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218-004
DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180040 Well Name/No. KUPARUK RIV UNIT 1H -103L1 Operator CONOCOPHILLIPS ALASKA, INC MO 15103 TVD 3884 REQUIRED INFORMATION Completion Date 5/4/2018 Mud Log No,/ DATA INFORMATION List of Logs Obtained: GR/ Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data A00cc API No. 50-029-23593-60-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No Samples No ✓usDirectional Survey Yes `/No (from Master Well Data/Logs) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 119 1882 6/29/2018 _ Electronic Data Set, Filename: CPAI_i H- 1031-1_Scope_Resistivity_RM_LAS_LWD001.1as 1702 8120 6/29/2018 Electronic Data Set, Filename: CPAI_1 H- 1031-1_Scope_Resistivity_RM_LAS _LW D002.las 7563 15102 6/29/2018 Electronic Data Set, Filename: CPAI_1H- 1031-1_Scope_Resistivity_RM_LAS _LW D006.las 22 15102 6/29/2018 Electronic Data Set, Filename: CPAI 1 H- - 1031 -1 103L1 _Scope_Resistivity_R M_LAS.Ias 6/29/2018 Electronic File: CPAI_1H- 103L1_Scope_Resisitivity_RM_DLIS_LW D001.ht ml 6/29/2018 Electronic File: CPAI_1H- 103L1_Scope_Resistivity_RM_DLIS_LW D001.dlI s 6/29/2018 Electronic File: CPAI_1 H- 103L1_Scope_Resisitivity_RM_DLIS_LW D002.diI s 6/29/2018 Electronic File: CPAI_1H- 1031-1Scope_Resisitivity_RM_DLIS_LW D002.ht ml 6/29/2018 Electronic File: CPAI_i H- 103L1_Scope_Resisitivity_RM_DLIS_LW D006.dli s 6/29/2018 Electronic File: CPAI 1H- 103L1_Scope_Resisitivity_RM_DLIS_LW D006. ht ml 6/29/2018 Electronic File: CPAI_1H- 103L 1 _Scope_Resistivity_RM_DLI S.diis Page 1 of 3 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180040 Well Name/No. KUPARUK RIV UNIT 1H-10311 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23593-60-00 MD 15103 TVD 3884 Completion Date 5/4/2018 ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data ED C 29445 Digital Data Log C 29445 Log Header Scans Completion Status 1-011- 0 -OIL 0 0 Current Status 1-0I1- UIC No 6/29/2018 Electronic File: CPAI 1H - 103L 1 _Scope_Resistivity_RM_DL IS. htm I 6/29/2018 Electronic File: CPAI_1 H - 103L t _Scope_Resistivity_2 MD_RM.pdf 6/29/2018 Electronic File: CPAI 1H - 103L 1 _Scope_Resistivity_2TVD_RM. pdf 6/29/2018 Electronic File: CPAI_1H- 1031-1 _Scope_Resistivity_5MD_RM.pdf 6/29/2018 Electronic File: CPAI 1H - 103L t_Scope_Resistivity_STVD_RM.pdf 6/29/2018 Electronic File: CPAI_1H-103L1_Survey_List.csv 6/29/2018 Electronic File: Gyrodata Survey - 1 H-103.pdf 6/29/2018 Electronic File: 1H-1031-1 NAD27 EOW Compass Survey [Cavnas].txt 6/29/2018 Electronic File: 1H-1031-1 NAD27 EOW Compass Survey [Macro].txt 6/29/2018 Electronic File: 1H-1031-1 NAD27 EOW Compass Survey [Petrel].tzt 6/29/2018 Electronic File: 1H-1031-1 NAD27 EOW Compass Survey [Surveys].tM 6/29/2018 Electronic File: 1H -103L1 NAD27 EOW Compass Surveys.pdf 6/29/2018 Electronic File: 1H-1031-1 NAD83 EOW Compass Survey [Cavnas].txt 6/29/2018 Electronic File: 1H-1031-1 NAD83 EOW Compass Survey [Macro].txl 6/29/2018 Electronic File: 1H-10311 NAD83 EOW Compass Survey [Petrel].t# 6/29/2018 Electronic File: 1H-1031-1 NAD83 EOW Compass Survey [Surveys].txt 6/29/2018 Electronic File: 1 H-1031-1 NAD83 EOW Compass Surveys.pdf 2180040 KUPARUK RIV UNIT 1H-1031-1 LOG HEADERS AOGCC Page 2 of 3 Monday, November 26, 2018 DATA SUBMITTAL COMPLIANCE REPORT 11/26/2018 Permit to Drill 2180040 Well Name/No. KUPARUK RIV UNIT 1H-1031-1 Operator CONOCOPHILLIPS ALASKA, INC. MD 15103 TVD 3884 Completion Date 5/4/2018 Completion Status 1-0I1 Current Status 1-0I1 Well Cores/Samples Information: Interval Sample Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED Completion Report 0 Production Test Information r/ NA Geologic Markers/Tops I Y �J COMPLIANCE HISTORY Completion Date: 5/4/2018 Release Date: 2/28/2018 Description Comments: Directional / Inclination Data &Y Mechanical Integrity Test Information Y / NA Daily Operations Summary D Date - -- ^� Compliance Reviewed By: _ _ _ _ _ Comments API No. 50-029-23593-60.00 UIC No Mud Logs, Image Files, Digital Data Y AR Core Chips Y / Composite Logs, Image, Data Files G) Core Photographs Y/& Cuttings Samples Y /O Laboratory Analyses Y / -42�&ff-9 Date: AOGCC Page 3 of 3 Monday, November 26, 2018 21 8004 29 44 5 moer Transmittal #: 29JUN18-SP02 Drilling & Measurements Product Delivery Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Natural Resources Tech Well Name: 1H-1031_1 Date Dispatched: 29 -Jun -18 Service Order #: 17AKA0033 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: N/A Contents on CD 2 -Apr -18 Scope Resistivity 2" MD x 2" TVD x 5" MD x 5" TVD RE ENE A N 2 9 2018 A GCC Digital Data NIA Contents on CD LAS/DLIS Data x Surveys N/A Contents on CD Directional Survey Nad27 x Directional Survey Nad83 x Gyrodata Survey x CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Surveys: PDF/TXT x Please sign and email a copy to:se sign and email a copy to: Tom.Osterkam Conoco h' i s.com Alask PTSPrintCenter slb.com Attn: Tom Osterkamp Attn: Ste hanie Pacillo Received By: 0 zi8-at�y Davies, Stephen F (DOA) From: Shumway, Kelsey <Kelsey.Shumway@conocophillips.com> Sent: Monday, June 11, 2018 7:53 AM To: Davies, Stephen F (DOA) Cc: Guhl, Meredith D (DOA); Haggerty -Sherrod, Ann (Northland Staffing Services) Subject: RE: [EXTERNAL]RE: KRU 1 H-103 (PTD #218-003) Producer Schematic Attachments: 1H-103 Well Schematic As Drilled Final.pdf Steve, Sorry for the mix up —the correct schematic is attached. Kelsey Shumway Senior Drilling Engineer ConocoPhillips, Alaska ! 907-440-0004 cell From: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Sent: Friday, June 08, 2018 11:13 AM To: Kelsey.shumway@cop.com; Shumway, Kelsey <Kelsey.Shumway@conocophillips.com> Cc: Guhl, Meredith D (DOA) <meredith.guhl@alaska.gov> Subject: [EXTERNAL]RE: KRU 1H-103 (PTD #218-003) Producer Schematic Hi Kelsey, The email address provided for you on the Well Completion Report for KRU 11-1-103 appears to be invalid. I'll try .conocophillips.com rather than .cop.com. I'm reviewing the Well Completion Report for KRU 11-1-103, and the accompanying producer schematic drawing has incorrect depths for the casing strings and TDs of each of the wellbores. My guess is that this is an as -proposed drawing rather than an as -completed drawing as the title indicates. Could you please check this and, if necessary, submit a revised version with all depths corrected? Thank you, Steve Davies Senior Petroleum Geologist AOGCC 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 Steve Davies at 907-793-1224 or steve.daviesr@alaska.gov. Casing, 20", 94#, K55 x 34", 0.312" 94# WT @ 119' MD 10-3/4",45.5#. L-80, Hyd563 MD / 1770' TVD Wellhead / Tubing Head / Tree, 13-3/8" x 4-'A". 5.000 ksi Hanger to tubing XO: 4-1/2". 12.6 #. L`80 IBTP x IBT P Tubing String: 4-1/2". 12.6 #. L-80 TXP 1H-103 Producer Schematic Final as -completed Gas Lift Mandrel, 4-1/2" x 1" KBMG BK -5 Latch w/dummy 2678' MD Gas Lift Mandrel, 4-12" x I" KBMG SK -5 Latch w/ dummy 4268' MD Gas Lift Mandrel. 4-12" x 1" KBMG Bek latch w/I"SOV 5801' MD - Sliding Sleeve (a) 6649' MD Permanent Down Hole Gauge 6714' MD � Tubing Seal Assembly 'O ZXP Packer - 6768' MD 0 m DB -6 Nipple 6826' MD �— L4 "D" Sand Bottom of Window @ 6911.75' MD / 3823' TVD ••••.• 6-3/4" D sand lateral la = 14437'MD/3809'TVD� ••• 2.IBTM L80. Slotted Liner LBO..••.•.Line. •' o m uM .................4 ..............................................................................e ---------------- T........................... .........•..................................................•............................... �' e •• L3 "B" Sand Bottom of Window n 7232' MD / 3901' TVD 6-3/4" B -D sand lateral = -• .•• 14904'MD/3831'TVD a 4 Stacked Baker Hook Hanger [� Level 3 Junction Systems 4-I/2" Slotted Liner, 12.6# IBTM L80 ..........................................................................................L.........--"'..n. ............................................................................................L................... •' ZXP Packers IH103L3: 7031' MD I1-11031-2: 7299' MD I14103LI: 7545' MD Lateral Entry Module Tubing Seal Assembly 'sA 3563" DB -6 nipple @ 7749.9' MD ,g ZXP packer7761' MD ffi 7-5/8",29.7#. L-80, Hyd563, Cap m4 8112'MD/ 4088'TVD L2 "A4" Sand Bottom of Window @ 7464' MD / 3960' TVD — 4-1/2" Slotted Liner. 12.6# TXP L I "A3" Sand Bottom of Window @ 7625' MD 139971 TVD 4-1/2"Sloned Liner, 12.6# IBTM L80 6-3/4" A4 -B sand lateral 14133' MD / 3881' TVD 6-3/4" A3 -A4 -B sand lateral liner 15032' MD / 3884' TVD 4-1/2". 12.6# SLHT Slotted/Blank. TXP Blank L80 6-3/4" A2 -A3 sand lateral liner 13655' MD/ 3995'1 VD .e.e.....----..r..y.---n.y�...=en.e....................................• RECEIVED STATE OF ALASKA JUN s 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN ta. Well Status: Oil2l• Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20a 025,105 20AAC 25.110 Development[] ' Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: A 4•0,18 Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Aband.: 5/4/2018 - 218-004 • 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 7. Date Spudded:,�t� 3P9/2018 A, . 5,1t 15. API Number: 50-029-23593-60-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 5260.48' FNL, 768.38' FEL, Sec28, T12N, R10E, UM • 4/1/2018 • KRU iH-1031-1 . Top of Production Interval 9. Ref Elevations: KB:93.03 • 17. Field / Pool(s): 991' FNL, 738' FEL, Sec 34, T12N, R10E, UM GL: 64 • BF: Kuparuk River FleIdNVest Sak Oil Pool Total Depth: 323' FNL, 838' FEL, Sec 27, T12N, R10E, UM 10. Plug Back Depth MD1 VD: NIA �� 18. Property Dysignation: 6ADL 2563$; ADL 25638 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 549573 y- 59807?PAL--�"# Zone- 4 11. Total Depth MD/TVD: . 