 012815 BP_Circle 0.00 0.00 6,077.00 -1,858.47 -11,424.15 5,946,896.06 1,616,971.31 plan misses target center by 17.43usft at 14393.56usft MD (6071.41 TVD, -1874.86 N, -11422.27 E) Circle (radius 1,320.00) 2M-38 21anding 102414 JC 0.00 0.00 6,092.00 -1,413.70 -10,936.12 5,947,340.00 1,617,460.00 plan misses target center by 403.31 usft at 13876.17usft MD (6027.26 TVD, -1811.08 N, -10912.51 E) Circle (radius 100.00) 2M-38 6.T3TD 112014 JC 0.00 0.00 6,077.00 -2,749.24 -15,572.45 5,946,012.00 1,612,822.00 plan misses target center by 1371.65usft at 18442.68usft MD (6101.50 TVD, -1385.03 N, -15431.84 E) Circle (radius 100.00) 2M-38 10. TD 122016 KEH 0.00 0.00 6,072.00 -2,486.05 -15,472.86 5,946,275.00 1,612,922.00 - plan misses target center by 1099.81 usft at 18370.48usft MD (6100.60 TVD, -1392.42 N, -15360.03 E) - Circle (radius 100.00) 2M-38 3.Crest 012615 JC 0.00 0.00 6,067.00 -1,960.96 -12,047.41 5,946,794.57 1,616,347.95 plan misses target center by 130.64usft at 14995.43usft MD (6075.79 TVD, -1833.57 N, -12019.84 E) Circle (radius 100.00) 2M-38 433TD 102414 JC 0.00 0.00 6,062.00 -2,760.77 -15,274.41 5,946,000.00 1,613,120.00 - plan misses target center by 1352.88usft at 18144.85usft MD (6097.78 TVD, -1415.50 N, -15135.60 E) -Circle (radius 100.00) Casing Points Measured Vertical Diameter Depth Depth 42 (usft) (usft) 7 113.20 113.20 20" x 42" 13,200.00 5,782.74 9-5/8" x 12-1/4" 14,200.00 6,071.88 7" x 8-1/2" by 9-7/8" 18,482.67 6,102.00 4-1/2" x 6-1/8" 3,053.00 2,661.38 13-3/8" x 16" Name Casing Hole Diameter Diameter 20 42 9-5/8 12-1/4 7 9-7/8 4-1/2 6-1/8 13-3/8 16 1/11/2017 12:46:52PM Page 13 COMPASS 5000.1 Build 74 Local Co-ordinate Reference: Well Rig: 2M-38 Database: OAKEDMP2 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Local Co-ordinate Reference: Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) North Reference: True Survey Calculation Method: Minimum Curvature Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (1) (�) 2,875.91 2,572.00 Base W Sak 13,223.10 5,792.00 Top HRZ 11,221.00 5,092.00 Base Iceberg / Growler 437.41 437.00 top T-3 Sand 13,745.19 5,992.00 K1 9,829.78 4,692.00 C-37 / Top Iceberg 13,493.13 5,901.00 Fault 1 —40-45' DTE 1,515.77 1,482.00 Base permafrost 13,495.53 5,902.00 Base HRZ/Top Kalubik 15,038.94 6,077.00 Deepest possible Kuparuk C 14,035.93 6,057.00 Top Kuparuk C 8,038.58 4,177.00 C-50 0.00 1,997.88 1,912.00 Top W Sak (W Sak D) 13,779.23 6,002.00 Fault 2 — 25' DTW 583.25 582.00 K-15 Marker 3,671.85 2,917.00 Camp SS 12,215.56 5,392.00 C-35 1/11/2017 12:46:52PM Page 14 COMPASS 5000.1 Build 74 Database: I OAKEDMP2 Local Co-ordinate Reference: , Well Rig: 2M-38 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Project: Kuparuk River Unit MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Wellbore: Rig: 2M-38 -697.87 Adjust TF to 0°, for 20' Design: 2M-38wp22 -767.91 -714.68 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 2,952.69 2,612.98 -738.35 -613.53 Adjust TF to 0°, for 100.31' 3,053.00 2,661.38 -762.99 -697.87 Adjust TF to 0°, for 20' 3,073.00 2,671.03 -767.91 -714.68 Start 2°/100' DLS, 41.54° TF, for 783.44' 3,856.44 2,974.56 -901.02 -1,421.86 Hold for 8067.23' 11,923.67 5,294.03 -1,643.38 -9,112.72 Start 2°/100' DLS, 175.5° TF, for 165.05' 12,088.72 5,346.00 -1,658.05 -9,268.66 Adjust TF to 179.99°, for 168.03' 12,256.75 5,408.06 -1,672.30 -9,424.13 Hold for 778.55' 13,035.30 5,716.77 -1,737.55 -10,135.88 Start 1°/100' DLS, -147.25° TF, for 10.64' 13,045.94 5,721.00 -1,738.44 -10,145.60 Adjust TF to -167.84°, for 19.28' 13,065.22 5,728.70 -1,740.08 -10,163.20 Hold for 362.37' 13,427.59 5,874.00 -1,771.00 -10,493.72 Start 2.5°/100' DLS, 179.7° TF, for 40.05' 13,467.65 5,890.38 -1,774.40 -10,530.11 Hold for 30.27' 13,497.92 5,903.00 -1,776.96 -10,557.51 Start 3.5°/100' DLS, -2.15° TF, for 74.08' 13,572.00 5,932.38 -1,783.35 -10,625.21 Hold for 34.2' 13,606.21 5,945.25 -1,786.36 -10,656.76 Start 3.5°/100' DLS, -6.25° TF, for 87.62' 13,693.83 5,976.00 -1,794.39 -10,738.40 Adjust TF to 19.85°, for 56.84' 13,750.67 5,993.63 -1,799.52 -10,792.20 Hold for 17.62' 13,768.29 5,998.81 -1,801.02 -10,808.97 Start 3.5°/100' DLS, -13.54° TF, for 355.91' 14,124.20 6,067.00 -1,840.94 -11,155.28 Adjust TF to 8.99°, for 180.15' 14,304.35 6,072.93 -1,864.46 -11,333.70 Hold for 33.92' 14,338.28 6,072.20 -1,868.60 -11,367.36 Start 3.5°/100' DLS, -170.39° TF, for 10.96' 14,349.24 6,072.00 -1,869.94 -11,378.23 Start 3.22°/100' DLS, 96.52° TF, for 798.06' 15,147.30 6,080.52 -1,791.74 -12,165.72 Hold for 1.2' 15,148.50 6,080.57 -1,791.36 -12,166.86 Start 3.22°/100' DLS, -87.31' TF, for 372.53' 15,521.03 6,092.00 -1,711.28 -12,529.80 Hold for 1184.22' 16,705.25 6,122.00 -1,578.14 -13,706.14 Start 3°/100' DLS, 10.71' TF, for 147.28' 16,852.53 6,120.15 -1,560.54 -13,852.31 Hold for 488.07' 17,340.60 6,095.55 -1,498.78 -14,335.83 Start 2°/100' DLS, -122.31' TF, for 83.15' 17,423.74 6,092.00 -1,489.27 -14,418.35 Adjust TF to 180°, for 135.76' 17,559.50 6,090.48 -1,475.38 -14,553.37 Hold for 923.17' 18,482.67 6,102.00 -1,380.94 -15,471.63 TD: 18482.67' MD, 6102' TVD 1/11/2017 12:46:52PM Page 15 COMPASS 5000.1 Build 74 AC Summary ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Rig: 2M-38 Rig: 2M-38 501032074600 2M-38wp22 Clearance Summary Anticollision Report 11 January, 2017 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Rig: 2M-38 - Rig: 2M-38 -2M-38wp22 Well Coordinates: 5,948,736.09 N, 1,628,397.28 E (700 16'17.48" N, 1500 05' 49.97" W) Datum Height: 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) Scan Range: 2,952.69 to 18,483.44 usft. Measured Depth. Scan Radius is 2,045.27 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Anticollision Report for Rig: 2M-38 - 2M-38wp22 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Rig: 21VI-38 - Rig: 21VI-38 - 2M-38wp22 Scan Range: 2,952.69 to 18,483.44 usft. Measured Depth. Scan Radius is 2,045.27 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2M Pad 2M-02 - 2M-02 - 2M-02 2M-02 - 2M-02 - 2M-02 2M-07 - 2M-07 - 2M-07 2M-07 - 2M-07 - 2M-07 2M-15 - 2M-15 - 2M-15 2M-27 - 2M-27 - 210-27 2M-28 - 2M-28 - 210-28 2M-28 - 2M-28 - 2M-28 2M-29 - 2M-29 - 2M-29 2M-29 - 2M-29 - 2M-29 2M-30 - 2M-30 - 2M-30 2M-30 - 2M-30 - 2M-30 2M-31 -2M-31 -2M-31 2M-31 - 2M-31 - 2M-31 2M-33 - 2M-33 - 2M-33 2M-34 - 2M-34 - 2M-34 2M-34 - 2M-34 - 2M-34 2M-35 - 2M-35 - 2M-35 3,668.87 390.06 3,668.87 314.38 3,100.00 5.154 Centre Distance Pass- Major Risk 3,769.75 397.46 3,769.75 308.93 3,225.00 4.489 Clearance Factor Pass - Major Risk 3,174.87 414.78 3,174.87 339.62 2,850.00 5.519 Centre Distance Pass - Major Risk 3,225.26 417.18 3,225.26 337.02 2,925.00 5.204 Clearance Factor Pass - Major Risk 2,965.62 1,351.78 2,965.62 1,287.79 3,675.00 21.124 Clearance Factor Pass - Major Risk 4,397.17 410.61 4,397.17 261.06 3,775.00 2.746 Clearance Factor Pass - Major Risk 6,720.22 377.80 6,720.22 191.57 5,875.00 2.029 Clearance Factor Pass - Major Risk 6,744.26 377.79 6,744.26 191.65 5,900.00 2.030 Centre Distance Pass - Major Risk 4,975.11 384.25 4,975.11 265.84 4,125.00 3.245 Centre Distance Pass - Major Risk 5,086.13 388.66 5,086.13 260.98 4,250.00 3.044 Clearance Factor Pass - Major Risk 4,262.98 449.50 4,262.98 328.01 3,500.00 3.700 Centre Distance Pass - Major Risk 4,355.12 457.60 4,355.12 320.13 3,625.00 3.329 Clearance Factor Pass - Major Risk 6,239.87 283.92 6,239.87 168.66 5,725.00 2.463 Centre Distance Pass - Major Risk 7,116.02 340.34 7,116.02 107.87 6,625.00 1.464 Clearance Factor Pass - Major Risk 3,106.94 712.46 3,106.94 652.29 2,575.00 11.840 Clearance Factor Pass - Major Risk 3,111.36 331.37 3,111.36 276.19 2,875.00 6.005 Clearance Factor Pass - Major Risk 3,135.67 330.99 3,135.67 276.46 2,900.00 6.070 Centre Distance Pass - Major Risk 2,959.59 590.26 2,959.59 521.55 3,125.00 8.591 Clearance Factor Pass - Major Risk 11 January, 2017 - 12:47 Page 2 of COMPASS Anticollision Report for Rig: 2M-38 - 2M-38wp22 Survey tool program From (usft) 74.39 847.52 2,952.69 2,953.69 13,200.00 13,200.00 14,200.00 14,200.00 To (usft) 809.01 2,952.69 4,452.69 2M-38wp22 13,200.00 2M-38wp22 14,200.00 2M-38wp22 14,200.00 2M-38wp22 15,700.00 2M-38wp22 18,482.67 2M-38wp22 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC 11 January, 2017 - 12:47 Page 3 of 5 COMPASS Ladder View 13:63, January 11 2 2M-38wp22 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 300 - c O td C O_ O U N Equivalent Magnetic Distance 150 U o N i U i 0 3000 4500 6000 7500 9000 10500 12000 13500 Displayed interval could be less than entire welhMeasured Depth2952.69 To 18483.44 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 74.39 809.01 2M-38 Srvy 1 - SLB _GWD70 (Rig: 2M-38) GYD-GC-SS 113.20 113.20 20" x 42" 847.52 2952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (Rig: 2MvW+IFR-AK-CAZ-SC 2661.38 3053.00 13-3/8" x 16" 2952.69 4452.69 2M-38wp22 (Rig: 2M-38) MWD 5782.74 13200.00 9-5/8" x 12-1/4" 2953.69 13200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC 6071.88 14200.00 7" x 8-1/2" by 9-7/8" 13200.00 14200.00 2M-38wp22 (Rig: 2M-38) MWD 6102.00 18482.67 4-1/2" x 6-1/8" 13200.00 14200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC 14200.00 15700.00 2M-38wp22 (Rig: 2M-38) MWD o 60- 0 0 m I ro O_ 0 C/) T a0i 30- 0 0 O c O U I 0 3150 3600 4050 4500 4950 5400 5850 Partial Measured Depth TC View -6 -90/270 0/360 0 2953 2953 3150 3150 3340 3340 3530 3530 3720 3720 3910 3910 --- 4110 4110 4300 4300 4890 4890 5480 5480 6060 6060 --- 6650 6650 - 7240 7240 7820 7820 8410 0410 - 9000 X00 10190 190 11370 370 12560 560 13740 740 14930 330 16110 110 17300 300 -" 18483 iETH 2M-0 2M -s- 2 -� 2 -�- 2 z E3- 8- 2M 2M B- 2M 2 ° Po -x- 2M - 2M - x- 2M 2Mm.2M2,.2M24„ 90 M❑ Inc Azi NO 61.15 253.]1 2612.98 '1 +W-9 -]38.35 ,EFW Oleg -613.53 0.3 TFaw 000 VS Ta . /"- ]32.43 1. 153.00 61.15 253.]1 2661 38 ]3.00 61.15 253]1 26]1.03 -]62 99 -]6]91 -69].8] 0.3 0.3 0.00 0.00 819 ]b 83].1] 2M-38wp22 785646 73.29 266.69 29]4.56 11923.68 73.29 64.49 529603 -901.3 -1663.38 ']14.68 421 0] 2.3 -9112.]3 0.3 61.56 000 1556.73 925965 2952.69 To 18483.447135 1238]3 7000 266.]6 536600 -1653.05 17- -9686] 2.00 1411.14 2.1 1]5.50 11 110.00 9615.]8 2M -381.C35051716 JC 3 35.31 66.64 6476 5716.778.06 13045.95 66.55 264.70 5721.00 717 -1]38.44 10135.89 03 -10145.61 100 -16].25 10283.62 139335 2.382. Top -051716 JC 1335.23 6836 264.66 5]28.70 13427.60 66.36 26666 58]4.00 1346].66 65.36 264.66 5890.36 1740.3 -1711.3 -1]]440W.12 -10163.21 1.00 -10493.73 03 2.50 -167.84 0.00 179.70 10310.9] 10841.86 2M-383 F-1051716 JC 10678.27 1329, January 11 2017 349].93 65.36 26466 590300 -11]6.96 -1055152 0.3 0.00 10]0589 2M-64.9aze HFn pKup.uk 051]16 JC 13572.01 6].90 26656 5932.38 1360622 67.90 266.56 5945.25 1369384 ]1.00 64.20 591600 -1783.35 -1786.36 -1]94.39 -13622 3.50 -10656.]) 03 -10738.41 3.50 -2.15 0.00 6.25 107]3.48 108 517 1386.86 2M-385. K-1051716 JG SURVEY PIgGHRM 13750.68 ]2.8] 264.91 5993.63 13768.30 ]2.8] 264.91 5998.81 14126 21 85.00 262.00 6067.00 16306.36 91.23 62.98 1707293 -1799.52 -1801.02 -1640.99 -1866.46 -10792.21 3.50 -10808.98 0.3 11155.29 3.50 -11333.]1 3.50 19.85 000 -13.54 6.99 1340.]3 10957.51 11305.49 2M-38 fi. Top C 051]16 JC 11685.28 pN Fmm O pN T° 9urveYlPlen Tool ]4.39 809.01 2M385rvyt5LB GWWO(81p 86].52 5952.W 21M385rvyS-SLB_MN9aGl1�iY�i-SOFi}Z-SC 14338.28 91.23 6298 6072.20 1436925 9085 262.92 6072.00 -1868.80 -1869.94 -11317].31 0.3 -11370.26 3.50 0.00 -170.39 11519.15 11530.10 2M3B 7.Lang 051716 JC 293.69 M52fi9 SM-38wp2i(W9: I-) MWD 5953.69 1-0.00 2M- 38 wp22(a19:2A438) MWDrIF0.A -ec 15144].30 8].95 6843 63052 15148.51 87.95 28843 6080.5] -1791 ]d -1]91.36 -12165.]2 3.22 -12166.8] 0.3 3.52 0.3 12292.03 12293.3 13200.00 16910.3 2M38wp22 (iBg:SM37 MWO 132003 11200.3 2M38wpY1 (P4:2M3B) MND�IFA-OJ(-CAZSC 15521.06 BBSS 27646 632.00 276,46 -1711.284 37D 1 00 -12529.81 3.22 -8].31 377,:62 2M38wce1 To Pmt KEH fiJant] 12636II 2M-6wp21 To Prat KEH 6Jan1] 14200.00 1573.3 2M38wP22 (Hta:28F6) MWD 1653.00 18182.67 SM38wp22 (a4:2M38) MWD,IFRRK-CAZ-SC 16852.54 916705.26 289 2)]28 816.55 15 17360.81 92.89 2]].28 63555 -1560.54 -1498.78 -1385232 3.3 -16335.&1 0.3 10.]1 0.3 13912.85 143]830 1]423]5 9200 215.87 609200 17559.51 89.28 275.87 609048 18482.68 89.28 27587 610200 -1689.2] -14]5.38 -1380.96 -14418.36 200 -16553.38 2.3 15471.64 0.3 -122.31 180.00 000 16657.92 2M-6wp21 To-KEH Nan17 14580.48 1547%39 2M38wp21 To Pm4 KEH 6Jan 17 CASING DETAILS TVDMD Name Size 113.20 113.20 20" x 42" 20 2661.38 3053.00 13-3/8" x 16" 13-3/8 5782.74 13200.009-5/8" x 12-1/4" 9-5/8 6071.88 14200.01' x 8-1/2" by 9-7/8" 7 6102.00 18482.67 4-1/2"x6-1/8" 4-1/2 -6 -90/270 0/360 0 2953 2953 3150 3150 3340 3340 3530 3530 3720 3720 3910 3910 --- 4110 4110 4300 4300 4890 4890 5480 5480 6060 6060 --- 6650 6650 - 7240 7240 7820 7820 8410 0410 - 9000 X00 10190 190 11370 370 12560 560 13740 740 14930 330 16110 110 17300 300 -" 18483 iETH 2M-0 2M -s- 2 -� 2 -�- 2 z E3- 8- 2M 2M B- 2M 2 ° Po -x- 2M - 2M - x- 2M 2Mm.2M2,.2M24„ 90 AC Wells Only Easting (3000 usft/in) 2M-38wp22 2952.69 To 6000100 casing WD MD 113x1 113.x1 x661.38 305300 5)81.]4 13x.1.10 60]1.88 14x00.11 6+01.01 1848x.6] D -11i Name 11"14x" 13'3/8"xlb" g5/8"xtx-t &1/x"b 9-]/8" 4'+/x"x6-f/8" / DeplR From Deplfi To Survey/Plan 7439 81901 xM-385ry I -SLR GWD]o(Rig, 847.51 x95x.fi9 -385-2-SLB MWDaLMAG(Pig:aM38)MWDNF0.AKAZ-SC 195x.69 4451.69 IM 08 1P (Rig:aM�38) x953 fig +3210.00 xM-311Pxx(Rig:xM 38) 3x11.11 14x11.11 xM-38wpu(Rig: xM-38) 13111.01 14x00.11 1M-38wp1x(Rig, xM-38) 14x01.00 15]00.00 1M-38wPa1(Rig:1M-38) 360 Tool IM -38) GY -SS MWD MW-FRAK{ -SC MWD MWDrIFR-AKtAZ-SC MYVD WP FA AK EAO 56 o 2953 2 953 3150 MD Azi0 2952.69 253.71 3150 3340 3053.00 253.71 18 O 3073.00 253.71 -30 33 0 3340 3530 3856-44 264-49 , 3530 3720 11923.68 264.49 12088.73 264.76 3720 3910 12256.76 264.76 12 0 3910 4110 13035.31 264.76 4110 --- 4300 13045.95 264-70 -6o/300 60 13065.23 264.66 4300 4890 13427.60 264.66 4890 5480 13467.66 264.66 6 0 548o 6o6o 13497.93 264.66 13572.01 264-56 6o6o 6650 136o6.22 264.56 6650 5 7240 13693.84 264.20 1375o.68 264.91 - 0 270 go 7240 7820 13768.30 264.91 7820 8410 14124.21 262.00 8410 9000 14304.36 262.98 14338.28 262.98 6 0 9000 10190 14349.25 262.92 ,1 10190 11370 15147.30 288.43 15148.51 288.43 �, n370 1256o 15521.04 276.46 -120/2140 1 120 1256o 13740 16705.26 276.46 16852.54 277.28 12 O 13740 14930 1734o.61 277.28 14930 16110 17423.75 275.87 16110 17300 17559.51 275.87 18482.68 275.87 �� -15 0 210 150 17300 18483 18o -18o/18o 13:33, January 11 2017 A [� VVV 2M_38Wp22 6000.00 To vY ` (],( 8000.00 -mg D-11 ND MD 113.00 113.00 0fifi1.38 3a530o 5]80.]4 13000.00 60)1.88 18000.00 6101.00 18880.6) Name 10"x80" 13'318"x16" g5/8"x10-114" "x 4,101- 9-J/8" 4-110"x6-1/8" / .,11 1- Np[h To Survey/Plan 7439 809.01 0M -3S S,,,- SLE 841.50 0951.69 0M-385rvyx-SLR_MWD+GMAG(Rig 1951.69 445a.fi9 0M-38wp00(Rig: IM 38) 095369 1-3000.10 3M-38wp03 (Rig:3M 38) 00.00 14000.00 0M 38wP30 19: M-38) 13100.00 14000.00 0M 3Rlll.(Rig:-38) 18000.00 15)00.00 2.38wp0a(Rig.aM-38) 360 Tool -38) GV6GC-SS z.M-38)MWD+IFR-A-SC MWD MWD+IF-K-SC MWD MWD+IFR-A-{ SC MWD 0 2953 2953 3150 MD Azi0 2952.69 253.71 3150 3340 3053.00 253.711 8 O 3073.00 253.71 -30/33 0 3340 3530 3856.44 z64.49 3530 3720 11923.68 264.49 -- 12088.73 264.76 3720 3910 12256.76 264.76 12 O 3910 4110 13035-31 264-76 4110 4300 13045.95 264.70 -60 300 6o 13o65.23 264.66 4300 4890 13427.60 264.66 4890 548o 13467.66 264.66 6o 5480 hobo 13497.93 264.66 13572.01 264-56 6o60 6650 136o6.22 264.56 6650 7240 13693.84 264.20 1375o.68 264.91 -C 0 / 270 , go 7240 7820 13768.30 264.91 7820 -8410 14124.21 262.00 8410 9000 14304.36 262.98 14338.28 262.98 r,,, 6 0 9000 10190 14349.25 262.921 10190 9 11 0 37 15147.30 288.43 15148.51 288.43 11370 1256o 15521-04 276.46 -120/240 120 1256o 13740 16705.26 276.46 16852.54 277.28 120 13740 14930 1734o.61 277.282 14930 16110 17423.75 275.87 N, i E; . _ - _ 16110 - 17300 17559.51 275.875 t 18482.68 275.87 -15 0' 210 � �, ',`' 150 17300 18483 0 -18o/18o 13:34, January 11 2017 2M-38wp22 8000.00 To (�,( ���^3.44 -mg Derail: ND - 113.10 113.10 x661-38 305300 5781.74 13100.00 61].88 14110.11 6101.00 18481.6] Name 0"x41" 13318"x16" 8518"x f1-114" &i/1"bY97/8" 4-111"x6-1/8" /36o D0"From Depth Tl survey/Plan 7439 809.11 1M 38 Sr -SLBGW071(Rig:1M-38) 84751 1951.69 1M -38", -SLB MWDaGWC(Mg:,M38)MWDAFR-AK{ 1951.69 4451.69 1M-38wp11(Rig:-38) 1953 69 +3311.11 2M-38wpv(Rig: 11-3B) 00.10 yio0.o0 1M-38wP13 (Rig:1M-38) 13101.00 14100.11 xM-38wP1i (RIg.1M-38) ig100.00 15710.01 1M-38wp1i (Rig: i.M-3B) 3 60 Tool G-6 -SS -SC MWD MW -FR -AK{ -SC MWO MWOtIFR-AK.CAZ SC MWD o - 2953 2953 3150 MD Azi0 2952.69 253.71 3150 3340 3053.00 253.71-----18o 3073.00 253.71 -30/33 0 3340 3530 3856.44 z64.49 3530 3720 11923.68 264.49 _ _ 3720 3910 12088.73 264.76 12256.76 264.76 1 2 0 3910 4110 13035-31 264-76 4110 4300 13045.95 264.70 -60 300 % 6 O 13065.23 264.66 4300 4890 13427.61 264.66 4890 5480 13467.66 264.66 6 O 5480 6060 1349793 264.66 13572.01 264.56 6o6o 6650 136o6.22 264.56 6650 7240 13693.84 264.20 1375o.68 264.91 - O / 270 90 7240 78zo 13768.30 264.91 7820 8410 14124.21 262.00 8410 9000 14304.36 262.98 14338.28 262.98 6 O 9000 10190 14349.25 z62.92 10190 9 11 0 37 15147.30 288.43 15148.51 288.43 11370 12561 15521-04 276.46 -120 / 240 1 120 1256o 13740 16705.26 276.46 16852.54 277.28 12 0 13740 14930 1734o.61 277.28 14930 16110 17423.75 275.87 16110 . _ 17300 17559.51 275.87 18482.68 275.87 -150/210 155 0 17300 18483 180 -18o/18o 13:34, January 11 2017 Errors Report ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Rig: 2M-38 Rig: 2M-38 Plan: 2M-38wp22 Report 11 January, 2017 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Report Local Co-ordinate Reference: Well Rig: 2M-38 TVD Reference: 2M-38: 101.3+30.7 @ 132.O0usft (Doyonl41) MD Reference: 2M-38: 101.3+30.7 @ 132.O0usft (Doyonl41) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKE D M P2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: -0.10 ° Well Rig: 2M-38 Well Position +N/ -S 0.00 usft Northing: Latitude: +E/ -W 0.01 usft Easting: Longitude: Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 101.30 usft Wellbore Rig: 2M-38 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (% (nT) BG G M 2016 1/20/2017 17.67 80.88 57,533 Design 2M-38wp22 Audit Notes: Version: Phase: PLAN Tie On Depth: 2,952.69 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (I 30.70 0.00 0.01 260.00 Survey Tool Program Date 1/11/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 74.39 809.01 2M-38 Srvy 1 - SLB_GWD70 (Rig: 2M-38) GYD-GC-SS Gyrodata gyro single shots 847.52 2,952.69 2M-38 Srvy 2 - SLB_MWD+GMAG (Rig: 2 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,952.69 4,452.69 2M-38wp22 (Rig: 2M-38) MWD MWD - Standard 2,953.69 13,200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,200.00 14,200.00 2M-38wp22 (Rig: 2M-38) MWD MWD - Standard 13,200.00 14,200.00 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 14,200.00 15,700.00 2M-38wp22 (Rig: 2M-38) MWD MWD - Standard 14,200.00 18,482.67 2M-38wp22 (Rig: 2M-38) MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (I (°) (usft) (usft) (°/100usft) (°) (usft) 2,952.69 61.15 253.71 2,612.98 2,480.98 0.00 0.00 5.16 Adjust TF to 0°, for 100.31' 3,000.00 61.15 253.71 2,635.81 2,503.81 0.00 0.00 5.42 3,053.00 61.15 253.71 2,661.38 2,529.38 0.00 0.00 5.78 Adjust TF to 0°, for 20' -13-3/8" x 16" 1/11/2017 12:47:33PM Page 2 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: Rig: 2M-38 North Reference: Wellbore: Rig: 2M-38 Survey Calculation Method: Design: 2M-38wp22 Database: Well Rig: 2M-38 2M-38:101.3+30.7 @ 132.00usft (Doyonl41) 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace I Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,073.00 61.15 253.71 2,671.03 2,539.03 0.00 0.00 5.94 Start 2°/100' DLS, 41.54° TF, for 783.44' 3,100.00 61.55 254.12 2,683.98 2,551.98 2.00 41.54 6.15 3,200.00 63.06 255.60 2,730.45 2,598.45 2.00 41.34 7.08 3,300.00 64.59 257.04 2,774.55 2,642.55 2.00 40.65 8.19 3,400.00 66.13 258.45 2,816.25 2,684.25 2.00 40.02 9.42 3,500.00 67.68 259.82 2,855.48 2,723.48 2.00 39.43 10.74 3,600.00 69.24 261.16 2,892.20 2,760.20 2.00 38.89 12.12 3,671.85 70.37 262.11 2,917.00 2,785.00 2.00 38.40 13.54 Camp SS 3,700.00 70.81 262.48 2,926.35 2,794.35 2.00 38.07 13.54 3,800.00 72.39 263.77 2,957.91 2,825.91 2.00 37.95 15.00 3,856.44 73.29 264.49 2,974.56 2,842.56 2.00 37.54 15.84 Hold for 8067.23' 3,900.00 73.29 264.49 2,987.09 2,855.09 0.00 37.33 16.52 4,000.00 73.29 264.49 3,015.84 2,883.84 0.00 0.00 18.06 4,100.00 73.29 264.49 3,044.59 2,912.59 0.00 0.00 19.62 4,200.00 73.29 264.49 3,073.34 2,941.34 0.00 0.00 21.19 4,300.00 73.29 264.49 3,102.09 2,970.09 0.00 0.00 22.76 4,400.00 73.29 264.49 3,130.85 2,998.85 0.00 0.00 24.34 4,500.00 73.29 264.49 3,159.60 3,027.60 0.00 0.00 11.18 4,600.00 73.29 264.49 3,188.35 3,056.35 0.00 0.00 11.71 4,700.00 73.29 264.49 3,217.10 3,085.10 0.00 0.00 12.24 4,800.00 73.29 264.49 3,245.85 3,113.85 0.00 0.00 12.79 4,900.00 73.29 264.49 3,274.60 3,142.60 0.00 0.00 13.33 5,000.00 73.29 264.49 3,303.36 3,171.36 0.00 0.00 13.88 5,100.00 73.29 264.49 3,332.11 3,200.11 0.00 0.00 14.43 5,200.00 73.29 264.49 3,360.86 3,228.86 0.00 0.00 14.99 5,300.00 73.29 264.49 3,389.61 3,257.61 0.00 0.00 15.55 5,400.00 73.29 264.49 3,418.36 3,286.36 0.00 0.00 16.11 5,500.00 73.29 264.49 3,447.11 3,315.11 0.00 0.00 16.67 5,600.00 73.29 264.49 3,475.87 3,343.87 0.00 0.00 17.23 5,700.00 73.29 264.49 3,504.62 3,372.62 0.00 0.00 17.80 5,800.00 73.29 264.49 3,533.37 3,401.37 0.00 0.00 18.37 5,900.00 73.29 264.49 3,562.12 3,430.12 0.00 0.00 18.94 6,000.00 73.29 264.49 3,590.87 3,458.87 0.00 0.00 19.51 6,100.00 73.29 264.49 3,619.62 3,487.62 0.00 0.00 20.08 6,200.00 73.29 264.49 3,648.38 3,516.38 0.00 0.00 20.65 6,300.00 73.29 264.49 3,677.13 3,545.13 0.00 0.00 21.22 6,400.00 73.29 264.49 3,705.88 3,573.88 0.00 0.00 21.80 6,500.00 73.29 264.49 3,734.63 3,602.63 0.00 0.00 22.37 6,600.00 73.29 264.49 3,763.38 3,631.38 0.00 0.00 22.95 6,700.00 73.29 264.49 3,792.14 3,660.14 0.00 0.00 23.52 6,800.00 73.29 264.49 3,820.89 3,688.89 0.00 0.00 24.10 6,900.00 73.29 264.49 3,849.64 3,717.64 0.00 0.00 24.68 1/11/2017 12.47.33PM Page 3 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Rig: 2M-38 Project: Kuparuk River Unit TVD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Site: Kuparuk 2M Pad MD Reference: 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) Well: Rig: 2M-38 North Reference: True Wellbore: Rig: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp22 Database: OAKEDMP2 -- - Planned Survey - - MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 7,000.00 73.29 264.49 3,878.39 3,746.39 0.00 0.00 25.25 7,100.00 73.29 264.49 3,907.14 3,775.14 0.00 0.00 25.83 7,200.00 73.29 264.49 3,935.89 3,803.89 0.00 0.00 26.41 7,300.00 73.29 264.49 3,964.65 3,832.65 0.00 0.00 26.99 7,400.00 73.29 264.49 3,993.40 3,861.40 0.00 0.00 27.57 7,500.00 73.29 264.49 4,022.15 3,890.15 0.00 0.00 28.15 7,600.00 73.29 264.49 4,050.90 3,918.90 0.00 0.00 28.73 7,700.00 73.29 264.49 4,079.65 3,947.65 0.00 0.00 29.31 7,800.00 73.29 264.49 4,108.40 3,976.40 0.00 0.00 29.89 7,900.00 73.29 264.49 4,137.16 4,005.16 0.00 0.00 30.47 8,000.00 73.29 264.49 4,165.91 4,033.91 0.00 0.00 31.06 8,038.58 73.29 264.49 4,177.00 4,045.00 0.00 0.00 31.64 C-50 8,100.00 73.29 264.49 4,194.66 4,062.66 0.00 0.00 31.64 8,200.00 73.29 264.49 4,223.41 4,091.41 0.00 0.00 32.22 8,300.00 73.29 264.49 4,252.16 4,120.16 0.00 0.00 32.80 8,400.00 73.29 264.49 4,280.91 4,148.91 0.00 0.00 33.39 8,500.00 73.29 264.49 4,309.67 4,177.67 0.00 0.00 33.97 8,600.00 73.29 264.49 4,338.42 4,206.42 0.00 0.00 34.55 8,700.00 73.29 264.49 4,367.17 4,235.17 0.00 0.00 35.14 8,800.00 73.29 264.49 4,395.92 4,263.92 0.00 0.00 35.72 8,900.00 73.29 264.49 4,424.67 4,292.67 0.00 0.00 36.30 9,000.00 73.29 264.49 4,453.42 4,321.42 0.00 0.00 36.89 9,100.00 73.29 264.49 4,482.18 4,350.18 0.00 0.00 37.47 9,200.00 73.29 264.49 4,510.93 4,378.93 0.00 0.00 38.06 9,300.00 73.29 264.49 4,539.68 4,407.68 0.00 0.00 38.64 9,400.00 73.29 264.49 4,568.43 4,436.43 0.00 0.00 39.22 9,500.00 73.29 264.49 4,597.18 4,465.18 0.00 0.00 39.81 9,600.00 73.29 264.49 4,625.94 4,493.94 0.00 0.00 40.39 9,700.00 73.29 264.49 4,654.69 4,522.69 0.00 0.00 40.98 9,800.00 73.29 264.49 4,683.44 4,551.44 0.00 0.00 41.56 9,829.78 73.29 264.49 4,692.00 4,560.00 0.00 0.00 42.15 C-37 / Top Iceberg 9,900.00 73.29 264.49 4,712.19 4,580.19 0.00 0.00 42.15 10,000.00 73.29 264.49 4,740.94 4,608.94 0.00 0.00 42.74 10,100.00 73.29 264.49 4,769.69 4,637.69 0.00 0.00 43.32 10,200.00 73.29 264.49 4,798.45 4,666.45 0.00 0.00 43.91 10,300.00 73.29 264.49 4,827.20 4,695.20 0.00 0.00 44.49 10,400.00 73.29 264.49 4,855.95 4,723.95 0.00 0.00 45.08 10,500.00 73.29 264.49 4,884.70 4,752.70 0.00 0.00 45.66 10,600.00 73.29 264.49 4,913.45 4,781.45 0.00 0.00 46.25 10,700.00 73.29 264.49 4,942.20 4,810.20 0.00 0.00 46.84 10,800.00 73.29 264.49 4,970.96 4,838.96 0.00 0.00 47.42 10,900.00 73.29 264.49 4,999.71 4,867.71 0.00 0.00 48.01 11,000.00 73.29 264.49 5,028.46 4,896.46 0.00 0.00 48.60 1/11/2017 12:47.33PM Page 4 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: Rig: 2M-38 North Reference: Wellbore: Rig: 2M-38 Survey Calculation Method: Design: 2M-38wp22 Database: Well Rig: 2M-38 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) 2M-38: 101.3+30.7 @ 132.00usft (Doyonl41) True Minimum Curvature OAKEDMP2 1/11/2017 12:47.,33PM Page 5 COMPASS 5000.1 Build 74 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 11,100.00 73.29 264.49 5,057.21 4,925.21 0.00 0.00 49.18 11,200.00 73.29 264.49 5,085.96 4,953.96 0.00 0.00 49.77 11,221.00 73.29 264.49 5,092.00 4,960,00 0.00 0.00 50.35 Base Iceberg / Growler 11,300.00 73.29 264.49 5,114.71 4,982.71 0.00 0.00 50.35 11,400.00 73.29 264.49 5,143.47 5,011.47 0.00 0.00 50.94 11,500.00 73.29 264.49 5,172.22 5,040.22 0.00 0.00 51.53 11,600.00 73.29 264.49 5,200.97 5,068.97 0.00 0.00 52.11 11,700.00 73.29 264.49 5,229.72 5,097.72 0.00 0.00 52.70 11,800.00 73.29 264.49 5,258.47 5,126.47 0.00 0.00 53.29 11,900.00 73.29 264.49 5,287.22 5,155.22 0.00 0.00 53.88 11,923.67 73.29 264.49 5,294.03 5,162.03 0.00 0.00 54.01 Start 20/100' DLS, 175.50 TF, for 165.05' 11,923.68 73.29 264.49 5,294.03 5,162.03 0.00 0.00 54.01 12,000.00 71.77 264.61 5,316.94 5,184.94 2.00 175.50 54.40 12,088.72 70.00 264.76 5,346.00 5,214.00 2.00 175.46 54.77 Adjust TF to 179.99°, for 168.03' 12,088.73 70.00 264.76 5,346.00 5,214.00 2.00 175.41 54.77 12,100.00 69.77 264.76 5,349.88 5,217.88 2.00 179.99 54.82 12,200.00 67.77 264.76 5,386.08 5,254.08 2.00 179.99 55.25 12,215.56 67.46 264.76 5,392.00 5,260.00 2.00 179.99 55.50 C-35 12,256.75 66.64 264.76 5,408.06 5,276.06 2.00 179.99 55.50 Hold for 778.55' 12,256.76 66.64 264.76 5,408.06 5,276.06 2.00 179.99 55.50 12,300.00 66.64 264.76 5,425.21 5,293.21 0.00 0.00 55.71 12,400.00 66.64 264.76 5,464.86 5,332.86 0.00 0.00 56.30 12,500.00 66.64 264.76 5,504.51 5,372.51 0.00 0.00 56.88 12,600.00 66.64 264.76 5,544.17 5,412.17 0.00 0.00 57.47 12,700.00 66.64 264.76 5,583.82 5,451.82 0.00 0.00 58.05 12,800.00 66.64 264.76 5,623.47 5,491.47 0.00 0.00 58.63 12,900.00 66.64 264.76 5,663.12 5,531.12 0.00 0.00 59.22 13,000.00 66.64 264.76 5,702.77 5,570.77 0.00 0.00 59.80 13,035.30 66.64 264.76 5,716.77 5,584.77 0.00 0.00 60.01 Start 1°/100' DLS, -147.25° TF, for 10.64' 13,035.31 66.64 264.76 5,716.77 5,584.77 0.00 0.00 60.01 13,045.94 66.55 264.70 5,721.00 5,589.00 1.00 -147.25 60.07 Adjust TF to -167.840, for 19.28' 13,045.95 66.55 264.70 5,721.00 5,589.00 1.00 -147.22 60.07 13,065.22 66.36 264.66 5,728.70 5,596.70 1.00 -167.84 60.16 Hold for 362.37' 13,065.23 66.36 264.66 5,728.70 5,596.70 1.00 -167.82 60.16 13,100.00 66.36 264.66 5,742.64 5,610.64 0.00 0.00 60.33 13,200.00 66.36 264.66 5,782.74 5,650.74 0.00 0.00 60.93 9-5/8" x 12-1/4" 1/11/2017 12:47.,33PM Page 5 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: Rig: 2M-38 North Reference: Wellbore: Rig: 2M-38 Survey Calculation Method: Design: 2M-38wp22 Database: Well Rig: 2M-38 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 13,223.10 66.36 264.66 5,792.00 5,660.00 0.00 0.00 61.57 Top HRZ 13,300.00 66.36 264.66 5,822.84 5,690.84 0.00 0.00 61.57 13,400.00 66.36 264.66 5,862.93 5,730.93 0.00 0.00 62.23 13,427.59 66.36 264.66 5,874.00 5,742.00 0.00 0.00 62.43 Start 2.5°/100' DLS, 179.7° TF, for 40.05' 13,427.60 66.36 264.66 5,874.00 5,742.00 0.00 0.00 62.43 13,467.65 65.36 264.66 5,890.38 5,758.38 2.50 179.70 62.70 Hold for 30.27' 13,467.66 65.36 264.66 5,890.38 5,758.38 2.50 179.70 62.70 13,493.13 65.36 264.66 5,901.00 5,769.00 0.00 0.00 62.91 Fault 1 -40-45' DTE 13,495.53 65.36 264.66 5,902.00 5,770.00 0.00 0.00 62.91 Base HRZrrop Kalubik 13,497.92 65.36 264.66 5,903.00 5,771.00 0.00 0.00 62.91 Start 3.6°/100' DLS, -2.16° TF, for 74.08' 13,497.93 65.36 264.66 5,903.00 5,771.00 0.00 0.00 62.91 13,500.00 65.43 264.66 5,903.86 5,771.86 3.50 -2.15 62.93 13,572.00 67.90 264.56 5,932.38 5,800.38 3.43 -2.14 63.45 Hold for 34.2' 13,572.01 67.90 264.56 5,932.38 5,800.38 3.43 -2.10 63.45 13,600.00 67.90 264.56 5,942.91 5,810.91 0.00 0.00 63.66 13,606.21 67.90 264.56 5,945.25 5,813.25 0.00 0.00 63.71 Start 3.5°/100' DLS, -6.26° TF, for 87.62' 13,606.22 67.90 264.56 5,945.25 5,813.25 0.00 0.00 63.71 13,693.83 71.00 264.20 5,976.00 5,844.00 3.56 -6.25 64.41 Adjust TF to 19.86°, for 56.84' 13,693.84 71.00 264.20 5,976.00 5,844.00 3.56 -6.13 64.41 13,700.00 71.20 264.28 5,978.00 5,846.00 3.50 19.85 64.45 13,745.19 72.69 264.84 5,992.00 5,860.00 3.50 19.82 64.84 K1 13,750.67 72.87 264.91 5,993.62 5,861.62 3.50 19.65 64.84 Hold for 17.62' 13,750.68 72.87 264.91 5,993.63 5,861.63 3.50 19.63 64.84 13,768.29 72.87 264.91 5,998.81 5,866.81 0.00 0.00 64.98 Start 3.6°/100' DLS, -13.54° TF, for 356.91' 13,768.30 72.87 264.91 5,998.81 5,866.81 0.00 0.00 64.98 13,779.23 73.24 264.81 6,002.00 5,870.00 3.50 -13.54 65.26 Fault 2 - 25' DTW 13,800.00 73.95 264.64 6,007.86 5,875.86 3.50 -13.52 65.26 13,900.00 77.36 263.80 6,032.64 5,900.64 3.50 -13.47 66.14 14,000.00 80.76 262.99 6,051.61 5,919.61 3.50 -13.26 67.05 14,035.93 81.99 262.70 6,057.00 5,925.00 3.50 -13.11 67.98 Top Kuparuk C 14,100.00 84.17 262.19 6,064.72 5,932.72 3.50 -13.06 67.98 1/11/2017 12:47.33PM Page 6 COMPASS 5000.1 Build 74 Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: Rig: 2M-38 North Reference: Wellbore: Rig: 2M-38 Survey Calculation Method: Design: 2M-38wp22 Database: Well Rig: 2M-38 2M-38:101.3+30.7 @ 132.00usft (Doyon141) 2M-38:101.3+30.7 @ 132.00usft (Doyon14l) True Minimum Curvature OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 14,124.20 85.00 262.00 6,067.00 5,935.00 3.50 -13.00 68.21 Adjust TF to 8.99°, for 180.15' 14,124.21 85.00 262.00 6,067.00 5,935.00 3.50 -12.98 68.21 14,200.00 87.62 262.41 6,071.88 5,939.88 3.50 8.99 63.03 7" x 8-1/2" by 9-7/8" 14,300.00 91.08 262.96 6,073.01 5,941.01 3.50 8.97 63.75 14,304.35 91.23 262.98 6,072.93 5,940.93 3.50 8.96 63.78 Hold for 33.92' 14,304.36 91.23 262.98 6,072.93 5,940.93 3.50 8.96 63.78 14,338.28 91.23 262.98 6,072.20 5,940.20 0.00 0.00 64.04 Start 3.6°/100' DLS, -170.39° TF, for 10.96' 14,338.28 91.23 262.98 6,072.20 5,940.20 0.01 0.00 64.04 14,349.24 90.85 262.92 6,072.00 5,940.00 3.50 -170.39 64.12 Start 3.22°/100' DLS, 96.62° TF, for 798.06' 14,349.25 90.85 262.92 6,072.00 5,940.00 3.50 -170.39 64.12 14,400.00 90.66 264.54 6,071.33 5,939.33 3.22 96.52 64.46 14,500.00 90.30 267.74 6,070.49 5,938.49 3.22 96.54 65.01 14,600.00 89.93 270.93 6,070.29 5,938.29 3.22 96.57 65.39 14,700.00 89.56 274.13 6,070.74 5,938.74 3.22 96.58 65.60 14,800.00 89.19 277.32 6,071.83 5,939.83 3.22 96.56 65.65 14,900.00 88.83 280.52 6,073.55 5,941.55 3.22 96.53 65.52 15,000.00 88.47 283.72 6,075.91 5,943.91 3.22 96.47 65.23 15,038.94 88.33 284.96 6,077.00 5,945.00 3.22 96.40 64.77 Deepest possible Kuparuk C 15,100.00 88.11 286.92 6,078.90 5,946.90 3.22 96.36 64.77 15,147.30 87.95 288.43 6,080.52 5,948.52 3.22 96.30 64.49 Hold for 1.2' 15,147.30 87.95 288.43 6,080.52 5,948.52 3.22 96.25 64.49 15,148.50 87.95 288.43 6,080.56 5,948.56 0.00 0.00 64.50 Start 3.22°/100' DLS, -87.31° TF, for 372.53' 15,148.51 87.95 288.43 6,080.57 5,948.57 0.00 0.00 64.50 15,200.00 88.02 286.77 6,082.38 5,950.38 3.22 -87.31 65.85 15,300.00 88.18 283.56 6,085.69 5,953.69 3.22 -87.26 68.33 15,400.00 88.34 280.35 6,088.72 5,956.72 3.22 -87.15 70.62 15,500.00 88.51 277.13 6,091.46 5,959.46 3.22 -87.05 72.70 15,521.03 88.55 276.46 6,092.00 5,960.00 3.22 -86.96 73.12 Hold for 1184.22' 15,521.04 88.55 276.46 6,092.00 5,960.00 3.22 -86.95 73.12 15,600.00 88.55 276.46 6,094.00 5,962.00 0.00 0.00 73.99 15,700.00 88.55 276.46 6,096.53 5,964.53 0.00 0.00 64.47 15,800.00 88.55 276.46 6,099.07 5,967.07 0.00 0.00 64.74 15,900.00 88.55 276.46 6,101.60 5,969.60 0.00 0.00 65.01 16,000.00 88.55 276.46 6,104.13 5,972.13 0.00 0.00 65.29 16,100.00 88.55 276.46 6,106.67 5,974.67 0.00 0.00 65.57 16,200.00 88.55 276.46 6,109.20 5,977.20 0.00 0.00 65.86 1/11/2017 12:47:33PM Page 7 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Planned Survey TVDSS DLeg MD Inc Azi (azimuth) (usft) (°/100usft) (°) 16,300.00 88.55 276.46 16,400.00 88.55 276.46 16,500.00 88.55 276.46 16,600.00 88.55 276.46 16,700.00 88.55 276.46 16,705.25 8855 276.46 Start 3°/100' DLS, 10.71° TF, for 147.28' 6,122.00 16,705.26 88.55 276.46 16,800.00 91.34 276.99 16,852.53 92.89 277.28 Hold for 488.07' 10.71 6,120.15 16,852.54 92.89 277.28 16,900.00 92.89 277.28 17,000.00 92.89 277.28 17,100.00 92.89 277.28 17,200.00 92.89 277.28 17,300.00 92.89 277.28 17,340.60 92.89 277.28 Start 2°/100' DLS, -122.31° TF, for 83.15' 0.00 17,340.61 92.89 277.28 17,400.00 92.25 276.27 17,423.74 92.00 275.87 Adjust TF to 180°, for 135.76' 73.47 17,423.75 92.00 275.87 17,500.00 90.48 275.87 17,559.50 89.29 275.87 Hold for 923.17' 17,559.51 89.28 275.87 17,600.00 89.28 275.87 17,700.00 89.28 275.87 17,800.00 89.28 275.87 17,900.00 89.28 275.87 18,000.00 89.28 275.87 18,100.00 89.28 275.87 18,200.00 89.28 275.87 18,300.00 89.28 275.87 18,400.00 89.28 275.87 18,482.67 89.28 275.87 TD: 18482.67' MD, 6102' TVD - 4-1/2" x 6-1/8" 18,482.68 89.28 275.87 Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: I Well Rig: 2M-38 2M-38:101.3+30.7 @ 132.00usft (Doyon141) 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) True Minimum Curvature OAKEDMP2 TVD TVDSS DLeg TFace (usft) (usft) (°/100usft) (°) 6,111.73 5,979.73 0.00 0.00 6,114.27 5,982.27 0.00 0.00 6,116.80 5,984.80 0.00 0.00 6,119.33 5,987.33 0.00 0.00 6,121.87 5,989.87 0.00 0.00 6,122.00 5,990.00 0.00 0.00 6,122.00 5,990.00 0.00 0.00 6,122.09 5,990.09 3.00 10.71 6,120.15 5,988.15 3.00 10.71 Lat. Error (usft) 66.15 66.44 66.74 67.04 67.35 67.36 67.36 67.52 67.60 6,120.15 5,988.15 3.00 10.72 67.60 6,117.76 5,985.76 0.00 0.00 67.75 6,112.72 5,980.72 0.00 0.00 68.06 6,107.68 5,975.68 0.00 0.00 68.38 6,102.64 5,970.64 0.00 0.00 68.70 6,097.59 5,965.59 0.00 0.00 69.03 6,095.55 5,963.55 0.00 0.00 69.16 6,095.55 5,963.55 0.00 0.00 69.16 6,092.88 5,960.88 2.00 -122.31 69.62 6,092.00 5,960.00 2.00 -122.36 69.80 6,092.00 5,960.00 2.00 -122.37 69.80 6,090.35 5,958.35 2.00 180.00 70.05 6,090.48 5,958.48 2.00 180.00 70.25 6,090.48 5,958.48 2.00 -180.00 70.25 6,090.98 5,958.98 0.00 0.00 70.39 6,092.23 5,960.23 0.00 0.00 70.72 6,093.48 5,961.48 0.00 0.00 71.06 6,094.73 5,962.73 0.00 0.00 71.41 6,095.98 5,963.98 0.00 0.00 71.76 6,097.22 5,965.22 0.00 0.00 72.11 6,098.47 5,966.47 0.00 0.00 72.46 6,099.72 5,967.72 0.00 0.00 72.82 6,100.97 5,968.97 0.00 0.00 73.18 6,102.00 5,970.00 0.00 0.00 73.47 6,102.00 5,970.00 0.00 0.00 73.47 1/11/2017 12:47.33PM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig 2M-38 Design: 2M-38wp22 Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 2M-38 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) True Minimum Curvature OAKEDMP2 Casing Points Vertical Depth Depth Measured Vertical (usft) Casing Hole Depth Depth 11,221.00 Diameter Diameter (usft) (usft) Name 9,829.78 4,692.00 113.20 113.20 20" x 42" 20 42 13,200.00 5,782.74 9-5/8" x 12-1/4" 9-5/8 12-1/4 14,200.00 6,071.88 7" x 8-1/2" by 9-7/8" 7 9-7/8 18,482.67 6,102.00 4-1/2"x6-1/8" 4-1/2 6-1/8 3,053.00 2,661.38 13-3/8" x 16" 13-3/8 16 Formations Measured Vertical Depth Depth (usft) (usft) Name 13,223.10 5,792.00 Top HRZ 11,221.00 5,092.00 Base Iceberg / Growler 13,745.19 5,992.00 K1 9,829.78 4,692.00 C-37 / Top Iceberg 13,493.13 5,901.00 Fault 1 -40-45' DTE 13,495.53 5,902.00 Base HRZ/Top Kalubik 15,038.94 6,077.00 Deepest possible Kuparuk C 14,035.93 6,057.00 Top Kuparuk C 8,038.58 4,177.00 C-50 13,779.23 6,002.00 Fault 2 - 25' DTW 3,671.85 2,917.00 Camp SS 12,215.56 5,392.00 C-35 Lithology Dip Dip Direction V) V) 0.00 1/11/2017 12:47:33PM Page 9 COMPASS 5000.1 Build 74 Company: ConocwPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 2M-38 2M-38:101.3+30.7 @ 132.00usft (Doyonl41) 2M-38:101.3+30.7 @ 132.00usft (Doyonl41) True Minimum Curvature OAKEDMP2 Casing Points Vertical Depth Depth Depth Measured Vertical (usft) Casing Hole Depth Depth 11,221.00 Diameter Diameter (usft) (usft) Name 9,829.78 4,692.00 113.20 113.20 20" x 42" 20 42 13,200.00 5,782.74 9-5/8" x 12-1/4" 9-5/8 12-1/4 14,200.00 6,071.88 7" x 8-1/2" by 9-7/8" 7 9-7/8 18,482.67 6,102.00 4-1/2"x6-1/8" 4-1/2 6-1/8 3,053.00 2,661.38 13-3/8" x 16" 13-3/8 16 Formations Measured Vertical Depth Depth Depth (usft) (usft) (usft) Name Lithology 13,223.10 5,792.00 Top HRZ 11,221.00 5,092.00 Base Iceberg / Growler 13,745.19 5,992.00 K1 9,829.78 4,692.00 C-37/ Top Iceberg 13,493.13 5,901.00 Fault 1 -40-45' DTE 13,495.53 5,902.00 Base HRZ/Top Kalubik 15,038.94 6,077.00 Deepest possible Kuparuk C 14,035.93 6,057.00 Top Kuparuk C 8,038.58 4,177.00 C-50 13,779.23 6,002.00 Fault 2 - 25' DTW 3,671.85 2,917.00 Camp SS 12,215.56 5,392.00 C-35 Plan Annotations Measured Depth (usft) 2,952.69 3,053.00 3,073.00 3,856.44 11, 923.67 12,088.72 12,256.75 13, 035.30 13,045.94 13,065.22 13,427.59 13,467.65 13,497.92 13,572.00 13,606.21 13,693.83 13,750.67 13,768.29 14,124.20 14,304.35 14,338.28 14,349.24 15,147.30 15,148.50 15.521.03 Vertical Local Coordinates Depth +N/ -S +El -W (usft) (usft) (usft) 2,612.98 -738.35 -613.53 2,661.38 -762.99 -697.87 2,671.03 -767.91 -714.68 2,974.56 -901.02 -1,421.86 5,294.03 -1,643.38 -9,112.72 5,346.00 -1,658.05 -9,268.66 5,408.06 -1,672.30 -9,424.13 5,716.77 -1,737.55 -10,135.88 5,721.00 -1,738.44 -10,145.60 5,728.70 -1,740.08 -10,163.20 5,874.00 -1,771.00 -10,493.72 5,890.38 -1,774.40 -10,530.11 5,903.00 -1,776.96 -10,557.51 5,932.38 -1,783.35 -10,625.21 5,945.25 -1,786.36 -10,656.76 5,976.00 -1,794.39 -10,738.40 5,993.63 -1,799.52 -10,792.20 5,998.81 -1,801.02 -10,808.97 6,067.00 -1,840.94 -11,155.28 6,072.93 -1,864.46 -11,333.70 6,072.20 -1,868.60 -11,367.36 6,072.00 -1,869.94 -11,378.23 6,080.52 -1,791.74 -12,165.72 6,080.57 -1,791.36 -12,166.86 6,092.00 -1,711.28 -12,529.80 Comment Adjust TF to 0°, for 100.31' Adjust TF to 0°, for 20' Start 2°/100' DLS, 41.54° TF, for 783.44' Hold for 8067.23' Start 2°/100' DLS, 175.5° TF, for 165.05' Adjust TF to 179.99°, for 168.03' Hold for 778.55' Start 1 °/100' DLS, -147.25° TF, for 10.64' Adjust TF to -167.84°, for 19.28' Hold for 362.37' Start 2.5°/100' DLS, 179.7° TF, for 40.05' Hold for 30.27' Start 3.5°/100' DLS, -2.15° TF, for 74.08' Hold for 34.2' Start 3.5°/100' DLS, -6.25° TF, for 87.62' Adjust TF to 19.85°, for 56.84' Hold for 17.62' Start 3.5°/100' DLS, -13.54° TF, for 355.91' Adjust TF to 8.99°, for 180.15' Hold for 33.92' Start 3.5°/100' DLS, -170.39° TF, for 10.96' Start 3.22°/100' DLS, 96.52° TF, for 798.06' Hold for 1.2' Start 3.22°/100' DLS, -87.31 ° TF, for 372.53' Hold for 1184.22' 1/11/2017 12:47:33PM Page 10 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Rig: 2M-38 Wellbore: Rig: 2M-38 Design: 2M-38wp22 Casing Points Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Rig: 2M-38 2M-38: 101.3+30.7 @ 132.00usft (Doyon141) 2M-38:101.3+30.7 @ 132.00usft (Doyon141) True Minimum Curvature OAKEDMP2 Measured Vertical -1,578.14 Casing Hole Depth Depth Depth Diameter Diameter (usft) (usft) Name C) ('7 113.20 113.20 20" x 42" 20 42 13,200.00 5,782.74 9-5/8" x 12-1/4" 9-5/8 12-1/4 14,200.00 6,071.88 7" x 8-1/2" by 9-7/8" 7 9-7/8 18,482.67 6,102.00 4-1/2" x 6-1/8" 4-1/2 6-1/8 3,053.00 2,661.38 13-3/8" x 16" 13-3/8 16 Formations 6,122.00 -1,578.14 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 13,223.10 5,792.00 Top HRZ 11,221.00 5,092.00 Base Iceberg / Growler 13,745.19 5,992.00 K1 9,829.78 4,692.00 C-37 / Top Iceberg 13,493.13 5,901.00 Fault 1 —40-45' DTE 13,495.53 5,902.00 Base HRZ/Top Kalubik 15,038.94 6,077.00 Deepest possible Kuparuk C 14,035.93 6,057.00 Top Kuparuk C 8,038.58 4,177.00 C-50 0.00 13,779.23 6,002.00 Fault 2 — 25' DTW 3,671.85 2,917.00 Camp SS 12,215.56 5,392.00 C-35 16,705.25 6,122.00 -1,578.14 -13,706.14 Start 3°/100' DLS, 10.71 ° TF, for 147.28' 16,852.53 6,120.15 -1,560.54 -13,852.31 Hold for 488.07' 17,340.60 6,095.55 -1,498.78 -14,335.83 Start 2°/100' DLS, -122.31° TF, for 83.15' 17,423.74 6,092.00 -1,489.27 -14,418.35 Adjust TF to 180°, for 135.76' 17,559.50 6,090.48 -1,475.38 -14,553.37 Hold for 923.17' 18,482.67 6,102.00 -1,380.94 -15,471.63 TD: 18482.67' MD, 6102' TVD Checked By: Approved By: Date: 1/11/2017 12:47:33PM Page 11 COMPASS 5000.1 Build 74 Pool Repor"i 2M-38 Surface Location t EZI. CPA1 Coo-dinate From: - ---- To: - — - -- --- I Datum: NAp83 Region: alaska Datum: NAD27 Region: alaska f Latitude/Longitude Decimal Degreesr Latitude/Longitude Decimal Degrees i UTM Zone: --- r- South r UTM Zone: True f- South a✓% State Plane Zone: 4 Units: us•ft . 4+ State Plane Zone: 4 Units: us ft j i i C Legal Description (NAD27 only)C Legal Description (NAD27 only) Starting Coordinates: ----- - Ending Coordinates: X 1628397.28 X: 488364.40708442 I Y 5948736.09 Y: 5948985.99661862 :............... Transform Quit iHelp tZ,, CPA&Coo-dinate From: - v-- -- —_ Datum: INAD83 Region: jalaska i t Latitude/Longitude Decimal Degrees C UTM Zone: w r South G State Plane Zone: q - Units: us -ft �" Legal Ciescript�or (PtA,D:r` ord�,�j F Starting Coordinates: - — -- --- — X: 1628397.28 Y:5948736.09 To: - -- -- Datum: NAD27 D, Region:alaska C Latitude/Longitude Decimal Degrees ii r' UTM Zone: True r South f State Plane Zone: F---] Units: us-fk G• Legal Description (NAD27 only) Legal Description Township: 011 N Range: 008 E Meridian: I U Section:27 FNL5165.2388 FEL 4755.8522 i Transform Quit Help 2M-38 Surface Casing n CPAI Coordinate Converter From: -- Datum: WD -8 —3'+] Region: lalaska r' Latitude/Longitude I Decimal Degrees r UTM Zonef— r— South Skate Plane Zone: F---:�] Units: F -I -ft Legal Description (NAD27only) Starting Coordinates: n, CPAICoodinate To: Datum: FZ27 + Region: [a—laska-----, r* Latitude/Longitude Decimal Degrees —7� UTM Zone: True F South State Plane Zone: F--:�] Units: !us ft Legal Description (NAD 27 only) Ending Coordinates: — X: 11627698.27 Y: JE947974.29 From: Datum: INAD83 Region: jalaska Latitude/Longitude r UTM Zone: F- F South State Plane Zone: 4 Units: us ft Starting Coordinates: X: 11627698.27 Y: 594797429 X: 487665.370002272 Y: 5948224.22411277— Transform : Quit Help . ................................ ------ ...... —'*---...� To: Datum: INAD27 Region: jal,,ka Latitude?Longitude 16ecimalDegrees UTM Zone: [T—rue r— South f- State Plane Zone: F---] Units: Fu Tf 7�-: I C• Legal Description (NAD27 only) Legal Description Township: 0-11 N Range: Fow Meridian: JU Sectionf3-3 FNL1 1648.19908 [FE 175.33827 QuittI p --—j 2M-38 Intermediate 1 Casing I r3 CPA1 Coordinate Conve I _ ( 7' ; From: Datum: [14A—H _ _�-] Region: alaska + t"- Latitude/Longitude IDecimalDegrees W r UTM Zone: �` F South C" Skate Plane Zone: 4 + Units: us ft _+ C Legal Description (NAD27 only) Starting Coordinates: -- ---- -- -- — X: 11618109.39 Y: 15947001.12 To: Datum: NAD27 Region: `alaska i Latitude/Longitude Decimal Degrees UTM Zone: True South is State Plane Zone: 4 � Units: us -ft + t Legal Description (NAD27 only) — i Ending Coordinates - X: 478076.304593326 I Y: 5947251.24469303 I Transform Quit Help CPAt Coordinate Con ter' From: Datum: INAD83 + Region: alaska r LatitudelLongitude IDecimalDegrees r UTM Zone: F— r South t+ State Plane Zone: 4 Units: us ft r Le. • l De_CrlptiLltl It-iAE) ' osis,) Starting Coordinates: –-------- --- X: 11GI8109.39 Y: 5947001.12 1.-_-- __ ------ ------ ---- –._._...--- To: __ _ ---- Datum: NAD27 Region: alaska i` Latitude/Longitude IDecimal Degrees +� r UTM Zone: True 1y South Stake Plane Zone: 4 + Units: us -ft + C� Legal Description (NAD27 only) Legal Description – ---- Township: 011 N + Range: 008 E . Meridian: U Section:32 FNL + 1643.0978 FEL 4485.8545 .................................... . Transform Quit Help 2M-38 Intermediate 2 Casing & Landing n- CPA: Coordinate From Datum: jNZ83 Region: Zs-kaA- F Latitude/Longitude DecimalDegrees UTM Zone: [- f- South r- State Plane Zone: 4 ] ----- F-Tft-�D Units: r Legal Description (NAD27 only) To: Datum: INAD27 Region: [a-jaS-ka r Latitude/Longitude IDecimal Degrees UTM Zone: I -True f South Stake Plane Zone:] F4---'- us ft Units: Legal Description (NAD27 only) Starting Coordinates: Ending Coordinates: X: 11617165.24 r X: F477132.137316676 Y: 15946903.02 Y: 15947153.16270568 .................. .......... .... ................ . .................. fr.a.n.siim .................i Quit Help I M CPM Coordinate Ccnv�.rter .=" M - t, = 1 1, e --,"J From: Datum: fiTA� Region: alaska LatitudOl-ongitude DecimalDegrees UTM Zone: f South State Plane Zone:q Units: U -ft-:-] r Legal Ele:-,cfiption fNAD 27, only] Starting Coordinates: X: 11617165.24 Y: 15946903.02 To: Datum: PZFF-�-:] Region: Fa7i.k-a--_--] Latitude/Longitude ]Decimal Degrees UTM Zone: f -True r- South State Plane Zone: F----] Units: us -ft---] Legal Description (NAD27 only) Legal Description Township: Fo 1 —1 FRange: 10-08 FD - Meridian: I U Section:131 [FNL 1743.9935 FEL _�,] f150.18885 Transform € Quit IHelp 2M-38 TD I3 CPA; Coordinate From: _...