15103/3884 • 19. DNR Approval Number: LO/NS 80-261, 931695000 TPI: x- 554892 y- 5979749 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 554739 y- 5985696 Zone- 4 N/A 1722/1638 5. Directional or Inclination Survey: Yes ❑� •(attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 761113994 22. Logs Obtainec ## List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary GR/Res 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT HOLE SIZE CEMENTING RECORD GRADE TOP BOTTOM TOP BOTTOM PULLED 20 94 H-40 39 119 39 119 42 Existing Cement 10314 45.5 L-80 41 1877 41 1770 131/2 1,060sx 11.0ppg UteCrete, 75/8 29.7 L-80 38 8112 28 4088 97/8 1,210sx 15.8ppg Class G 41/2 12.6 L-80 7607 15032 3993 3884 63/4 Slotted Liner 24. Open to production or injection? Yes Q No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 41/2 6806 N/A SLOTS @: COMPLETIp;v 7735 - 8509 MD and 4019.4041 TVD ... 413/18 DATE 8749 - 9075 MD and 4040-4032 TVD...4/3/18 'v,• � t �f p 1009 9892 MD and 4007-4005 TVD...4/3/18 --�= 6IED E 10094 - 11193 MD and 4000-3974 TVD...4/3/16 VERIFIED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� - Per 20 AAC 25.283 2 attach electronic and printed information ()() DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11895 - 12263 MD and 3978-3954 TVD ... 413118 _�fh 12711 -14990 MD and 3923-3883 TVD ... 4/3118 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 5/13/2018 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 5/27/2018 7.5hrs Test Period695 BBL 186 8 28% open 179 Flow Tubing Press. 331 sl Casino Press: 1546 si Calculated 24 -Hour Rate Oil -Bbl: 2076 STB Gas -MCF: 1 Water -Bbl: 26 Oil Gravity- API (corr): 187 Form 10-407 Revised 5/2017 RMS��N Q' 15frTINUED ON PAGE 2 �L �V -2�/ � Submit ORIGINIAL onlf 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� - Sidewall Cores: Yes ❑ No 2 , 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 ❑� If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1722 1638 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation @TPI -West Sak A4 7611 3994 TD 15103 3884 Formation at total depth: WEST SAK B 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontoloair-alreport. 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. t, Authorized Name: G.L. Alvord Contact Name. f else Ilfo humw Authorized Title: Alaska Drillin Manager Contact Email: kelsey.shumway0cop.cdfn Authorized C�v�fz- Contact Phone: 265-1577 Signature: ate: t 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 ta: 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 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Wellhead) Tubing Head l Tree, ,mlmed C9nduemr 13 -318•x4 -'A", 5,000 kai 1H-103 Producer Schematic Cuing, 20", 94k, K55 x 34'L 0.312" Haugerw robing XO'. 4.1/2', 12.6 k. LAO Final as -completed WTrj IBTPxHIT P +/-SO'MD Tubing String. 4-12', 12,61, LAD TXP Lift Mandrel, 4-12" x I" KBMG BK -5 Lurch w/dummy cane 2263.5' MD G. Lift MandmL 4-IQ"x 1" KBMG BKA In.hu/ dummy 4438' MD G. Lift MandreL 0.12" x 1"KBMG Bek latch w/I" SOV 524] 9' MD 1LAO,yd563 4 W BakerCMU.,M3812"DBNipplepmfil..B Cplogin9WiM5316.1'MD L-80, Hyd563 �� 1893' MD 117654'ND Camra 4-W Solid gauge mandml. NpPG. eingk gauge Permanem Dawn Hole Gauge 5379.6' MD /—Tubing Said Assembly 9 ZXP Packer-5439.4'MD� Carrion, 4-Wx3.25" DBfi Nipplc 5494'--L4'D" Sand Bonom ofWindara5528'MD 13662'TVD MD 6a/4"DmMla¢ml m = ,,, II2U85'MD/3244'TYO� •. 4-1212.6# IBTM LBO, Sloncd Liner =- m o - ••- ...........................................................................................-.., f ---------------- S 2 ..................................................................................................................... e g L3 "B"' Sand Bottom of Window (d 5853' MD 1373 1- TVD 6-3/4"Bland lamrel 11802 3'MD /3295' TVD c a 4 Staled Baker Hook Hanger 4-I12" SI led Liner 12 Be IBTM L80 t• Lerd3Junetion SYrtema.........................................................................••-•------------................. e 3 . ................................. a..........................................................................= ZXP Packers R"A4-Sand Bonom.&Window Ob 6046'MD 13285' TVD '•. 6-i/4''A4 mMlateral IHIOIL3: 56553'MD IHI01L2: 5926A' MD .......� 12" Slolmd Lincq 12 6q MTM L80 XO m 116q MTM L80 11809' MD/ 3825'ND� ., IHI01-LI:61268'MD ------------------------- LI "A3' Said Batton of Window,, 62044' MD / 3828' TVD 63/4"A3 wand [Brant liner Labral Bnw Module i� J-IQ"Slotted Liner, 1164IBTM LBO �.................................... .. 11812.7 MD 139119' TVD .....................................�' Tubing S.1 AeumblY ......................................... ... .....................................• 3.562" DE; -6 nipple r4l liner 6-314"-211944.9'MD/595D/ ZXP rim 6292r MD � 0.1Q "Slotted Llne, ll6k IBTM L80 p •. 395m4.4'TVD � m S: ...........................— .. ...--_•___......� 2-5/8", 2924, 480, Ce__ ---- _ ___ ____ --------- aHvd563, 48394 ............................. ......................................... 448T •.•.. .6832-M KUP PROD CowcoPUllipS&w1ZES7`S1A1K Well Attributes 1'[t P185kB.IOC. 1H-103 MULTIPLE LATERALS. 1N103, 6bobla 9]6Li AM Last Tag veawlvm.ma4olwu6q Ertl Doe pepnNute) ImlMla ey HANGER:3].1 AG: 1¢nnaX IL Last Rev Reason ___ MnobWn EMDa1e Lasl Mctl BY ...__..._. ................. ._...__...._...._...._... ... ...._. Rev ReIAT apOn'FMTI 5/412018 jennall Casing Strings Ching Donlpllon ODDn) 10 on1 Top INKe1 bel Depth I..) ser pep- Ovs).-VJINen 0 -Montle Tep Threet CONDUCTOR 20 19.12 3B.9 1190 119.0 94.00 B eDNDIICTOR;3a.9-118.0 Laving 0-optlen OD DnI 10(in) Top INKe1 bel 0epin(.be) bet Depd lTVp)... WN.eo N... Grate Top TMruN SURFACE 1014 9.95 40.6 1,8763 1,7702 45.50 LA0 HydrI563 SURFACE; hsl,WSi Luing De -.10.n INTERMEDIATE DD,,10 7518 bin Top INKD1 6.88 37.8 Set Depin INKB) Ser Orotn ITVrW DI-. W11Len R... Ge Top Tnhe 8,112.1 4,0802 29.70 680 Hye 563 Mqg GPi:26Ji.fi LUI1p DanipNon LINER OD lln 4112 s, lint Tep IM1KB1 4.00 >.J61.0 Set Dep11p1he fin 0.. IND1... WULen IT. Gray top "holed 13654.8 3,9954 1250 L-80 51HT Liner Details W6 LET. 4,188.4 m-io lD Top (NKO) iop(NDj lhKB Top Incl (°) Ihm Dvs m' lin) tus MET; SAWS 7,761.0 4,0)05 75.94 PACKER x Lax-Od Gnenop packs roP@n6zn ° 4.880 smeso 6.M8.6 7,780.9 4,035.3 75.92 NIPPLE Baker &. 1RS'Pa ff Seal Nppb 170 L 0Hy8 6880 563 box x box GAUGe6,n6a 7,7838 4,036.0 ]5.92 RANGE FMo4 Urerhngel 1701-40 4810 HSE 563 Pin x pin LOGTOR;Si7d6 .R;..7673 ),]93.6 4,038.4 )5.90 SBE 8W°e 190oxtt ID Seal Bore en4on. 1? 4.750 I82 esti.AM;.784 (IyC $63116[x Oin SSE STBiA 7,813.2 4,043.2 >5.88%0 S.SHy0 15. Nbo%x4.5't2.fiY Pop-pun3930 Cms mcr %O;aeoTl NIPPLE;gaz60 8,638.4 4,098.4 91.31 SWELL Baker so -OD Swed Paler Y6 SN 052826-001-36 3970 PACKER Tnpk mmeM swap: SB69.B Tnpk mmme¢bbg;6.B 11 IAUNER; 6,693 8,775.4 4,093.) 93.07 SWELL PACKER akar 0' N N:0 -W 39]0 ;4,61].1 PA.gr: 9,169.0 4,082.9 90.)9 SWELL Beke 6.0" OSveIlPaknl SN'. 2626-001.18 3.9]0 7:Nt3 seE:7osu PACKER %0;7.OlDB- 9,511.8 4,073.2 97.01 SWELL Notes 6.T 00 Seoul PrknN N: 65-09WMT 3970 Tege mmen bM-I 7.313.1 PACKER Dklnm®M bukrg:J¢I6.2 11,270.7 4,021.5 91.85 SWELL r .PO a bsN T 140 3970 o DNER7m8.x14 o1 PACKER 11.613.5 4,0336 85.04 S LL 0' Sweq Packs 11 SN: 052826-001-13 3.970 PACKER: 72gs8 PACKER �. Tubing Strings %0'. 73386 Tubing Devcnptbn fia one bee -IND I6 r3. INKB) ant h (N.. fief Deptn RVDI 1... wHIM[1 r6p Gnnedkn TlpkmmabWkM: 7.4m1 TUBING 4112 3.96 33.1 6.806.1 J.79Z7 12.fi0 L80 TXP-m 6.1 L-810 Tnpb evmeG tnount:],43.3 uI NER)7461114,X91 Completion Details Top AVO) Top mcl PACKER: 7,45.0 TeP11KRl I1Kfi) I") Ilem Des Com 33.1 33.1 0.00 HANGER Volm Goal MB222Ao ,Meyer vY bowl(Al Cv.E 13375' s6E;7.SR.0 %0:7548 OD) Tllpe coma buwlM: LEm.S Tnpk Lan� ewi.7-IA=e DNER;7�SJ-1$0]1.9 6,648.6 3,759.8 76.65 SLEEVE Bake14-11Y 1DMl Sktin Sleeve, IBTm, 3.812 CMU, RHC IDB B Pb9wLt 6.7138 3.7762 76.01 GAUGE HES1-12Sok6lleyeMartel.N PG.skykp9Upe, ROC -150 ]3.842 T)4Pvn 6,7]6.6 3,79D.5 75.87 LOCATOR Baker 192.4] brMle Beal eseemb OD 638-) Large OD above bcalT0 6.778.2 3,]90.9 ]5.87 SEALASSY Baker 19247 baa,n ae assembly w whine shoeo- 1eE Perforations 8 Slots INTERI7EdATE; 37861121 Snot 6LDT6; B l..,Xsb9 Top (WD) Sim (WD) Dens (snotslN Top NIKBI BIm IRKS)MSS (AID4,08 'Ps4.09) IinkNZonv ) iTS Com 0, i26 8.3568 ,08.5 4.0969 ATI Y2fil2018 320 SLOTS 9xmws par Lwis2l' 6 6LpT6; 8.4>bafil9.a-j [ ° pere M,ch, C65M i53'011g RI/8'xNe 8,547.8 8,6190 4,100.0 4,0988 WSA; Y2F2018 324 SLOTS 4xrpws pee fool wl8 sbiz per row -each zbi is 3'bly B' wine 8.8002 9, 150.7 4,092.4 4,0832 WSA;"• W2 18 72.0 SLOTS 4 rml9 per bol xYB sots sorra; a,elyl9.FA.3� Per row -each slot is 3° bn9 x PIE pile I 9.535. 9.6466 4,072.1 4,0673 WS 3125IM18 32.0 SLOTS 4xr6ws per foal x118 sbts per mw-uni shpt D 3- berg x USEvi0 979B.4 9,950.4 4.059.4 IF04.3 31262018 320 SLOTS 4 x rpxxper loo, wI 8 sbis per row -Taco see N 7 bog 6LOr6: tieaSS4S8�1 x 1IB' wNe 10821.5 11.252.1 4,049.1 4,022:1 YNM2018 32.0 SLOTS 4 x rows per b01 w 9 slots I{ per row -each KIM T ley 6,MTSa1£8.48990.4 1 e Ile WNC 11,637.1 12,900.9 4,035.5 4,017.0 5262018 320 SLOTS 4xrowa gel W ell 8 sots L poo rvw-eec6 sbl M J- sly 6LDT6;10.1.5-11=1 L 13,296.4 13,6103 4,006.2 3,9963 DIE e,pa 32 1 .0 SLOTS 4xrows per 1001W 05b4" p¢rmw-eaU slot is T x118'wkie Mandrel Inserts 61 alt N Top (TVD) lip INK0) hKID Make Meet, notes Vid. La2M1 P. St. TRO Run Sery Type Type (In) DMI) Run Date Cont 6LDT6; 11,957.1-129M. .8 '° 1' 1 2,677.61 2,304.6. 1 GAS LIFT GLV BK0.188 1,508.0 611272018 2 4,628.0 3,205. 