-- Datum: INAD83 + Region: alaska r Latitude/Longitude Decimal Degrees C UTM Zonef— r South f- State Plane Zone: 4 Units: us -ft f Legal Description (NAD27 only) i Starting Coordinates: ---- ----- - — X: 1612925.00 Y: 15947380.00 -To-- Datum: To: Datum: NAD27 Region: alaska r Latitude/Longitude IDecimal Degrees C' UTM Zone: True F South is State Plane Zone: F-----3 Units: us -ft t' Legal Description (NAD27 only) Ending Coordinates. - —- --- IX: 472891.83911096 Y: 5947630.2092613F- .......... 947630.20926135 ...................................... Transform Quit Help CPA[CoordinateConve-- - From: Datum: NAD Region: alaska f Latitude/Longitude Decimal Degrees r UTM Zone: F South rt State Plane Zone: 4---+] Units: us ft t"` Lrq.ul C� _._nptior� jfd.4Cr'7 nnl,) Starting Coordinates: -- - X: 1612925.00 Y: 15947380.00 To: -- i Datum: .NAD27 Region: alaska i LatitudelLongitude Decimal Degrees I UTM Zone: True r South f State Plane Zone: 4 + Units: us --ft 7-1 C+ Legal Description (NAD27 only) Legal Description - -- — Township: 011 N . Range: 008 E Meridian: U Section:31 FNL 1280.9838 14390.6751 i ......................................................... . Transform Quit Help 2 M-38w p 22 WELLBORE TARGET DETAILS (WP CO-ORDINATES) 13:22, January 11 2017 Name T o sAPpe 2A 1 C35 W 1716 JC 53 D) O ie (Ratli�s: 100.001 Quarter Mile View 2,3 Top HRZ051716 JC 521.00 O'de(Radiw 1X 00) 2K+363. TIP 2171716 —1 . Oi (Radi.:100.00) 214 J. Base HRZTop Kuparu 051716 JC 5W3.W Circe ftdiva. 100.00) 2K+365. K-1051716 JC 5076.W Clyde lRadius:l W.W7 Imary 2Ph 6 6056.60 ( Ian: 2f 36 Plan: 2A+36 2 36660.X 7 TP,dilg5-7161 ]116 6061.. Orde(Rad,.: 100.001 2KT367. landing 14%IIPJC 6o]2.W o'd (R.Nm: IW.W) 2Ak367. Landidgl'S KEH 60..W iwe(R.d-132000) 2A -P21 T01 Prd1 KEH Wan17 fi092.W c, IRatlius: 25.X) 2A436vg21 T01 Pro3 KEH 6Jantr 6092.. W13 C I IRatl 25X1 _ 1 M' TCM,', .............II", G. 3 iF21.1!Rad�s 1320X)_._ ,. 2A4..214y1 Prot KEH Went] 6122.. tde f%dl 25X1 21111?� 6000. _ _ ' I I j I 2M, 8 000o3000- C) a�'a 0 n a 0 0- 0 O _- 1 ;;�3000 .1 O o -6000- __ - _ ......... P 241.0 I -s000- _ __ _........ ., -21000 -18000 -15000 -12000 -96-00 -6000 -36'60 0 3000 West(-)/East(+) (3000 usft/in) _- � r�7 ~' As -built REV I DATE I BY I CK I APP DESCRIPTION I REV I DA7E BYAPP DESCRIPTION 3 8/19/1 LGM JLS AB 37 & 38 PerK160005ACS 2 10/20/1 JFC MEH AB 36 Per K140144ACS 16 13 =,A t iI i� � 21 22 23 4 wV4 1 j ASP GRID PRD�CT D �acAnoN .s � � .�x..._. 2a z� 2s + <2. 26 • � f 1' - 25 • _ �. D67}I 24 • 33 34 3t 3, 31 Li 31� T11 N DS20 i 23f 38 i T10N ~ 2 22 • II O_ 21 0- 20 • 20 VICINITY MAP 1" = 2 MILES 35 • 18 • 34 • 17 •_... ..... _.......... .� 33 • t 16 • (i 15 •C LEGEND" 31 • I 14 •� J`I— —' • EXISTING CONDUCTORS LOCATIONS 13 • _:_ -_ X ABANDONED CONDUCTORS LOCATIONS AS—BUILT CONDUCTOR LOCATION DS2M i 12 • '1 �� = NOTES: 11 • J 1. BASIS OF LOCATION & ELEVATION IS DS2M MONUMENTATION PER LOUNSBURY & ASSOC. 10 *-1, 9 •� 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27, AND GEODETIC COORDINATES ARE NAD 27. 8A�---' 6 • 3. ELEVATIONS ARE B.P.M.S.L. 5 • 4 •— j 4. ALL CONDUCTORS ARE LOCATED WITHIN 2 iG°�—� PROTRACTED SECTIONS 27 & 28, T11N.—R8E., 1 �- �_,_._____.�,) 27 N UMIAT MERIDIAN, ALASKA. M1 vil 5. DATES OF SURVEY: 8-18 THRU 8-25-16 FIELD 28 • , - 00 • 36 N BOOKS L16-21, L16-23 • 3 - •-2 6. ALL DISTANCES SHOWN ARE GROUND 2A �d 32 0— GRAPHIC SCALE 37 gg 0 50 100 200 LOUNSBURY & ASSOCIATES, INC. OI% L y 1 inch = ZOO ft. SURVEYORS ENGINEERS PLANNERS r_-- AREA: 2M MODULE: XXXX UNIT: D2 ConocoPhilli S DS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6213D29 1/13/0 7 CEA—D2MX-6213D29 1 of 3 3 3 18/19/10 LGM I JLS I I AB 37 & 38 PerK160005ACS 1 2 110/20/14) JFC I MEH I JAB 36 Per K140144ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 27 T. 11 N., R. 8 E., UMIAT MERDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X LAT. LONG. F.S.L. F.W.L. O.G. PAD 1 2 5,948,985.87 5,948,985.89 487,859.47 487,874.36 70' 16' 18.578" 70' 16' 18.579" 150' 05' 53.483" 150' 05' 53.050" 114 114 19 34 100.9 100.8 105.5 105.2 4 5,948,985.79 487,889.49 70' 16' 18.578" 150' 05' 52.609" 114 49 100.8 105.4 5 5,948 985.81 487,904.31 70' 16' 18.578" 150' 05' 52.178" 114 64 100.8 105.3 5A 5,948,985.93 487,854.41 70' 16' 18.579" 150' 05' 53.630" 114 14 100.9 105.1 6 5,948,985.71 487,919.44 70' 16' 18.578" 150' 05' 51.737" 114 79 100.8 105.4 6A 5,948,985.93 487,879.38 70' 16' 18.579" 150' 05' 52.903" 114 39 100.8 105.2 7 5,948,985.89 487 934.60 70' 16' 18.579" 150' 05' 51.296" 114 94 100.8 105.3 8 5,948,985.84 487,949.23 70' 16' 18.579" 150' 05' 50.870" 114 109 100.7 105.5 8A 5,948,985.66 487,929.31 70' 16' 18.517" 150' 05' 51.450" 114 89 100.8 105.4 9 5,948,985.87 487 964.69 70' 16' 18.580" 150' 05' 50.420" 114 124 100.7 105.5 9A 5,948 985.72 487,954.37 70' 16' 18.578" 150' 05' 50.720" 114 114 100.7 105.5 10 5,948,985.84 487 979.31 70' 16' 18.580" 150' 05' 49.994" 114 139 100.6 105.5 11 5,948,985.95 488,004.39 70' 16' 18.581" 150' 05' 49.264" 114 164 100.6 105.5 12 5,948,985.85 488,029.45 70' 16' 18.581" 150' 05' 48.534" 114 189 100.5 105.5 13 5,948,985.74 488 119.27 70' 16' 18.581" 150' 05' 45.919" 114 279 100.3 105.6 14 5,948 985.92 488,144.43 70' 16' 18.583" 150' 05' 45.186" 114 304 100.2 105.6 15 5,948,985.98 488 169.02 70' 16' 18.584" 150' 05' 44.470" 114 329 100.2 105.5 16 5,948,985.94 488,194.04 70' 16' 18.584" 150' 05' 43.742" 114 354 100.1 1105.6 17 5,948,986.06 488,219.15 70' 16' 18.586" 150' 05' 43.011" 114 379 100.0 105.7 18 5,948,985.98 488 244.31 70' 16' 18.585" 150' 05' 42.278" 114 404 99.9 105.7 19 5,948 985.88 488 269.19 70' 16' 18.585" 150' 05' 41.554" 114 429 99.9 105.6 20 5,948,985.94 488 294.03 70' 16' 18.586" 150' 05' 40.831" 114 454 99.8 105.4 21 1 5,948.985.88 488,319.18 70' 16' 18.585" 150' 05' 40.098" 114 479 99.7 105.3 22 5,948,985.77 488,344.40 70' 16' 18.585" 150' 05' 39.364" 114 504 99.7 105.0 23 5,948,985.83 488 368.91 70' 16' 18.586" 150' 05' 38.650" 114 529 99.6 104.9 24 5,948,985.75 488 394.29 70' 16' 18.585" 150' 05' 37.911" 114 554 99.5 104.9 25 5,948,985.79 488 419.22 70' 16' 18.586" 150' 05' 37.186" 114 579 99.4 104.9 26 5,948,985.92 488,434.76 70' 16' 18.588" 150' 05' 36.733" 115 594 99.4 104.9 27 5,948,985.97 487,844.42 70' 16' 18.579" 150' 05' 53.921" 114 4 100.9 105.5 31 5,948,985.64 488 156.27 70' 16' 18.581" 150' 05' 44.841" 114 316 1100.2 104._7 33 5,948 985.93 488,206.85 70' 16' 18.584" 150' 05' 43.369" 114 367 10g1O34 5,948 985.32 488 232.32 70' 16' 18.579" 150' 05' 42.627" 114 392 99.35 5 948,986.23 488,256.36 70' 16' 18.588" 150' 05' 41.928" 115 416 99.38 5,948,986.00 488364.41 70' 16' 18.591" 150' 05' 38.78" 115 524 101 * CONDUCTOR ASBUILT THIS SURVEY LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: 2M MODULE: XXXX UNIT: D2 ConocoPhilli S DS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CALK62 3D29 1/13/07 DRAWING No. CEA-D2MX-6213D29 PART: 2 OF 3 REV: 3 13 18/19/161 LGM I JSL I I AB 37 & 38 PerK160005ACS 1 2 110/20/14 JFC I MEH I JAB 36 Per K140144ACS CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28 T.11 N., R. 8 E., UMIAT MERIDIAN well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X LAT. LONG. F.S.L. F.E.L. O.G. PAD 1A 5,948,985.83 487,754.61 70' 16' 18.576" 150' 05' 56.536" 114 86 101.0 104.9 2A 5,948,985.93 487,779.58 70' 16' 18.577" 150' 05. 55.809" 114 61 101.0 104.9 3 5,948,985.91 487 804.53 70' 16' 18.578" 150' 05' 55.083" 114 36 101.0 105.0 28 5,948,985.91 487,829.44 70' 16' 18.578" 150' 05' 54.358" 114 11 101.0 105.0 29 5 948,986.05 487,789.80 70' 16' 18.579" 150' 05' 55.512" 114 51 101.0 105.2 30 5,948,986.04 487 774.40 70' 16' 18.578" 150' 05' 55.960"_ 114 66 101.0 105.2 32 5,948 986.10 487,74+38 70' 16' 18.579" _ 150' 05' 56.834" 114 96 101.0 105.1 36 5,948,984.77 487,817.93 70' 16' 18.567" 150' 05' 54.693" 113 22 101.0 101.3 98 5,948,986.04 487,759.38 70' 16' 18.578" 150' 05' 56.397" 114 81 101.0 105.0 99 5,948,985.93 487,729.52 70' 16' 18.577" 150' 05' 57.267" 114 111 101.0 104.9 37 5,948,985.74 487,726.19 70' 16' 18.579" 150' 05' 57.364" 113 114 101.0 102.3 * CONDUCTOR ASBUILT THIS SURVEY ... Aw °fir th •� .......,...,r�...,,....1�a.....�....;: .......................................... -.JEREMIAH F. CORNELL.- �o�� �J LS -12663z AWC3 AV SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF AUGUST 25, 2016. `"►,rlklmw LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS 1'LASNERS AREA: 2M MODULE: XXXX UNIT: D2 ConocoPhillips DS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6213D29 1 Z13 07 CEA-D2MX-6213D29 1 3 OF 3 1 3 PUNCH MARK (TYP.) ON 45' ROTATION ORIENTATION LINE 1 i 37 CUT OFF REFERENCE POINTS LK91►1111f111C91Z CONDUCTOR & CELLAR PLAN VIEW SCALE: N.T.S. N O CONDUCTOR PUNCH MARKS ON ORIENTATION LINE SCALE: N.T.S. NOTE: 1. REF. DRAWINGS: DM100208428 2. SURVEY DATED: 08/25/2016 3. ELEVATIONS ARE BPMSL CUT OF[ E - L_. =19_1_, REFERE POINTS TOP OF CELLAR DRILL SITE N m CELLAR PUNCH MARKS ON ORIENTATION LINE SCALE: N.T.S. LOUNSBURY & ASSOCUTES, INC. �W SURVEYORS ENGINEERS PLANNERS AREA: MODULE: XXXX UNIT: ConocoPhillips DS2M CONDUCTOR MARKINGS Alaska, Inc. WELLS 37 I CADD FILE NO. 08/25/2016 1 DRAWING NO. I PART: 1 OF 1 1 REV: 0 1 PUNCH MARK (TYP.) ON 45' ROTATION �5 ORIENTATION LINE.' 38 i CUT OFF EL. =100.5' REFERENCE POINTS CONDUCTOR CELLAR CONDUCTOR & CELLAR PLAN VIEW SCALE: N.T.S. Lo N O CONDUCTOR PUNCH MARKS ON ORIENTATION LINE SCALE: N.T.S. CUT OFF Ems= IDO REFERE POINTS TOP OF CELLAR DRILL SITE N CELLAR PUNCH MARKS ON ORIENTATION LINE SCALE: N.T.S. �n N O Ln N O NOTE: 1. REF. DRAWINGS: DM100208428 LOUNSBURY 2. SURVEY DATED: 08/25/2016 & ASSOCIATES, INC. 3. ELEVATIONS ARE BPMSL KSU YORS ENGINEERS PLANNERS 0 46 AREA: MODULE: XXXX UNIT: ConocoPhillips CONDUCTOR MARKINGS Alaska, Inc. WELLS 38 CADD FILE N0. DRAWING No. PART: REV: 08/25/2016 1 of 1 0 Loepp. Victoria T (DOA) From: Voss, Jake <Jake.Voss@conocophillips.com> Sent: Friday, January 13, 2017 10:57 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2M-38 (PTD# 216-083) Attachments: 2M-38 Updated Cement Calcs.pdf Victoria, Please see attached cement calculations for revised well KRU 2M-38 (PTD #216-083). Sorry for the urgency, but thanks for making this a priority. With the updated lateral orientation, we feel this will help produce a better well. Jake From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, January 10, 2017 2:29 PM To: Voss, Jake <Jake.Voss@conocophillips.com> Cc: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Subject: [EXTERNAL]RE: KRU 2M-38 (PTD# 216-083) Jake, Please submit a revised PTD with the updated information shown in red and the new directional survey. Please make this submission as soon as possible. What is the timing for deviating from the approved well path? 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. Loepp(a)alaska.gov 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 From: Voss, Jake[mailto:Jake.Voss@conocophillips.com] Sent: Tuesday, January 10, 20171:59 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: KRU 2M-38 (PTD# 216-083) Good afternoon Victoria, I have a question regarding directional plan change and the requirement for updating the PTD. Based on the results of 2M-37, our Geologist have updated our new well path #21 (shown below in red) to aid in sweep efficiency and avoid siderite (and increase C -sand). This amendment will not change the landing point into the Kuparuk reservoir. Only the azimuthal orientation of the lateral. However, the TD will be over 500' away from our approved PTD directional plan. This map shows the change in orientation of the lateral. The boxes show the location of the points (ignore the one on the right, it shows the landing point). In addition to the updated directional plan, what other information/updates do you need on our end (updated 10- 401, with changes in red, but do you need the whole PTD packet as well)? 2M-38 is currently drilling the intermediate #1 hole section, the plan forward is to continue drilling per the approved well path 19 into the reservoir. From there we would update our well trajectory with the new AOGCC-approved well plan. Thanks, Jake Voss Sr Drilling Engineer I ConocoPhillips Alaska I Office: (907) 265-6935 1 Mobile: (832)-499-9085 TRANSMITTAL LETTER CHECKLIST WELL NAME: kA 3 <, I l/1`S PTD: 9.1(o -0?3 /Development Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL: �)Wtr- 66-/ 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 sam les 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 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 11 Well Name: KUPARUK R- IV UNIT -2M-38 - _ __ _ _ Program DEV Well bore seg ❑ PTD#:2160830 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type __DEV / 1 -OIL _ GeoArea 890 _ Unit 11160 _ On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes ADL0025586, Surf Loc; ADL0025585, Top Prod Intery & TD. 3 Unique well name and number Yes KRU 2M-38 '4 Well located in a defined -pool Yes KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed -by Conservation_ Order No. 432D 5 Well located proper distance from drilling unit boundary Yes CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells_ Yes CO 432D has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) 8 If deviated, iswellboreplat included Yes 18 9 Operator only affected party Yes Wellbore will be more than 500' from an external property line where ownership or landownership changes. 10 Operator has appropriate_ bond in force Yes Yes Yes CMT vol adequate to circulate on conductor & surf csg 80' conductor set 3034' MD 154% excess Productive interval will be completed with perforated pup liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; Major risk failure 2M-23 which is abd Diverter is acceptable Max reservoir pres is 3821 psig(12.1 ppg EMW); will drill -w/ 8.6-12.5 ppg EMW; MPD MPSP is 3216 psig; will test BOPs to 3500 psig 1-12S measures required Wells on 2M -Pad are H2S-bearing. H2S measures required Expected reservoirpressureis 12.14 ppg EMW; will be drilled using 8.6 to 12.5 ppg mud. 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development well to be drilled. Geologic Engineering Public Date Revision to Doyon 141 and updated directional plan for lateral orientation. VTL 1/13/17 Commissioner: Date: Commissioner: Date Commissioner DTS 1 1 3 ( ��dAwvw-l-N3-17 11 Permit can be issued without conservation order Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes PKB 1/13/2017 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 18 Conductor string provided - Yes Engineering 19 Surface casing protects all known USDWs Yes 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost_ Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 1.0-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes '33 Is presence of H2S gas probable Yes 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 _Seismic analysis of shallow gas zones NA PKB 1/13/2017 38 Seabed condition survey _(if off -shore) NA 80' conductor set 3034' MD 154% excess Productive interval will be completed with perforated pup liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; Major risk failure 2M-23 which is abd Diverter is acceptable Max reservoir pres is 3821 psig(12.1 ppg EMW); will drill -w/ 8.6-12.5 ppg EMW; MPD MPSP is 3216 psig; will test BOPs to 3500 psig 1-12S measures required Wells on 2M -Pad are H2S-bearing. H2S measures required Expected reservoirpressureis 12.14 ppg EMW; will be drilled using 8.6 to 12.5 ppg mud. 39 Contact name/phone for weekly progress reports [exploratory only] NA Onshore development well to be drilled. Geologic Engineering Public Date Revision to Doyon 141 and updated directional plan for lateral orientation. VTL 1/13/17 Commissioner: Date: Commissioner: Date Commissioner DTS 1 1 3 ( ��dAwvw-l-N3-17 PFO 2/4-053 Loepp. Victoria T (DOA) From: Bearden, J Daniel <J.Daniel.Bearden@conocophillips.com> Sent: Wednesday, December 28, 201610:54 AM To: Schwartz, Guy L (DOA); Quick, Michael J (DOA); Loepp, Victoria T (DOA) Cc: Voss, Jake; Alexa, Kurt J; Woodard, Madeline E Subject: 2M-38 (PTD 216-083) - Rig Change Follow Up Flag: Follow up Flag Status: Flagged Victoria/Guy, Due to a change in our rig schedule, Doyon 141 is now planned to spud 2M-38 (PTD 216-083) instead of Doyon 142. The anticipated spud date is January 2"d, 2016 - right after release from 2M-37. If there is anything you need from me, please let me know. Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell THE STATE ®f A L ,--x AsKA GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Cas Conservati®n Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-38 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-083 Surface Location: 5165' FNL, 4756' FEL, SEC. 27, Tl IN, R8E, UM Bottomhole Location: 2649' FNL, 4494' FEL, SEC. 31, TI IN, R8E, 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 . Foerster Chair DATED this —%' day of July, 2016. STATE OF ALASKA AL :A OIL AND GAS CONSERVATION COMM'i_ ;ON PERMIT TO DRILL C-etil1 GIkh(. 20 AAC 25.005 JUN 0 6 2016 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas J RWService - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill Lateral ❑ Stratigraphic Test ❑ Development -Oil LVA Service- Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ 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 2M-38 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 18688 TVD: 6079 Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 5165 FNL 4756 FEL, Sec. 27 Twn 11 N Rng 8E, UM ADL025586, ADL025585 Kuparuk Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1733 FNL 75 FEL, Sec. 31 Twn 11 N Rng 8E, UM 931894000, 931893000 7/10/2016 9. Acres in Property: 14. Distance to Nearest Propertv: Total Depth: 2649 FNL 4494 FEL, Sec. 31 Twn 11 N Rng 8E, UM 2560, 2491 530 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 144.3 15. Distance to Nearest Well Open Surface: x- 488363.9 Y- 5948985.8 Zone- 4 GL Elevation above MSL (ft): 104.9 to Same Pool: 215 16. Deviated wells: Kickoff depth: 275 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93.2 degrees Downhole: 3821 psi Surface: 3213 psi 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# H-40 Welded 80 39 39 121.5 121.5 cement in place 16" 13.375" 68# L-80 Hydril 563 2940 39 39 2979 2642 1305 sx 11 ppg DeepCRETE, 250 sx 15.8 ppg Class 'G' 12.25" 9.625" 40# L-80 Hydril 563 9822 2829 39 12951 5694 470 sx 15.8ppg Class'G' 8.75" 7" 26# L-80 Hydril 563 14212 39 39 14251 1 6084 305 sx 15.8ppg Class 'G' 6.125" 4.5" 1 12.6# L-80 IBTM 18649 1 39 39 18688 1 6079 1 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): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat BOP Sketch Drilling Program ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Kurt Alexa @ 263-4993 Email KUrt.J.AIexa(@COP.Com Printed Name G. Alvord Title Alaska Drilling Manager Signature i� , (� Phone 265-6120 Date Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: _ 083 50 []13" a 117 " 044 r OQ Date:1-7 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methan gas hydrates, or gas contained in shales: Other: QOP fCSt fo .35-6,0 P5., Samples req'd: Yes❑ No 10 Mud log req'd: Yes❑ Nov /1 k-1 ra v l a i' J.2 rG>'« �f ��5 fo 2 5 O0 P52�jHZS measures: Yes [ No❑ Directional svy req'd: Yes [Z No❑ Spacing exception req'd: Yes ❑ Nov Inclination -only svy req'd: Yes ❑ Nov Post initial injection MIT req'd: Yes ❑ No M--' APPROVED BY by: 7 "?- l Approved COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 (Re sed 11/2015) i 11TA T7ths from the date of proval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4180 June 6, 2016 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2M-38 Re: Application for Permit to Drill Well 2M-38, a Kuparuk C Sand Producer Dear Commissioner: ECEI JUN 0 6 2016 ()GC ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots producer well from the 2M pad. The expected spud date for this well is July 10, 2016. It is planned to use rig Doyon 142. 2M-38 is planned to be a horizontal well in the Kuparuk C sand. The surface section will be drilled with 16" bit and run 13-3/8" casing to +/-2,979'MD / 2,642'TVD. The intermediate section (I) will be drilled with 12-1/4" bit and run 9-5/8" casing to 12,951'MD / 5,694'TVD. The intermediate section (II) will be drilled with 8-3/4" bit with 9-7/8" under reamer and run 7" casing to 14,25VNID / 6,084'TVD. The production hole will be drilled with 6-1/8" bit and run 4-1/2" perforated liner to +/- 18,688'MD / 6,079'TVD. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Kurt Alexa at 263-4933 (Kurt.J.Alexa@conocophillips.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Application for Permit to Drill, Well 2M-38 Permit It - Kuparuk Well 21VI-38 Application for Permit to Drill Document Table of Contents 1. Well Name.................................................................................................................. 3 Requirements of 20 AAC 25.005(0........................................................................................................ 3 2. Location Summary..................................................................................................... 3 Requirements of 20 AAC 25.005(c)(2)................................................................................................... 3 Requirements of 20 AAC 25.050(b)........................................................................................................ 3 3. Blowout Prevention Equipment Information............................................................... 3 Requirements of 20 AAC 25.005(c)(3)................................................................................................... 3 4. Drilling Hazards Information..................................................................................... 4 Requirements of 20 AAC 25.005 (c) (4)........................................................................................................ 4 Requirements of 20 AAC 25.005 (c)(5)........................................................................................................ 4 S. Casing and Cementing Program................................................................................. 5 Requirements of 20 AAC 25.005(c)(6)................................................................................................... 5 6. Diverter System Information...................................................................................... 6 Requirements of 20 AAC 25.005(c)(7)................................................................................................... 7 7. Drilling Fluid Program............................................................................................... 7 Requirements of 20 AAC 25.005(c)(8)................................................................................................... 7 8. Abnormally Pressured Formation Information........................................................... 7 Requirements of 20 AAC 25.005 (c)(9).................................................................................................. 