1GAS LIFT GLV BK 0.188 1,519.05/12YNIIB Cllr 3 5,800.5 3,561.1 1GASLIFT Ov BK 0.250 0091X2018 6LDT6: 13,�6.613.fi10.3�}ftI 13,4.eJ LINER:],]61.aw KUP PROD 1H-103 ConocoPhillips Alaska, Im. MULTIPLE UTEPALS-IX-1 0, SnUM 9:S:49PM mzleme m zl, (znu9 MANGER', 33.1 Notes: General & Safely Era w1.ri S'1 0 B W IRSuAeG ew GasU Design PUIbdRHC Pn, Pin, WNDUCTOR:388119G 6VRFPCE: W.B1.B)i] Gi6IlFT: 2fi]!b GAS UI4AsL0 . UFT: eme. SLEEVE:6.61 6 GAUGE; B.]ISB IOCATOR:6.]16.6 PACKER; 6.16]5 SFALTSBE;6.71 %0;5,691.1 NPpLE ... TrIeS.—Einn",b.se Tip"-. n`OZ5 3-9 IA UNER:B,a9241L0.i1.1 PACKER:).W13 SBE:)KLI Tiple EEu.Nry:]91;1 Tap" -I bus. ]3163 L9UNER:]3IG3.1<.MY PACKER; ],..9 SEE :]b18.9 6;],98.5 TnP" uu.M auGiN: ). W 0.1 Tlige q:4.1. Li NER: ],M11f1,ISt3 U.S.;14 PACKER:),%58 SBE : T�8 M:]SN.6 Tngeemmnbwiry:),tl15 TaFA.•mnMbWm9: 7,..7 LI UNER:),608 els=e IMEPMEONTE;9841121� BLOTsLmm d3%I r II S1-Oi5; B,51)b4619e�' SLOi5; a.8CO3$fE63� SLOT6:9,5U5,EAO 5— II SLOTS; 9.18.49. W.1 yJ ILS SLOTM n)ZUA-11=17 L SLOTS, 11,W].I-13.6M9�� 9LOTS:ISS6.0.13b1031 II � LINER', 7,761813bHb� I Vperations Summary (with Timelog Depths) 11-1-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dw(hr) Plisse Op Code Activity Code Time P-T-xO Aeration start Depm (MB) End DepM(MB) 3/12/2018 3/12/2018 1.00 MIRU MOVE MOB P Move rockwasher. 0.0 0.0 11:00 12:00 3/12/2018 3/12/2018 6.00 MIRU MOVE MOB P Move motors, pump, & pits 0.0 0.0 12:00 18:00 complexes. Move pipe shed & sub complexes. Spot sub over well. 3/12/2018 3/12/2018 1.50 MIRU MOVE RURD P Spot pump, motor, pipe shed & 0.0 0.0 18:00 19:30 rockwasher complexes. Hook up electrical interconnects & service lines. 3/12/2018 3/12/2018 1.00 MIRU MOVE RURD P Continue to RU service lines & 0.0 0.0 19:30 20:30 electrical interconnects. Spot cuttings tank, berm around cellar, continue to RU mud lines, & load SLB BHA into pipe shed. Swap to 3512 gen power @ 20:30 hrs. 3/12/2018 3/12/2018 2.50 MIRU MOVE RURD P Continue to work on dg acceptance 0.0 0.0 20:30 23:00 check list, lower skate rail & test run, circulate steam & water. RU drain lines on sub. 3/12/2018 3/12/2018 0.50 MIRU MOVE SFTY P Pre -spud meeting w/ CPAI, DDI, MI, & 0.0 0.0 23:00 23:30 SLB. Rig accepted @ 23:00 hrs. 3/12/2018 3/13/2018 0.50 MIRU MOVE NUND P Obtain RKBs. RU accumulator lines to 0.0 0.0 23:30 00:00 surface annular. Check diverter bolts. 3/1312018 3/13/2018 2.00 MIRU MOVE NUND P NU riser, install pitcher nipple & mer, 0.0 0.0 00:00 02:00 TQ all bolts, & fill pits w/ spud mud 3/13/2018 3/13/2018 0.50 MIRU MOVE RURD P Install elevators & PU 4 its of 5" DP, 0.0 0.0 02:00 02:30 tag conductor @ 99' 3/13/2018 3/13/2018 0.50 MIRU MOVE BOPE P Perform diverter test, witness waived 0.0 0.0 02:30 03:00 by AOGCC rep Bob Noble. Use 1 x joint 5" HWDP. Observe knife valve open in 7 seconds and annular close in 25 seconds. Perform accumulator test. Initial pressure at 3025 psi. After functioning 1900 psi. Observe system build 200 psi in 5 seconds with 2 x electric pumps, attain full system pressure in 45 seconds with 2 x electric pumps and 2 x air pumps. 6 x backup nitrogen bottle average 1996 psi. Test all gas and PVT alarms - no issues. 3/13/2018 3/13/2018 1.00 MIRU MOVE SHAH P PU BHA tools to dg floor, loaded 5" 0.0 0.0 03:00 04:00 DP & HWDP, & performed pre -spud checklist 3/13/2018 3/13/2018 0.50 MIRU MOVE SVRG P Rig service, inspected TDS 0.0 0.0 04:00 04:30 3/13/2018 3/13/2018 3.25 MIRU MOVE BHAH P PJSM, PU surface BHA as per SLB 0.0 119.0 04:30 07:45 rep, scribe tools, & RIH 3/13/2018 3/13/2018 0.25 MIRU MOVE SEQP P FIII conductor & perform mudline test 119.0 119.0 07:45 08:00 to 3,500 psi (Test Good) 3/13/2018 3/1372018 0.25 MIRU MOVE WASH P Wash and clean out conductor 119.0 119.0 08:00 08:15 1 Page 1/54 Report Printed: 5116/2018 L.perations Summary (with Timelog G.pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Dep h Siad Time Endnm Dur(hr) Phase Op Code Activity Code Tone P-T-% Operation (Po(B) End Depth pUKfl 3/1312018 3/13/2018 3.75 SURFAC DRILL DDRL P Drill 13.5" Surface F/ 119'T/ 386'@ 119.0 386.0 08:15 12:00 450 gpm, 735 psi, 31% F0, 40 RPM, 3.5k TQ, 21 WOB, PU 68k, SO 79k, ROT 73k, .5k off btm TQ, Gas unit= 4, AST= .61 hrs, ART= 1.91 hrs, ADT= 2.52 hrs, Bit hrs= 2.52, & jar hrs= 51.05 3/132018 3/13/2018 6.00 SURFAC DRILL DDRL P Drill 13.5" Surface F/ 386' T/ 937'@ 386.0 937.0 12:00 18:00 600 gpm, 1,450 psi, 32% FO, 60 RPM, 6k TO, 33 WOB, PU 67k, SO 94k, ROT 91k, .1 k off btm TO, Gas unit= 103, AST= 1.77 hrs, ART= 2.33 his, ADT= 4.10 hrs, Bit hrs= 6.62, & jar hrs= 55.15 3/13/2018 3/14/2018 6.00 SURFAC DRILL DDRL P Drill 13.5" Surface F/ 937'T/ 1,701'@ 937.0 1,701.0 18:00 00:00 600 gpm, 1,620 psi, 32% FO, 60 RPM, 71k TO, 41 WOB, PU 105k, SO 102k, ROT 103k, 2k off btm TO, Gas unit= 7,570, AST= 1.66 hrs, ART= 2.33 hrs, ADT= 3.99 hrs, Bit hrs= 10.61, & jar hrs= 59.14 3/14/2018 3/14/2018 1.50 SURFAC DRILL DDRL P Drill 13.5" Surface F/ 1,701' T/ 1,882' 1,701.0 1,882.0 00:00 01:30 @ 600 gpm, 1,600 psi, 33% FO, 60 RPM, 7k TO. 24 WOB, PU 107k, SO 106k, ROT 106k, 31k off btm TO, Gas unit= 650, AST= .5 hrs, ART= .31 hrs, ADT= .85 hrs, Bit hrs= 11.46, & jar hrs= 59.96 3/142018 3/14/2018 0.50 SURFAC CASING CIRC P Circ BU & recip pipe F/ 1,882'T/ 1,882.0 1,882.0 01:30 02:00 1,797' MD @ 600 gpm, 1,280 psi, 34% FO, 60 RPM, 3k TO, PU 107k, SO 1061k, ROT 1061k, & tagged bottom 3/142018 3/14/2018 0.25 SURFAC CASING OWFF P Flow check (No flow) 1,882.0 1,882.0 02:00 02:15 3/142018 3/142018 3.25 SURFAC CASING BKRM P BROOH R/ 1,882' T/ 853' MD @ 600 1,882.0 853.0 02:15 05:30 gpm, 1,110 psi, 32% FO, & 60 RPM 3/14/2018 3/142018 0.50 SURFAC CASING CIRC P Circ BU & recip pipe F/ 853' T/ 760' 853.0 853.0 05:30 06:00 MD @ 600 gpm, 1,110 psi, 32% FO, 60 RPM & 21k TO. 3/14/2018 3/14/2018 0.50 SURFAC CASING SRW P BD TDS and drop GYRO 853.0 853.0 06:00 06:30 3/14/2018 3/14/2018 0.75 SURFAC CASING TRIP P POOH on elevators F/ 853' T/ 296' MD 853.0 296.0 06:30 07:15 3/1412018 3/14/2018 2.75 SURFAC CASING BHAH P PJSM, LD BHA per SLB, drain motor, 296.0 0.0 07:15 10:00 1 break out bit, & LD all tools 3/142018 3/1412018 0.50 SURFAC CASING BHAH P Clean dg floor & prep for casing run 0.0 0.0 10:00 10:30 3/142018 3/14/2018 1.50 SURFAC CASING RURD P PJSM, RU CRT and casing equipment 0.0 0.0 10:30 12:00 3/142018 3/14/2018 0.50 SURFAC CASING SFTY P PJSM on running 10.75" casing 0.0 0.0 12:00 12:30 3/142018 3/142016 1.00 SURFAC CASING PUTB P MU shoe track T/ 165' and test floats 0.0 165.0 12:30 13:30 3/14/2018 3/142018 3.50 SURFAC CASING PUTB P Run 10 314" #45.5 L-80 csg F/ 165'T/ 165.0 1,470.0 13:30 17:00 1,470' MD, MU connections T/ 20k TQ, fill on the fly & top off every 5 jts. 3/142018 3/14/2018 0.75 SURFAC CASING WASH T Tight spot F/ 1,470' T/ 1,523' MD, 1,470.0 1,523.0 17:00 17:45 j j j washed @ 3 bpm, 100 psi, 14% FO, PU 110k, & SO 94k Page 2154 ReportPrinted: 5116/2016 . t, aerations Summary (with Timelog L,:pths) 11-1-1103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End TNe COrh (0 Phase Op code Activity Code Tone P -T -X Operation Start Depth (rt De EM Depth (ftKe) 3/14/2018 3/14/2018 2.50 SURFAC CASING PUTS P Run 10 3/4" #45.5 L-80 mg F/ 1,523' 1,523.0 1,876.0 17:45 20:15 T/ 1,876' MD, MU connections T/ 20k TO, fill on the fly & top off every 5 its. One joint had bad threads on the box and had to be replaced 3/14/2018 3/14/2018 0.75 SURFAC CASING HOSO P PU & MU casing hager, land & 1,876.0 1,876.0 20:15 21:00 confirm. PU 120k & SO 103k 3/14/2018 3/14/2018 2.00 SURFAC CEMENT CIRC P MU cmt hose, stage pumps to 3 bpm, 1,876.0 1,876.0 21:00 23:00 90 psi, 6 bpm, 197 psi, 8 bpm, 287 psi while recip pipe. Staged up slowly due to Iooses.Stage up to 8 bpm, 287 psi, PU 122k & SO 109k. Conditioned/diluted mud per MI 3/14/2018 3/15/2018 1.00 SURFAC CEMENT CIRC T SLB cementer had issues with a valve 1,876.0 1,876.0 23:00 00:00 freezing up while circulating and Conditioning the hole per Ml. Continued circ @ 8 bpm till valve was thawed. 3/15/2018 3/15/2018 0.50 SURFAC CEMENT CIRC T SLB cementer had issues with a valve 1,876.0 1,876.0 00:00 00:30 freezing up while circulating and conditioning the hole per Ml. Continued circ @ 8 bpm till valve was thawed. 3/15/2018 3/15/2018 3.50 SURFAC CEMENT CMNT P Line up to SLB, pump 5 bbls 1,876.0 0.0 00:30 04:00 freshwater, and pressure test lines to 3,500 psi - good test. Pump 40 bbls Chemwash CW100 at 4.2 bpm, 80 psi, 10% F/O. Pump 80 bbls 10.5 ppg MudPush II spacer at 5 bpm, 110 psi, 12% F/O. Drop DHP bottom plug. Bach up lead slurry, cement wet at 0119 hrs. Pump 360 bbls 11.0ppg LiteCrete lead slurry at 5.4 bpm, 180 psi, 18% F/O. Observe bottom plug land out at 169 bbls of lead cement pumped. Batch up tail slurry and pump 64.4 bbls 12.Oppg LiteCrete tail slurry at 4.7 bpm, 231 psi, 12% F/O. Drop DHP top plug. SLB pump 9.9 bbls freshwater at 6.7 bpm, 280 psi, 18% F/O. Reciprocate pipe 20' while SLB pumping, PUW 126k, SOW 113k. Swap to dg and displace cement with 9.5ppg spud mud @ 8 bpm, drop rate to 3 bpm 10 bbls from bumping plug, FCP 3031. Bump plug on calculated at 1612 strokes. Pressure up to 827 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Stop reciprocating pipe once it started getting sticky just after rig started displacing cement. Cement in place at 03:50 firs. Observed 62 bbls of good 11.Oppg lead cement back to surface. No losses observed throughout cement job. 3/15/2018 3/15/2018 0.75 SURFAC CEMENT PRTS P Pressure test mg to 3,000 psi for 30 0.0 0.0 04:00 04:45 1 I min 3/15/2018 3/15/2018 1.25 SURFAC CEMENT RURD P Drain/flush stack, clean & prep rig 0.0 0.0 04:45 06:00 1 I I floor Page 3154 ReportPrinted: 511612018 M7777� operations Summary (with Timelog L-pths) Ad IH -103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depm SWTM End TM Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (ftKa) End Depth (111<9) 3/15/2018 3/15/2018 1.25 SURFAC CEMENT RURD P Unplug 4" conductor valves, draing 0.0 0.0 06:00 07:15 stack, clean pits & rock washer 3/15/2018 3/15/2018 1.25 SURFAC CEMENT W W WH P MU 5" DP & flush tool, wash divereter 0.0 0.0 07:15 08:30 & riser, clean flowline, drain stack & suck out cellar 3/15/2018 3/15/2018 3.50 SURFAC CEMENT NUND P Pull mouse hole, clean out flow box, 0.0 0.0 08:30 12:00 ND surface riser, annular & diverter Tee 3/15/2018 3/15/2018 1.50 SURFAC WHDBOP NUND P Pull casing head & clean, cleared out 0.0 0.0 12:00 13:30 packed of casing head flutes, MU starting head, set wellhead 3/15/2018 3/15/2018 3.50 SURFAC WHDBOP WAIT T Wail on CPA/ pad operator for 0.0 0.0 13:30 17:00 verification on wellhead alignment, MU floor & safety valves, hoo up BOP to cranes, rmove casing head, woek on hole fill suction, clean rig floor, pits, and cellar 3/15/2018 3/15/2018 1.00 SURFAC WHDBOP NUND P Perform 2,000 psi test on casing head 0.0 0.0 17:00 18:00 seals (good test) 3/15/2018 3/15/2018 4.00 SURFAC WHDBOP NUND P NU drilling spool, BOP, & drain pan, 0.0 0.0 16:00 22:00 hook up koomy lines, chain & center stack 3/15/2018 3/15/2018 1.00 SURFAC WHDBOP RURD P Fill all lines, shell test BOP, FOSV, & 0.0 0.0 22:00 23:00 j choke manifold to 250 psi low & 3,500 psi high Page 4154 Report Printed: 5116/2018 operations Summary (with Timelog 6. pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Time End Time our (hu Phase Op Code Activity Code Time P -T -X Operabon Start Depth (ftKa) End Depth(ftKa) 3/15/2018 3/16/2018 1.00 SURFAC WHDBOP BOPE P Begin test BOPE w/ 4", 5', and 7-5/8" 0.0 0.0 23:00 00:00 test joints to 250/3,500 psi, 5/5 min, charted. Witnessed by AOGCC rep Adam Earl Test Sequence as follows: With 7-5/8" Test joint 1) Annular, Mud Manifold valves 1,12,13, 14, 4" Kill line, and 4" XT39 dart valve 2) Upper 7-5/8" Casing Rams, Mud Manifold valves 9, 11, Mez Kill line, and 4" XT39 FOSV 3) Mud Manifold valves 8,10, HCR Kill line, and 4-1/2" IF Dart valve 4) Mud Manifold valves 6, 7, Manual Kill, and 4-1/2" IF FOSV 5) Manually Operated Choke and Super Choke tested to 2000 psi 6) Mud Manifold valves 2 and 5 Remove 7-5/8" test joint 7) Blind Rams, Mud Manifold valves 3 and 4 With 4" Test Joint 8) Annular, HCR choke, and upper IBOP 9) Manual choke and lower IBOP 10) Lower 3-1/2" x 6" Rams With 5" test joint: 11) Lower 3-1/2" x 6" Rams Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,825 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 51 seconds N2 = 6 each @ 2,058 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. Page 5154 ReportPrinted: 5/16/2018 %,perations Summary (with Timelog b,pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Mr (m) Phase Op Code Activity Cade Time PJA Operetian (ftKB) End Depth(ftKB) 3/16/2018 3/16/2018 4.50 SURFAC WHDBOP BOPE P Begin test BOPE w14", 5", and 7-5/8" 0.0 0.0 00:00 04:30 test joints to 250/3,500 psi, 5/5 min, charted. Witnessed by AOGCC rep Adam Earl - Test Sequence as follows: With 7-5/8" Test joint 1) Annular, Mud Manifold valves 1,12,13, 14, 4" Kill line, and 4" XT39 dart valve 2) Upper 7-5/8" Casing Rams, Mud Manifold valves 9, 11, Mea Kill line, _ and 4" XT39 FOSV 3) Mud Manifold valves 8, 10. HCR Kill line, and 4-1/2" IF Dart valve 4) Mud Manifold valves 6, 7, Manual Kill, and 4-1/2" IF FOSV 5) Manually Operated Choke and Super Choke tested to 2000 psi 6) Mud Manifold valves 2 and 5 Remove 7-5/8" test joint 7) Blind Rams, Mud Manifold valves 3 and 4 With 4" Test Joint 8) Annular, HCR choke, and upper IBOP 9) Manual choke and lower IBOP 10) Lower 3-112" x 6" Rams With 5" lest joint: 1 t) Lower 3-1/2" x 6" Rams Perform koomey drawdown test: System Pressure = 3,000 psi PSI after closure = 1,825 psi 200 psi Attained with 2 x electric pumps = 8 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 51 seconds N2 = 6 each @ 2,058 psi Tested all gas and 1-12S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. 3/16/2018 3/16/2018 2.50 SURFAC WHDBOP BOPE T Choke HCR failed test, RD HRC, & 0.0 0.0 04:30 07:00 installed new HCR 3/16/2018 3/16/2018 0.50 SURFAC WHDBOP BOPE P Pressure teseted HCR to 250 Low & 0.0 0.0 07:00 07:30 3,500 psi High for 5/5 min 3/16/2018 3116/2018 1.25 SURFAC WHDBOP RURD P MD & RD testing equipment, pull lest 0.0 0.0 07:30 08:45 plug, drain stack, install wear bushing & prep for BHA PU. 3/16/2018 3116/2018 0.50 SURFAC CEMENT SVRG P Service & inspect TDS 0.0 0.0 08:45 09:15 3/16/2018 3/16/2018 2.50 SURFAC CEMENT BHAH P PJSM, MU BHA as per SLB T/ 737' 0.0 737.0 09:15 11:45 3/16/2018 3/16/2018 0.50 SURFAC CEMENT TRIP P RIH F1 73T T/ 1,587' monitor 737.0 1,587.0 11:45 12:15 displacement via trip tank 3116/2018 3/16/2018 0.50 SURFAC CEMENT DHEO P Fill pipe, perform shollow pulse test & 1,587.0 1,567.0 12:15 12:45 send downlink Page 6154 Report Printed: 5/1 612 01 8 L.Nerations Summary (with Timelog L..aths) 1H-103 Gog: DOYON 142 Job: DRILLING ORIGINAL Time Log Sial Tune I End Tim, Dur (hr) Plass op Code Activity Code Time P -T -X Cpmition start Depth (W) End Depth(IIKB) 3/16/2018 3/16/2018 0.50 SURFAC CEMENT PRTS P Flush kill line, cloase annular, pump 1,587.0 1,587.0 12:45 13:15 down DP & OA pressure to 3,000 psi. No leaks on valve. Witnessed by CPAI rep 3/16/2018 3/16/2018 1.50 SURFAC CEMENT SLPC P Slip & cut 59' of drill line 1,587.0 1,587.0 13:15 14:45 3/1612018 3/16/2018 1.75 SURFAC CEMENT SVRG P CO41/2"IF saver sub 1,587.0 1,587.0 14:45 16:30 3/16/20183/16/2018 0.50 SURFAC CEMENT COCF P Wash F/ 1,587'@ 3 bpm, 115 psi, 8% 1,587.0 1,781.0 16:30 17:00 FO, 40 RPM tag cmt @ 1,781' MD. PU 102k & SO 99k 3/16/2018 3/16/2018 5.00 SURFAC CEMENT DRLG P Drill out cement, plugs, float collar, & 1,781.0 1,882.0 17:00 22:00 float shoe F/ 1,781' T/ 1,882'@ 450 GPM, 670 psi, 60 rpm, 4k TQ, 5-22 WOB, & 28% FO. 3/16/2018 311612018 0.50 SURFAC CEMENT DDRL P Drill 20' of new formation F/ 1,882'T/ 1,882.0 1,902.0 22:00 22:30 1,902' MD @ 450 GPM, 670 psi, 60 rpm, 4k TO, 12 WOB, 28% FO. ADT -.33 hrs, Bit hrs-.33, Jar hrs- 95.46. Swapped out spud mud for LNSD 3/16/2018 3/16/2018 1.00 SURFAC CEMENT FIT P Pulled back into shoe, performed 12.0 1,902.0 1,902.0 22:30 23:30 ppg FIT. Pressured up OA & DP to 280 psi (12.0 ppg equiv), pressure bled to 146 psi. .9 bbls pumped and .8 bbls returned. 3116/2018 3/17/2018 0.50 INTRMI DRILL CIRC P Tip back to bottom and obtain slow 1,902.0 1,902.0 23:30 00:00 pump rates: SPR's 1,902' MD, 1,791' TVD, 9.0 ppg MP#1: 30 spm- 80 psi, 40 spm- 100 psi MP#2: 30 spm- 80 psi, 40 spm- 100 psi 3/17/2018 3/17/2018 6.00 INTRMI DRILL DDRL P Drill 97/8" intermediate Ft 1,902'T/ 1,902.0 2,460.0 00:00 06:00 2,640' MD 12,285' TVD. 605 gpm, 9251900 psi on/off, 120 rpm, 5k TO on, 4k TQ off, 5-8k WOB, 31 % FO, PU 112k, SO 107k, ROT 107k, ECD 10.7 ppg, Max gas 107 units, ADT- 3.67 hrs, Bit- 4 hrs, & Jars- 99.13 hrs 3/17/2018 3/17/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F/ 2,640' T/ 2,460.0 3,287.0 06:00 12:00 3,287' MD 12,648' TVD. 600 gpm, 9411940 psi ontoff, 120 rpm, 7k TO on, 3k TO off, 3k WOB, 29% FO, PU 125k, SO 105k, ROT 111 it, ECD 10.24 ppg, Max gas 78 units, ADT - 4.65 hrs, Bit- 8.65 hrs, & Jars- 103.78 hrs SPR's Q 2,720' MD / 2,327' TVD MW - 9.2 MP#1: 30 spm- 150 psi, 40 spm -180 psi MP#2: 30 spm- 150 psi, 40 spm- 180 psi Page 7/54 ReportPrinted: 5/1612018 . V aerations Summary (with Timelog U,pths) 1 H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log S Cour n D Start Tme End Time Dur (hr) Phase Op Code Acti ' Code My Time P-T-% Operation End Depth (m(B) 3/17/2018 3/17/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F/3,28TT/ 3,287.0 4,140.0 12:00 1800 4,140' MD / 3,052' TVD. 650 gpm, 1,260/1,255 psi on/off, 160 rpm, 8k TO on, 7k TQ off, 7k WOB, 32% FO, PU 129k, SO 109k, ROT 115k, ECD 10.84 ppg, Max gas 90 units, ADT- 4.19 hrs, Bit- 12.84 hrs, & Jars- 107.97 hrs SPR's @ 4,138' MD / 3,053' TVD MW- 9.3 MP#1: 30 spm- 180 psi, 40 spm- 200 psi MP#2: 30 spm- 180 psi, 40 spm- 200 psi 3/17/2018 3/18/2018 6.00 INTRM1 DRILL DDRL P Drill 9 718" intermediate F/ 4,140'T/ 4,140.0 4,900.0 18:00 00:00 4,900' MD / 3,291' TVD. 700 gpm, 1,600/1,590 psi ontoff, 120 rpm, 10- 14k TO on, 8k TQ off, 5-9k WOB, 32% FO, PU 138k, SO 100k, ROT 116k, ECD 10.8 ppg, Max gas 108 units, ADT- 4.41 hrs, Bit- 17.25 hrs, & Jars- 112.38 hrs 3/18/2018 3/18/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F/ 4,900'T/ 4,900.0 5,874.0 00:00 06:00 5,874' MD / 3,574' ND. 700 gpm, 1,700/1,695 psi onloff, 120-175 rpm, 10-18k TQ on, 10-18k TO off, 10-22k WOB, 32% FO, PU 150k, SO 104k, ROT 121 k, ECD 11.09 ppg, Max gas 108 units, ADT- 4.25 hrs, Bit- 21.5 hrs, & Jars- 166.63 hrs 3/18/2018 3/1812018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F1 5,874'T/ 5,874.0 6,410.0 06:00 12:00 6,410' MD / 3,708' TVD. 700 gpm, 1,83511,805 psi onloff, 150 rpm, 10k TQ on, 10k TQ off, 7k WOB, 32% FO, PU 150k, SO 105k, ROT 123k, ECD 11.85 ppg, Max gas 184 units, ADT- 4.45 hrs, Bit- 25.95 hrs, & Jars- 171.08 hrs SPR's @ 5,937' MD / 3,598' TVD MW- 9.4 MP#1: 30 spm- 200 psi, 40 spm- 240 psi MP#2: 30 spm- 200 psi, 40 spm- 240 psi 3/18/2018 3/18/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F/ 6,410' T/ 6,410.0 6,884.0 12:00 1800 6,884' MD / 3,817' TVD. 700 gpm, 1,89511,885 psi onloff, 150-170 rpm, 12.5k TQ on, 11.5k TO off, 10-25k WOB, 32% FO, PU 150k, SO 109k, ROT 126k, ECD 11.08 ppg, Max gas 177 units, ADT- 3.92 hrs, Bit- 29.87 hrs, & Jars- 175.0 hrs Page 8154 Report Printed: 5116/2018 L Aerations Summary (with Timelog L�pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tme EM Time Our (hr) Phase Op Code Acbv ty Code Time P -T -x Operation (MB) End Depth (#KB) 3/18/2018 3/19/2018 6.00 INTRMI DRILL DDRL P Drill 9 7/8" intermediate F/ 6,884' T/ 6,884.0 7,499.0 18:00 00:00 7,499' MD 13,967' TVD. 700 gpm, 1,882/1,880 psi on/off, 150-170 rpm, 12.5k TO on, 11.5k TO off, 10-25k WOB, 32% FO, PU 150k, SO 109k, ROT 126k, ECD 11.08 ppg, Max gas 177 units, ADT- 4.49 hrs, Bit- 34.36 hrs, & Jars- 179.49 hrs SPR's @ 7,072' MD / 3,862' TVD MW - 9.4 MP#1: 30 spm- 200 psi, 40 spm- 240 psi MP#2: 30 spm- 200 psi, 40 spm- 240 psi 3/19/2018 3/19/2018 6.00 INTRMI DRILL DDRL P DOI 9 7/8" intermediate F/7,499'T/ 7,499.0 8,120.0 00:00 06:00 8,120' MD 14,090' TVD. 700 gpm, 2,100/2,092 psi onloff, 150-170 rpm, 15k TO on, 12k TO off, 10-25k WOB, 32% FO, PU 180k, SO 107k, ROT 136k, ECD 11.28 ppg, Max gas 40 units, ADT- 3.87 hrs, Bit- 38.23 hrs, & Jars -183.36 hrs SPR's @ 8,120' MD / 4,090' TVD MW - 9.4 MP#1: 30 spm- 240 psi, 40 spm- 280 psi MP#2: 30 spm- 240 psi, 40 spm- 280 psi 3/1912018 3119/2018 1.25 INTRMI CASING CIRC P LD single, circ BU, dilute system with 8,120.0 8,120.0 06:00 07:15 290 bible new mud, flow check (no flow). 