7 9. Seismic Analysis......................................................................................................... 7 Requirements of 20 AAC 25.005 (c)(10)................................................................................................ 7 10. Seabed Condition Analysis.......................................................................................... 8 Requirements of 20 AAC 25.005 (c)(11)................................................................................................ 8 11. Evidence of Bonding................................................................................................... 8 Requirements of 20 AAC 25.005 (c)(12)................................................................................................ 8 12. Proposed Drilling Program......................................................................................... 8 Requirements of 20 AAC 25.005 (c)(13)................................................................................................ 8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 9 Requirements of 20 AAC 25.005 (c)(14)................................................................................................ 9 14. Attachments............................................................................................................... 9 Attachment 1 Directional Plan............................................................................................................... 9 Attachment 2 Drilling Hazards Summary ............................................................................................... 9 Attachment 3 Cement Program Summary ............................................................................................. 9 Attachment4 Well Schematic................................................................................................................ 9 Attachment 5 Pad with diverter schematic............................................................................................. 9 ration for Permit to Drill, Well 2M-38 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 ivith 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 2M-38 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 identifting 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 Top of Productive 1733 FNL 75 FEL Sec. 31 Twn 1 IN Rng 8E, UM Location at Surface 1 5165 FNL 4756 FEL, Sec. 27 Twn 11N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates Northings 5,948,985.83 Eastings: 488,363.9 RKB Elevation 144.3' AMSL Pad Elevation 104.9' AMSL Location at Top of Productive 1733 FNL 75 FEL Sec. 31 Twn 1 IN Rng 8E, UM Interval Ku aruk "C" Sand) Total Vertical Depth, RKB: 6,079' ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 14,058' Total Vertical Depth, RKB: 6,071' Northings: 5,947,163.29 Eastings: 477,207.08 Total Vertical Depth, SS: 5,928' Location at Total Depth 1 2649 FNL 4494 FEL, Sec. 31 Twn 11N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates Northings: 5,946,262.2 Eastings: 472,789.68 Measured Depth, RKB: 18,688' Total Vertical Depth, RKB: 6,079' Total Vertical Depth, SS: 5,935' and (D) other information required by 20 AAC 25.050(b); 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) inehide a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent ivelibores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 2M-38 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those ivells, 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 AAC 25.037, as applicable; Please reference 130P schematics on file for Doyon 142. ( ration for Permit to Drill, Well 2M-38 4. 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 potential surface pressure (MPSP) while drilling 2M-38 is calculated using an estimated maximum reservoir pressure of 3,822 psi (12.1 ppg, based on nearby 2M wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,074' TVD (WP12.2): C4 Sand Estimated. BHP = 3,821 psi C4 Sand estimated depth (WP10) = 6,079' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 608 psi (6,079' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,213 psi (3,821 psi — 608 psi) (B) data on potential gas zones: The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation ->ones, and _ones that have a propensity for differential sticking, See attached 2M-38 Drilling Hazards Summary 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 AAC 25.0300; A procedure is on file with the commission for performing LOT'S. A ;ation for Permit to Drill, Well 2M-38 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 AAC 25.030, and a description of arty slotted liner, pre perforated liner, or screen to be installed: Casing and Cementing Program See also Attachment 3: Cement Summary] Csg/Tbg Hole Weight Grade Conn. Length Top MDlrVD Btm MD/TVD Cement Program OD (in) Sin) (Ib/ft) (ft) (g) (ft) 20 42 94 H-40 Welded 80 Surf 121.5 / 121.5 Cement in place 13-3/8 16 68 L-80 Hydril 2,940 Surf 2,979 / 2,642 1305 sx 11 ppg DeepCRETE, 250 sx `G' 563 15.8ppg Class 9-5/8 12-1/4 40 L-80 BTC -M 9,822 2,829 / 2,553 12,951 / 5,694 470 sx 15.8ppg Class'G' with TOC to 11,100' MD 7 8-3/4 26 L-80 Hyd563 14,212 Surf 14,351 / 6,084 305 sx 15.8ppg Class 'G' with TOC to /BTC -M 12,801' MD 41/2 6-1/8 12.6 L-80 IBT-M 5,587 14,101 / 6,014 18,688 / 6,079 No Cement 2M-38 Wp13 Cementing Schematic 16" Hole West Sak 2,887' MD / 2,592' TVD ...................................... .......................................... Camp SS 3,860' MD / 2,956' TVD 12-1/4" Hole .............. I ................... ....... Iceberg 10,045' MD / 4,749' TVD ........................................... C -Sand Top 14,059' MD / 6,072' TVD 6-1/8" Hole ration for Permit to Drill, Well 2M-38 20" Conductor to 121' ......I .................. 13-3/8" 68 L-80 HYD563 2,979' MD / 2,642' TVD @ 58 inc. .................................. Top of Cement 11,100' MD / 5,055' TVD 9-518" 40# L-80 HYD563/BTC-M Casing 12,951 MD / 5,694' TVD @ 67- ........... I ......................... Top of Cement to hanger 12,801' MD / 5,635' TVD 7" Liner 26# L80 Hyd563 14,251' MD / 6,084' TVD ............................................................... 4'/2" Production Perforated Liner 12.6# L80 IBT-M ..........1.8.,688' MD./ 6;079' TVD. ration for Permit to Drill, Well 2M-38 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, exceptfor 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 AAC 25.035. unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematics on file for Doyon 142. 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 far an item already on file with the commission and identified in the application: (8) a drilling thrid progrmn, including a diagram and description of the drilling fluid system. as required by 20 AAC 25.033; Mud Program Summary Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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, exceptfor 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 25.0330: 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 most be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (l0) 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. Surface 16" Hole 13-3/8" Casing Intermediate 12-1/4" Hole 9-5/8" Casing Intermediate 8-3/4 x 9-7/8" Hole 7" Casing Production 6-1/8" Hole 4-1/2" Liner Mud System Spud mud (WBM) LSND (WBM) LSND (WBM) FLO-PRO NT (WBM) Density 8.6-9.5 9.2-10.5 10.5-12.5 10.5-12.5 PV 30-50 10-20 10-20 10-20 YID 40-80 16-24 17-28 16-24 Funnel Viscosity 200-300 N/A N/A N/A Initial Gel 30-50 10-12 11-15 5-8 10 minute Gel 30-50 10-18 12-22 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 < 10 pH 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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, exceptfor 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 25.0330: 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 most be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: (l0) 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. ration for Permit to Drill. Well 2M-38 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 ivuh the commission and identified in the application: (11) for a ieell drilled from an offshore platform, mobile bottom founded structure, jack-up rig, orfloating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b): Not applicable: Application is not for an offshore well. 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 i-vith the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been filet: 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 fnust he 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" conductor to f 121' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/-2979' MD / 2642' TVD as per directional plan. (LWD Program: GR/RES) 11 4. Run and cement 13-3/8", 68#, L80, 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 13-5/8" x 5,000 psi BOP'S to 3500 si anular prevente_r to 2500 si . Notify AOGCC 24 hrs before test. - 6. PU 12-1/4" bit and 8" drilling assembly, with MWD. Run in hole, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and 20' of new hole. Perform formation integrity test to minimum 12.5ppg EMW, recording results. 8. Directionally drill 12-1/4" hole to casing point at +/-12,951' MD / 5,694' TVD in the HRZ. (LWD Program: GR/RES/PWD). 9. Circulate wellbore clean and pull out of the hole. 10. Run 9-5/8", 40# L80, liner and liner top packer. Top of cement to be +/-11,100' MD / 5,055' TVD which is +/- 1,850' above the intermediate casing shoe. 11. PU 8-3/4" x 9-7/8" rotary steerable system and under reamer. RIH, clean out cement to top of float equipment and test casing to 3000 psi. 12. Drill out cement and 20' of new hole. Perform formation integrity test to a minimum of 13.5ppg EMW, recording results. 13. Directionally drill 8-3/4" x 9-7/8" hole to casing point at 14,251' MD / 6084' TVD in the Kuparuk C sand. (LWD Program: GR/RES/NEU/DEN/PWD) 14. Circulate well clean and pull out of hole. 15. Run 7", 26# L80 liner and liner top packer. Top of cement to be at the liner top packer. 16. Run 7", 26# L80 tie -back. Prior to stinging into the seal bore extension displace 7" x 9-5/8" x 13-3/8" annulus to corrosion inhibited brine and freeze protect. -ation for Permit to Drill, Well 2M-38 17. PU 6-1/8" PDC Bit and drilling assembly, with MWD and LWD logging tools. RIH and clean out cement to top of float equipment. Test casing to 3000 psi. 18. Drill out cement and 20' of new hole. Perform formation integrity test to a minimum of 13.5ppg EMW, recording results. Displace hole to lateral drilling system. 19. Directionally drill 6-1/8" hole into the Kuparuk C sand and to TD at +/-18,688' MD / 6079' TVD as per directional plan. (LWD Program: GR/RES/NEU/DEN/PWD) 20. Pull out of hole. 21. PU and run 4-1/2", 12.6# L80 lower completion with perforated pups. 22. PU and run 3-1/2", 9.3# L80 EUE tubing upper completion, circulate around with kill weight brine 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 3.5" x 7" annulus, taking returns from tubing and allowing to equalize. 26. Set BPV, secure well and move rig off. 27. No fractured stimulation is planned on 211-38 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 ander 20 AAC 25.080,1for 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.i All cuttings generated will be hauled 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 used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. J 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 Pad with diverter schematic - Permit Pack 2M-38wpl 3 s Plan Summary Base West Sak TD in C4 across fit 5 1 C-35 K-bp Ciz Fault (C to A2) _7�' D Surface Location Ba a Permafrost t is subjec# to Change IL Iceberg �\ 1 t. ' to 1 i Top HIRZ Be e`, op Kalublk U adi Can pSS C-37 rn r O 1 I C 50 ff 6d I / \ 50 I O 0 0" x 42' i 13-3/8" x 16' QO 0 4500 9000 13500 18000 20� x 42' Measured Dep 9-5/8" x 12-1/4 o /8 x 16 Depth Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) 0 Rig: Doyon142 0 uD a o 0 0 o p0 rn o o `� ^o 0 0 0 -5/8"; 5 m o 0 0 7" x 8-3/4" by 9-1/2' o 0 39 ....... 275 0 2000 4000 6000 8000 10000 12090 14000 -1 00 0 275 - 460 Horizontal Departure 2M 460 - 650 330 650 - 840 840 - 1030 o ( - .z 1030 - 1220 m 60 - 300 60 1220 1410 a e 1410 - 1600 rCR 1600 - 2310 required zm-z 2310 3030 M22 _ 3030 - U 30 L 1 1 3740 o I \ \ 2 23 - -_ _ 270 3740 - 4450 -- -z 4450 - 5160 w 1 \ 2M720 2M- 4 '. 5160 - 5870 U I - 6590 2 -25 2M-21 - 0 -. 6590 7300 6 7300 - 8720 0 2500 5000 7500 10000 12500 15000 17500 zao 1zo e7zo - 10150 SURVEY PROGRAM 0150 - 1157 Surface Location 11570 - 1299 Depth From Depth To Survey/Plan Tool Pad Elevation: 104.90 - _ _ lzsso - 1442 39.00 1100.00 2M-38wpl3 (Plan: 2M-38) GYD-GC-SS 210 • 150 1100.00 2100.00 2M-38wp13 (Plan: 2M-38) MWD ,, 14420 15849 1100.00 2978.93 2M-38wpl3 (Plan: 2M-38) MWD+IFR-AK-CAZ-SC 189 15840 17269 2978.93 4478.93 2M-38wp13 (Plan: 2M-38) MWD CASING DETAILS 17260 - 1ese7 2978.93 12950.54 2M-38wpl3 (Plan: 2M-38) MWD+IFR-AK-CAZ-SC 12950.54 14350.60 2M-38wp13 (Plan: 2M-38 MWD TVD MD Name 12950.54 14350.60 2M-38wp13 Plan: 2M-38 MWD+IFR-AK-CAZ-SC 121.50 121.50 20" x 42" Magnetic Model: BGGM2016 T 14350.60 15850.60 2M-38wpl3 (Plan: 2M-38 MWD 2641.90 2978.93 13-3/8" x 16" Magnetic Model Date: 15-Aug-16 14350.60 18687.21 2M-38wp13 (Plan: 2M-38) MWD+IFR-AK-CAZ-SC 5693.90 12950.54 9-5/8" x 12-1/4 Magnetic Declination: 17.92° 6083.90 14350.60 7" x 8-3/4" by 9-1/2" To convert a Magnetic Direction to a True Direction, Add 1 .92° East 6078.90 18687.21 4-1/2" x 6-1/8" SECTION DETAILS 1493.9 Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 180° TF, for 325.39' 3 600.39 4.88 180.00 600.00 -13.85 0.00 1.50. 180.00 2.41 Start 2°/100' DLS, 0° TF, for 871.59' Base Permafrost 4 1471.98 22.31 180.°0 1443.90 -217.96 0.00 2.00 Fd 0.00 37.85 Hold for 108.09' 5 1580.08 22.31 180.00 1543.90 -259.00 0.00 0.00 0.00 44.98 Start 4°/100' DLS, 90° TF, for 1398.85' 6 2978.93 58.81 255.6 1 2641.90 -709.61 -630.46 4.00 90.00 744.10 Hold for 20' 7 2998.93 58.81 255.61 2652.26 -713.86 -647.03 0.00 0.00 761.16 Start 3.5°/100' DLS, 29.72° TF, for 463.26' 2591.9 8 3462.19 73.15 263.93 2840.64 -787.03 -1062.17 3.50 29.72 1182.70 Hold for 8314.89' 9 11777.08 73.15 263.93 5251.04 -1628.84 -8975.36 0.90 0.00 9121.85 Start 2°/100' DLS, 172.94° TF, for 313.2' Base West Sak 10 12090.28 66.93 264.76 5357.90 -1657.88 -9268.17 2.00 172.94 9415.25 2M-38 1.C35 051716 JC Adjust TF to 5.17°, for 3.81' 2955.9 11 12094.09 67.01 264.77 5359.39 -1658.20 -9271.65 2.00 5.17 9418.75 Hold for 856.45' 12 12950.54 67.01 264.77 5693.90 -1730.07 -10056.81 0.00 0.00 10204.45 Adjust TF to 0°, for 20' 13 129 70 .54 67.01 264.77 5701.71 -1731.75 -10075.14 9.00 0.00 10222.80 Start 3.5°/100' DLS, -174.83° TF, for 35.09' 14 13005.64 65.79 264.65 571.5.76 -1734.71 -10107.16 3.50 -174.83 10254.84 Hold for 41.01' CampSS 15 13046.65 65.79 264.65 5732.58 -1738.20 -10144.40 0.00 0.00 10292.12 Start 3°/100' OLS, 3.21° TF, for 0.78' 16 13047.43 65.81 264.65 5732.90 -1738.27 -10145.11 3.00 3.21 10292.83 210-38 2. Top HRZ 051716 JC Start 3°/109' DLS, 3.21 ° TF, for 0.78' 17 13076.34 66.39 264.66 5744.61 -1740.73 -10171.43 2.00 0.64 10319.18 Hold for 352.74' 18 13429.08 66.39 264.66 5885.90 -1770.83 -10493.23 0.00 0.00 10641.32 210-38 3. Faultl 051716 JC Start 2.2°/100' DLS, 179.81 ° TF, for 56.3' 3963.9 19 13485.38 65.15 264.66 5909.01 -1775.61 -10544.35 2.20 179.81 10692.49 Hold for 14.02' 20 13499.40 65.15 264.66 5914.90 -1776.79 -10557.02 0.00 0.00 10705.17 2M-38 4. Base HRZ/Top Kupawk 051716 JC Start 3.07°/100' DLS, -3.21' TF, for 159.81' 21 13659.22 70.04 264.37 5975.79 -1790.91 -10704.05 3.07 -3.21 10852.42 Hold for 8.56' C-50 22 13667.78 70.°4 264.37 5978.71 -1791.70 -10712.06 0.00 0.00 10860.44 Start 3.5°/100' DLS, 7.3° TF, for 27.55' 23 13695.33 71.00 264.50 5987.90 -1794.22 -10737.91 3.50 7.30 10886.34 2M-38 5. K-1 051716 JC Adjust TF to -11.43°, for 160.19' 24 13855.52 76.29 263.40 6033.00 -1810.43 -10890.71 3.50 -11.43 11039.63 Hold for 27.31' $§�7 25 13882.83 76.29 263.40 60 39.47 -1813.48 -10917.06 0.00 0.00 11066.12 Start 3.5°/100' DLS, 0.65° TF, for 242.77' 26 14125.60 85.00 263.50 6078.90 -1640.77 -11154.79 3.50 0.65 11304.97 210-38 6. Top C 051716 JC Start 4°/100' DLS, -13.39° TF, for 139.37' 27 14264.96 90.42 262.21 6084.46 -1858.09 -11292.91 4.00 -13.39 11444.00 Hold for 66.23' Iceberg 28 14331.20 90.42 262.21 6083.97 -1867.06 -11358.53 0.00 0.00 11510.18 Start 3.25°/100' DLS, -132.27° TF, for 19.41' 29 14350.60 90.00 261.74 6083.9° -1869.77 -11377.74 3.25 -132.27 11529.57 2M-38 7. Landing 051716 JC Hold for 20' 5288.9 30 14370.60 90.00 261.74 6083.90 -1872.64 -11397.54 0.00 0.00 11549.56 Start 2°/100' DLS, 0° TF, for 28.2' C-35 3 1 14398.80 90.56 261.74 6083.76 -1876.69 -11425.45 2.00 0.00 11577.75 Hold for 1001.73' 32 1540°.53 90.56 261.74 6073.90 -2020.51 -12416.75 0.00 0.00 12578.97 2M-38 8. Crest 051716 JC Start 3°/100' DLS, -174.7° TF, for 75.15' 569P.9 33 15475.69 88.32 261.54 6074.63 -2031.44 -12491.10 3.00 -174.70 12654.08 Hold for 1094.91' CO T HRZ 34 16570.60 88.32 261.54 6106.75 -2192.52 -13573.62 0.00 0.00 13748.13 Start 3°/100' DLS, -83.51 ° TF, for 484.81' SYEJj e'���SoPrl 35 17055.41 90.00 247.09 6113.90 -2323.26 -14039.06 3.00 -83.51 14229.20 2M-38 9. Fault 2 051716 JC Start 4°/109' DLS, -72.51° TF, for 267.72' 19 RCARAMVA 0' 36 17323.13 93.20 236.86 6106.40 -2448.80 -14274.96 4.00 -72.51 14483.32 Hold for 131.35' 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 Ilision avoidance plan as set out in the audit pack. 1 approve it as the basis for the final well Dlan and wells drawin s. I also acknoW ed a that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by: Checked by I Accepted by: Approved by: Vinent Osara Nate BE Ifeanyi Ifesie 20, May 19 201 c s i 0 z 2M-38wp 3 9E Easting (4000 usft/in) T-36 \ -22 -23 A-17 2A-08 r 2A-12 A 2A-13 2V-0 -14 W SAK 18 Kuparuk 2A Pad - , - - 2A-14 2V-01 -13 2M-13 -20 1 P9 f � ?7 2 -1 A- 8 2 - 3 2A -15B-123 2A-26 r S'f�-1 14 2M-21 2M-06 2 -11 2M -192A-09 2A-04114 2A-05 2A-16 2M-20 z 2M-0 -10 2 -18 2H-16 2H-09 2H-02 2H-06 2B-08 21#02 S 3 17 c 0 pprkc`d 2M-25 -15 €Cuprk 2H-05 2B-07 Brfl3 y 2B-03 22 2H-0 2G-03 M- _ 2M-26 2M-22H-14AH-13 H-11 2H-07 04 2H- AL a �WO-0 2M-22 G-01 -30 2M-17 2H-14 2H-10 2H-01 2H-08 G-0` l 2 9 2 09A 1 2M-02 M-0 2M-1 2K-04 2K-03e�v 2K-05 2K-01 -16 -15 21-01 1,R15 K_p �L8 arkL �� 2K-07 2M-33 2 -04 2M -32L1 PB1 2M-08 2M -090 p 2G-14 4L1 cr�1 -13 2M-32L1PB 2M-34 2 ML,120 2G -14A 2G- AL2 2M-35 -13 -1 1 2 L 2fC- 2 -26 AL1 Easting (4000 usft/in) 2M-38wpl3 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 4000- 2000— 2M-38 2. Top HRZ 051716 C 21VI-38 1.C35 051716 J 2M-38 7. Landing 051716 J 0 00 C, -' 20" x 42"------ r I2M-38 6. Top C 051716 J 1000 N �- Q 13-3/8" x 1 oho ��O .� + `. 02000 �dj ? o o 7" x 8-3/�'- - - `_ d o Z- CD - o-- --- o _, ----- -___ .'4-1/2" x 6-1/8"--\ o _ 2M-38 3. Fault1 051716 J L 0 2M-38 8. Crest 051716 C - 2M-38 4. Base HRZ/Top Kuparuk 051716 JC -4000 12M-38 9. Fault 2 051716 J 21V!-�8 7.Climbing Point 021915 J 2M-38 5. K-1 051716 J 2M-38 10. TD 051716 J -6000— -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 West( -)/East(+) (2000 usft/in) 2M-38wpl 3 Section View -2000- 20" x 42" 0- Base Permafrost 00 Base West Sak 100 CampSS p0 0 2000 �''® ®� ' C-50 C-37 Top HRZ o o '� Iceberg Fault 1 (cross in HRZ) _ ... - o ami o 00 ° ,'o o o C-35 se HRZ/Top Kalubik 4000 13-3/8 - ---- , x 16 ----" ------------- CO N----- r .- -- -. o - --- ---,' - - - --K-1 - .__TD -in C4 a "Top -- -- _. ro s fit o 0 0 C -TD - o - ' � in C4 across fit w ^cv b o " " " " o 70 ~ ------------ - - C, o 6000 -- -- - - -- - ----------- --- ---- - _-- --- _ -__ - --- --- - - --- - �- -- _ --- __-- ------,-- - 0'), 00 CO 9-5/8" x 12-1/4" o o v 7" x 8-3/4" by 9-1/2"""-'" TD in C4 across flt 8000 Fault 2 (C to A2) 50-70' DTE) 4-1/2" x 6-1/8" I 0 2000 4000 6000 8000 10000 12000 14000 16000 Vertical Section at 260.00° (2000 usft/in) 1 2M-38wpl 3 Section View ,o ..... ... _ -- - 5400 Top HRZ 0 0 5550 ' Fault 1 (cross in HRZ) c � o0 0 0 �^ X5700 --------------- - Base HRZ/Top Kalubik Q- (1) , - r) 9-5/8" x 12-1/4" �oCO - -- K-1 X5850 ---_ _-____-----------------_'_ - - Top C TD in C4 across fit I -' TD in C4 across flt- ' 6 6000 - ----- -. ----- -- - 0 ,- --- 0 0 - ----- --- _ ----------- ------------- -a d o w o-' o ------------- CO 6150 0 ,--'' -o C) CO 7" x 8-3/4" by 9-1/2" Fault 2 (C to A2) 50-70' DTE)rD in C4 across fit 4-1/2" x 6-1/8" 9000 10000 11000 12000 13000 14000 15000 16000 17000 Vertical Section at 260.00° (1000 usft/in) 1 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-38 Plan: 2M-38 Plan: 2M-38wp13 Report Permit Pack 01 June, 2016 Surface location is 5ft West of 2M-23 r; TC Surface location is 5ft West of 2M-23 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-38 Wellbore: Plan: 2M-38 Design: 2M-38wpl3 Schlumberger Report Local Co-ordinate Reference: Well Plan: 2M-38 TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2M Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plam 2M-38 usft Latitude: usft Longitude: 0" Grid Convergence: Well Position +N/ -S 0.00 usft Northing: usft To +El -W 0.00 usft Easting: usft Position Uncertainty 0.00 usft Wellhead Elevation: usft Wellbore Plan: 2M-38 1,100.00 Magnetics Model Name Sample Date Declination 2,978.93 BGGM2016 8/15/2016 17.92 Design 2M-38wp13 14,350.60 2M-38wp13 (Plan: 2M-38) Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 39.00 0.00 Survey Tool Program Date 6/1/2016 From To (usft) (usft) Survey (Wellbore) 39.00 1,100.00 2M-38wp13 (Plan: 2M-38) 1,100.00 2,100.00 2M-38wp13 (Plan: 2M-38) 1,100.00 2,978.93 2M-38wp13 (Plan: 2M-38) 2,978.93 4,478.93 2M-38wpl3 (Plan: 2M-38) 2,978.93 12,950.54 2M-38wpl3 (Plan: 2M-38) 12,950.54 14,350.60 2M-38wpl3 (Plan: 2M-38) 12,950.54 14,350.60 2M-38wp13 (Plan: 2M-38) 14,350.60 15,850.60 2M-38wp13 (Plan: 2M-38) 14,350.60 18,687.21 2M-38wp13 (Plan: 2M-38) Planned Survey MWD+IFR-AK-CAZ-SC MD Inc Azi (azimuth) (usft) MWD 39.00 0.00 0.00 100.00 0.00 0.00 121.50 0.00 0.00 20" x 42" TVDSS 200.00 0.00 0.00 Latitude: Longitude: Ground Level: -0.10' 104.90 usft Dip Angle Field Strength (°) (nT) 80.88 57,538 Tie On Depth: 39.00 +E/ -W Direction (usft) (°) 0.00 260.00 Tool Name Description 6/1/2016 10:45:09AM Page 2 COMPASS 5000.1 Build 74 GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°/100usft) (°) (usft) 39.00 -104.90 0.00 0.00 0.00 100.00 -43.90 0.00 0.00 0.04 121.50 -22.40 0.00 0.00 0.19 200.00 56.10 0.00 0.00 0.19 6/1/2016 10:45:09AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (1) (1) (usft) (usft) (°/100usft) V) (usft) 275.00 0.00 0.00 275.00 131.10 0.00 0.00 0.30 KOP: Start 1.5°/100' DLS, 180° TF, for 325.39' 300.00 0.37 180.00 300.00 156.10 1.50 180.00 0.32 400.00 1.87 180.00 399.98 256.08 1.50 0.00 0.36 500.00 3.37 180.00 499.87 355.97 1.50 0.00 0.45 600.00 4.87 180.00 599.61 455.71 1.50 0.00 0.57 600.39 4.88 180.00 600.00 456.10 1.50 0.00 0.57 Start 2°1100' DLS, 0° TF, for 871.59' 700.00 6.87 180.00 699.08 555.18 2.00 0.00 0.70 800.00 8.87 180.00 798.13 654.23 2.00 0.00 