700 gpm, 1,795 psi, 32% FO, 150 rpm, 10-14k TO, ECD- 10.75 ppg, PU 177k, SO 110k, ROT 101 k. 3/19/2018 3/20/2018 16.75 INTRMI CASING BKRM P BROOH F/ 8,120' T1,879 @ 700 gpm, 8,120.0 1,879.0 07:15 00:00 31 % FO, 150 rpm, 9-12k TO, & ECD 10.2-10.75 ppg. 3/20/2018 3/20/2018 0.50 INTRMI CASING CIRC P Circ hot clean Q shoe, 2,600 stks, 1,879.0 1,879.0 00:00 00:30 1,050 psi, 700 gpm & monitor well 3/20/2018 3/20/2018 1.50 INTRMI CASING PULD P POOH LD 5" DP F/ 1,879' T/ 737' 1,879.0 737.0 00:30 02:00 3/20/2018 3/2012018 2.00 INTRMI CASING SHAH P PJSM, LD BHA per SLB rep, break bit 737.0 0.0 02:00 04:00 & clean floor 3/2012018 3120/2018 0.50 INTRMI CASING RURD P Pull wear bushing (verified by CPAI 0.0 0.0 04:00 04:30 rep) 3/2012018 3120/2018 1.50 INTRMI CASING RURD P Wash wellhead & stack, RU power 0.0 0.0 04:30 06:00 longs, Volant, slips, bring pups to the rig floor, & prep for casing run 3/20/2018 3/20/2018 1.00 INTRM1 CASING RURD P PJSM, PU power tongs, hyd unit, fill 0.0 0.0 06:00 07:00 up line, & slips. Verify pipe tally 3/2012018 3/20/2018 3.50 INTRMI CASING PUTB P PJSM MU & Bakerlok shoe track, fill 0.0 1,876.0 07:00 10:30 pipe, test floats (passed), RIH MU 7 5/8" 29.7# L-80 csg F/ shoe track T/ 1,876' MD MU @ 12.4 fUlbs, filling on the fly & topping off every 10 Its 3/20/2018 3/20/2018 0.50 INTRMI CASING CIRC P Circ on casing volume at shoe (a3 6 1,876.0 1,876.0 10:30 11:00 bpm, 100 psi, 939 stks, PU 89k, & SO 91k Page 9154 Report Printed: 511 612 01 8 Summary (with Timelog Lvpths) 1H-103 lip%.,perations Rig: DOYON 142 Job: DRILLING ORIGINAL Start Depth EM Time Phase Op Code Activity Coe Time P-T-x operation (fd(B) Eed Depth (111<8) 3/202018 -r 6.75 INTRMI CASING PUTB P Continue RIH MU 7 5/8" 29.7# L-80 1,876.0 6,654.0 17:45 csg F/ 1,876'T/ 6,654' MD MU @ 12.4 ff/Ibs, filling on the fly & topping off r3/20/2018 every 10 jts. PU 163k & SO 95k 3/20/2018 1.75 INTRMI CASING CIRC P Circ BU due to pushing mud away 6,654.0 6,654.0 19:30 while running pipe. 8 bpm & 350 psi 3120/2018 1.50 INTRMI CASING PUTS P Continue RIH MU 7 5/8" 29.7# L-80 6,654.0 8,070.0 21:00 csg FI 6,654' TI 8,070' MD MU @ 12.4 fUlbs, filling on the fly & topping off every 10 its. PU 200k & SO 100k 3/202018 3/202018 0.50 INTRMI CASING HOSO P MU hanger & landing joint & land mg 8,070.0 8,112.0 21:00 21:30 j 3/20/2018 3/21/2018 2.50 INTRMI CEMENT CIRC P Stage up pump to 8 bpm, 320 psi, & 8,112.0 21:30 00:00 recip pipe F/ 8,112'T/ 8,092'. Circ 1.5 casing volume and condition mud to 6.0 LSYP. PU 190k & SO 107k 3/21/2018 3/21/2018 0.50 INTRMI CEMENT CIRC P Cont. to circulate and condtion mud 8,112.0 8,112.0 00:00 00:30 for cement job @ 8 bpm= 320 psi to 6 LSYP as per MI rep. P/U= 190K, S/O= 107K. 3/21/2018 3/21/2018 4.00 INTRMI CEMENT CMNT P Line up to Schlumberger and pump 8,112.0 0.0 00:30 04:30 5.1 bbls of water to pressure lest lines to the floor. Pressure up to 500 psi low / 4000 psi high - good lest. Drop bottom plug (Davis Lynch Lap/N anti- rotation). Schlumberger batch MudPush to 12.5 ppg. Pump 47.5 bbls of Mud Push II @ 3.8 bpm wl FCP 120 psi. Recip w/ 200k up and 105 k down weight. Drop bottom plug (Davis Lynch Lap/N anti-rotation). Schlumberger clean tub, then mix cement to 15.8 ppg. Pump 250.2 bbis cement slurry averaging 6 bpm w/ FCP of 243 psi. Drop top plug (Davis Lynch Lap/N anti-rotation). Schlumberger pump 10 bbls of water behind plug. Swap to rig pumps to displace w/ 9.1 ppg _SND. Reciprocated pipe until 220 bbls were pumped by the rig, set on hanger wl 46 it last down weight. Continued displacing @ 6 bpm until 348 bbls pumped, slowed to 3 bpm and bumped plug w/ 358.5 bbls of mud (3567 strokes). Pressure up 512 psi over (1912 psi), held 5 minutes, bled off pressure, shut in and confirmed no pressure buildup. No losses observed while cementing. 31212018 3/21/2018 0.50 INTRMI CEMENT PRTS P Pressure test 7-5/8" casing to 3500 psi 0.0 0.0 04:30 05:00 for 30 min on chart, good. 3/21/2018 3/21/2018 0.50 INTRMI CEMENT RURD P Rig down GBR Volant tool, blow down 0.0 0.0 05:00 05:30 and dg down cement lines. 3/212018 3/21/2018 1.75 INTRMI CEMENT WWSP P Make up packoff running tool and 0.0 0.0 05:30 07:15 install packoff. Run in lock down screws and lay down running assembly. Inject packoff with packing and pressure test to 5000 psi 110 min, witnessed by CPAI - good test. Installed 9.0' OD wear bushing. Page 10154 ReportPrinted: 611612018 operations Summary (with Timelog Ldpths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime End Time Dur (m-) Phase Op Code Activity Code Time P-T-X Operation (III(B) End Depth(W) 3/21/2018 3/21/2018 2.25 INTRMI CEMENT RURD P Change out saver sub to 4" XT-39 and 0.0 0.0 07:15 09:30 adjust stand jump on topdrive. 3/21/2018 3/21/2018 0.50 INTRMI CEMENT SVRG P Service topdrive, blocks and crown. 0.0 0.0 09:30 10:00 3/2112018 3121/2018 0.50 INTRMI CEMENT BHAH P Mobilize BHA components to rig floor. 0.0 0.0 10:00 10:30 SIMOPS; remove old pipe dope and redope w/ NCS30 on HWDP. 3/21/2018 3/21/2018 1.50 INTRMI CEMENT BHAH P M/U 6-3/4" RSS BHA as per SLB to 0.0 302.0 10:30 12:00 302' MD. 3/21/2018 3121/2018 2.25 INTRMI CEMENT TRIP P RIH F/ 302' TI 2,202' MD wl new 4" 302.0 2,202.0 12:00 14:15 DP. PU 78k & SO 80k 3/21/2018 3/2112018 0.50 INTRMI CEMENT DHEA P Fill pipe & shallow hole test tools 2,202.0 2,202.0 14:15 14:45 (passed) 3/21/2018 3/21/2018 5.75 INTRMI CEMENT TRIP P Cont RIH F/2,202'T/8,001'w/new 4" 2,202.0 8,001.0 1445 20:30 DP SIMOPS- Freeze proteced OA; pumped 100 bbls FW & 80 bbis diesel 3/21/2018 3/21/2018 3.25 INTRMI CEMENT DRLG P Tag top of plugs @ 8,022' MD, set 8,001.0 8,120.0 2030 2345 down 51k, drill out floats, shoe track & rat hole @ 203-230 gpm, 1,154 psi, 5- 14k TQ, PU 140k, SO 70k, & RT 100k 3/21/2018 3/22/2018 0.25 INTRMI CEMENT DDRL P Drill 20' of new formation FI 8,120' T/ 8,120.0 8,140.0 23:45 00:00 8,140', 4,090' TVD, @ 230 gpm, 1,390 psi, 15% FO, 80 rpm, 8k TQ, ECD's 10.15 ppg, PU 140k, SO 70k, & ROT 100k, ADT-21 bra, Bit-.21 bra, & Jar F.21 hrs 3/2212018 3/22/2018 1.50 INTRMI CEMENT CIRC P Circualte and condition mud for FIT, 8,140.0 8,140.0 00:00 01:30 same mud weight in/out and shakers dean. 3/22/2018 3/22/2018 0.50 INTRMI CEMENT FIT P Rig up and perform FIT to 13.0 ppg. 8,140.0 8,140.0 01:30 02:00 Applied 850 psi w/ 9.1 ppg mud weight. Shoe @ 8,112' MD (4,088' TVD). Pumped 11 strokes (1.1 bbls, bled off 1.0 We after test. After 10 min pressure bled down to 800 psi or 12.9 ppg equiv. 3122/2018 3/22/2018 1.50 PROD1 DRILL DISP P Displaced well with 9.2 ppg FloPro 8,140.0 8,140.0 02:00 03:30 mud, pump @ 230 gpm w/ 1400 psi, rotate @ 50 rpm's. 3/22/2018 312212018 2.50 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 8,140.0 8,304.0 03:30 06:00 8140'to 8304' MD, 4093' TVD. Pump at 260 gpm, 1650 psi, ECD 10.42 ppg, 19% F/O. Rotate at 80 rpm, 6k Tq on- btm, 3-6k Tq off-btm. 3k WOB. P/U= 120K, S/0= 90K, ROT= 102K, Max gas= 33 units, ADT= 2.14, Bit hours= 2.23, Jar hours= 2.23 Page 11154 ReportPrinted: 511612018 Liperations Summary (with Timelog L,epths) 111-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Start Tme End Time Dur (M Phase Op Code Activdy Code Time P -T -X Operation IMB) End Depth(Po(B) 3122/2018 3/22/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 8,304.0 8,850.0 0600 12.00 8304'to 8850' MD, 4090' TVD. Pump at 275 gpm, 1625 psi, ECD 10.63 ppg, 20% F/O. Rotate at 80-150 rpm, 3-6k Tq on-btm, 3-6k Tq off-btm. 2k WOB. P/U= 115K, S/O= 89K, ROT= 100K, Max gas= 136 units, ADT= 4.27, Bit hours= 6.5, Jar hours= 6.5 Encountering severe slick slip of 115% avg and level 2 shocks. Adjusting parameters w/ no success. Increased Lube f/ 1 % to 2-1/2%. Obtain slow pump rates @ 8373' MD, 4096' TVD, MW= 9.1 ppg, 06:45 hours MP#1: 20 spm=360 psi, 30 spm=540 psi MP #2:20 spm= 380 psi, 30 spm= 560 psi OA pressure @ 7:00 = 380 psi. 3/22/2018 3/22/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 8,850.0 9,514.0 12:00 18:00 8,850' to 9,514' MD, 4,077' TVD. Pump at 260 gpm, 2,120 psi, ECD 11.26 ppg, 19% F/O. Rotate at 150 rpm, 6.5k Tq on-btm, 5k Tq off-btm. 4k WOB. P/U= 118K, S/O= 85K, ROT= 97K, Max gas= 284 units, ADT= 4.83, Bit hours= 11.74, Jar hours= 11.74 SPR's @ 9,608' MD, 4,065' TVD, & MW= 9-2 ppg MP#1: 20 spm- 500 psi, 30 spm- 700 psi MP#2: 20 spm- 500 psi, 30 spm- 680 psi 3/22/2018 3/23/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 9,514.0 10,113.0 18:00 00:00 9,514' to 10,113' MD, 4,054' TVD. Pump at 277 gpm, 2,362 psi, ECD 11.7 ppg, 19% F/O. Rotate at 140 rpm, 7k Tq on-btm, 6k Tq off-btm. 4.5k WOB. P/U= 119K, S/O= 80K, ROT= 96K, Max gas= 110 units, ADT= 3.63, Bit hours= 15.37, Jar hours= 15.37 3/23/2018 3/23/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 10,113.0 10,950.0 00:00 06:00 10,113' to 10,950' MD, 4,029' TVD. Pump at 277 gpm, 2,452 psi, ECD 12 ppg, 19% F/O. Rotate at 140 rpm, 8k Tq on-btm, 6k Tq off-btm. 5k WOB. P/U= 120K, S/0= 79K, ROT= 93K, Max gas= 1,498 units, ADT= 4.68, Bit hours= 20.05, Jar hours= 20.05 SPR's @ 11,125' MD, 4,026' TVD, & MW- 9.2 ppg MP#1: 20 spm- 700 psi, 30 spm- 880 psi MP#2: 20 spm- 660 psi, 30 spm- 840 psi Page 12154 ReportPrinted: 5/16/2018 t,.perations Summary (with Timelog L„,pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Start Torre End Time Dur (hr) Phase Op Code Activiy Cocle time P -T -x Operation (N(9) End Depth (fIKB) 3/23/2018 3/23/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 10,950.0 11,680.0 06:00 12:00 10,950'to 11,680' MD, 4,037' TVD. Pump at 277 gpm, 2,530 psi, ECD 12 ppg, 19% F/O. Rotate at 140 rpm, 7k Tq on-btm, 6k Tq off-btm. 4k WOB. P/U= 128K, S/O= 76K, ROT= 94K, Max gas= 309 units, ADT= 4.7, Bit hours= 24.75, Jar hours= 24.75 3/23/2018 3/23/2018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 11,680.0 12,219.0 12:00 18:00 11,680'to 12,219' MD, 4,020' TVD. Pump at 275 gpm, 2,691 psi, ECD 12.23 ppg, 20% F/O. Rotate at 140 rpm, 8k Tq on-btm, 7k Tq off-btm. 3-6k WOB. PIU= 134K, S/O= 76K, ROT= 103K, Max gas= 15 units, ADT= 4.37, Bit hours= 29.12, Jar hours= 29.12 SPR's (d3 11,867' MD, 4,045' TVD, & MW- 9.3 ppg MP#1: 20 spm- 750 psi, 30 spm- 900 MP#2: 20 spm- 720 psi, 30 spm- 850 3/23/2018 3/2412018 6.00 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 12,219.0 12,773.0 18:00 00:00 12,219' to 12,773' MD, 4,004' TVD. Pump at 277 gpm, 2,450 psi, ECD 12.0 ppg, 20% F/O. Rotate at 140 rpm, 7k Tq on-btm, 6k Tq off-btm. 6k WOB. P/U= 143K, S/0= 76K, ROT= 102K, Max gas= 40 units, ADT= 3.74, Bit hours= 32.36, Jar hours= 32.86 SPR's @ 12,695' MD, 4,010' TVD, MW- 9.2 ppg MP#1: 20 spm- 740 psi, 30 spm- 940 psi MP#2: 20 spm- 710 psi, 30 spm- 920 psi 3/24/2018 3/24/2018 6.00 PRODI DRILL DDRL P Drill 6-3/4" production A2 lateral from 12,773.0 13,248.0 00:00 06:00 12,773'to 13,248' MD, 4,010' TVD. Pump at 280 gpm, 3,100 psi, ECD 12.5 ppg, 20% F/O. Rotate at 160 rpm, 7k Tq on-btm, 7k Tq off-btm. 4k WOB. P/U= 150K, SIO= 78K, ROT= 11 OK, Max gas= 22 units, ADT= 3.85, Bit hours= 36.71, Jar hours= 36.71 3/24/2018 3/24/2018 6.75 PROD1 DRILL DDRL P Drill 6-3/4" production A2 lateral from 13,248.0 13,710.0 06:00 12:45 13,248'to 13,710' MD, 3,995' TVD. Pump at 275 gpm, 3,022 psi, ECD 12.32 ppg, 20% F/O. Rotate at 130 rpm, 8k Tq on-btm, 7k Tq off-btm. 4k WOB. PIU= 159K, S/O= 87K, ROT= 111 K, Max gas= 96 units, ADT= 5.65, Bit hours= 42.36, Jar hours= 42.36 SPR's @ 13,707' MD, 3,994' TVD & MW- 9.3 ppg MP#1: 20 spm- 690 psi, 30 spm- 900 psi MP#2: 20 spm- 600 psi, 30 spm- 820 psi Page 13/54 ReportPrinted: 511612018 L Aerations Summary (with Timelog Gt;pths) 114-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sf�rt Depd+ End Tyne cur(er) Phase Op Code Acdrity Code Tyne P-T-X Operation WS) End Dept ifKB) 3/24/2018 1.25 PROM CASING CIRC P ROT & recip F/ 13,71 VT/ 13,619 MD 13,710.0 13,710.0 14:00 @ 277 gpm, 3,005 psi, 20% FO, 110 rpm, 7-8k TO, 12.32 ECD, PU 155k, r28 SO 83k, ROT 113k & 4,236 stks pumped total 3/24/2018 0.50 FROM CASING OWFF P 30 min flow check (no flow) 13,710.0 13,710.0 14:30 3/24/2018 3/25/2018 9.50 PROW CASING BKRM P BROOH F/ 13,710' T/ 10,462' MD @ 13,710.0 10,642.0 14:30 00:00 270 gpm, ICP- 3,005 psi & FCP- 2,310 psi, 20% FO, 130 rpm, 7-8k TQ, IECD's-11.93 ppg & FECD's- 11.28 ppg 3/25/2018 3/25/2018 6.50 FROM CASING BKRM P Cont. to BROOH f/ 10462' MD to 10,642.0 8,090-- 00:00 06:30 8090' MD, Pump @ 277 gpm= 2310 psi, 19% FO, ECD= 11,28 ppg,Rotate @ 130 rpm's w/ 5K Tq. PIU= 116K, S/0= 85K, ROT= 96K. Adjust pulling speed f/ max of 700 fph to 500 fph across high DL & out of zone footage, No hole problems while BROOH> 3/25/2018 3/2512018 1.50 PROM CASING CIRC P CBU X 2 inside casing shoe, pump @ 8,090.0 7,995.0 06:30 08:00 230 gpm= 1503 psi, IECD= 10.73, FECD= 10.54 ppg. Shakers clean out after 1.5 BU. P/U= 116K, S/0= 96K, ROT= 94K. 3125/2018 3/25/2018 0.50 FROM CASING OWFF P OWFF, slight flow to static. 7,995.0 7,995.0 08:00 08:30 3/25/2018 3/25/2018 0.50 PROM CASING TRIP P POOH on elevators 5 stands f/ 7995' 7,995.0 7,520.0 08:30 09:00 MD to 7520' MD. Good hole fill, no swabbing. P/U= 115K, S/0= 96K. 3/25/2018 3/25/2018 0.25 FROM CASING CIRC P Pump dry job and blow down top 7,520.0 7,520.0 09:00 09:15 drive. 3/25/2018 3/252018 0.50 FROM CASING SVRG P Service top drive and blocks. 7,520.0 7,520.0 09:15 09:45 3125/2018 3252018 2.75 FROM CASING TRIP P Cont to POOH f/ 7520' MD to BHA @ 7,520.0 303.0 09:45 12:30 300' MD' Calculated displacement--42.0 bbls , Actual displacement= 52.5 bbls, lost 10.5 bbls POOH. 3/252018 3125/2018 0.25 PROW CASING OWFF P Flow check (no flow) retrieve rabbit 303.0 303.0 12:30 j 12:45 j 3/25/2018 3/25/2018 0.75 PROD1 CASING SHAH P PJSM, LD 6 3/4" lateral assembly per 303.0 0.0 12:45 13:30 SLB rep 325/2018 3/25/2018 0.50 FROM CASING SHAH P Clean rig floor of BHA tools 0.0 0.0 13:30 14:00 3/25/2018 3/252018 1.25 COMPZ1 CASING RURD P PU casing running tools, slips, XO's, 0.0 0.0 14:00 15:15 hoses, hang off tongs, & MU safety joint 3/25/2018 31252018 7.25 COMPZ1 CASING PUTS P PU & MU LO liner T/ 5,832' with TXP & 0.0 5,832.0 15:15 22:30 SLHT pipe. MU TXP to 7,000 ft-lbs & SLHT to 4,000 ft-lbs, floating centralizers on every joint, & inspecting packers before running them in hole. 3/25/2018 325/2018 1.00 COMPZ1 CASING OTHR P PJSM, PU Baker PBR & ZXP/Flex 5,832.0 5,893.0 22:30 23:30 j hanger, MU, verify pin settings, & RIH 3/25/2018 3/26/2018 0.50 COMPZ1 CASING RUNL P Tie in on first stand, circ through 5,893.0 6,854.0 23:30 00:00 1 I hanger @ 2 bpm, 60 psi, & RIH on OP T/ 6,854' Page 14154 ReportPrinted: 5/1612018 operations Summary (with Timelog Dcpths) h - 1H -103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth End Tans Dw(hr) Phase Op Code Ach%*Code Torre P -T-% Operation (fll(B) End Depth WE) 3/26/2018 4.50 COMPZ1 CASING RUNL P Run liner in on 4" DP F/ 6,854' to 6,854.0 13,656.0 04:30 13656'. P/U= 164K, S/0= 90K 3/26/2018 0.50 COMPZI CASING CIRC P Pump drill pipe volume before 13,656.0 13,656.0 r3/26/2018 05:00 dropping ball @ 3.5 bpm= 550 psi. Pumped a total of 680 bbis. P/U= 164K, S/0= 90K. Place liner on depth w/ shoe @ 13656'MD. 3/26/2018 0.75 COMPZI CASING PACK P Drop ball and pump down @ 3.5 13,656.0 7,762.8 05:45 bpm= 550 psi. Pressure up to 1700 psi to set Fle%Lock, continue to pressure up to 4200 psi to set ZXP w/ pusher tool and release. Set down 30K to ensure liner is hung, good. P/U and observed free travel @ 146K to confirm released. 3/26/2016 3/26/2018 0.50 COMPZ1 CASING PRTS P Test ZXP liner top packer to 3500 psi 7,762.8 7,762.8 05:45 06:15 f/ 10 min on chart, good. 3/26/2018 3126/2018 0.50 COMPZ1 WELLPR CRIH P P/U 15' out of RS packoff nipple and 7,762.8 7,755.0 06:15 06:45 spot 20 bbls of Cl brine f/ 7755' MD to above L1 Whipstock @ 7612' MD, pump @ 5 bpm= 913 psi w/ 15% FO, displace out of drill pipe @ 6 bpm= 1225 psi, w/ 752 strokes. 3/26/2018 3/26/2018 0.50 COMPZ1 WELLPR OWFF P Stand back 1 stand, blow down and 7,755.0 7,741.0 06:45 07:15 OWFF, static. P/U= 146K, S/O= 121 K. 3/26/2018 326/2018 2.75 COMPZ1 WELLPR TRIP P POOH on elevators f/ 7741' MD to 7,700.0 50.0 07:15 10:00 1 Baker running tools @ 50'. 326/2018 3/26/2018 1.00 COMPZ1 WELLPR SHAH P UD Baker running tools as per Baker 50.0 0.0 10:00 11:00 1 rep. 326/2018 3/26/2018 1.00 COMPZ1 WELLPR BHAH P Clean and dear floor, UD Baker 0.0 0.0 11:00 12:00 running tools from rig floor via beaver slide. 3/26/2018 3/262018 1.50 COMPZ1 WELLPR SLPC P Slip & cut 60' of drill line 0.0 0.0 12:00 13:30 3/26/2018 3/26/2018 0.75 PROD2 WHPST BHAH P Bring all whipstock tools to the dg floor 0.0 0.0 13:30 14:15 & prep for BHA PU 3/26/2018 326/2018 2.25 PROD2 WHPST BHAH P PJSM, MU whipstock BHA as per BHI 0.0 308.0 14:15 16:30 1 rep T/ 308' 3/26/2018 3/262018 5.50 PROD2 WHPST TRIP P RIH w/whipstock BHA F/308'T/ 308.0 7,761.0 16:30 22:00 7,761'. Shallow pulse test @ 1,500' (lest good) @ 225 gpm & 597 psi. 3/26/2018 3/26/2018 1.00 PROD2 WHPST WPST P Orient tool face to 20'L, pumping @ 7,761.0 7,610.0 22:00 23:00 225 gpm, 1,109 psi, PU 143k, SO 116k. Wash in hole maintaining 20'L. Tag liner top @ 7,761' MD (1' high), set 10k down, PU 1 O over, set down 25k over, & observe pin shear. 3/26/2018 327/2018 1.00 PROD2 WHPST MILL P Mill L1 window F/ 7,610' T/ 7,611.5' 7,610.0 7,611.5 23:00 00:00 MD, Continue milling till mills are dear and 8' of new formation. 3/27/2018 3/27/2018 6.00 PROD2 WHPST MILL P Mill 6.75" window @ 80-100 rpm, 5-7k 7,611.0 7,616.0 00:00 06:00 tq, 2-3k WOB, 250 gpm, 1,383 psi, PU 137k, SO 114k, & ROT 120k. Page 15/54 ReportPrinted: 511 612 01 8 operations Summary (with Timelog Depths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stmt Time End Tkm DW(hr) phse Op code Ac&*Ctm Time P -T -x Operation (fixe) End Depth (XIS) 3/27/2018 3/27/2018 6.00 PROD2 WHPST MILL P Mill 6.75" window @ 100 rpm, 5-7k tq, 7,618.0 7,644.0 06:00 12:00 3-6k WOB, 250 gpm, 1,483 psi, PU 137k, SO 114k, & ROT 120k. TOW = 7,611' MD, BOW = 7,624' MD. Drill to 7,644' MD. Pump hi vis super sweep @ 7,621' MD. 3/27/2018 3/27/2018 1.25 PROD2 WHPST MILL P Mill 6.75" window @ 80-100 rpm, 5-7k 7,644.0 7,648.0 12:00 13:15 tq, 6-10k WOB, 250 gpm, 1,575 psi, PU 137k, SO 114k, & ROT 120k. TOW = 7,611' MD, BOW = 7,624' MD. Drill to 7,648' MD for 8' of gauge hole. Pump hi vis super sweep @ 7,646' MD. 3/27/2018 3/27/2018 0.75 PROD2 WHPST REAM P Work mills through window. Ream up 7,648.0 7,640.0 13:15 14:00 & down @ same drilling rates x3. Work mills through window w/ no pumps or rotary x2. No obstructions observed. PUW = 137k, SOW= 118k. 3/27/2018 3/27/2018 0.25 PROD2 WHPST TRIP P POOH from 7,640' MD to 7,471' MD to 7,640.0 7,471.0 14:00 14:15 insure no contact w/ window. 3/27/2018 3/27/2018 1.25 PROD2 WHPST CIRC P Rotate & reciprocate from 7,471' MD 7,471.0 7,471.0 14:15 15:30 to 7,377' MD w/ 300 gpm, 1880 psi, 19% flow out. PUW = 137k, SOW = 118k. Total stks pumped = 4724. 