0.85 900.00 10.87 180.00 896.64 752.74 2.00 0.00 1.01 1,000.00 12.87 180.00 994.50 850.60 2.00 0.00 1.19 1,100.00 14.87 180.00 1,091.58 947.68 2.00 0.00 1.38 1,200.00 16.87 180.00 1,187.76 1,043.86 2.00 0.00 1.49 1,300.00 18.87 180.00 1,282.93 1,139.03 2.00 0.00 1.63 1,400.00 20.87 180.00 1,376.97 1,233.07 2.00 0.00 1.92 1,471.98 22.31 180.00 1,443.90 1,300.00 2.00 0.00 2.20 Hold for 108.09' 1,500.00 22.31 180.00 1,469.82 1,325.92 0.00 0.00 2.32 1,526.03 22.31 180.00 1,493.90 1,350.00 0.00 0.00 2.69 Base Permafrost 1,580.08 22.31 180.00 1,543.90 1,400.00 0.00 0.00 2.69 Start 4°/100' DLS, 90° TF, for 1398.85' 1,600.00 22.33 182.10 1,562.33 1,418.43 4.00 90.00 2.77 1,700.00 22.80 192.46 1,654.71 1,510.81 4.00 88.06 3.11 1,800.00 23.90 202.18 1,746.56 1,602.66 4.00 78.48 3.44 1,900.00 25.56 210.89 1,837.41 1,693.51 4.00 69.56 3.78 2,000.00 27.67 218.49 1,926.84 1,782.94 4.00 61.64 4.16 2,100.00 30.13 225.01 2,014.40 1,870.50 4.00 54.85 4.59 2,200.00 32.88 230.59 2,099.67 1,955.77 4.00 49.13 2.53 2,300.00 35.83 235.37 2,182.23 2,038.33 4.00 44.38 2.75 2,400.00 38.95 239.49 2,261.68 2,117.78 4.00 40.43 3.01 2,500.00 42.20 243.09 2,337.64 2,193.74 4.00 37.15 3.31 2,600.00 45.55 246.26 2,409.72 2,265.82 4.00 34.42 3.65 2,700.00 48.97 249.08 2,477.59 2,333.69 4.00 32.13 4.03 2,800.00 52.45 251.61 2,540.91 2,397.01 4.00 30.22 4.43 2,886.72 55.52 253.63 2,591.90 2,448.00 4.00 28.61 4.87 Base West Salk 2,900.00 55.99 253.92 2,599.37 2,455.47 4.00 27.43 4.87 2,978.93 58.81 255.61 2,641.90 2,498.00 4.00 27.26 5.23 Hold for 20' - 13-318" x 16" 2,998.93 58.81 255.61 2,652.26 2,508.36 0.00 -153.56 5.33 Start 3.5°/100' DLS, 29.72° TF, for 463.26' 3,000.00 58.84 255.63 2,652.81 2,508.91 3.50 29.72 5.34 3,100.00 61.89 257.60 2,702.26 2,558.36 3.50 29.70 5.96 6/1/2016 10:45:09AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 3,200.00 64.97 259.46 2,746.98 2,603.08 3.50 28.73 6.87 3,300.00 68.08 261.22 2,786.81 2,642.91 3.50 27.90 7.99 3,400.00 71.20 262.91 2,821.60 2,677.70 3.50 27.20 9.26 3,462.19 73.15 263.93 2,840.64 2,696.74 3.50 26.61 10.10 Hold for 8314.89' 3,500.00 73.15 263.93 2,851.60 2,707.70 0.00 0.00 10.64 3,600.00 73.15 263.93 2,880.59 2,736.69 0.00 0.00 12.10 3,700.00 73.15 263.93 2,909.57 2,765.67 0.00 0.00 13.60 3,800.00 73.15 263.93 2,938.56 2,794.66 0.00 0.00 15.12 3,859.80 73.15 263.93 2,955.90 2,812.00 0.00 0.00 16.66 CampSS 3,900.00 73.15 263.93 2,967.55 2,823.65 0.00 0.00 16.66 4,000.00 73.15 263.93 2,996.54 2,852.64 0.00 0.00 18.22 4,100.00 73.15 263.93 3,025.53 2,881.63 0.00 0.00 19.78 4,200.00 73.15 263.93 3,054.52 2,910.62 0.00 0.00 21.36 4,300.00 73.15 263.93 3,083.51 2,939.61 0.00 0.00 22.94 4,400.00 73.15 263.93 3,112.50 2,968.60 0.00 0.00 24.53 4,500.00 73.15 263.93 3,141.49 2,997.59 0.00 0.00 11.23 4,600.00 73.15 263.93 3,170.48 3,026.58 0.00 0.00 11.77 4,700.00 73.15 263.93 3,199.47 3,055.57 0.00 0.00 12.31 4,800.00 73.15 263.93 3,228.45 3,084.55 0.00 0.00 12.85 4,900.00 73.15 263.93 3,257.44 3,113.54 0.00 0.00 13.40 5,000.00 73.15 263.93 3,286.43 3,142.53 0.00 0.00 13.95 5,100.00 73.15 263.93 3,315.42 3,171.52 0.00 0.00 14.50 5,200.00 73.15 263.93 3,344.41 3,200.51 0.00 0.00 15.06 5,300.00 73.15 263.93 3,373.40 3,229.50 0.00 0.00 15.62 5,400.00 73.15 263.93 3,402.39 3,258.49 0.00 0.00 16.18 5,500.00 73.15 263.93 3,431.38 3,287.48 0.00 0.00 16.74 5,600.00 73.15 263.93 3,460.37 3,316.47 0.00 0.00 17.31 5,700.00 73.15 263.93 3,489.36 3,345.46 0.00 0.00 17.87 5,800.00 73.15 263.93 3,518.34 3,374.44 0.00 0.00 18.44 5,900.00 73.15 263.93 3,547.33 3,403.43 0.00 0.00 19.01 6,000.00 73.15 263.93 3,576.32 3,432.42 0.00 0.00 19.58 6,100.00 73.15 263.93 3,605.31 3,461.41 0.00 0.00 20.15 6,200.00 73.15 263.93 3,634.30 3,490.40 0.00 0.00 20.73 6,300.00 73.15 263.93 3,663.29 3,519.39 0.00 0.00 21.30 6,400.00 73.15 263.93 3,692.28 3,548.38 0.00 0.00 21.87 6,500.00 73.15 263.93 3,721.27 3,577.37 0.00 0.00 22.45 6,600.00 73.15 263.93 3,750.26 3,606.36 0.00 0.00 23.03 6,700.00 73.15 263.93 3,779.25 3,635.35 0.00 0.00 23.60 6,800.00 73.15 263.93 3,808.23 3,664.33 0.00 0.00 24.18 6,900.00 73.15 263.93 3,837.22 3,693.32 0.00 0.00 24.76 7,000.00 73.15 263.93 3,866.21 3,722.31 0.00 0.00 25.34 7,100.00 73.15 263.93 3,895.20 3,751.30 0.00 0.00 25.91 7,200.00 73.15 263.93 3,924.19 3,780.29 0.00 0.00 26.49 6/1/2016 10:45:09AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl 3 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (°) (°) (usft) (usft) (°/100usft) (°) (usft) 7,300.00 73.15 263.93 3,953.18 3,809.28 0.00 0.00 27.07 7,336.98 73.15 263.93 3,963.90 3,820.00 0.00 0.00 27.65 C-50 7,400.00 73.15 263.93 3,982.17 3,838.27 0.00 0.00 27.65 7,500.00 73.15 263.93 4,011.16 3,867.26 0.00 0.00 28.23 7,600.00 73.15 263.93 4,040.15 3,896.25 0.00 0.00 28.81 7,700.00 73.15 263.93 4,069.14 3,925.24 0.00 0.00 29.40 7,800.00 73.15 263.93 4,098.13 3,954.23 0.00 0.00 29.98 7,900.00 73.15 263.93 4,127.11 3,983.21 0.00 0.00 30.56 8,000.00 73.15 263.93 4,156.10 4,012.20 0.00 0.00 31.14 8,100.00 73.15 263.93 4,185.09 4,041.19 0.00 0.00 31.72 8,200.00 73.15 263.93 4,214.08 4,070.18 0.00 0.00 32.31 8,300.00 73.15 263.93 4,243.07 4,099.17 0.00 0.00 32.89 8,400.00 73.15 263.93 4,272.06 4,128.16 0.00 0.00 33.47 8,500.00 73.15 263.93 4,301.05 4,157.15 0.00 0.00 34.06 8,600.00 73.15 263.93 4,330.04 4,186.14 0.00 0.00 34.64 8,700.00 73.15 263.93 4,359.03 4,215.13 0.00 0.00 35.22 8,800.00 73.15 263.93 4,388.02 4,244.12 0.00 0.00 35.81 8,900.00 73.15 263.93 4,417.00 4,273.10 0.00 0.00 36.39 9,000.00 73.15 263.93 4,445.99 4,302.09 0.00 0.00 36.97 9,100.00 73.15 263.93 4,474.98 4,331.08 0.00 0.00 37.56 9,200.00 73.15 263.93 4,503.97 4,360.07 0.00 0.00 38.14 9,300.00 73.15 263.93 4,532.96 4,389.06 0.00 0.00 38.73 9,400.00 73.15 263.93 4,561.95 4,418.05 0.00 0.00 39.31 9,500.00 73.15 263.93 4,590.94 4,447.04 0.00 0.00 39.90 9,600.00 73.15 263.93 4,619.93 4,476.03 0.00 0.00 40.48 9,700.00 73.15 263.93 4,648.92 4,505.02 0.00 0.00 41.07 9,800.00 73.15 263.93 4,677.91 4,534.01 0.00 0.00 41.65 9,855.17 73.15 263.93 4,693.90 4,550.00 0.00 0.00 42.24 C-37 9,900.00 73.15 263.93 4,706.90 4,563.00 0.00 0.00 42.24 10,000.00 73.15 263.93 4,735.88 4,591.98 0.00 0.00 42.82 10,044.90 73.15 263.93 4,748.90 4,605.00 0.00 0.00 43.41 Iceberg 10,100.00 73.15 263.93 4,764.87 4,620.97 0.00 0.00 43.41 10,200.00 73.15 263.93 4,793.86 4,649.96 0.00 0.00 44.00 10,300.00 73.15 263.93 4,822.85 4,678.95 0.00 0.00 44.58 10,400.00 73.15 263.93 4,851.84 4,707.94 0.00 0.00 45.17 10,500.00 73.15 263.93 4,880.83 4,736.93 0.00 0.00 45.75 10,600.00 73.15 263.93 4,909.82 4,765.92 0.00 0.00 46.34 10,700.00 73.15 263.93 4,938.81 4,794.91 0.00 0.00 46.93 10,800.00 73.15 263.93 4,967.80 4,823.90 0.00 0.00 47.51 10,900.00 73.15 263.93 4,996.79 4,852.89 0.00 0.00 48.10 11,000.00 73.15 263.93 5,025.77 4,881.87 0.00 0.00 48.69 6/1/2016 10:45:09AM Page 5 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit 5,610.19 Site: Kuparuk 2M Pad TVD Reference: Well: Plan: 2M-38 Plan: 39+104.9 @ 143.90usft (Doyon142) 5,650.25 Wellbore: Plan: 2M-38 Plan: 39+104.9 @ 143.90usft (Doyon142) 61.21 Design: 2M-38wp13 True 0.00 Planned Survey Survey Calculation Method: Minimum Curvature MD Inc Azi (azimuth) (usft) 62.65 OAKEDMP2 11,100.00 73.15 263.93 11,200.00 73.15 263.93 11,300.00 73.15 263.93 11,400.00 73.15 263.93 11,500.00 73.15 263.93 11,600.00 73.15 263.93 11,700.00 73.15 263.93 11,777.08 73.15 263.93 Start 2°/100' DLS, 172.94° TF, for 313.2' 5,141.73 11,800.00 72.69 263.99 11,899.18 70.73 264.25 C-35 0.00 51.62 11,900.00 70.71 264.25 12,000.00 68.72 264.51 12,090.28 66.93 264.76 Adjust TF to 5.17°, for 3.81' 5,107.14 12,094.09 67.01 264.77 Hold for 856.45' 5,113.87 2.00 12,100.00 67.01 264.77 12,200.00 67.01 264.77 12,300.00 67.01 264.77 12,400.00 67.01 264.77 12,500.00 67.01 264.77 12,600.00 67.01 264.77 12,700.00 67.01 264.77 12,800.00 67.01 264.77 12,900.00 67.01 264.77 12,950.54 67.01 264.77 Adjust TF to 0°, for 20'- Top HRZ - 9-5/8" x 12-1/4" 12,970.54 67.01 264.77 Start 3.5°/100' DLS, -174.83° TF, for 35.09' 5,439.81 13,000.00 65.98 264.67 13,005.64 65.79 264.65 Hold for 41.01' 0.00 56.35 13,046.65 65.79 264.65 Start 3°/100' DLS, 3.21° TF, for 0.78' 56.94 13,047.43 65.81 264.65 Start 2°/100' DLS, 0.64° TF, for 28.91' 57.52 13,076.34 66.39 264.66 Hold for 352.74' 58.11 5,635.10 13,100.00 66.39 264.66 13,200.00 66.39 264.66 13,300.00 66.39 264.66 13,306.74 66.39 264.66 Fault 1 (cross in HRZ) 59.58 5,701.71 13,400.00 66.39 264.66 Schlumberger Report Local Co-ordinate Reference: Well Plan: 2M-38 5,610.19 0.00 TVD Reference: 60.53 Plan: 39+104.9 @ 143.90usft (Doyon142) 5,650.25 MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) 61.21 North Reference: True 0.00 0.00 Survey Calculation Method: Minimum Curvature 5,693.00 0.00 Database: 62.65 OAKEDMP2 5,730.35 0.00 TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°/100usft) (°) (usft) 5,054.76 4,910.86 0.00 0.00 49.27 5,083.75 4,939.85 0.00 0.00 49.86 5,112.74 4,968.84 0.00 0.00 50.45 5,141.73 4,997.83 0.00 0.00 51.03 5,170.72 5,026.82 0.00 0.00 51.62 5,199.71 5,055.81 0.00 0.00 52.21 5,228.70 5,084.80 0.00 0.00 52.79 5,251.04 5,107.14 0.00 0.00 53.25 5,257.77 5,113.87 2.00 172.94 53.36 5,288.90 5,145.00 2.00 172.93 53.77 5,289.17 5,145.27 2.00 172.85 53.77 5,323.83 5,179.93 2.00 172.84 54.18 5,357.90 5,214.00 2.00 172.75 54.55 5,359.39 5,215.49 2.00 5.17 54.57 5,361.70 5,217.80 0.00 19.72 54.60 5,400.76 5,256.86 0.00 0.00 55.18 5,439.81 5,295.91 0.00 0.00 55.77 5,478.87 5,334.97 0.00 0.00 56.35 5,517.93 5,374.03 0.00 0.00 56.94 5,556.99 5,413.09 0.00 0.00 57.52 5,596.04 5,452.14 0.00 0.00 58.11 5,635.10 5,491.20 0.00 0.00 58.69 5,674.16 5,530.26 0.00 0.00 59.28 5,693.90 5,550.00 0.00 0.00 59.58 5,701.71 5,557.81 0.00 0.00 59.70 5,713.46 5,569.56 3.50 -174.83 59.89 5,715.76 5,571.86 3.50 -174.79 59.92 5,732.58 5,588.68 0.00 -175.20 60.18 5,732.90 5,589.00 3.00 3.21 60.18 5,744.61 5,600.71 2.00 0.64 60.37 5,754.09 5,610.19 0.00 0.00 60.53 5,794.15 5,650.25 0.00 0.00 61.21 5,834.20 5,690.30 0.00 0.00 61.91 5,836.90 5,693.00 0.00 0.00 62.65 5,874.25 5,730.35 0.00 0.00 62.65 6/1/2016 10:45:09AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl3 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (1 (°) (usft) (usft) (°/100usft) (°) (usft) 13,429.08 66.39 264.66 5,885.90 5,742.00 0.00 0.00 62.87 Start 2.2°/100' DLS, 179.81° TF, for 56.3' 13,473.17 65.42 264.66 5,903.90 5,760.00 2.20 179.81 63.30 Base HRZ/Top Kalubik 13,485.38 65.15 264.66 5,909.01 5,765.11 2.20 179.81 63.30 Hold for 14.02' 13,499.40 65.15 264.66 5,914.90 5,771.00 0.00 0.00 63.41 Start 3.07°/100' DLS, -3.21° TF, for 159.81' 13,500.00 65.17 264.66 5,915.15 5,771.25 3.07 -3.21 63.41 13,600.00 68.23 264.48 5,954.70 5,810.80 3.07 -3.21 64.22 13,659.22 70.04 264.37 5,975.79 5,831.89 3.07 -3.13 64.72 Hold for 8.56' 13,667.78 70.04 264.37 5,978.71 5,834.81 0.00 -2.70 64.79 Start 3.5°/100' DLS, 7.3° TF, for 27.55' 13,695.33 71.00 264.50 5,987.90 5,844.00 3.50 7.30 65.02 Adjust TF to -11.43°, for 160.19' - K-1 13,700.00 71.16 264.47 5,989.41 5,845.51 3.50 -11.43 65.06 13,800.00 74.59 263.75 6,018.85 5,874.95 3.50 -11.42 65.97 13,855.52 76.29 263.40 6,033.00 5,889.10 3.11 -11.21 66.48 Hold for 27.31' 13,882.83 76.29 263.40 6,039.47 5,895.57 0.00 0.00 66.74 Start 3.5°/100' DLS, 0.65° TF, for 242.77' 13,900.00 76.89 263.41 6,043.46 5,899.56 3.50 0.65 66.90 14,000.00 80.39 263.45 6,063.15 5,919.25 3.50 0.65 67.86 14,058.57 82.44 263.47 6,071.90 5,928.00 3.50 0.64 68.84 Top C 14,100.00 83.89 263.49 6,076.83 5,932.93 3.50 0.63 68.84 14,125.60 85.00 263.50 6,078.90 5,935.00 4.35 0.63 69.10 Start 4°/100' DLS, -13.39° TF, for 139.37' - TD in C4 across fit 14,200.00 87.90 262.81 6,083.51 5,939.61 4.00 -13.39 69.87 14,264.96 90.42 262.21 6,084.46 5,940.56 4.00 -13.34 70.54 Hold for 66.23' 14,300.00 90.42 262.21 6,084.20 5,940.30 0.00 0.00 70.90 14,331.20 90.42 262.21 6,083.97 5,940.07 0.00 0.00 71.23 Start 3.25°/100' DLS, -132.27° TF, for 19.41' 14,350.60 90.00 261.74 6,083.90 5,940.00 3.25 -132.27 62.60 Hold for 20' - 7" x 8-3/4" by 9-1/2" 14,370.60 90.00 261.74 6,083.90 5,940.00 0.00 -132.27 62.74 Start 2°/100' DLS, 0° TF, for 28.2' 14,398.80 90.56 261.74 6,083.76 5,939.86 2.00 0.00 62.95 Hold for 1001.73' 14,400.00 90.56 261.74 6,083.75 5,939.85 0.00 0.00 62.96 14,500.00 90.56 261.74 6,082.76 5,938.86 0.00 0.00 63.70 14,600.00 90.56 261.74 6,081.78 5,937.88 0.00 0.00 64.48 14,700.00 90.56 261.74 6,080.80 5,936.90 0.00 0.00 65.29 14,800.00 90.56 261.74 6,079.81 5,935.91 0.00 0.00 66.14 6/1/2016 10:45:09AM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey MD Inc Azi (azimuth) TVD TVDSS DLeg TFace Lat. Error (usft) (1) V) (usft) (usft) (°/100usft) V) (usft) 14,900.00 90.56 261.74 6,078.83 5,934.93 0.00 0.00 67.02 15,000.00 90.56 261.74 6,077.84 5,933.94 0.00 0.00 67.92 15,100.00 90.56 261.74 6,076.86 5,932.96 0.00 0.00 68.86 15,200.00 90.56 261.74 6,075.87 5,931.97 0.00 0.00 69.82 15,300.00 90.56 261.74 6,074.89 5,930.99 0.00 0.00 70.81 15,400.00 90.56 261.74 6,073.91 5,930.01 0.00 0.00 71.82 15,400.53 90.56 261.74 6,073.90 5,930.00 0.00 0.00 71.82 Start 3°/100' DLS, -174.7° TF, for 75.15' 15,475.69 88.32 261.54 6,074.63 5,930.73 3.00 -174.70 72.59 Hold for 1094.91' 15,500.00 88.32 261.54 6,075.35 5,931.45 0.00 0.00 72.84 15,600.00 88.32 261.54 6,078.28 5,934.38 0.00 0.00 73.90 15,700.00 88.32 261.54 6,081.21 5,937.31 0.00 0.00 74.98 15,800.00 88.32 261.54 6,084.15 5,940.25 0.00 0.00 76.08 15,900.00 88.32 261.54 6,087.08 5,943.18 0.00 0.00 66.30 16,000.00 88.32 261.54 6,090.01 5,946.11 0.00 0.00 66.58 16,100.00 88.32 261.54 6,092.95 5,949.05 0.00 0.00 66.86 16,200.00 88.32 261.54 6,095.88 5,951.98 0.00 0.00 67.14 16,300.00 88.32 261.54 6,098.81 5,954.91 0.00 0.00 67.43 16,400.00 88.32 261.54 6,101.75 5,957.85 0.00 0.00 67.72 16,500.00 88.32 261.54 6,104.68 5,960.78 0.00 0.00 68.02 16,570.60 88.32 261.54 6,106.75 5,962.85 0.00 0.00 68.23 Start 3°/100' DLS, -83.51° TF, for 484.81' 16,600.00 88.42 260.66 6,107.59 5,963.69 3.00 -83.51 68.30 16,700.00 88.76 257.68 6,110.05 5,966.15 3.00 -83.48 68.41 16,800.00 89.11 254.70 6,111.91 5,968.01 3.00 -83.41 68.34 16,900.00 89.46 251.72 6,113.16 5,969.26 3.00 -83.35 68.09 17,000.00 89.81 248.74 6,113.81 5,969.91 3.00 -83.31 67.66 17,055.41 90.00 247.09 6,113.90 5,970.00 3.00 -83.29 67.35 Start 4°/100' DLS, -72.51° TF, for 267.72'- Fault 2 (C to A2) 50-70' DTE) 17,100.00 90.54 245.39 6,113.69 5,969.79 4.00 -72.51 66.93 17,200.00 91.74 241.57 6,111.71 5,967.81 4.00 -72.52 65.79 17,300.00 92.93 237.75 6,107.64 5,963.74 4.00 -72.60 64.35 17,323.13 93.20 236.86 6,106.40 5,962.50 4.00 -72.75 63.98 Hold for 131.35' 17,400.00 93.20 236.86 6,102.11 5,958.21 0.00 0.00 64.22 17,454.48 93.20 236.86 6,099.07 5,955.17 0.00 0.00 64.39 Start 4°/100' DLS, 95.96° TF, for 707.59' 17,500.00 93.01 238.68 6,096.60 5,952.70 4.00 95.96 65.42 17,600.00 92.58 242.66 6,091.72 5,947.82 4.00 96.06 67.43 17,700.00 92.14 246.64 6,087.60 5,943.70 4.00 96.25 69.13 17,800.00 91.69 250.61 6,084.26 5,940.36 4.00 96.42 70.51 17,900.00 91.23 254.59 6,081.72 5,937.82 4.00 96.55 71.55 18,000.00 90.76 258.56 6,079.98 5,936.08 4.00 96.65 72.27 18,100.00 90.29 262.53 6,079.06 5,935.16 4.00 96.72 72.64 6/1/2016 10:45 09AM Page 8 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad (Doyon142) Well: Plan: 2M-38 MD Reference: Wellbore: Plan: 2M-38 (Doyon142) Design: 2M-38wp13 North Reference: Planned Survey MD Inc Azi (azimuth) (usft) (1) V) 18,162.07 90.00 265.00 Start 2°/100' DLS, 90° TF, for 409.48' OAKEDMP2 18,200.00 90.00 265.76 18,300.00 90.00 267.76 18,400.00 90.00 269.76 18,500.00 90.00 271.76 18,571.55 90.00 273.19 Hold for 115.66' 96.76 18,600.00 90.00 273.19 18,687.21 90.00 273.19 TD: 18687.21' MD, 6078.9' TVD 6,078.90 5,935.00 Schlumberger Report Local Co-ordinate Reference: Well Plan: 2M-38 TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°/100usft) C) (usft) 6,078.90 5,935.00 4.00 96.76 72.70 6,078.90 5,935.00 2.00 90.00 72.76 6,078.90 5,935.00 2.00 90.00 72.84 6,078.90 5,935.00 2.00 90.00 72.84 6,078.90 5,935.00 2.00 90.00 72.76 6,078.90 5,935.00 2.00 90.00 72.65 6,078.90 5,935.00 0.00 0.00 72.75 6,078.90 5,935.00 0.00 0.00 73.05 6/1/2016 10:45:09AM Page 9 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit ND Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 7,336.98 3,963.90 C-50 2,886.72 2,591.90 Base West Sak 13,473.17 5,903.90 Base HRZ/Top Kalubik 17,055.41 6,113.90 Fault 2 (C to A2) 50-70' DTE) 12,950.54 5,693.90 Top HRZ 14,058.57 6,071.90 Top C 14,125.60 6,078.90 TD in C4 across flt 9,855.17 4,693.90 C-37 3,859.80 2,955.90 CampSS 1,526.03 1,493.90 Base Permafrost 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 5,288.90 C-35 0.00 13,306.74 5,836.90 Fault 1 (cross in HRZ) 6/112016 10:45:09AM Page 10 COMPASS 5000.1 Build 74 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl 3 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1) (�) 7,336.98 3,963.90 C-50 2,886.72 2,591.90 Base West Sak 13,473.17 5,903.90 Base HRZ/Top Kalubik 17,055.41 6,113.90 Fault 2 (C to A2) 50-70' DTE) 12,950.54 5,693.90 Top HRZ 14,058.57 6,071.90 Top C 14,125.60 6,078.90 TD in C4 across flt 9,855.17 4,693.90 C-37 3,859.80 2,955.90 CampSS 1,526.03 1,493.90 Base Permafrost 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 5,288.90 C-35 0.00 13,306.74 5,836.90 Fault 1 (cross in HRZ) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 275.00 275.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 180° TF, for 325.39' 600.39 600.00 -13.85 0.00 Start 2°/100' DLS, 0° TF, for 871.59' 1,471.98 1,443.90 -217.96 0.00 Hold for 108.09' 1,580.08 1,543.90 -259.00 0.00 Start 4'/100' DLS, 90° TF, for 1398.85' 2,978.93 2,641.90 -709.61 -630.46 Hold for 20' 2,998.93 2,652.26 -713.86 -647.03 Start 3.5°/100' DLS, 29.72° TF, for 463.26' 3,462.19 2,840.64 -787.03 -1,062.17 Hold for 8314.89' 11,777.08 5,251.04 -1,628.84 -8,975.36 Start 2°/100' DLS, 172.94° TF, for 313.2' 12,090.28 5,357.90 -1,657.88 -9,268.17 Adjust TF to 5.17°, for 3.81' 12,094.09 5,359.39 -1,658.20 -9,271.66 Hold for 856.45' 12,950.54 5,693.90 -1,730.07 -10,056.81 Adjust TF to 0°, for 20' 12,970.54 5,701.71 -1,731.75 -10,075.14 Start 3.5°/100' DLS, -174.83° TF, for 35.09' 13,005.64 5,715.76 -1,734.71 -10,107.16 Hold for 41.01' 13,046.65 5,732.58 -1,738.20 -10,144.40 Start 3°/100' DLS, 3.21° TF, for 0.78' 13,047.43 5,732.90 -1,738.27 -10,145.11 Start 2°/100' DLS, 0.64° TF, for 28.91' 13,076.34 5,744.61 -1,740.73 -10,171.43 Hold for 352.74' 13,429.08 5,885.90 -1,770.83 -10,493.23 Start 2.2°/100' DLS, 179.81° TF, for 56.3' 13,485.38 5,909.01 -1,775.61 -10,544.35 Hold for 14.02' 13,499.40 5,914.90 -1,776.79 -10,557.02 Start 3.07°/100' DLS, -3.21° TF, for 159.81' 13,659.22 5,975.79 -1,790.91 -10,704.05 Hold for 8.56' 13,667.78 5,978.71 -1,791.70 -10,712.06 Start 3.5°/100' DLS, 7.3° TF, for 27.55' 13,695.33 5,987.90 -1,794.22 -10,737.91 Adjust TF to -11.43°, for 160.19' 13,855.52 6,033.00 -1,810.43 -10,890.71 Hold for 27.31' 6/1/2016 10:45:09AM Page 11 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan. 2M-38 Wellbore: Plan: 2M-38 Design: 2M-38wp13 Casing Points Formations Schlumberger Report Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 2M-38 Plan: 39+104.9 @ 143.90usft (Doyon142) Plan: 39+104.9 @ 143.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Measured Vertical C-50 Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name TD in C4 across flt 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Measured Depth (usft) 7,336.98 2,886.72 13,473.17 17, 055.41 12,950.54 14,058.57 14,125.60 9,855.17 3,859.80 1,526.03 13,695.33 10, 044.90 11,899.18 13,306.74 13, 882.83 14,125.60 14,264.96 14,331.20 14,350.60 14, 370.60 14,398.80 15,400.53 15,475.69 16,570.60 17,055.41 17,323.13 17,454.48 18,162.07 18, 571.55 18,687.21 Vertical Depth (usft) 3,963.90 2,591.90 5,903.90 6,113.90 5,693.90 6,071.90 6,078.90 4,693.90 2,955.90 1,493.90 5,987.90 4,748.90 5,288.90 5,836.90 6,039.47 6,078.90 6,084.46 6,083.97 6,083.90 6,083.90 6,083.76 6,073.90 6,074.63 6,106.75 6,113.90 6,106.40 6,099.07 6,078.90 6,078.90 6,078.90 Name C-50 Base West Sak Base HRZ/Top Kalubik Fault 2 (C to A2) 50-70' DTE) Top HRZ Top C TD in C4 across flt C-37 CampSS Base Permafrost K-1 Iceberg C-35 Fault 1 (cross in HRZ) -1,813.48 -10,917.06 -1,840.77 -11,154.79 -1,858.09 -11,292.91 -1,867.06 -11,358.53 -1,869.77 -11,377.74 -1,872.64 -11,397.54 -1,876.69 -11,425.45 -2,020.51 -12,416.75 -2,031.44 -12,491.10 -2,192.52 -13,573.62 -2,323.26 -14,039.06 -2,448.80 -14,274.96 -2,520.49 -14,384.78 -2,749.09 -15,046.53 -2,755.55 -15,455.61 -2,749.12 -15,571.09 Dip Dip Direction Lithology (1) (') 0.00 Start 3.5°/100' DLS, 0.65° TF, for 242.77' Start 4°/100' DLS, -13.39° TF, for 139.37' Hold for 66.23' Start 3.25°/100' DLS, -132.27° TF, for 19.41' Hold for 20' Start 2°/100' DLS, 0° TF, for 28.2' Hold for 1001.73' Start 3°/100' DLS, -174.7° TF, for 75.15' Hold for 1094.91' Start 3°/100' DLS, -83.51' TF, for 484.81' Start 4°/100' DLS, -72.51' TF, for 267.72' Hold for 131.35' Start 4°/100' DLS, 95.96° TF, for 707.59' Start 2°/100' DLS, 90° TF, for 409.48' Hold for 115.66' TD: 18687.21' MD, 6078.9' TVD Checked By: Approved By: Date: 6/1/2016 10:45:09AM Page 12 COMPASS 5000.1 Build 74 MD CL Inc Aa TVD TVDSS MS F'�•Y Northing Fasting Dogleg T.Face {usft)Section Type Target -1 39.00 0.00: 0.00 39.00 -104.90 0,00 0.00 5948735.92 1623396,78 0.00 0.00 Tieune 2 275,00: -3 236.00 0400 0.00 275.00 131.10 0.00 0.00 5948735.92 1628396 78 0.00 000:Str' tMD 600.39; 325,39 4,88 131.00:: 600.00 456.10 -13.85 0.00 594872207 1629396.76: 1.50 180.00 -DT2TVD -. 4 147L98. 871.59 2231 180.00 -. 1443.90 1.300.00 -217.96 0.00 5948517.98.E 1629396.43..1 2.00 5 1580.08 108.09. 2231 180,00 ; 1543 90 _ 74W.00 : -259,00. 0,00 5948476,94 1628396.37 0,00 0.00 Stra tTVD J 6 2978.93 3398.85 5&81 255.61. 264190 2998.W -709.61 -63D.46 5948027,39. 162776%25' 4.D0 90.00 DT2TVD 7 2998.93 20.00 58,81- 255.61 265126 = 2508.36 -713.86. -647.03 5948023.17 3627748,68. 0.00 0.00 '.5 trn 8 346119 463.25 73.15 _ 263.93 2890.64. 2696.74 _ -787,03 _ -106117 5947950.66 1627333.46 3.50 .29.72 OPT AL DLS 9 11777.08 8314.89 .73,15. _ 26393 5251.04 5107.14 -1628.84 -8975. 594712Y.58 1619419.72 0,00 - - 0,00 (dltip) 30 12090,28 313.91'. 66.93•, 264.76. 5357.90 5214.00 -1657.88• 9268.17 5947093.01 1619I26.90. 2.00 172.94 (ditto) 2M-38 I.C3S051716 JC 11 12094.09 � 3.8Y � ... - 67.01- .. .. .. 264,77 5359.39 � _ .. 5215.49, -164E,20 -..- 4k!MW 927166 -.. .. 594709270 - 1619723,1. .. 2.00 5.17 DTSCiTang 12 12950.54 656.45 67.01. 264.77 -. 5693.90 5550.00 '�. -1730.07 -1tk156.81' 5947)2109 1618338,22 - 0.00 0.00 {ditto) -. ' 13 12970.54'. 20.00 67.01 - 264.77. 5911.71 5557.81 - -173L75 -10075.14 5947120,44 1618319.89 0.00 0.00 Straight MD 14 13005.64 35,09 65,79 %4.65. 5715.76 5571.86 • -1734.73 - 10107.16 5947017.52. 1613287,87 3.50 -174.83 OPT AL IMS 15 13046,65 - 41.01 : 65.79 --55.81 - - 264.65 5732.58 - 5598.68 -1739,93 -10144.40 5947014,10 1613250.63 0.00_ 0.00 (diko}. - Ib 33047.43 0.78 254.65' 5732.90, 5589.00 -1738.27- -10145.11 5947014,03 ,- 1618249.92; _-� -3.00-- _ -- - 3.21' (ditth) 2M-361 TOPHRZ 051716 JC 17 13076.34 78.91 _ 66.39 264.66'. 