3/27/2018 3/27/2018 0.25 PROD2 WHPST OWFF P OWFF (static) 7,471.0 7,471.0 15:30 15:45 3/27/2018 3/27/2018 0.25 PROD2 WHPST CIRC P Pump slug & blow down topdrive. 7,471.0 7,471.0 1545 16:00 3/27/2018 3/27/2018 3.25 PROD2 WHPST TRIP P POOH from 7,471' MD to 150' MD. 7,471.0 158.0 16:00 19:15 PUW = 137k, SOW = 118k. Monitor displacement via trip tank. 3/27/2618 3/27/2018 1.25 PROD2 WHPST BHAH P LD & clean milling BHA per Baker, 158.0 0.0 19:15 20:30 removing swarf from magnets & upper string mill in -gauge. 3/27/2018 3/27/2018 0.50 PROD2 WHPST BHAH P LD milling BHA components via 0.0 0.0 20:30 21:00 beaver slide. PU clean out BHA components to floor. Flush stack w/ stack jetting tool. 3/27/2018 3/27/2018 1.50 PROD2 WHPST BHAH P MU up motor/clean out assembly per 0.0 631.4 21:00 22:30 SLB to 631' MD. 3/27/2018 3128/2018 1.50 PROD2 WHPST TRIP P RIH w/ clean out BHA on 4" DP from 631.4 3,954.1 22:30 00:00 derrick from 631' MD to 3,954' MD. PUW = 95k, SOW = 85k. Monitor displacement via trip tank. 3/28/2018 3/28/2018 1.50 PROD2 WHPST TRIP P RIH w/ clean out BHA (BHA #6) on 4" 3,954.1 7,497.0 00:00 01:30 DP from derrick from 3954' MD to 7497' MD. PUW = 139k, SOW = 112k. Monitor displacement via trip tank. 3/28/2018 3/28/2018 0.76 PROD2 WHPST TRIP P Orient motor to 20L deg, trip down 7,497.0 7,648.0 01:30 02:15 though window f/ 7611' MD to 7624.65' MD, no issues. Tag bottom @ 7648' MD and set down 5K. Page 16154 ReportPrinted: 5116/2018 %,perations Summary (with Timelog Lvpths) qRg: 1 H-103 DOYON 142 Job: DRILLING ORIGINAL Time Log Suit Deem Steil Tone End Time Ur(M Phase Op Code Activity Code Time P -T -X Operation (AKS) End Oepm(ftKB) 3/28/2018 3/28/2018 5.00 PROD2 DRILL DDRL P DDrill 6-3/4" Production hole f/ 7648' 7,648.0 7,900.0 02:15 07:15 MD to 7900' MD, TVD= 4037'. Pump @ 226 gpm= 1605 psi on, 1451 psi off w/ 17% FO. Rotate @ 40 rpm's wl 5K Tq., 6-11K WOB. ADT= 3.35 hrs, AST= 2.02, ART= 1.33, Bit hrs= 3.35. Total jar hrs= 44.84 hours. Displaced to new 9.2 ppg FloPro NT on the fly when drilling ahead. No issues gaining separation from main bore. 3/28/2018 3/2812018 1.25 PROD2 DRILL CIRC P Circulate hole clean @ 226 gpm= 7,900.0 7,760.0 07:15 08:30 1450 psi, 17% FO, Rotate @ 40 rpm's w/ 4K Tq, Stand 2 stands back to 7760' MD. Orient motor to 20L deg. Obtain P/U= 141K, S/0= 113K before tripping through window. 3/28/2018 3128/2018 0.50 PROD2 DRILL TRIP P POOH on elevators through window, 7,760.0 7,484.0 08:30 09:00 TOW @ 7611' MD, BOW @ 7624.65' MD. No overpull when tripping through window. 3/28/2018 31282018 0.25 PROD2 DRILL OWFF P OWFF, static. 7,484.0 7,484.0 09:00 09:15 3/282018 3/282018 0.50 PROD2 DRILL CIRC P Pump slug & blow down topdrive. 7,484.0 7,484.0 09:15 09:45 3128/2018 3/28/2018 2.25 PROD2 DRILL TRIP P POOH on elevators from 7,484' MD to 7,484.0 631.0 09:45 12:00 631' MD. PUW = 138k, SOW = 114k. Monitor displacement via trip tank. 3/28/2018 3/282018 1.25 PROD2 DRILL BHAH P LD clean out run BHA per SLB from 631.0 0.0 12:00 13:15 631' MD. Monitor displacement via trip tank. 31282018 328/2018 1.00 PROD2 DRILL SHAH P Clean & dean rig floor. 0.0 0.0 13:15 14:15 3/28/2018 328/2018 0.25 PROD2 P MU stack washing tool&flush swarf 0.0 0.0 14:15 14:30 from stack @ 850 gpm, 113 psi, 30 rpm, 0.2k tq. RD stack washer. Blow down topdrive. 3/28/2018 3/28/2018 0.50 PROD2 FDRILLWWWH RURD P PU 4" test jt, pull wear bushing, & 0.0 0.0 14:30 15:00 install test plug. MU tx each XT39 floor valve & dart valve. 3/282018 3/28/2018 0.50 PROD2 RURD P Flood all lines and perform BOP body 0.0 0.0 15:00 15:30 test to 3,500 psi (good). Page 17154 Report Printed: 5116/2018 operations Summary (with Timelog GGpths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Stat lane End Time Write) Phase Op Code Activit' Gode Tens PJ -X OPSMUM (flKB) Entl DeP(ftKB) 3/28/2018 3/28/2018 4.00 PROD2 WHDBOP BOPE P Test BOPE w/ 4" & 4-1/2" lest Its to 0.0 0.0 15:30 19:30 250/3,500 psi for 5/5 min, charted. Test witness waived by AOGCC Rep Lou Laubenstein. Test Sequence as follows: With 4" Test joint 1) Annular, Choke Manifold valves 1,12,13, 14, 4" Kill on mud line, and 4" XT39 dart valve 2) Choke Manifold valves 9, 11, Mez Kill line valve, and 4" XT39 FOSV 3) Choke Manifold valves 8,10, & HCR Kill 4) Choke Manifold valves 6, 7, & Manual Kill 5) Manually Operated Choke and Hydraulic Super Choke tested to 3500 psi 6) Choke Manifold valves 2, 5 & upper IBOP 7) Lower 3-1/2" x 6" VBRs & lower IBOP Remove 4" Test Jt 8) Blind Rams, Choke Manifold valves 3, 4, 6 With 4.5" Test Joint 9) Annular, HCR choke 10) Annular, Manual choke 11) Lower 3-1/2" x 6" VBRS Perform koomey drawdown lest: System Pressure = 3,150 psi PSI after closure = 1,725 psi 200 psi Attained with 2 x electric pumps = 7 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 57 seconds N2 = 6 each @ 2,200 psi Tested all gas and 1-12S sensors, PVF and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. 3/28/2018 3/28/2018 0.50 PROD2 WHDBOP RURD P Blow down choke & kill lines. Break 0.0 0.0 19:30 20:00 out test jt, pull lest plug & reinstall wear bushing. 3/28/2018 3/28/2018 0.75 PROD2 DRILL BHAH P MU 6-3/4" L1 Drilling BHA (BHA #7) 0.0 303.2 20:00 20:45 per SLB. SOW = 56k. 3/28/2018 3/28/2018 1.00 PROD2 DRILL PULD P PU 30xjts of 4" DP singles from shed 303.2 1,253.0 20:45 21:45 to 1,253' MD. SOW = 70k. 3/28/2018 3129/2018 2.25 PROD2 DRILL TRIP P RIH w/ BHA #7 on 4" DID from derrick 1,253.0 6,389.0 21:45 00:00 to 6,389' MD. PUW = 110k, SOW = 90k. Page 18/54 ReportPrinted: 5/1612018 uVerations Summary (with Timelog Dwpths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sten Time End Time our(hr) Phase Op Code Atl*Cade Time P -T -x Operaron Stad DepN (We) End Depth(WEI) 3129/2018 3/29/2018 2.00 PROD2 DRILL TRIP P Continue RIH on 4" DP from derrick w/ 6,389.0 7,900.0 00:00 02:00 6-3/4" L1 production drilling BHA (BHA #6) from 6,389' MD to 7,900' MD. PUW = 11 Ok, SOW = 90k. See 2k of drag passing through window. Wash down last two stands in order to log @ 350 fph, 257 gpm, 1573 psi, 19% flow out. 3/292018 3/29/2018 4.00 PROD2 DRILL DDRL P Drill 6-3/4" Ll production hole from 7,900.0 8,195.0 02:00 06:00 7,900' MD to 8,195' MD / 4,075' TVD @ 258 gpm, 1614 psi, 19% flow out, 80-120 rpm, 5-8k tq, 3-9k WOB. ECDs = 10.05 ppg, off bottom = 1600 psi, PUW = 11 Ok, SOW = 89k, ROT = 100k, 4k off bottom tq. Max gas = 32 units. ADT = 2.83, bit hrs = 2.83, jar hrs = 48.54. SPRs @ 7,889' MD / 4,100' TVD, MW = 9.2 ppg, 02:00 hrs MP#1: 20 spm = 340 psi, 30 spm = 510 psi MP#2: 20 spm = 340 psi, 30 spm = 510 psi 3/29/2018 3/29/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 8,195.0 8,850.0 06:00 12:00 8,195' MD to 8,850' MD / 4,039' TVD @ 270 gpm, 1855 psi, 19% flow out, 125 rpm, 4-5k tq, 2-6k WOB. ECDs = 10.60 ppg, off bottom = 1850 psi, PUW = 112k, SOW = 88k, ROT = 11 Ok, 4k off bottom tq. Max gas = 150 units. ADT = 4.86, bit hrs = 7.69, jar hrs = 53.4. SPRs @ 8,75' MD / 4,043' TVD, MW = 9.2 ppg, 07:00 hrs MP#1: 20 spm = 380 psi, 30 spm = 540 psi MP#2: 20 spm = 380 psi, 30 spm = 540 psi 3/29/2018 3/29/2018 6.00 PROD2 DRILL DDRL P D6116-3/4" L1 production hole from 8,850.0 9,420.0 12:00 18:00 8,850' MD to 9,420' MD / 4,022' TVD @ 270 gpm, 1942 psi, 20% flow out, 125-150 rpm, 4-6k tq, 2-6k WOB. ECDs = 10.95 ppg, off bottom = 1937 psi, PUW = 115k, SOW = 96k, ROT = 96k, 4k off bottom tq. MW = 9.2 ppg, max gas = 78 units. ADT = 4.29, bit hrs = 11.98, jar hrs = 65.38. Page 19/54 ReportPrinted: 5/16/2018 Uperations Summary (with Timelog Depths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur(n) Phase Op Code Activity Code Tim P -T -X Operation (HKB) End Depth(dKe) 3/29/2018 3/30/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 9,420.0 10,110.0 18:00 00:00 9,420' MD to 10,110' MD 13,999' TVD @ 267 gpm, 2075 psi, 19% flow out, 130 rpm, 5k tq, 2-8k WOB. ECDs = 11.41 ppg, off bottom = 2030 psi, PUW = 115k, SOW= 83k, ROT= 93k, 3k off bottom tq. MW = 9.2 ppg, max gas = 40 units. ADT = 4.13, bit hrs = 16.1 1. jar his = 69.51. SPRs @ 9,512' MD 13,999' TVD, MW = 9.2 ppg, 18:30 hrs MP#1: 20 spm = 480 psi, 30 spm = 680 psi MP#2: 20 spm = 460 psi, 30 spm = 660 psi 3/30/2018 3/30/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 10,110.0 10,885.0 00:00 06:00 10,110' MD to 10,885' MD 13,978' TVD @ 267 gpm, 1994 psi, 19% flow out, 130 rpm, 6k tq, 2-8k WOB. ECDs = 11.25 ppg, off bottom = 1990 psi, PUW = 123k, SOW = 77k, ROT = 97k, Sk off bottom tq. MW = 9.2 ppg, max gas = 57 units. ADT = 4.19, bits hrs = 20.30, jar hrs = 73.70. Perform 30% mud volume dump & dilute for AIS, MBT, & ECD @ 10,630' MD. 3/30/2018 3/30/2018 6.00 PROD2 DRILL DDRL P Drill 6-314" L1 production hole from 10,885.0 11,509.0 06:00 12:00 10,885' MD to 11,509' MD 13,985' TVD @ 260 gpm, 2065 psi, 19% flow out, 150 rpm, 6-7k tq, 2-5k WOB. ECDs = 11.40 ppg, off bottom = 2038 psi, PUW = 124k, SOW = 78k, ROT = 97k, 5k off bottom tq. MW = 9.2 ppg, max gas = 84 units. ADT = 4.23, bit hrs = 24.53, jar hrs = 77.93. SPRs @ 10,934' MD 13,976' TVD, MW = 9.2 ppg, 06:20 hrs MP#1: 20 spm = 490 psi, 30 spm = 700 psi MP#2: 20 spm = 500 psi, 30 spm = 700 psi 3/30/2016 3/30/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 11,509.0 12,033.0 12:00 18:00 11,509' MD to 12,033' MD / 3,968' TVD @ 260 gpm, 2205 psi, 19% flow out, 150 rpm, 7k tq, 2-5k WOB. ECDs = 11.74 ppg, off bottom = 2200 psi, PUW = 127k, SOW = 74k, ROT = 99k, 6k off bottom tq. MW = 9.3 ppg, max gas = 61 units. ADT = 3.74, bit hrs = 28.27, jar hrs = 81.67. Page 20154 Report Printed: 511612018 VNerations Summary (with Timelog Depths) 11-1-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SM Depth Start Tim End Time Dur(hr) Phase op code Activity Code time P -T -x opereum 00) End Depth (W11) 3/30/2018 3/31/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 12,033.0 12,604.0 18:00 00:00 12,033' MD to 12,604' MD / 3,936' TVD @ 270 gpm, 2580 psi, 19% flow out, 150 rpm, 8.5k tq, 5k WOB. ECDs = 12.21 ppg, off bottom = 2570 psi, PUW = 136k, SOW = 62k, ROT = 92k, 8k off bottom tq. Max gas = 20 units. ADT = 4.43, bit hrs = 32.7, jar hrs = 86.1. Perform 30% mud volume dump & dilute for AIS, MST, & ECD @ 12,550' MD. SPRs @ 12,079' MD / 3,966' TVD, MW = 9.3+ ppg. 18:39 hrs MP#1: 20 spm = 670 psi, 30 spm = 840 psi MP#2: 20 spm = 630 psi, 30 spm = 820 ps 3/31/2018 3/31/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 12,604.0 13,088.0 00:00 06:00 12,604' MD to 13,088' MD 13,901 - 3,901'TVD TVD @ 270 gpm, 2590 psi, 19% flow out, 150 rpm, 8k tq, 2k WOB. ECDs = 12.07 ppg, off bottom = 2580 psi, PUW = 134k, SOW = 63k, ROT = 91k, 8k off bottom tq. Max gas = 19 units. ADT = 4.43, bit hrs = 37.13, jar hrs = 90.53. 