5744.61. 5600.71- -1740.73 -1770,83 -10171.43 594.0111,61: 1618223.60- 100 0.64 DT5 CH Tang 16 13429.08 352,74 66.39 264,66. 5885.90 5742,00 -10493.23 5M982.03' 161790L78 0.00 _ _ 0.00 (a-)226-38 3, FauIt1051735 JC 19 13485.38 56.E 65.15 264:66 5909 .01 5765,11 -1775.61 44 -105.35 5446977.33 1617850.66' 220. 179.81 DT5 CH Tang 20 13499.90 14.02 65.15 264,66 5914,90 .5771.00 -1776.79 -10557.02 594697&17 1617837,99 0.00 0,00 Oft) 2M-384. 629 HRZ/Top Kupaivk 651716 JC 21 13659,22 159.81- 7104 -70,04 264.37' 5975479: 5831,89 -1790.91. -10704.05 5945962,28 1617693.95 3.07 -3.21 OPT AL DLS Z2 13667.78 - 8.56 .... -. 264.37 5978.71 5634.81 ... -179L70 , -10712.06 5946961.51 1617682,94 0,00 - 0.00 23 13695.33 27.55: 71.00'. 264.50 5987,90 5844.00 -1794.22 - _ -10737,91 5946959.03 1617657.09: .-. .... 3,50- -, .. -. - 7.30 (Gttcj 2M-385, K-1 61716 1716 70 24 13855.52 360,19 76.29: 263,40 • 603300 5889,10 -1810,43 10890.71 5446943106 1617504.28 3.50 -11.43.OPT AL INS 25 1388283 27.31•, 76.29 263.40_... 6039,47 5895,57 41348 30917.06 59%940.06 1617477.42 0.00_ 0.00 26 14125.60 24177 85.00 263.50 • 6078.90 5935.00 -1890.77 -11154.'7 5946913.15 1617240.18 -_ 3.50 0.65 (ditln)226-38 6. TOP C 051716 x 27 14264.96 - 139.37 90.42• 262.21 6084.46. 5940.% -1858,09' -11292.91 5946896.06' 1617102.05 4.00 -13,39 OPT AL DIS 28 14331.20. - 66.23 90.02 _... . ...._ 252.21 - .. 6083.97 -. 5940.07 -1867.06 -1135&53 5946887.19 1617036.42 • 0T, , 0.00 (diad) 79 14350.60.. 19.91! 9000: 261.74 6083.90 5990.00 -3869.77 - -11377.74 -. 5946884.51. 1617017,29! 3.25 .. -132.27 (ditto) - _. 61716 94-387. Lar�hg 05171630 .. 29 14370.60: 20.00 90.00 - 261.74 6083.90. 5940,00 -1372.64 -11397.54 5996881,67; 1616947.40 -. oboo Itm 31 14398.80 . 29.20 - ... ,. 9D.56' 261,74 6083,76 5939,86 -W&119 -11425.45 5946877.67 1615959.49. 2.00 0.00 DTS CH Twg 32 15400.53 , 1001.73. 90.56 261.74 6673.90. 5930.00 -202.0.51 -12416.75 5946735.44 1615978.06 ... ... 0.00 0. W {dikoj -.. 226-38 8. Crest 053716 ]C . 33 15475,69: 75.15 88.32 261.54 6079.63 5930.73 -2!031.44. -12491:10 5946724.64. 1615903.70 3.00 -174.71 -OPT AL DLS 34 16570,60 ... _ 1094.91 _.. 88.32 261.54 . - _ 6106,75 _. 5962.85 ... -2192.51. -1357362 5946565.x.. 1614921.04 0,00 - 0,04 [ditto) 35 17055,41 484.81: 90.00 247.09 6113.90 5971.00 -2323.26 _ .. -14039.06 - . 5946435.32 1614355.43' . _ .. .. 3.00' - ... -sim 6fitto) - 1226-389. Fau02051716 JC 36 ll323. 13 267.72 - 93.20.. 226,86 6106.40 - _ 596150 -2448.80 _ -14274.96 5946310.17: 1614119.35 4.00 -72.51 OPT AL DLS v 37 17454.48 _- 131.35 _ 93 D3' 236:86 6099.07 5955,17 - -2591,49 -19384.79 5946 11 238.66 161929]9.43 0.00 - 0.00 - - -- (mtw) - -- - ". 38 18167.07 717.59 90.00: 265.00 - 6078.90 - 5935.00 . -2749.09 -15046.53 9996011.14 1613347.29 4.00 95.96 (ditto) ZM-387.MTi hlg Pant 021915 JC 39 18573.55 _ 409.48.. - 90,E - - 273..19 6078.90 5935.00 - -2755.55 - -15455,61 %46W5.33 - 1612938:33 2.00 - 90.00 OTSCHTaN 90 18687.21 . 115.66 • 90.00 27119 6078.93 5935.00 -2749.12 . -15571.09 594601L95 161282'187 - 0,00 0.00 - {tllttn) 2M-38 10, TD 051716 K . ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-38 Plan: 2M-38 50103xxxxx00 2M-38wp13 Clearance Summary Anticollision Report 01 June, 2016 Fail Anti -Collis( Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-38 - Plan: 2M-38 - 2M-38wp13 Well Coordinates: Datum Height: Plan: 39+104.9 @ 143.90usft (Doyon142) Scan Range: 0.00 to 18,687.21 usft. Measured Depth. Scan Radius is 2,064.82 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-38 - 2M-38wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-38 - Plan: 2M-38 - 2M-38wp13 Scan Range: 0.00 to 18,687.21 usft. Measured Depth. Scan Radius is 2,064.82 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft Kuparuk 2M Pad 2M-02 - 2M-02 - 2M-02 3,630.38 387.74 3,630.38 311.39 3,025.00 5.079 Centre Distance Pass - Major Risk 2M-02 - 2M-02 - 2M-02 3,685.53 391.27 3,685.53 306.89 3,100.00 4.637 Clearance Factor Pass - Major Risk 2M-07 - 2M-07 - 2M-07 143.90 429.34 143.90 426.51 146.00 151.861 Centre Distance Pass - Major Risk 2M-07 - 2M-07 - 2M-07 3,190.80 453.32 3,190.80 376.18 2,875.00 5.877 Clearance Factor Pass - Major Risk 2M-13 - 2M-13 - 2M-13 567.62 240.57 567.62 228.08 575.00 19.262 Centre Distance Pass - Major Risk 2M-13 - 2M-13 - 2M-13 639.28 241.18 639.28 226.87 650.00 16.852 Clearance Factor Pass - Major Risk 2M-14 - 2M-14 - 2M-14 899.09 217.10 899.09 195.96 900.00 10.270 Centre Distance Pass - Major Risk 2M-14 - 2M-14 - 2M-14 1,228.21 221.34 1,228.21 191.67 1,225.00 7.458 Clearance Factor Pass - Major Risk 2M-15 - 2M-15 - 2M-15 570.32 193.86 570.32 181.33 575.00 15.462 Centre Distance Pass - Major Risk 2M-15 - 2M-15 - 2M-15 792.00 195.97 792.00 177.85 800.00 10.811 Clearance Factor Pass - Major Risk 2M-16 - 2M-16 - 2M-16 602.05 167.12 602.05 153.82 600.00 12.573 Centre Distance Pass - Major Risk 2M-16 - 2M-16 - 2M-16 774.36 168.74 774.36 151.08 775.00 9.557 Clearance Factor Pass - Major Risk 2M-17 - 2M-17 - 2M-17 1,346.30 93.08 1,346.30 60.82 1,350.00 2.885 Centre Distance Pass - Major Risk 2M-17 - 2M-17 - 2M-17 1,396.35 93.68 1,396.35 60.34 1,400.00 2.810 Clearance Factor Pass - Major Risk 2M-18 - 2M-18 - 2M-18 470.76 119.38 470.76 109.27 475.00 11.802 Centre Distance Pass - Major Risk 2M-18 - 2M-18 - 2M-18 718.77 121.41 718.77 105.15 725.00 7.464 Clearance Factor Pass - Major Risk 2M-19 - 2M-19 - 2M-19 469.98 92.77 469.98 82.45 475.00 8.989 Centre Distance Pass - Major Risk 2M-19 - 2M-19 - 2M-19 543.39 93.69 543.39 81.57 550.00 7.732 Clearance Factor Pass - Major Risk 2M-20 - 2M-20 - 2M-20 522.34 67.03 522.34 55.41 525.00 5.766 Centre Distance Pass - Major Risk 2M-20 - 2M-20 - 2M-20 571.52 67.71 571.52 54.88 575.00 5.278 Clearance Factor Pass - Major Risk 2M-21 - 2M-21 - 2M-21 471.05 43.06 471.05 32.94 475.00 4.257 Centre Distance Pass - Major Risk 2M-21 - 2M-21 - 2M-21 520.27 43.82 520.27 32.50 525.00 3.873 Clearance Factor Pass - Major Risk 2M-22 - 2M-22 - 2M-22 422.84 18.95 422.84 9.77 425.00 2.064 Centre Distance Pass - Major Risk 2M-22 - 2M-22 - 2M-22 721.39 21.51 721.39 5.04 725.00 1.306 Clearance Factor Pass - Major Risk 2M-23 - 2M-23 - 2M-23 253.90 5.00 253.90 0.78 250.00 1.185 Centre Distance Pass - Major Risk 2M-23 - 2M-23 - 2M-23 2M-24 - 2M-24 - 2M-24 322.91 29.85 322.91 22.89 325.00 4.289 Centre Distance Pass - Major Risk 2M-24 - 2M-24 - 2M-24 372.92 30.32 372.92 22.23 375.00 3.748 Clearance Factor Pass - Major Risk 01 June, 2016 - 10:44 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-38 - 2M-38wp13 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-38 - Plan: 2M-38 - 2M-38wp13 Scan Range: 0.00 to 18,687.21 usft. Measured Depth. Scan Radius is 2,064.82 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2M-25 - 2M-25 - 2M-25 143.90 55.32 143.90 52.49 140.00 19.566 Centre Distance Pass - Major Risk 2M-25 - 2M-25 - 2M-25 303.89 56.29 303.89 51.15 300.00 10.952 Clearance Factor Pass - Major Risk 2M-26 - 2M-26 - 2M-26 147.90 70.86 147.90 67.95 150.00 24.391 Centre Distance Pass - Major Risk 2M-26 - 2M-26 - 2M-26 297.88 72.38 297.88 66.01 300.00 11.352 Clearance Factor Pass - Major Risk 2M-27 - 2M-27 - 2M-27 4,312.39 354.15 4,312.39 209.79 3,675.00 2.453 Clearance Factor Pass - Major Risk 2M-28 - 2M-28 - 2M-28 6,598.74 347.86 6,598.74 166.96 5,750.00 1.923 Clearance Factor Pass - Major Risk 2M-28 - 2M-28 - 2M-28 6,622.82 347.82 6,622.82 167.10 5,775.00 1.925 Centre Distance Pass - Major Risk 2M-29 - 2M-29 - 2M-29 4,843.32 396.97 4,843.32 283.15 3,975.00 3.488 Centre Distance Pass - Major Risk 2M-29 - 2M-29 - 2M-29 4,977.56 402.46 4,977.56 277.54 4,125.00 3.222 Clearance Factor Pass - Major Risk 2M-30 - 2M-30 - 2M-30 4,172.64 468.80 4,172.64 353.00 3,375.00 4.049 Centre Distance Pass - Major Risk 2M-30 - 2M-30 - 2M-30 4,284.77 478.69 4,284.77 344.91 3,525.00 3.578 Clearance Factor Pass - Major Risk 2M-31 - 2M-31 - 2M-31 571.27 206.29 571.27 197.70 575.00 23.997 Centre Distance Pass - Major Risk 2M-31 - 2M-31 - 2M-31 6,826.59 328.83 6,826.59 108.13 6,325.00 1.490 Clearance Factor Pass - Major Risk 2M-33 - 2M-33 - 2M-33 143.90 157.07 143.90 154.24 147.00 55.557 Centre Distance Pass - Major Risk 2M-33 - 2M-33 - 2M-33 296.90 157.46 296.90 152.57 300.00 32.241 Clearance Factor Pass - Major Risk 2M-34 - 2M-34 - 2M-34 39.30 131.60 39.30 129.55 42.40 64.328 Centre Distance Pass - Major Risk 2M-34 - 2M-34 - 2M-34 96.90 131.81 96.90 129.00 100.00 46.854 Clearance Factor Pass - Major Risk 2M-35 - 2M-35 - 2M-35 646.69 100.19 646.69 89.68 650.00 9.529 Centre Distance Pass - Major Risk 2M-35 - 2M-35 - 2M-35 745.98 100.78 745.98 88.63 750.00 8.299 Clearance Factor Pass - Major Risk Plan: 2M-39 - 2M-39 - 2M-39 wp02 17,100.00 656.30 17,100.00 236.69 16,325.00 1.564 Clearance Factor Pass - Major Risk 01 June, 2016 - 10:44 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-38 - 2M-38wp13 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 1,100.00 2M-38wp13 GYD-GC-SS 1,100.00 2,100.00 2M-38wp13 MWD 1,100.00 2,978.93 2M-38wp13 MWD+IFR-AK-CAZ-SC 2,978.93 4,478.93 2M-38wp13 MWD 2,978.93 12,950.54 2M-38wp13 MWD+IFR-AK-CAZ-SC 12,950.54 14,350.60 2M-38wp13 MWD 12,950.54 14,350.60 2M-38wp13 MWD+IFR-AK-CAZ-SC 14,350.60 15,850.60 2M-38wp13 MWD 14,350.60 18,687.21 2M-38wp13 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 01 June, 2016 - 10:44 Page 4 of 6 COMPASS Ladder View 10:59, June 01 2016 2M-38wp13 The ReferenceWell is along the x-axis. rror Ellipses are the Sum of the Reference and Offset Well Errors ..�g.N 300i c oI ll' I 111 15 I ci 150 - - - �— -- -- - - — - - - -- -- --- - -- - - -- — - N U II i 0 Equivalent Magnetic Distance V 2500 5000 7500 10000 12500 15000 17500 Displayed interval could be less than entire well:Measured Depth 39.00 To 18687.21 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1100.00 2M-38wp13 (Plan: 2M-38) GYD-GC-SS 121.50 121.50 20" x 42" 1100.00 2100.00 2M-38wp13 (Plan: 2M-38) MWD 2641.978.93 13-3/8" x 16" 1100.00 2978.93 2M-38wp13 (Plan: 2M-38) MWD+IFR-AK-CAZ-SC 5693.UD50.54 9-5/8" x 12-1/4" 2978.93 4478.93 2M-38wp13 (Plan: 2M-38) MWD 6083.1)(B50.60 x 8-3/4" by 9-1/2" 2978.9312950.54 2M-38wp13 (Plan: 2M-38) MWD+IFR-AK-CAZ-SC 60781M87.21 4-1/2" x 6-1/8" 12950.5414350.60 2M-38wp13 (Plan: 2M-38) MWD 12950.5414350.60 14350 6015850 60 2M-38wp13 (Plan: 2M-38) 2M-38wn13 (Plan- 2M-38) MWD+IFR-AK-CAZ-SC MWD fV N N N 60— 0 C: Q Q ( I 30--- C) i U 4 0 I 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance 1 �► I n plT yp tl�; ft :6�a®r� a�0 fi ti 6:40, May 18 201 P Q vire s 'Q (NOT a Spider) 12M-38w� Easting (3000 usft/in) Easting (3000 usft/in) 21 2M-20 'M-25 V1-24 V1-22 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-38 Plan: 2M-38 Plan: 2M-38wp13 Report - Errors 01 June, 2016 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-38 Wellbore: Plan: 2M-38 Design: 2M-38wpl3 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2M-38 TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2M Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 usft Slot Radius: Well Plan: 2M-38 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore Plan: 2M-38 Magnetics Model Name usfl BGGM2016 Design 2M-38wp13 Audit Notes: Sample Date 8/15/2016 Version: Phase: Vertical Section: Depth From (TVD) usfl (usft) MWD 39.00 Survey Tool Program Date 6/1/2016 From To (usft) (usft) Survey (Wellbore) 39.00 1,100.00 2M-38wpl3 (Plan: 2M-38) 1,100.00 2,100.00 2M-38wpl3 (Plan: 2M-38) 1,100.00 2,978.93 2M-38wpl3 (Plan: 2M-38) 2,978.93 4,478.93 2M-38wp13 (Plan: 2M-38) 2,978.93 12,950.54 2M-38wp13 (Plan: 2M-38) 12,950.54 14,350.60 2M-38wpl3 (Plan: 2M-38) 12,950.54 14,350.60 2M-38wpl3 (Plan: 2M-38) 14,350.60 15,850.60 2M-38wp13 (Plan: 2M-38) 14,350.60 18,687.21 2M-38wp13 (Plan: 2M-38) Planned Survey MD MD Error Inc (usft) (usft) V) 39.00 0.00 0.00 100.00 1.15 0.00 121.50 1.15 0.00 20" x 42" 200.00 1.15 0.00 usft Latitude: usft Longitude: 0" Grid Convergence: usft Latitude: usft Longitude: usfl Ground Level: -0.10 ° 104.90 usft Declination Dip Angle Field Strength (nT) 17.92 80.88 57,538 PLAN Tie On Depth: 39.00 +Nl-S +E/ -W Direction (usft) (usft) C) 0.00 0.00 260.00 Ellipse Inc 0.00 0.00 0.00 0.00 Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD MWD - Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC TVDSS Vert. Error (usft) (usft) -104.90 0.00 -43.90 1.15 -22.40 1.15 56.10 1.15 Lat. Error Horz. Error (usft) (usft) 0.00 0.00 0.04 0.04 0.19 0.19 0.19 0.19 6/1/2016 10:45:54AM Page 2 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Well Plan: 2M-38 Site: Kuparuk 2M Pad TVD Reference: Well: Plan: 2M-38 1.15 MD Reference: Wellbore: Plan: 2M-38 1.15 North Reference: Design: 2M-38wpl3 1.15 Survey Calculation Method: Planned Survey 1.15 Database: MD MD Error Inc 1.15 (usft) (usft) (°) (°) (usft) 275.00 1.15 0.00 KOP: Start 1.5°/100' DLS, 180° TF, for 325.39' 300.00 1.15 0.37 400.00 1.15 1.87 500.00 1.15 3.37 600.00 1.15 4.87 600.39 1.15 4.88 Start 2°/100' DLS, 0° TF, for 871.59' 3.57 700.00 1.16 6.87 800.00 1.16 8.87 900.00 1.17 10.87 1,000.00 1.17 12.87 1,100.00 1.18 14.87 1,200.00 1.20 16.87 1,300.00 1.21 18.87 1,400.00 1.23 20.87 1,471.98 1.24 22.31 Hold for 108.09' 1.37 44.68 1,500.00 1.24 22.31 1,526.03 1.25 22.31 Base Permafrost 1.50 50.37 1,580.08 1.25 22.31 Start 4°/100' DLS, 90° TF, for 1398.85' 1.52 1,600.00 1.25 22.33 1,700.00 1.28 22.80 1,800.00 1.35 23.90 1,900.00 1.46 25.56 2,000.00 1.63 27.67 2,100.00 1.85 30.13 2,200.00 1.56 32.88 2,300.00 1.67 35.83 2,400.00 1.79 38.95 2,500.00 1.93 42.20 2,600.00 2.08 45.55 2,700.00 2.25 48.97 2,800.00 2.43 52.45 2,886.72 2.62 55.52 Base West Sak 2,900.00 2.62 55.99 2,978.93 2.78 58.81 Hold for 20'- 13-3/8" x 16" 2,998.93 2.83 58.81 Start 3.5°/100' DLS, 29.72° TF, for 463.26' 3,000.00 2.83 58.84 3,100.00 3.03 61.89 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2M-38 1.15 TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) 1.15 MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) 1.15 North Reference: True 1.15 Survey Calculation Method: Minimum Curvature 1.15 Database: OAKEDMP2 1.15 0.22 Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (°) (usft) (usft) (usft) (usft) 1,233.07 0.00 131.10 1.15 0.30 0.30 135.00 156.10 1.15 0.32 0.32 135.00 256.08 1.15 0.36 0.36 90.00 355.97 1.15 0.45 0.45 90.00 455.71 1.15 0.57 0.57 90.00 456.10 1.15 0.57 0.57 45.00 555.18 1.15 0.00 654.23 1.15 0.00 752.74 1.15 0.00 850.60 1.15 0.00 947.68 1.15 0.05 1,043.86 1.15 0.22 1,139.03 1.14 0.28 1,233.07 1.14 0.29 1,300.00 1.14 0.30 1,325.92 1.14 0.30 1,350.00 1.15 0.30 1,400.00 1.15 0.28 1,418.43 1.16 1.22 1,510.81 1.18 3.57 1,602.66 1.20 6.95 1,693.51 1.22 10.96 1,782.94 1.25 15.35 1,870.50 1.29 17.59 1,955.77 1.21 22.69 2,038.33 1.23 27.70 2,117.78 1.25 32.48 2,193.74 1.28 36.92 2,265.82 1.32 40.99 2,333.69 1.37 44.68 2,397.01 1.43 48.00 2,448.00 1.50 48.00 2,455.47 1.50 50.37 2,498.00 1.57 50.35 2,508.36 1.52 50.38 2,508.91 1.52 54.08 2,558.36 1.54 0.70 0.69 0.85 0.83 1.01 0.97 1.19 1.11 1.38 1.26 1.49 1.34 1.63 1.35 1.92 1.38 2.20 1.41 2.32 1.43 2.69 1.49 2.69 1.49 2.77 1.51 3.11 1.66 3.44 1.91 3.78 2.22 4.16 2.54 4.59 2.85 2.53 1.94 2.75 2.03 3.01 2.12 3.31 2.20 3.65 2.27 4.03 2.33 4.43 2.39 4.87 2.44 4.87 2.44 5.23 2.47 5.33 2.49 5.34 2.48 5.96 2.43 611/2016 10:45:54AM Page 3 COMPASS 5000.1 Build 74 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-38 Wellbore: Plan: 2M-38 Design: 2M-38wp13 Planned Survey Well Plan: 2M-38 MD MD Error (usft) (usft) 3,200.00 3.24 3,300.00 3.46 3,400.00 3.70 3,462.19 3.86 Hold for 8314.89' 3,500.00 3,600.00 3,700.00 3,800.00 3,859.80 CampSS 3,900.00 4,000.00 4,100.00 4,200.00 4,300.00 4,400.00 4,500.00 4,600.00 4,700.00 4,800.00 4,900.00 5,000.00 5,100.00 5,200.00 5,300.00 5,400.00 5,500.00 5,600.00 5,700.00 5,800.00 5,900.00 6,000.00 6,100.00 6,200.00 6,300.00 6,400.00 6,500.00 6,600.00 6,700.00 6,800.00 6,900.00 7,000.00 7,100.00 7,200.00 Schlumberger Report - Errors Local Co-ordinate Reference: Well Plan: 2M-38 TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature Database: OAKEDMP2 Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (°) (°) (usft) (usft) (usft) (usft) 64.97 58.63 2,603.08 1.61 6.87 2.42 68.08 62.93 2,642.91 1.74 7.99 2.45 71.20 66.56 2,677.70 1.92 9.26 2.52 73.15 68.48 2,696.74 2.06 10.10 2.58 3.86 73.15 69.51 2,707.70 2.15 10.64 2.67 3.87 73.15 71.75 2,736.69 2.41 12.10 2.91 3.87 73.15 73.46 2,765.67 2.69 13.60 3.17 3.88 73.15 74.79 2,794.66 2.98 15.12 3.45 3.88 73.15 75.84 2,812.00 3.28 16.66 3.74 3.88 73.15 75.84 2,823.65 3.28 16.66 3.74 3.89 73.15 76.69 2,852.64 3.58 18.22 4.04 3.89 73.15 77.39 2,881.63 3.89 19.78 4.34 3.90 73.15 77.97 2,910.62 4.21 21.36 4.66 3.90 73.15 78.46 2,939.61 4.53 22.94 4.98 3.91 73.15 78.88 2,968.60 4.85 24.53 5.30 3.78 73.15 72.42 2,997.59 2.88 11.23 3.31 3.79 73.15 73.15 3,026.58 3.03 11.77 3.46 3.80 73.15 73.80 3,055.57 3.18 12.31 3.60 3.80 73.15 74.38 3,084.55 3.33 12.85 3.75 3.81 73.15 74.91 3,113.54 3.48 13.40 3.90 3.82 73.15 75.38 3,142.53 3.64 13.95 4.05 3.82 73.15 75.82 3,171.52 3.79 14.50 4.20 3.83 73.15 76.21 3,200.51 3.95 15.06 4.35 3.84 73.15 76.57 3,229.50 4.10 15.62 4.51 3.85 73.15 76.89 3,258.49 4.26 16.18 4.67 3.85 73.15 77.19 3,287.48 4.42 16.74 4.83 3.86 73.15 77.47 3,316.47 4.58 17.31 4.99 3.87 73.15 77.72 3,345.46 4.74 17.87 5.15 3.88 73.15 77.96 3,374.44 4.90 18.44 5.31 3.89 73.15 78.18 3,403.43 5.06 19.01 5.47 3.90 73.15 78.38 3,432.42 5.22 19.58 5.64 3.90 73.15 78.57 3,461.41 5.39 20.15 5.80 3.91 73.15 78.75 3,490.40 5.55 20.73 5.97 3.92 73.15 78.91 3,519.39 5.71 21.30 6.13 3.93 73.15 79.07 3,548.38 5.87 21.87 6.30 3.94 73.15 79.21 3,577.37 6.04 22.45 6.46 3.95 73.15 79.35 3,606.36 6.20 23.03 6.63 3.96 73.15 79.47 3,635.35 6.36 23.60 6.80 3.97 73.15 79.59 3,664.33 6.53 24.18 6.97 3.98 73.15 79.71 3,693.32 6.69 24.76 7.14 3.99 73.15 79.81 3,722.31 6.86 25.34 7.30 4.00 73.15 79.92 3,751.30 7.02 25.91 7.47 4.01 73.15 80.01 3,780.29 7.19 26.49 7.64 6/1/2016 10:45.54AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit ND Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 7,300.00 4.02 73.15 80.10 3,809.28 7.35 27.07 7.81 7,336.98 4.03 73.15 80.19 3,820.00 7.52 27.65 7.98 C-50 7,400.00 4.03 73.15 80.19 3,838.27 7.52 27.65 7.98 7,500.00 4.04 73.15 80.27 3,867.26 7.68 28.23 8.15 7,600.00 4.05 73.15 80.35 3,896.25 7.85 28.81 8.32 7,700.00 4.06 73.15 80.43 3,925.24 8.01 29.40 8.49 7,800.00 4.07 73.15 80.50 3,954.23 8.18 29.98 8.66 7,900.00 4.08 73.15 80.57 3,983.21 8.34 30.56 8.83 8,000.00 4.09 73.15 80.63 4,012.20 8.51 31.14 9.01 8,100.00 4.10 73.15 80.69 4,041.19 8.68 31.72 9.18 8,200.00 4.11 73.15 80.75 4,070.18 8.84 32.31 9.35 8,300.00 4.12 73.15 80.81 4,099.17 9.01 32.89 9.52 8,400.00 4.13 73.15 80.87 4,128.16 9.17 33.47 9.69 8,500.00 4.15 73.15 80.92 4,157.15 9.34 34.06 9.86 8,600.00 4.16 73.15 80.97 4,186.14 9.51 34.64 10.04 8,700.00 4.17 73.15 81.02 4,215.13 9.67 35.22 10.21 8,800.00 4.18 73.15 81.06 4,244.12 9.84 35.81 10.38 8,900.00 4.19 73.15 81.11 4,273.10 10.01 36.39 10.55 9,000.00 4.20 73.15 81.15 4,302.09 10.17 36.97 10.73 9,100.00 4.22 73.15 81.19 4,331.08 10.34 37.56 10.90 9,200.00 4.23 73.15 81.24 4,360.07 10.51 38.14 11.07 9,300.00 4.24 73.15 81.27 4,389.06 10.67 38.73 11.24 9,400.00 4.25 73.15 81.31 4,418.05 10.84 39.31 11.42 9,500.00 4.27 73.15 81.35 4,447.04 11.01 39.90 11.59 9,600.00 4.28 73.15 81.38 4,476.03 11.17 40.48 11.76 9,700.00 4.29 73.15 81.42 4,505.02 11.34 41.07 11.94 9,800.00 4.30 73.15 81.45 4,534.01 11.51 41.65 12.11 9,855.17 4.32 73.15 81.48 4,550.00 11.67 42.24 12.28 C-37 9,900.00 4.32 73.15 81.48 4,563.00 11.67 42.24 12.28 10,000.00 4.33 73.15 81.51 4,591.98 11.84 42.82 12.45 10,044.90 4.34 73.15 81.54 4,605.00 12.01 43.41 12.63 Iceberg 10,100.00 4.34 73.15 81.54 4,620.97 12.01 43.41 12.63 10,200.00 4.35 73.15 81.57 4,649.96 12.17 44.00 12.80 10,300.00 4.37 73.15 81.60 4,678.95 12.34 44.58 12.98 10,400.00 4.38 73.15 81.63 4,707.94 12.51 45.17 13.15 10,500.00 4.39 73.15 81.65 4,736.93 12.68 45.75 13.32 10,600.00 4.41 73.15 81.68 4,765.92 12.84 46.34 13.50 10,700.00 4.42 73.15 81.70 4,794.91 13.01 46.93 13.67 10,800.00 4.44 73.15 81.73 4,823.90 13.18 47.51 13.84 10,900.00 4.45 73.15 81.75 4,852.89 13.35 48.10 14.02 11,000.00 4.46 73.15 81.77 4,881.87 13.51 48.69 14.19 61112016 10:45:54AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl 3 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 11,100.00 4.48 73.15 81.80 4,910.86 13.68 49.27 14.37 11,200.00 4.49 73.15 81.82 4,939.85 13.85 49.86 14.54 11,300.00 4.50 73.15 81.84 4,968.84 14.01 50.45 14.71 11,400.00 4.52 73.15 81.86 4,997.83 14.18 51.03 14.89 11,500.00 4.53 73.15 81.88 5,026.82 14.35 51.62 15.06 11,600.00 4.55 73.15 81.90 5,055.81 14.52 52.21 15.24 11,700.00 4.56 73.15 81.92 5,084.80 14.68 52.79 15.41 11,777.08 4.57 73.15 81.93 5,107.14 14.81 53.25 15.54 Start 2°1100' DLS, 172.94° TF, for 313.2' 11, 800.00 4.58 72.69 81.94 5,113.87 14.85 53.36 15.59 11,899.18 4.66 70.73 81.95 5,145.00 15.02 53.77 15.77 C-35 11,900.00 4.66 70.71 81.95 5,145.27 15.02 53.77 15.77 12,000.00 4.80 68.72 81.96 5,179.93 15.18 54.18 15.94 12,090.28 4.97 66.93 81.97 5,214.00 15.32 54.55 16.08 Adjust TF to 5.17°, for 3.81' 12,094.09 4.97 67.01 81.97 5,215.49 15.33 54.57 16.09 Hold for 856.45' 12,100.00 4.97 67.01 81.97 5,217.80 15.34 54.60 16.10 12,200.00 4.98 67.01 81.99 5,256.86 15.50 55.18 16.27 12,300.00 5.00 67.01 82.02 5,295.91 15.65 55.77 16.44 12,400.00 5.01 67.01 82.04 5,334.97 15.81 56.35 16.61 12,500.00 5.03 67.01 82.06 5,374.03 15.97 56.94 16.78 12,600.00 5.04 67.01 82.08 5,413.09 16.13 57.52 16.95 12,700.00 5.05 67.01 82.10 5,452.14 16.29 58.11 17.12 12,800.00 5.07 67.01 82.13 5,491.20 16.44 58.69 17.29 12,900.00 5.08 67.01 82.15 5,530.26 16.60 59.28 17.46 12,950.54 5.11 67.01 82.15 5,550.00 16.65 59.58 17.51 Adjust TF to 0°, for 20'- Top HRZ - 9-518" x 12-1/4" 12,970.54 5.11 67.01 82.15 5,557.81 16.65 59.70 17.51 Start 3.5°/100' DLS, A74.83° TF, for 35.09' 13,000.00 5.15 65.98 82.16 5,569.56 16.65 59.89 17.48 13,005.64 5.17 65.79 82.16 5,571.86 16.65 59.92 17.48 Hold for 41.01' 13,046.65 5.17 65.79 82.16 5,588.68 16.66 60.18 17.48 Start 3°/100' DLS, 3.21° TF, for 0.78' 13,047.43 5.17 65.81 82.16 5,589.00 16.66 60.18 17.48 Start 2°/100' DLS, 0.64° TF, for 28.91' 13,076.34 5.13 66.39 82.17 5,600.71 16.66 60.37 17.50 Hold for 352.74' 13,100.00 5.13 66.39 82.17 5,610.19 16.66 60.53 17.50 13,200.00 5.15 66.39 82.19 5,650.25 16.67 61.21 17.51 13,300.00 5.16 66.39 82.21 5,690.30 16.69 61.91 17.53 13,306.74 5.18 66.39 82.23 5,693.00 16.72 62.65 17.56 Fault 1 (cross in HRZ) 13,400.00 5.18 66.39 82.23 5,730.35 16.72 62.65 17.56 6/1/2016 10:45:54AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl 3 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (1) (°) (usft) (usft) (usft) (usft) 13,429.08 5.18 66.39 82.24 5,742.00 16.73 62.87 17.57 Start 2.2°/100' DLS, 179.81° TF, for 56.3' 13,473.17 5.30 65.42 82.25 5,760.00 16.75 63.30 17.56 Base HRZ/Top Kalubik 13,485.38 5.30 65.15 82.25 5,765.11 16.75 63.30 17.56 Hold for 14.02' 13,499.40 5.30 65.15 82.26 5,771.00 16.75 63.41 17.57 Start 3.07°1100' DLS, -3.21° TF, for 159.81' 13,500.00 5.30 65.17 82.26 5,771.25 16.75 63.41 17.57 13,600.00 5.03 68.23 82.28 5,810.80 16.79 64.22 17.66 13,659.22 4.95 70.04 82.29 5,831.89 16.81 64.72 17.70 Hold for 8.56' 13,667.78 4.95 70.04 82.30 5,834.81 16.81 64.79 17.70 Start 3.5°/100' DLS, 7.3° TF, for 27.55' 13,695.33 4.99 71.00 82.30 5,844.00 16.83 65.02 17.72 Adjust TF to -11.43°, for 160.19' - K-1 13,700.00 4.98 71.16 82.30 5,845.51 16.83 65.06 17.73 13,800.00 4.87 74.59 82.33 5,874.95 16.88 65.97 17.72 13,855.52 4.93 76.29 82.33 5,889.10 16.91 66.48 17.71 Hold for 27.31' 13,882.83 4.93 76.29 82.34 5,895.57 16.93 66.74 17.73 Start 3.5°/100' DLS, 0.65° TF, for 242.77' 13,900.00 4.99 76.89 82.34 5,899.56 16.94 66.90 17.72 14,000.00 5.45 80.39 82.35 5,919.25 17.01 67.86 17.67 14,058.57 6.05 82.44 82.37 5,928.00 17.08 68.84 17.56 Top C 14,100.00 6.05 83.89 82.37 5,932.93 17.08 68.84 17.56 14,125.60 6.26 85.00 82.37 5,935.00 17.11 69.10 17.51 Start 4°/100' DLS, -13.39° TF, for 139.37' - TD in C4 across fit 14,200.00 6.74 87.90 82.38 5,939.61 17.17 69.87 17.35 14,264.96 7.27 90.42 82.38 5,940.56 17.23 70.54 17.19 Hold for 66.23' 14,300.00 7.28 90.42 82.38 5,940.30 17.26 70.90 17.22 14,331.20 7.28 90.42 82.38 5,940.07 17.29 71.23 17.25 Start 3.25°/100' DLS, -132.27° TF, for 19.41' 14,350.60 7.24 90.00 82.20 5,940.00 16.82 62.60 16.82 Hold for 20'- 7" x 8-3/4" by 9-1/2" 14,370.60 7.25 90.00 82.19 5,940.00 16.82 62.74 16.82 Start 2°1100' DLS, 0° TF, for 28.2' 14,398.80 7.37 90.56 82.19 5,939.86 16.82 62.95 16.76 Hold for 1001.73' 14,400.00 7.37 90.56 82.19 5,939.85 16.82 62.96 16.76 14,500.00 7.38 90.56 82.17 5,938.86 16.83 63.70 16.77 14,600.00 7.39 90.56 82.15 5,937.88 16.84 64.48 16.79 14,700.00 7.40 90.56 82.14 5,936.90 16.87 65.29 16.81 14,800.00 7.41 90.56 82.12 5,935.91 16.90 66.14 16.85 6/1/2016 10:45:54AM Page 7 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (usft) (usft) (°) (°) (usft) (usft) (usft) (usft) 14,900.00 7.43 90.56 82.11 5,934.93 16.94 67.02 16.89 15,000.00 7.44 90.56 82.09 5,933.94 16.99 67.92 16.94 15,100.00 7.45 90.56 82.08 5,932.96 17.04 68.86 16.99 15,200.00 7.46 90.56 82.07 5,931.97 17.11 69.82 17.06 15,300.00 7.47 90.56 82.05 5,930.99 17.18 70.81 17.13 15,400.00 7.48 90.56 82.04 5,930.01 17.26 71.82 17.21 15,400.53 7.48 90.56 82.04 5,930.00 17.26 71.82 17.21 Start 3°/100' DLS, -174.7° TF, for 75.15' 15,475.69 7.05 88.32 82.03 5,930.73 17.32 72.59 17.46 Hold for 1094.91' 15,500.00 7.05 88.32 82.02 5,931.45 17.34 72.84 17.49 15,600.00 7.07 88.32 82.01 5,934.38 17.44 73.90 17.58 15,700.00 7.08 88.32 81.99 5,937.31 17.54 74.98 17.68 15,800.00 7.09 88.32 81.98 5,940.25 17.65 76.08 17.78 15,900.00 7.10 88.32 82.12 5,943.18 17.05 66.30 17.19 16,000.00 7.12 88.32 82.11 5,946.11 17.08 66.58 17.22 16,100.00 7.13 88.32 82.11 5,949.05 17.11 66.86 17.25 16,200.00 7.14 88.32 82.10 5,951.98 17.14 67.14 17.29 16,300.00 7.16 88.32 82.10 5,954.91 17.18 67.43 17.32 16,400.00 7.17 88.32 82.09 5,957.85 17.22 67.72 17.36 16,500.00 7.18 88.32 82.08 5,960.78 17.25 68.02 17.40 16,570.60 7.19 88.32 82.08 5,962.85 17.28 68.23 17.43 Start 3°/100' DLS, -83.51° TF, for 484.81' 16,600.00 7.39 88.42 82.08 5,963.69 17.30 68.30 17.43 16,700.00 8.96 88.76 82.06 5,966.15 17.34 68.41 17.44 16,800.00 11.44 89.11 82.04 5,968.01 17.38 68.34 17.45 16,900.00 14.36 89.46 81.99 5,969.26 17.43 68.09 17.47 17,000.00 17.48 89.81 81.94 5,969.91 17.48 67.66 17.49 17,055.41 19.26 90.00 81.91 5,970.00 17.50 67.35 17.50 Start 4°/100' DLS, -72.51 ° TF, for 267.72' - Fault 2 (C to A2) 50-70' DTE) 17,100.00 21.12 90.54 81.87 5,969.79 17.53 66.93 17.50 17,200.00 25.29 91.74 81.79 5,967.81 17.58 65.79 17.51 17,300.00 29.42 92.93 81.69 5,963.74 17.63 64.35 17.57 17,323.13 30.37 93.20 81.67 5,962.50 17.64 63.98 17.60 Hold for 131.35' 17,400.00 30.37 93.20 81.58 5,958.21 17.69 64.22 17.64 17,454.48 30.37 93.20 81.52 5,955.17 17.72 64.39 17.67 Start 4°/100' DLS, 95.96° TF, for 707.59' 17,500.00 28.42 93.01 81.47 5,952.70 17.74 65.42 17.67 17,600.00 24.08 92.58 81.39 5,947.82 17.80 67.43 17.70 17,700.00 19.72 92.14 81.31 5,943.70 17.86 69.13 17.75 17,800.00 15.45 91.69 81.25 5,940.36 17.92 70.51 17.81 17,900.00 11.55 91.23 81.21 5,937.82 17.98 71.55 17.89 18,000.00 8.68 90.76 81.18 5,936.08 18.05 72.27 17.99 18,100.00 8.16 90.29 81.16 5,935.16 18.11 72.64 18.09 6/1/2016 10:45:54AM Page 8 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit TVD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon 142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wp13 Database: OAKEDMP2 Planned Survey TVDSS Vert. Error MD MD Error Inc (°) (usft) (usft) (°) (usft) 18,162.07 9.28 90.00 Start 2°/100' DLS, 90° TF, for 409.48' 72.70 18,200.00 9.82 90.00 18,300.00 11.51 90.00 18,400.00 13.46 90.00 18,500.00 15.58 90.00 18,571.55 17.17 90.00 Hold for 115.66' 81.25 5,935.00 18,600.00 17.17 90.00 18,687.21 17.17 90.00 TD: 18687.21' MD, 6078.9' TVD 81.29 Ellipse Inc TVDSS Vert. Error Lat. Error Horz. Error (°) (usft) (usft) (usft) (usft) 81.17 5,935.00 18.16 72.70 18.16 81.17 5,935.00 18.18 72.76 18.18 81.19 5,935.00 18.25 72.84 18.25 81.21 5,935.00 18.32 72.84 18.32 81.25 5,935.00 18.39 72.76 18.39 81.28 5,935.00 18.44 72.65 18.44 81.29 5,935.00 18.47 72.75 18.47 81.34 5,935.00 18.53 73.05 18.53 6/1/2016 10:45:54AM Page 9 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Depth Project: Kuparuk River Unit (usft) Name Lithology ND Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) Site: Kuparuk 2M Pad 2,591.90 Base West Sak MD Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) Well: Plan: 2M-38 6,113.90 Fault 2 (C to A2) 50-70' DTE) North Reference: True Top HRZ Wellbore: Plan: 2M-38 Top C 14,125.60 Survey Calculation Method: Minimum Curvature 9,855.17 Design: 2M-38wp13 3,859.80 2,955.90 Database: OAKEDMP2 1,493.90 Casing Points 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 Measured Vertical 13,306.74 5,836.90 Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name () (") 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 7,336.98 3,963.90 C-50 2,886.72 2,591.90 Base West Sak 13,473.17 5,903.90 Base HRZ/Top Kalubik 17,055.41 6,113.90 Fault 2 (C to A2) 50-70' DTE) 12,950.54 5,693.90 Top HRZ 14,058.57 6,071.90 Top C 14,125.60 6,078.90 TD in C4 across flt 9,855.17 4,693.90 C-37 3,859.80 2,955.90 CampSS 1,526.03 1,493.90 Base Permafrost 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 5,288.90 C-35 0.00 13,306.74 5,836.90 Fault 1 (cross in HRZ) 6/1/2016 10:45:54AM Page 10 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-38 Project: Kuparuk River Unit ND Reference: Plan: 39+104.9 @ 143.90usft (Doyonl42) Site: Kuparuk 2M Pad MD Reference: Plan: 39+104.9 @ 143.90usft (Doyon142) Well: Plan: 2M-38 North Reference: True Wellbore: Plan: 2M-38 Survey Calculation Method: Minimum Curvature Design: 2M-38wpl3 Database: OAKEDMP2 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (") (") 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1) (�) 7,336.98 3,963.90 C-50 2,886.72 2,591.90 Base West Sak 13,473.17 5,903.90 Base HRZ/Top Kalubik 17,055.41 6,113.90 Fault 2 (C to A2) 50-70' DTE) 12,950.54 5,693.90 Top HRZ 14,058.57 6,071.90 Top C 14,125.60 6,078.90 TD in C4 across flt 9,855.17 4,693.90 C-37 3,859.80 2,955.90 CampSS 1,526.03 1,493.90 Base Permafrost 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 5,288.90 C-35 0.00 13,306.74 5,836.90 Fault 1 (cross in HRZ) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 275.00 275.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 180° TF, for 325.39' 600.39 600.00 -13.85 0.00 Start 2°/100' DLS, 0° TF, for 871.59' 1,471.98 1,443.90 -217.96 0.00 Hold for 108.09' 1,580.08 1,543.90 -259.00 0.00 Start 4°/100' DLS, 90° TF, for 1398.85' 2,978.93 2,641.90 -709.61 -630.46 Hold for 20' 2,998.93 2,652.26 -713.86 -647.03 Start 3.5°/100' DLS, 29.72° TF, for 463.26' 3,462.19 2,840.64 -787.03 -1,062.17 Hold for 8314.89' 11,777.08 5,251.04 -1,628.84 -8,975.36 Start 2°/100' DLS, 172.94° TF, for 313.2' 12,090.28 5,357.90 -1,657.88 -9,268.17 Adjust TF to 5.17°, for 3.81' 12,094.09 5,359.39 -1,658.20 -9,271.66 Hold for 856.45' 12,950.54 5,693.90 -1,730.07 -10,056.81 Adjust TF to 0°, for 20' 12,970.54 5,701.71 -1,731.75 -10,075.14 Start 3.5°/100' DLS, -174.83° TF, for 35.09' 13,005.64 5,715.76 -1,734.71 -10,107.16 Hold for 41.01' 13,046.65 5,732.58 -1,738.20 -10,144.40 Start 3°/100' DLS, 3.21° TF, for 0.78' 13,047.43 5,732.90 -1,738.27 -10,145.11 Start 2°/100' DLS, 0.64° TF, for 28.91' 13,076.34 5,744.61 -1,740.73 -10,171.43 Hold for 352.74' 13,429.08 5,885.90 -1,770.83 -10,493.23 Start 2.2°/100' DLS, 179.81° TF, for 56.3' 13,485.38 5,909.01 -1,775.61 -10,544.35 Hold for 14.02' 13,499.40 5,914.90 -1,776.79 -10,557.02 Start 3.07°/100' DLS, -3.21 ° TF, for 159.81' 13,659.22 5,975.79 -1,790.91 -10,704.05 Hold for 8.56' 13,667.78 5,978.71 -1,791.70 -10,712.06 Start 3.5°/100' DLS, 7.3° TF, for 27.55' 13,695.33 5,987.90 -1,794.22 -10,737.91 Adjust TF to -11.43°, for 160.19' 13,855.52 6,033.00 -1,810.43 -10,890.71 Hold for 27.31' 6/1/2016 10:45:54AM Page 11 COMPASS 5000.1 Build 74 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: Plan: 2M-38 North Reference: Wellbore: Plan: 2M-38 Survey Calculation Method: Design: 2M-38wp13 Database: Casing Points Well Plan: 2M-38 Plan: 39+104.9 @ 143.90usft (Doyon142) Plan: 39+104.9 @ 143.90usft (Doyon142) True Minimum Curvature OAKEDMP2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name Lithology V) (`) 14,350.60 6,083.90 7" x 8-3/4" by 9-1/2" 7 9-1/2 2,978.93 2,641.90 13-3/8" x 16" 13-3/8 16 12,950.54 5,693.90 9-5/8" x 12-1/4" 9-5/8 12-1/4 18,687.21 6,078.90 4-1/2" x 6-1/8" 4-1/2 6-1/8 121.50 121.50 20" x 42" 20 42 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology V) (`) 7,336.98 3,963.90 C-50 2,886.72 2,591.90 Base West Sak 13,473.17 5,903.90 Base HRZ/Top Kalubik 17,055.41 6,113.90 Fault 2 (C to A2) 50-70' DTE) 12,950.54 5,693.90 Top HRZ 14,058.57 6,071.90 Top C 14,125.60 6,078.90 TD in C4 across flt 9,855.17 4,693.90 C-37 3,859.80 2,955.90 CampSS 1,526.03 1,493.90 Base Permafrost 13,695.33 5,987.90 K-1 10,044.90 4,748.90 Iceberg 11,899.18 5,288.90 C-35 0.00 13,306.74 5,836.90 Fault 1 (cross in HRZ) 13,882.83 6,039.47 -1,813.48 -10,917.06 Start 3.5°/100' DLS, 0.65° TF, for 242.77' 14,125.60 6,078.90 -1,840.77 -11,154.79 Start 4°/100' DLS, -13.39° TF, for 139.37' 14,264.96 6,084.46 -1,858.09 -11,292.91 Hold for 66.23' 14,331.20 6,083.97 -1,867.06 -11,358.53 Start 3.25°/100' DLS, -132.27° TF, for 19.41' 14,350.60 6,083.90 -1,869.77 -11,377.74 Hold for 20' 14,370.60 6,083.90 -1,872.64 -11,397.54 Start 2°/100' DLS, 0° TF, for 28.2' 14,398.80 6,083.76 -1,876.69 -11,425.45 Hold for 1001.73' 15,400.53 6,073.90 -2,020.51 -12,416.75 Start 3°/100' DLS, -174.7° TF, for 75.15' 15,475.69 6,074.63 -2,031.44 -12,491.10 Hold for 1094.91' 16,570.60 6,106.75 -2,192.52 -13,573.62 Start 3°/100' DLS, -83.51° TF, for 484.81' 17,055.41 6,113.90 -2,323.26 -14,039.06 Start 4°/100' DLS, -72.51' TF, for 267.72' 17,323.13 6,106.40 -2,448.80 -14,274.96 Hold for 131.35' 17,454.48 6,099.07 -2,520.49 -14,384.78 Start 4°/100' DLS, 95.96° TF, for 707.59' 18,162.07 6,078.90 -2,749.09 -15,046.53 Start 2°/100' DLS, 90° TF, for 409.48' 18,571.55 6,078.90 -2,755.55 -15,455.61 Hold for 115.66' 18,687.21 6,078.90 -2,749.12 -15,571.09 TD: 18687.21' MD, 6078.9' TVD Checked By. Approved By: Date: 6/1/2016 10:45:54AM Page 12 COMPASS 5000.1 Build 74 9:45, May 19 201$ 2 M _38wp 13 WELLBORE Name 2M-38 1.C35 051716 JC TARGET DETAILS TVD 5357.90 (MAP CO-ORDINATES) Circle (Radius: Shape p 100.00) Quarter Mile View 2M-36 2. Top HRZ 051716 JC 2M-38 3. Faul11 RWo K 2M-36 4. Base Kupamk 5732.90 5885.90 05175971.90 Circle (Radius: Circle (Radius: Circle (Radius: 100.00) 100.00) 100.00) 1716Top 2M-38 5. K -i 051716 JC 5987.90 Circle (Radius: 100.00) 2M-38 6. Top C 051716 JC 2M-38 7. Landing 051716 JC 6078.90 6083.90 Circle (Radius: Circle (Radius: 100.00) 100.00) 2M-38 8. Crest 051716 JC 6073.90 Circle (Radius: 100.00) 2M-38 9. Fault 2 051716 JC 6113.90 Circle (Radius: 100.00) 2M-38 ].Climbing Point 021915 JC 6078.90 Circle (Radius: 100.00) 2M-38 10. TD 051716 JC 2M-3810. TD 051718 JC Circle 6078.90 6078.90 Circle (Radius: 100.00) Circle (Radius: 1320.00) 716 JC -.N -38 7. landing 051_ ircle 083.90 ,Circle (Radi s: 3000) ]2. 12000 2M-13 I 2 03 Pr\h 8000 - - - o- 241 ' 1 2 2M.19 ? 2A.o9 p4 2A r 2A 1 q.°S o ^6 - - ti 04000 Mm - 14 2 18 - �'o 2H-09. 2 ' 1f o2 O CO O + v N N ? %7 N 4-, 0 N H-12 O m p I �+ 2"'1a� �b �y 0-01 X4000 �- a� 2M.1� -q47 w 2y 2H-10 4 2 M.07 K29L1 m -8000 �Q�� SA14�'1� 04 N 2M-08 2M-32L1P N e 2 ? -16000 -12000 -,8000 s�i°1-400035 0 4 00 000 L 71 0 160*,- P7 7 WELLBORE TARGET DETAILS (MAP CO-ORDINATES) 9:42, May 19 2016 2 M _38wp 13 Name TVD Shape 2M-38 1.C35 051716 JC 5357.90 Circle (Radius: 1D0.00) 2M-38 2. Top HRZ 051716 JC 5732.90 Circle (Radius: 100.00) Quarter Mile View 2M-38 3. Base 051716 JC 5885.90 Circle (Radius: 100.00) 2M-38 5. Base 1716Jp Kuparuk 05175981.90 Circle (Radius: 100.00) 2M-38 5. K-1 051716 JC 5987.90 Circle (Radius: 100.00) 2M-38 6. Top C 051716 JC 6078.90 Circle (Radius: 100.00) 2M-38 7. Landing 051716 JC 6083.90 Circle (Radius: 100.00) 2M-38 8. Crest 051716 JC6073.90 Circle (Radius: 100.00) 2M-38 9. F.. t 2 051716 JC 6113.90 Circle (Radius: 100.00) 2M-38 7.Climbing Point 021915 JC 6078.90 Circle (Radius: 100.00) 2M38 10. TD 051716 JC 6078.90 Circle (Radius: 100.00) 2M-38 10. TD 051716 JC Circle 6078.90 Circle (Radius: 1320.00) 2M-38 7 landing 051716 JC_Circle ,6083.90 Circle (Ratlius:. 1320.00) 4000 2 do 000 � M O N O O O 0— jC, L O 5;2000-- I -r O -4000 - w �o -6000 19 -18000 -16000 -14000 -12000 -10000 -9600 ?660?�,�pdg 24000 04 4000 2M-08 E IMA 0 2M-38wp13 39•oo To l000.00 MD Azi TVD 39.00 0.00 1z1.5o 275.00 0.00 569390 600.39 180.00 1435o.6o 1471.98 180.00 4478.93 2M-38w'P8 1580.o8 180.00 12950.54 2M-38wP8 2978.93 255.61 -60 2998.93 255.61 14350.6o 2M-38wpg 3462.19 263.93 15850.60 2M-38wp13 11777.o8 263.93 12090.28 264.76 12094.09 264.77 12950.54 264.77 0/270 /270 12970.54 264.7 13005.64 264.65 13046.65 264.65 13047.43 264.65 13076.34 264.66 13429.o8 264.66 13485.38 264.66 -120 / 13499.40 264.66 13659.22 264.37 13667.78 264.37 13695.33 264.50 13855.52 263.40 13882.83 263.40 11:05, June 01 2o16 Name Casing Details TVD MD 121.So 1z1.5o 2641.90297893 1100.00 569390 12950.54 6o83.90 1435o.6o 6078.90 18687.21 Name Depth From Depth To Survey/Plan 20"x42„ 39.00 1100.00 2M-38wpt3 13-3/8" x 16" 1100.00 2100.00 2M-38wP13 9 1z-114 1100.00 2978.83 zM-38wP13 7" x 8-3/4 by 9-1h" 2978.93 4478.93 2M-38w'P8 4-1h" x 6-118" 2978.93 12950.54 2M-38wP8 12950.54 14350.66 2M-38wpt3 1295054 14350.6o 2M-38wpg 14350.60 15850.60 2M-38wp13 2M-21 b/360 Tool GYD-GC-SS MWD MWD+I FR AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD M W D+I FR-AK-CAZ-SC MWD M W D+I FR-AK-CAZ-SC -18o/18o 39 275 275 460 460 650 650 840 840 1030 1030 1220 1220 1410 1410. 1600 16o0 2310 2310 3030 3740 - 4450 516o- 5870 - 16o -5870- 6590- 7300 8720- 10150 11570 - 12990 - 14420 15840 1726o - 3030 3740 4450 - ---- __ 516o 5870 6590 7300 8720 10150 11570 12990 14420 15840 1726o 18687 +v' 2 M _3 � � � � 9 o O.O O To 2000.00 Casing Details TVD MD Name Depth From 39.00 1n.5o 11.53 0" x 41" 1100.00 1641.90 1978.93 83/B" x t6" 1100.00 5693.90 11950.54 9-5/8x11-1/4.. 6083.90 14350.6o 1978.93 T x84-1/2' Y9 -1/z" 2978.93 6078 go 8687.21 4 t/z" x 6 1/B" 12950.54 12950.54 14350.6o 14350.60 Survey Program Depth To Survey/Plan noo.0o zM-38wpt3(Plan:2M-38) 2100.00 2M-38WP13 (Plan: zM-38) 1978.93 2M-38wp13 (Plan: 2M-38) 447893 zM-38wp13(Plan: 2M-38) 12950.54 2M-38Wpt3 (Plarn M-36) 14350.60 2Mg8Wpg(PIan:2M-38) 14350.60 2M-38wp, (Plan:zM-38) 1585o.60 2M-38wpt3(Plan: 2M-38) 18687.21 2M-38wpg(Plan:2M-38) Tool GVD-GC-SS MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC MWD MWD+IFR-AK-CAZ-SC Q 39 275 275 46o M D Azi 0/360 46o 650 650 840 39.00 0.00 275.00 0.00 -30/33 90 0 840 1030 600.39 180.o0 2M-22 1030 1220 1471.98 180.00 / "` 1220 1410 1580.o8 180.o0 2978.93 255.61 r 1410 1600 2998.93 255.61 -60/300 6 0 1600 2310 62.1263-93 34 9 2310 3030 11777.o8 263.93 12090.28 264.76 3030 3740 12094.09 264.77 _ . 3740 4450 12950.54 264.77 0 7 0 o 4450 ---- 516o 516o 12970.54 264.j 9 ' , 516o 5870 13005.64 264.65 _ __ .� 13046.65 264.65 5870 _ 6590 13047.43 264.65 30 6590 7300 13076.34 264.66 7300 8720 13429.o8 264.66 13485.38 264.66 -120/240 _- 120 8720 10150 13499.40 264.66 60 10150 11570 13659.22 264.37 '- 13667.78 264.37 11570 12990 13695.33 264.50-150 210 - 150 12990 14420 13855.52 263.40 14420 15840 13882.83 263.40 -180 f 180 15840 1726o 1726o 18687 11co6, Juane oi zotb Casing Details Survey Program 2M TVD MD Name Depth From 39.00 50 50 o"x42" noo.00 Depth To Survey/Plan noo.00 2M-38wpt3(Plam 2M-38) zlno.00 zM-38wpg(Plan:zM38) Tool CYD-GC-SS MWD 39 275 38wp�3 2641.90 2978.93 13-318"x16" 11oo.o0 5693.90 14950.54 9-5/8" x iz-1/4° 1978.93 6.83.80 14350.60 7" x 8-3/4" 6y 9-Uz" 2978.93 2M-38wp13(Plan: 2M-38) 4478.93 zM-38wp13 (Plan: 1M-38) MWD+IFR-AK-CAZ-SC MWD /� 19 O O.O O To 18 ` 8 7.1 � V / L z 93 6o78.go 18687.21 4-1/z"x6-t18" 978. 12950.54 12950.54 1z o. 4 zM- 8w 1 Plan:zM- 8 95 5 3 P 3 ( 3) 14350.60 2M-38wpg (Plan: zM-38) 14350.60 zM-38wp13 (Plan:zM-38) MWD+IFR-AK-SC MWD MWD+IFR-AK-CA2-SC 275 46o 14350.60 15850.60 zM-38wp13 (Plan: zM-38) MWD 14350.60 18687.21 2M-38wpg(PIam M-38) MWD+IFR-AK-CAZ-SC 650 MD Azi 0/36o 460 650 840 39.00 0.00 90 840 1030 275.00 0.00 -30/33 0 600.39 180.00 1030 -� 1220 1471.98 180.00 1220 1410 1580.08 180.00 60 1410 1600 2978.93 255.61 2998.93 255.61 6o/300 6o 1600 2310 3462.19 263.93 2310 3030 11777.o8 263.93 12090.28 264.76 30 3030 3740 12094.09 264.77 3740 4450 12950.54 264.77 0 1270 0 4450 - - 516o 12970.54 264.7 9 5160 5870 13005.64 264.65 13046.65 264.65 5870 6590 13047.43 264.65 30 6590 7300 13076.34 264.66 7300 8720 13429.o8 264.66 13485.38 264.66 -120/240 120 8720 10150 13499.40 264.66 6o 10150 11570 13659.22 264.37 11570 12990 13667.78 264.37 13695.33 264.50 -150/210 150 12990 14420 13855.52 263.40 go 14420 15840 13882.83 263.40 -18o/18o 15840 17260 17260 18687 11:07, June of 2o16 2M-38wp13 Surface Location CPAI Coordinate Converter.-1�� ----__ t- From: __.__ ________________.____._.,__. _. __._ _ _� � __.._. o: Datum: NAD83 Region: alaska+ Datum: A627 y+ Region: alaska ► _ r Latitude}Longitude Decimal Degrees f' Latitude/Longitude Decimal Degrees + I UTM Zone: j South { t UTM Zone: True f� South E Stake Plane Zone: 4 + Units: us fk Skate Plane Zane: Units: us-ft I" Legal Description (NAD27 only] C Legal Description (NAD27 only) Starting Coordinates: - - - -------� Ending - - i g Coordinates: 1628396.78 X: 488363.907071682 I Y: 1594873EE Y: 5948985.8266316 Transform Q uit Help 2M-38wp13 Intermediate Casing CPAI Coordinate Converter From: _ -_____ __� ____� _ _._.___-- —� -To: -------- _------ _�_ ______--... Datum:NAD83 Region: + g alaska Datum: NAD 27 Region: alaska + r Latitude/Longitude IDecimal Degrees + r Latitude/Longitude Decimal Degrees r UTM Zone: ( South r UTM Zone: True South C State Plane Zone:4 Units: us ft + State Plane Zone:. 4 +, Units: us ft + Legal Description (NAD27 only) i r Legal Description (NAD27 only) Starting Coordinates: - - - - ----- ---- Ending Coordinates:--- oordinates: - X: X: 1618338.22 X: 478305.138718259 Y: 5947022.09 Y: 5947272.21036825 3 .... Transform Quit Help 2M-38wa13 Intermediate Casina II 1 I f CPAI Coordinate Converter "' l�J From: Datum: NAD83 Region: alaska LatitudelLongitude Decimal Degrees r UTM Zone: f— F South is State Plane Zone: q F! Units: us -ft Legal Description (NAD27 only) Starting Coordinates: — — X: 1617017.20 Y: 15946884.51 2M -38w 4, CP.AI Coordinate -To: Datum: NAD27 - Region: alaska .'.! LatitudelLongitudeDecimal Degrees UTM Zone: True F South t. State Plane Zone: q Units: us Ft t C Legal Description (NAD27 only) Ending Coordinates: X: 476984.094539961 Y: 5947134.65557716 r i r Transform Quit Help 13 Toa of Production Horizon From: - -- Datum: Npg3 Region: alaska r Latitude/Longitude Decimal Degrees t- UTM Zone: F— F South r State Plane Zone: F---] Units: us -ft w Legal Description (NAD27 only) Starting Coordinates: -- -- -- X: ji917240.18 w Y:5946913.15 To: E E Datum: 1NTD77 Region: alaska , ! Latitude/Longitude Decimal Degrees r UTM Zone: True South I i+ Stake Plane Zone: q Units: us -ft .r Legal Description (NAD27 only) i F Ending Coordinates: X: f 477207.078737563 I Y: 5947163.29123965 .... Transform Quit Help ..., ..... ..... 2M-38wpI3 TD To ---' ----------- — ------�---- Datum: NAD�� Region: Latitude/Longitude IDecimal Degrees 7 ,r' UTM Zone: FT—rue r South r- State Plane Zone: Units: rus —It ---I EndinnCnordinoteo ---------- X: S7�90U8 Y: 88857 | Transform— Quit Help 2M-38wp13 Surface Location CPAI Coordinate Converter -From: Datum: Region: alaska r Latitude/Longitude DecimalDegrees UTM Zone: South State Plane Zone: 4 Units: fuu—sit-1-11 r Legal Cje:i:cription (NAD27 oniy) Starting Coordinates: -- X: 11628396.78 Y: 15948735.92 To: Datum: NAD27 Region: alaska Latitude/Longitude Decimal Degrees UTM Zone:Frue r- South State Plane Zone: +' -1 Units: ; Legal Description (NAD27 only) Legal Description Township: �011 �N� Range: 0-08 F -D Meridian: Section: 1, 27 JFN[ Dw jE1E.499 FEL -I, F475 .34E ........... .......... ... ransG 2M-38wp13 Intermediate Casing I CPAI Coordinate Converter From: Datum: INAD83 Region: jalaska Latitude/Longitude IDecimal De;,,,, r UTM Zone: r— I- South %` State Plane Zone: I ' Units: .14 -1 1 -u;:ii C' LeQal Description (NAD27 only) F- Starting Coordinates: X: 111318338.E Y: 15947022.09 Quit Help To: Datum: INAD27 �,] Region: lalaska C Latitude/Longitude I Decimal 6 e;"rees C` UTM Zone:r- South FTrue r Stake Plane Zone: 14 Units: I us -ft Legal Description (NAD27 only) Legal Description 1 Township: F01Range: 00-8-1 K-3 Meridian: Section:f3_2 _ FNL 11621.4748 fFEL 4256.9844 Q uit Help Transform ........................................ I — I 2M-38wp13 Intermediate Casing II CPAI Coordinate Con Vertex From: __ __ _ __ _� To: Datum: NAD83 + Region: alaska Datum: NAD27 + Region: alaska + Lakitudell-ongitude Decimal Degrees I Latitude/Longitude Decimal Degrees p � UTM Zone: South I £ j UTM Zone: iTrue I- South i t roState Plane Zone: 14 1 Units: us-ft C Skate Plane Zone: q + Units: us-ft + i Legal Description (NAD27 onlyj Legal Description (NAD27 only) j Starting Coordinates: ------ - -----_-_w__ --. Legal Description -- �: X: 11617017.26 Township: f0-11 N +' Range: 008 E + Y: 15946884.51 Meridian: Section:' 31 FNL 1762.9527 IFEL +j 1296.25469 Transform Quit Help 2M-38wp13 Top of Production Horizon CPAI Coordinate Convert From _.---.._ __...._..