3131/2018 3/31/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 13,088.0 13,476.0 06:00 12:00 13,088' MD to 13,476' MD 13,884' TVD @ 273 gpm, 2550 psi, 19% flow out, 130 rpm, 8k tq, 1-5k WOB. ECDs = 11.92 ppg, off bottom = 2508 psi, PUW = 145k, SOW = 65k, ROT = 103k, 8k off bottom tq. Max gas = 75 units. ADT = 4.17, bit hrs = 41.30, jar hrs = 94.70. SPRs @ 13,091' MD / 3,901' TVD, MW = 9.4 ppg, 06:15 hrs MP#1: 20 spm = 650 psi, 30 spm = 900 psi MP#2: 20 spm = 660 psi, 30 spm = 880 psi 3/31/2018 3131/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 13,476.0 13,925.0 12:00 18:00 13,476' MD to 13,925' MD / 3,882' TVD @ 272 gpm, 2533 psi, 19% flow out, 130 rpm, 7-8k tq, 1-6k WOB. ECDs = 11.68 ppg, off bottom = 2488 psi, PUW = 150k, SOW = 50k, ROT = 109k, 8.5k off bottom tq. Max gas = 66 units. ADT = 4.54, bit hrs = 45.84, jar hrs = 95.07. Perform 60% mud volume dump and dilute @ 13,735' MD. Page 21154 ReportPrinted: 5/16/2018 Summary (with Timelog Dcpths) IH -103 lipoperations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sran oepur Stall Time End Time DW(hr) Phase Op Code Activity Code Time P -T -X Operabon (RKB) End Depth(OKB) 3/31/2018 4/1/2018 6.00 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 13,925.0 14,656.0 18:00 00:00 13,925' MD to 14,656' MD / 3,885' TVD @ 271 gpm, 2750 psi, 19% flow out, 130 rpm, 8k tq, 4k WOB. ECDs = 11.99 ppg, off bottom = 2760 psi, PUW = 165k, SOW = 60k, ROT = 113k, 81k off bottom to. MAx gas = 50 units, ADT = 4.58, bit hrs = 50.42, jar hrs = 99.65. SPRs @ 14,014' MD / 3,885' TVD, MW = 9.1+ ppg. 18:50 hrs MP#1: 20 spm = 650 psi, 30 spm = 880 psi MP#2: 20 spm = 640 psi, 30 spm = 830 psi 4/1/2018 4/1/2018 4.75 PROD2 DRILL DDRL P Drill 6-3/4" L1 production hole from 14,656.0 15,103.0 0000 04:45 14656' MD to 15103' MD / 3,883' TVD @ 271 gpm, 2900 psi, 19% flow out, 130 rpm, 9.5k tq, 2k WOB. ECDs = 12.19 ppg, off bottom = 2890 psi, PUW = 170k, SOW = Unable, ROT = 113k, 8.5k off bottom to. Max gas = 20 units, ADT = 2.69, bit hrs = 53.11, jar hrs = 102.34. SPRs @ 15,103' MD / 3,883' TVD, MW = 9.2 ppg, 06:30 hrs MP#1: 20 spm = 700 psi, 30 spm = 900 psi MP#2: 20 spm = 700 psi, 30 spm = 900 psi 4/1/2018 4/1/2018 1.75 PROD2 CASING CIRC P Circulate hole clean and perform 580 15,103.0 15,100.0 04:45 06:30 bbls dilution. Pump @ 272 gpm= 2640 psi, rotate @ 130 rpm's w/ 7K Tq. Increased Lube to 3% while performing dilution. Obtain final torque/drag post dilution, P/U=_163K, S/0= 75K, ROT= 118K. 4/1/2018 4/1/2018 0.50 PROD2 CASING CIRC P Obtain SPRs and stand back one 15,100.0 15,075.0 06:30 07:00 stand. SPRs @ 15103' MD / 3,883' TVD, MW = 9.2 ppg, 06:30 hrs MP#1: 20 spm = 700 psi, 30 spm = 900 psi MP#2: 20 spm = 700 psi, 30 spm = 900 psi 4/1/2018 4/1/2018 0.25 PROD2 CASING OWFF P OWFF, static. 15,075.0 15,075.0 07:00 07:15 4/1/2018 4/1/2018 4.75 PROD2 CASING BKRM P BROOH from 16,075'M to 13,188' MD 15,075.0 13,188.0 07:15 12:00 @ 272 gpm, ICP = 2640 psi, FCP = 2320 psi, 19% flow out, 120 rpm, 6.5k to. ECD = 11.47 ppg. PUW @ rate = 11 Ok. Pull @ 700 fph. 4/1/2018 4/1/2018 6.00 PROD CASING BKRM P BROOH from 13,188' MD to 11,223' 13,188.0 11,223.0 12:00 18:00 MD @ 272 gpm, ICP = 2320 psi, FCP = 2120 psi, 19% flow out, 120 rpm, 6.5k tq. ECD = 11.08 ppg, PUW @ rate = 100k, SOW w/ no pump = 75k. Pull @ 700 fph. Page 22154 ReportPrinted: 5111612018, Summary (with Timelog Depths) 1H-103 isoperations Rig: DOYON 142 Job: DRILLING ORIGINAL s� Depth End Time Dz(hri Phase Op Code Achy co" Time P -T -x Opeiafbn rRK3) End Depth(WEI) 4/2/2018 6.00 PROD2 CASING BKRM P BROOH from 11,223' MD to 9,234' 11,223.0 9,234.0 00:00 MD @ 272 gpm,1940 psi, 19% flow out, 120 rpm, 4.5k tq. ECD = 10.89 ppg. PUW = 118k, SOW = 91 k. Pull @ 700 fph. See minor pack off @ 9,951' MD w/ 220 psi pressure spike, drop to 200 fph for that std. r4/2/201 4/2/2018 4.75 PROD2 CASING BKRM P BROOH from 9.234'MD to 7,809'MD 9,234.0 7,809.0 04:45 @ 272 gpm, 1840 psi, 19% flow out, 120 rpm, 3.5k tq. ECD = 10.69 ppg, PUW = 120k, SOW = 97k. Pulling speed 700 fph. 4/2/2018 1.25 PROD2 CASING TRIP P Attempt to POOH on elevators @ 7,809.0 7,425.0 06:00 7,809' MD. Encounter 25k overpull @ 7.781' MD. Kelly up & attempt to pump OOH. Encounter 25k overpull again @ 7,781' MD. BROOH from 7,788' MD to 7,770' MD w/ 273 gpm, 1823 psi, 19% flow out, 15 rpm, 3-6k tq. Kill rotary @ continue to pump OOH from 7,770' MD to 7,711' MD. POOH on elevators from 7,711' MD to 7,425' MD. PUW = 117k, SOW = 96k. 4/2/2018 4/2/2018 1.50 PROD2 CASING CIRC P Rotate and reciprocate pipe from 7,425.0 7,425.0 06:00 07:30 7,422' MD to 7,334' MD w/ 240 gpm, 1500 psi, 17%flouw out, 80 rpm, 2.5k tq. Pump 30 bbl hi vis sweep SIS. Total stks pumped = 5325 stks. PUW = 112k, SOW = 98k, ROT = 103k. 4/2/2018 4/2/2018 0.50 PROD2 CASING OWFF P OWFF, static. 7,425.0 7,425.0 07:30 08:00 4/2/2018 4/2/2018 0.50 PROD2 CASING CIRC P Pump slug, blow down topdrive. 7,425.0 7,425.0 08:00 08:30 4/212018 4/2/2018 2.50 PROD2 CASING TRIP P POOH on elevators from 7,426' MD to 7,425.0 300.0 08:30 11:00 300' MD. Monitor displacement via trip tank. 4/2/2018 4/2/2018 0.25 PROD2 CASING OWFF P OWFF, static. SIMOPS: PJSM on LD 300.0 300.0 11:00 11:15 drilling BHA. 4/212018 4/2/2018 0.75 PROD2 CASING BHAH P LD L1 drilling BHA from 300' MD as 300.0 0.0 11:15 12:00 per SLB DD. Monitor displacement via trip tank. 4/2/2018 4/212018 1.00 PROD2 CASING BHAH P Clean/clear rig floor. 0.0 0.0 12:00 13:00 4/2/2018 412/2018 1.50 50MPZ2 FISH BHAH P PJSM. PU whipstock retrieval BHA 0.0 0.0 13:00 14:30 (BHA #7) as per BOT rep to 250' MD. Monitor displacement via trip lank. 4/2/2018 412/2018 4.00 COMPZ2 FISH TRIP P RIH w/ whipstock retrieval BHA from 0.0 7,573.0 14:30 18:30 250' MD to 7,573' MD. Fill every 25x stds. Blow down topdrive after each fill. Shallow pulse test MWD @ 2,621' MD w/ 250 gpm, 700 psi, 16% flow out, good test. 4/2/2018 4/2/2018 1.00 COMPZ2 FISH FISH P Bring on pumps to 250 gpm, 1370 psi, 7,573.0 7,597.0 18:30 19:30 18% flow out, & orient to 155 deg R. Wash over slot to 7,625' MD. Orient to 17 deg L & engage slot w/ 5k set down @ 7,615' MD. Toolface snapped to 22 deg L. Pull whipstock assembly free w/ 1 jar hit @ 204k. Page 23154 Report Printed: 5116/2018 operations Summary (with Timelog Dcpths) 1H-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Depth Siert Tune EMTtine Dur(hr) Phase Op Cule Activity Code Imre P -T -X Operation (Po(B) End Depth(WJ3) 4/2/2018 4/2/2018 1.50 COMPZ2 FISH CIRC P CBU X2 @ 7,597' MD w/ 250 gpm, 7,597.0 7,597.0 19:30 21:00 1330 psi, 17% flow out. MW in= 9.3 ppg, MW out = 9.3+ ppg, Total stks pumped = 5200, losses for circulation = 70 bbls. PUW = 141k. 4/2/2018 4/2/2018 0.50 COMPZ2 FISH OWFF P Rack back 1x std & OWFF for 30 min 7,597.0 7,566.0 21:00 21:30 (diminishing flow until static). Drop 2" drift w/ 104 wire on std #78. 4/2/2018 4/2/2018 2.00 COMPZ2 FISH TRIP P POOH from 7,566' MD to 5,910' MD. 7,566.0 5,910.0 21:30 23:30 Monitor displacement via trip tank. PUW = 119k. 4/212018 4/2/2018 0.25 COMPZ2 FISH CIRC P Pump 15 bbl slug, blow down topdrive. 5,910.0 5,910.0 23:30 23:45 4/2/2018 4/3/2018 0.25 COMPZ2 FISH TRIP P Continue to POOH on elevators from 5,910.0 5,311.0 23:45 00:00 5,910' MD to 5,311' MD. Monitor displacement via trip tank. PUW = 108k. 4/3/2018 4/3/2018 3.00 COMPZ2 FISH TRIP P Continue POOH w/whipstock retrieval 5,311.0 402.0 00:00 03:00 BHA & whipstock from 5,311' MD to 402' MD. PUW = 61k. Monitor displacement via trip tank. 4/3/2018 4/3/2018 2.00 COMPZ2 FISH BHAH P LD whipstock & retrieval BHA (BHA 402.0 0.0 03:00 05:00 #7) from 402' MD as per Baker. Monitor displacement via trip tank. 4/3/2018 413/2018 0.50 COMPZ2 FISH BHAH P Clean & clear rig floor. 0.0 0.0 05:00 05:30 4/3/2018 4/3/2018 0.50 COMPZ2 CASING RURD P RU to run L1 lower completion. RU 0.0 0.0 05:30 06:00 elevators, power tongs, & verify pipe count in shed. 4/3/2018 413/2018 0.50 COMPZ2 CASING SVRG P Service topdrive. 0.0 O.0 06:00 06:30 4/3/2018 4/3/2018 5.50 COMPZ2 CASING PUTB P RIH w 44-112" 12,6# L-80 TXP-m 0.0 4,360.0 06:30 12:00 slofted/blank lower completion liner per detail to 4,360' MD. Install 6-1/8" OD thick wall hydroform centralizers per It, use Jet Lube Run -n -Seal dope, MU to 7,000 ft -lbs. Monitor displacement via trip tanl. PUW = 75k, SOW = 70k. 4/3/2018 4/3/2018 3.00 COMPZ2 CASING PUTS P RIH w/4-1/2" 12,6# L-80 TXP-m 4,360.0 7,397.0 12:00 15:00 slotted/blank lower completion liner per detail from 4,360' MD to 7,397' MD. Install 6-1/8" OD thick wall hydroform centralizers per It, use Jet Lube Run-nSeal dope, MU to 7,000 ft -lbs. Monitor displacement via trip lanl. PUW = 95k, SOW = 73k. 4/312018 413/2018 1.00 COMPZ2 CASING OTHR P PU Hook Hanger & SlimPulse MWD 7,397.0 7,431.0 15:00 16:00 as per Baker & SLB. Scribe and confirm toolface offset. RIH firm 7,397' MD to 7,431' MD. Monitor displacement via trip tank. PUW