� To: Datum: FNA—D-83---Region: alaska Datum: NAD27 Region: lalaska LatitudelLongikude Decimal Degrees' Latitude/Longitude Decimal Degrees + UTM Zone: W r- South UTM Zone: True F South r State Plane Zone:q + Units: us-ft + r State Plane Zone: q Units: us-ft +! r Legal De-:criptior-, (NIAD27 onty) Legal Description (NAD27 only) Starting Coordinates: - — - Legal Description - - ----- X: 1617240.18 Township: 011 N + Range: '_008 E + } Y: 5946913.15 Meridian: ju Section: 31 FF —NL I 1733.6331 IFEL 75.232169 .... € Transform Quik Help 2M-38wp13 TD [ CPAI Coordinate Conve � f From. Datum: Ngpg3 Region: jalaska >r"' Latitude}Longitude Decimal Degrees UTM Zone: - I— South State Plane Zone: 4 Units: us-ft r Legal Description (NAD27 or-iiy) Starting Coordinates: X: 1612822.87 Y: 15946011.95�� -- To: Datum: NAD27 Region: alaska 7 C Latitude/Longitude ' Decimal Degrees T >" UTM Zone: True r South E C' State Plane Zone:. 4 - Units: us -ft r Legal Description (NAD27 only) - Legal Description --- -- --- ) Township: fol 1 N Range: 008 E I Meridian: U �,, Section:31 FNL 2649.5066 1FE ;j 4490.5123 ...................................... € Transform Quit Help As -built 1 11 /13/0 DMP I JFC I lAsbuilt Per K07007ACS 12 10/20/1 J I MEH I JAB 36 Per K140144ACS ` -� AT NOT TO SCALE 250 N 16 15 ( 14 13 I. 16 j 1 V 240 W -2A ( ..................4 2 230 I SCALE- SAKI — I W 220 O� I 1'-2 Mae 21_ 22 23 4 1 1 .I 210 0 2 W 0_ _ i8 J 0 190 3500 28 27 7 26 25 3Q•""'•• ~2 18 I 2M 1340 70 !I I C 300 .......... ... 1' - �, LEGEND: 3 0 r- I I o EXISTING CONDUCTORS 1 40 130 DS -7N I ` --J I :::; x ABANDONED CONDUCTORS .. 134 3 36 31 120 110 \ ASP GRID •,� W m 909A T11N 6607 TI ON NOTES: 266A 1. BASIS OF LOCATION & ELEV. IS DS2M MONUMENTATION PER 195A N \1 \ l VICINITY MAP 260 NOT TO SCALE 250 1 240 I 230 I I I W 220 I z J 210 W 0_ 200 0 190 3500 ( 18 I 1340 70 !I I C 300 II �, LEGEND: 3 0 r- I I o EXISTING CONDUCTORS 1 40 130 ? `— I ` --J :::; x ABANDONED CONDUCTORS DS2M ' 0 CONDUCTORS ASBUILT THIS SURVEY 120 110 100 909A 6607 50 40 NOTES: 266A 1. BASIS OF LOCATION & ELEV. IS DS2M MONUMENTATION PER 195A N M LOUNSBURY & ASSOC. NEW opr�� 2. ELEV. SHOWN ARE B.P.M.S.L. DATUM. I CONDUCTOR o36 `4 V) 3. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD27. 029 I 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 27 & 2A630 28, T11N.—R8E., UMIAT MERIDIAN, ALASKA. I34o1A I 5. THIS IS A RE—DRAFT CONSOLIDATION OF EXISTING DRILL SITE X99 DRAWINGS: CEA—D2MX-6213D15, NSK 6.213D12 & D7. 6. DS2M GRID NORTH IS ROTATED 90'00'47" EAST FROM A.S.P. GRID NORTH. 1 7. REFER TO SHEETS 2 & 3 FOR CONDUCTOR LOCATION INFORMATION. GRAPHIC SCALE 0 75 150 300 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS 1 inch = 150 ft. y� AREA: 2M MODULE: XXXX UNIT: D2 ®n®c®PhillipsDS2M WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6213D29 1/13/07 1_ _ CEA—D2MX-6213D29 1 of 3 2 1 11/13/071 DMP I JFC I 1 Asbuilt Per K07007ACS 12 110/20/141 JFC I MEH I IAB 36 Per K140144ACS * PROTRACTED SECTION 28, T11 N RISE Well NAD 27 NAD 27 No. ASP Coordinates Geographic Coordinates Section Offset Elev. 'Y' 'X' LATITUDE LONGITUDE F.S.L. F.E.L. O.G. PAD 1A 5,948,985.83 487,754.61 70' 16' 18.576" 150' 05' 56.536" 114 86 101.0 104.9 2A 5,948,985.93 487,779.58 70' 16' 18.577" 150' 05' 55.809" 114 61 101.0 104.9 3 5,948,985.91 487,804.53 70' 16' 18.578" 150' 05' 55.083" 114 36 101.0 105.0 28 5,948,985.91 487,829.44 70' 16' 18.578" 150' 05' 54.358" 114 11 101.0 105.0 29 5,948,986.05 487,789.80 70' 16' 18.579" 150' 05' 55.512" 114 51 101.0 105.2 30 5,948,986.04 487,774.40 70' 16' 18.578" 150' 05' 55.960" 114 66 101.0 105.2 32 5,948,986.10 487,744.38 70' 16' 18.579" 150' 05' 56.834" 114 96 101.0 105.1 36 5,948,984.77 487,817.93 70' 16' 18.567" 150' 05' 54.693" 113 22 101.0 101.3 98 5,948,986.04 487,759.38 70' 16' 18.578" 150' 05' 56.397" 114 81 101.0 105.0 99 5,948,985.93 1 487 729.52 70' 16' 18.577" 1 150' 05' 57.267" 114 111 1 101.0 104.9 * Indicates Conductor Asbuilt this Survey OF 40, ••..............• • +i T.�....................... ..... •�^ • A,••N, J. ROOKUS •• •' '01 P J'] ••. LS 803 J!%41 +++�;ROFESSIONAL�Pf ®s SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 17, 2014. LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: 2M MODULE: XXXX UNIT: D2 oncoPillisDS2M WELL CONDUCTORS Alaska, Inc. ASBUILT LOCATION CADD FILE NO. DRAWING NO. PART: REV: LK6213D29 1/13/07 1 CEA-D2MX-6213D29 1 3 of 3 2 Grid Convergence 0.00 Surface ASP Coordinates ASP Y (N/ -S) ASP X (E/ -W) 0.00 0.00 spatial Calculator This values coordinates are in Nad 27 2 N I-23 2M-22 Displacement (ft) 2-D Closure Angle (deg from True North) 2-D Closure Distance (ft in horizontal plane) 3-D Distance (ft) 3-D Distance (ft) 2-D Closure Distance (ft in horizontal plane) 2-D Closure Angle (deg from True North) Displacement (ft) 2NI-2° 2-1-3f� Coords. - ASP Subsea TVD (a) Coords. - TRUE N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) 5948985.83 488368.91 5948985.77 488344.40 Answer 5948985.83 488363.91 S -0.06 W -24.51 W 269.86 24.51 True North 4 CI-Angk t�triLt P�t�r 5.00 % W 270.00 Final Puts S n_nn W -5.00 Answer Q Coords. - ASP Subsea TVD (ft) Coords. - TRUE N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) N(+)/S(-) E(+)/W(-) Lat. (Y) Dep. (X) 5948985.83 488368.91 5948985M 488363.91 Answer 5948985.83 488363.91 Rami To: Datum [NZ27 ; Region. P-ka Datum: 4AD83 jf—R-- alaska—I C Latdude/Lanplude Decimal Degrees C` LatitudelLor>gitude Decima Degrees —� i` UTM Zone: r SWh -'. f UTM Zone: fr, r South r. State Plane Zorx: 4 Units: us4t C• State Plane Zone: �q -7j Uras: usdt f LegalDes rt ll`idD2 only) T Legal De=Wjon [NAD27 orgy) Starting Coordinates: Endesg Coordinates. X [d88363.91 X 1628396.7829282 y59a898583 Y 59x8 35.9232 �% �; Translam Quit H* ) Nad83 conversion Spatial Calculator Page 1 of 1 (2M-38wp09 SpatialCalculator_5ft West 2M-23.xlsx) 1/13/2016 11:41 AM 2M-38 Drilling Hazards S-Lmmary 16" Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Gas Hydrates Low Monitor well at base of permafrost, controlled drilling rates, low mud temperatures. Additions of Lecithin. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced sever mud lost. Monitor real time equivalent circulating density (ECD) to below Lost Circulation Moderate expected formation fracture gradient. Prepare enough lost Lost Circulation Low circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of Hole swabbing on trips Moderate hole if necessary. Monitor real time surveys closely, shut in nearby wells Anti -Collision Low that we have collision concerns with, run gyro survey to eliminate magnetic interference from nearby wells when needed Washouts / Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize circulating time when possible 12-1/4" Hole - 9-5/8" Liner Interval Hazard Risk Level I Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and torque/drag real time The Iceberg formation pressure is estimated to be Abnormal Reservoir Pressure Moderate 10.1ppg. Weight up mud to 10.4-10.5ppg before drill into Iceberg formation. Monitor ECD to below expected formation fracture Lost Circulation Low gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary Attachment 2 - 2M-38 Drilling Hazards Summary. docx 6/6/2016 8:23:00 AM 8-3/4"x9-7/8" INTRM2 Section -7" Liner w/ Tieback Hazard Risk Level I Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and Abnormal Reservoir Pressure Moderate torque/drag real time The intermediate II section is penetrating into the reservoir of Kuparuk C, which is estimated to be 12.1 - Abnormal Reservoir Pressure Moderate 12.3 ppg. Utilize MPD for shale stability and pore pressure management. Shut in nearby injectors to prevent Lost Circulation Moderate pore pressure rise. Monitor real time equivalent circulating density (ECD) to Lost Circulation Moderate below expected formation fracture gradient. Prepare Getting Liner to bottom Moderate enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy The reservoir pore pressure of Kuparuk C is estimated to Abnormal Reservoir Pressure Moderate be 12.1-12.3 ppg. Utilize MPD pore pressure management to ensure wellbore overbalance. Shut in nearby injectors to prevent pore pressure rise. Stuck Pipe Low Keep good hole cleaning practices, use PWD tools monitoring and analysis, stabilized BHA Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program, control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly clean hole prior to pulling out of hole to run liner. Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use of trip sheets), pumping backreaming out if necessary Attachment 2 - 2M-38 Drilling Hazards Summary.docx 6/6/2016 8:23:00 AM 2M-38 Cement Calculations Surface Cement Lead Hole Size ft (Top) ft (Bottom) OD ID ppf Conductor Depth: XS% Below PF 39 121.5 20 19.124 94 Surface Casing Depth: 16 39 2979 13.375 12.415 68 Intermediate #1 Casing Depth: 12.25 2829 12951 9.625 8.8325 40 Intermediate #2 Casing Depth: 9.5 39 14251 7 6.276 26 Surface Cement Lead 1.91 ft3/ sx of 11 ppg DeepCRETE Tail 1.63 ft3/ sx of 15.8 Class G Permafrost (PF) depth 1580 ft XS% Above PF 200 % XS% Below PF 50 % Capacities OH 0.24869 16"x13-3/8" 0.07491 20"x13-3/8" 0.1815 13-3/8" 0.14973 Tail Cement Length 500 ft 500 x 0.07490711 x 1.5 56.18033 Shoe Track 80 ft 80 x 0.14973016 x 1 11.97841 Open Hole 10 x 0.24868856 x 1.5 3.730328 Total 71.88907 bbl 248 sx Lead Top Tail Cement to Permafrost 899 ft 899 x 0.07490711 x 1.5 101.0122 bbl Permafrost to 20" Casing 1458.5 ft 1458.5 x 0.07490711 x 3 327.756 bbl Conductor Length 80 ft 80 x 0.18150063 14.52005 bbl Total: 443.2883 bbl 1303 sx Intermediate #1 Cement: Need 100bbls in Annulus + Shoe Track XS% for open hole and annulus: 30 100 1.3 x 5.614/ 1.63 447.7423 sx 80 ft x 0.07582789 x 5.614/1.63 20.89314 sx Total: 468.6355 sx Intermediate #2 Cement: Cement to Liner Top Hole Size: 9.875 Capacities: 9.875" x 7" 0.04713 9.625"x7" 0.02818 7" 0.03826 %XS 30 Open Hole Length from Shoe to 9.625 shoe: 1300 1300 x 0.04713 x 1.3 79.6497 bbl 150 Overlap of Liner 150 x 0.02818443 4.227665 bbl Shoe Track 80 x 0.03826324 3.061059 bbl Open Hole 10 x 0.09473055 1.3 1.231497 bbl Total: 88.16993 bbl 303.6724 sx zM-38 'v' Grass Roots Horizontal "C" Sand Producer ConoeoPhillips Proposed Wellbore Schematic (4 -String) (WP13) Conductor To Be Installed: 20" 94# H-40 set @ +/-121' Spud mudI I I I I 16" Surface Hole 8.6-9.5PPG est , 2,887' MD / 2,592' ND 9 5/8" x 13 3/8" Liner hanger: ± 3,471' MD Surface Casing: Below West Salk 13-3/8" 68# L-80 Hydril 563 ± 2,979' MD / 2,642' ND 3,860' MD / 2,956' ND C MpS.......... LSND WBM 9.5-10.5 PPG 1.0,045' MD / 4,749' ND :::::::::::Icor':::::::::: $ I I Tubing: ± 13,436' 3-%" 9.3# L-80 EUE8RD TOC @ ± 11,100' MD 9 5/8" x 7" liner hanger @ ± 12,801' MD 12-1/4" Intermediate Hole Intermediate 1: 9 5/8" 40#, L80,Hyd563/BTC-M LSND WBM @ ± 12,951' MD / 5,694' ND 10.5-12.5 PPG 8-3/4" x 9-7/8" Intermediate Hole Production Liner: 4-1/2" 12.6#L-80 IBTM Perforated Pups 14,101'— 18,688'MD/6,079' TVD eSarid?d'::s4;Q59'!t/kB:�S,Dr!a. Fr/P::: . p. . 7';2xP-lutdrT-.dPT4)cer.til.+4,M1.MLl 7!':x4':'•':Baker Flex tockEirief fieri ' r•: ::: ...............: ' r e dia i�'sa::$ : Fa nt rme ..te2 ..,•.,,4•D,.Hyd.,6,.@.::::: ::-:ia;2si�:aa :Z . osa. > n::::::::::::::::::::::::::::::::.:::::::.:.:.:::::::::::::.:.:.::::: 6:8•.Prfldvct�an:Hole:;:;.;.•:• .Br:::::::::::::::::::::::::::::::: .................................... 0000000000 ° 00000 00000 000000000 0 0 00000 00 0 0 0 0000 0 0 00 0° ............................ .:: ......:ii Production Liner: 4-1/2" 12.6#L-80 IBTM Perforated Pups 14,101'— 18,688'MD/6,079' TVD To DS2L (31) 37 1 A9I8 2A 3 28 5A 6A -0 (33) 99 3 30 29 36 27 1 2 4Lkj 6 DRILL SITE 2M SCALE 00 1 50 100 8A 9A 9 1p371I1381k co 1F 1 1k 1k F 1 rSWSA PIG PIT SWSA 0 U w Pipelines To CPF-2 `' ConocoPhillips TITLE: DRILL SITE 2M Alaska, Inc. DRAWN BY: ALKET MICI DATE: 06-01-2016 REV: 1 o-ael�s-xnca-ad:; � � eeDD � uasN PIPELI VES (ALLEY OPTION A: ;Utilize the slot 19 production tie-ins inside the manifold module for the Z €'E ':2M-38 (prod) lateral tie-in. Well 18 is currently tied-ln to slot 19 for ,injection service, but is a LTSI well, °RILL sne We would demo out the injection piping from well 18 back to slot 19 in GRaPHIC SCALE the manifold module and use the slot to tie-in the production line from the new well to be drilled in location 23. The production piping would o !run along the existing pipe rack from the manifold module out to well ;location 23. This will require HSM modifications or new VSMs for the last \� ;three HSMs In the pipe rack. ® oPnc cneLE oNLv IaANsroRMLx— � © oneP r< o m cAeL< Os .N I ST03M WATER STORAGE AREA E 12+1% + I I \\ I I \\ I € € I ------------ J / °! —I— E LB+aO } 1 j b % ❑c1ej1 Xo q3 X38 - - - - - -ABANDON v.ELL LOCATION (T-) li GRADEBEAMS (i J yi -- v I To 11-1 --------------------------------- D R 11 11 I ST E 2M ALLEY OPTION B: To D52L _ E B+BB + Locate 2M-37 (inj) at 20' from center of well 32, It a + ------------ + would be tripled with wells 3 and 30 for injection service. E QD L WI lines to each well will be independently isolated $ $ from the other wells with isolation plug valves and I °^ ,6 spec blinds to be located inside the well 03 well house. Additionally, facilities will install an orifice meter for each WI line to independently monitor e1 ASSOCIATES. INC. 9 un�vevons enawan nnx Ne flow to each well (3, 30, and 37). D\ u Y NT„rs — I I PRINTS 3-10 ARE 0 PPEP DP 2 GRWPS Or 2 EACH CA3LE5. L, Alaska, Inc. 2. ALL EOORD'. NATE`. APEDRILLSITE 2-M PLANT CPID 3. ALL ELEVATioNS AR. EPMSL DAIUM AREA: 2M MODULE: XXXX UNIT: D2 I € € I ------------ J / °! —I— E LB+aO } 1 j b % ❑c1ej1 Xo q3 X38 - - - - - -ABANDON v.ELL LOCATION (T-) li GRADEBEAMS (i J yi -- v I To 11-1 --------------------------------- D R 11 11 I ST E 2M To D52L _ E B+BB + '------------------ —I— ------------------------------------------------------ + + ------------ + ------------- ------------------ - L $ $ LOUNSBURY ASSOCIATES. INC. 9 un�vevons enawan nnx Ne NT„rs ConocoPhillips PRINTS 3-10 ARE 0 PPEP DP 2 GRWPS Or 2 EACH CA3LE5. Alaska, Inc. 2. ALL EOORD'. NATE`. APEDRILLSITE 2-M PLANT CPID 3. ALL ELEVATioNS AR. EPMSL DAIUM AREA: 2M MODULE: XXXX UNIT: D2 DS2M UNDERGROUND UTILITIES ASBUILT Well: 2M-38 I <== Data Input Name: I V Loepp I — Data Input Mud Weight (ppg) 1 12.50 — Data input Neak point or LOT - Measured depth (ft) 2,829' — Data Input Neak point or LOT True vertical depth (ft) 2,560' <== Data Input Neak point or LOT - Hole angle (deg) 55.00 — Data Input Neak point or LOT - Hole size (in) 13.375" — Data Input Neak point pressure or LOT - EMW (ppg) 12.50 — Data Input cone of interest - measurea aeptn ttt/ 14,zar — uata input Zone of interest - True vertical depth (ft) 6,084' — Data Input Zone of interest - Hole angle (deg) 90.00 — Data Input Zone of interest - Hole size (in) 12.250" — Data Input Zone of interest - Pore pressure EMW (ppg) 12.10 — Data Input <== Data Input Bottom hole assembly OD (in) 8.0" 1 <== Data Input Bottom hole assembly length (ft) 200' <== Data Input Drill pipe OD (in) 5.500" — Data Input BHA annular vol. @ zone of interest (bbl/ft) 0.0836 DP annular vol. @ zone of interest (bbl/ft) 0.1164 DP annular vol. A weak point (bbl/ft) 0.1444 Additional safety margin (psi) 1 0.00 1 <== Data Input Weak point pressure (psi): PIo 1,664 psi Weak point pressure - Safety margin: Pmax Pmax EMW 1,664 psi 12.50 ppg Max anticipated formation pressure (psi): Pf 3,828 ps Weak Pt to Zone of Interest distance (TVD ft): OH {TVD} 3,524' Weak Pt to Zone of Interest distance (MD ft): OH {MD} 11,422' Maximum influx height at the bit (TVD ft): H {TVD) 230' Maximum influx height at the bit (MD ft): H {MD} Calc. volume of (H) around BHA: Calc. volume of (H) around drill pipe: Calc. volume that H equals @ initial shut in: V1bha V1dp V1 ########### 16.7 bbl # Calc. vol. that H equals @ weak point (MD ft): VWp 57.9 bbl Calc. volume of VWp @ initial shut in: V2 25.2 bbl Kick Tolerance: V2 25.2 bbl TE: Loepp, Victoria T (DOA) From: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Sent: Thursday, July 07, 2016 8:50 AM To: Loepp, Victoria T (DOA) Subject: RE: KRU 2M-38(PTD 216-083) Anti -collision Victoria, 2M-23 is already abandoned and we also intend on running Gyro to survey. Let me know if you need more. Cheers. Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, July 07, 2016 8:45 AM To: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Subject: [EXTERNAL]KRU 2M-38(PTD 216-083) Anti -collision Kurt, In the anti -collision analysis, 21VI-23 fails major risk. What mitigation measures are planned? Do you plan to shut in 2M- 23 during drilling? 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. Loepp(cDalaska.go 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(c�alaska.gov Bettis, Patricia K (DOA) From: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Sent: Wednesday, June 08, 2016 3:48 PM To: Bettis, Patricia K (DOA) Subject: RE: KRU 2M-38: Permit to Drill Application My apologies Patricia, This well (2M-38) will be a development oil well. Kurt Alexa Staff Drilling Engineer ConocoPhillips Alaska (907) 263-4933 ( Office ) (907) 787-9637 ( Cell ) From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, June 08, 2016 3:32 PM To: Alexa, Kurt J <Kurt.J.Alexa@conocophillips.com> Subject: [EXTERNAL]KRU 2M-38: Permit to Drill Application Good afternoon Kurt, On Form 10-401, Box 1b, the exploratory gas box is checked. On the accompanying cover letter from ConocoPhillips, it is stated that the operator applies for a permit to drill an onshore grassroots producer well that will target the Kuparuk C sand. Please verify whether the proposed application is for an exploratory gas well or a development oil well. 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 cx alaska.gov. TRANSMITTAL LETTER CHECKLIST WELL NAME: kk, a ► i — 3 zS PTD: o )(I — 003 /Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: V6,r R1 6f V+� 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 ( PIT) 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 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUKRIV UNIT 2M-38 _ Program DEV _ Well bore seg ❑ PTD#: 2160830 Company CON_ OCOPHILLIPS ALASKA INC Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 11 Permit fee attached_ - - - - - - - - - - - - - - - - - - - -NA_ - - . Appr Date PKB 6/9/2016 Engineering Appr Date VTL 7/7/2016 Geology Appr Date PKB 6/9/2016 2 Lease number appropriate_ - - - - - - - _ - - - - - - - Yes - _ - - - ADL0025586, Surf Loc; ADL0025585,Top Prod_Intery &_TD. - - - - - - - - - - - - - - - - - - - 3 Unique well name and number - - _ _ - - - - - - - - -- - - - - - Yes - - - - _ _ - KRU 2M-38 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - 4 Well located in_a_defined -pool - - - - - - - - - - - Yes - _ _ - - KUPARUK RIVER,_KUP_ARUK_RIV OIL - 4901.00,_ governed -by Conservation_ Order No. 43-2D- 5 Well located proper distance from drilling unit boundary- Yes - - - - - - CO 432D contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells_ - - - - - - - - - - - - Yes _ CO 432D has no interwell spacing restrictions-- - - - - - - - - - - - 7 Sufficient acreage_availablein-drilling unit- --- - -- -- - -- Yes--------------------------------------------------------------------------- - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - -- - - - 8 if_deviated,is_wellboreplat-included ------------ ------------- - Yes------------------------------------------- ------------------------ 9 Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - . - - Wellbore will be more than 500' from an external property line where ownership or landownership_ changes._ 10 Operator has -appropriate bond in force - - - Yes - - - - - - - - - - - - - - - - - - - - 11 Permit_ can be issued without conservation order- - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - 12 Permit_can be issued without administrativ-e_approval Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - _ - . 13 Can permit be approved before 15 -day wait ------------- _------- -------- - Yes_________________-_____--___-_____------------------------- - - -- 14 Well located within area and -strata authorized by Injection Order # (put 10# in -comments)- (For- NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells- within _1Arnil_e area -of review identified (For service well only)_ - - - - - - - - - NA_ - - - - - - - - . 16 -Pre-produced injector. duration of pre -produQtion less. than 3 months- (For service well only) - _ NA- - - - - - - - - - - - - 17 Nonconven, gas conforms to AS31.05.030Q.1.A),Q.2.A-D) - - - - - . - - - - - - N_A- - - - - - - - - - - - - - 18 19 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 Conductor string provided - - - - -- - - - - - - ---------- Yes - - - _ _ - 80' conductor set_ Su face casing_ protects all -known_ USDWs Yes - - - - _ 2979'_MD - - - _ CMT -vol adequate_ to circulate -on conductor _& surf_csg - - - - - - - - - - - - - - - - - - Yes - - - - - - 132%_excess --- - - - - - - - - - - - _ - - - - - _ - - - CMT_vol_ adequate -to tie -in -long string to -surf csg__ _ _ - ---- -- No_ __ __ _----------- _________ _---------- -CMT CMTwill coverall known -productive horizons_ - - - - No_ - Productive. interval will_be_completed with perforated pup liner_ Casing designs adequate for C,_T,13&_permafrost- Yes - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - -- - - - Adequatefan_kage.or reserve pit - - - - - - - - - Yes - Rig has steel tanks; all waste -to approved disposal wells_ - - - - - - - - - If_a_re-drill, has.a 1.0-403 for abandonment been approved . - - - - _ - - - - - - NA_ - - - ..- ...--------------- -- - - - - . - - - - - - - - - - - - - - - - - Adequate wellbore separation -proposed Yes _ _ Anti -collision analysis complete; Major risk failure 2M -23 -which is abd. - - . If_diverter required, does it meet regulations_ - - - - - - - - Yes Diverter is acceptable - - - - - _ - Drilling fluid program schematic-&- equip -list-adequate _ - - - - - . Yes - - - Max reservoirpres is -3-821 psig(12.1_ ppg_EMW); will drill- w/ 8.6-1.2.5_ppg EMW; MPD_ BOPES,_do they meet regulation Yes - -- - - - - - - ------------ BOPE_press rating appropriate; _test to -(put psig in comments)_ Yes - - - MPSP [s_3213 psig; will test BOPs_to 3500_psig - - - - - - Choke _manifold complies w/API_ RP -53 (May 84) _ - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - Yes - - - - - - _ - - _ - - - - - - - - . - - - - - - _ - - - Is presence of H2S gas probable_ - - - - Yes - - H2S measures required_ - - _ Mechanical_ condition of wells within AOR verified (For service well only). _ _ _ _ __ _ _ _ _ _ _ _ _NA _ - _ - _ - _ - - _ - - - - - _ _ - - - - - - - _ - _ -- _ -- - - - - _ Permit can be issued w/o hydrogen sulfide measures No_ Wells- on 2M -Pad are H2S-bearing. _11_25 measures. required _ _ _ _ _ Data. presented on_ potential overpressure zones - - - Yes Expected reservoirpressure is 12.11 ppg_ EMW;-will be drilled_ using 8.6.to 12.5 ppg_ mud. Seismic_analysis_ of shallow gas_zones_ - - - - - - - - _N_A_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Seabed.condition survey (if off -shore) _ - .. NA- - - - - - Contact name/phone for weekly -progress reports [exploratory only] _ - - - - - - - - - - NA_ _ Onshore development well to -be -drilled - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering Public Commissioner: Co 'sinner: Commissioner Date �Date�� 77a��
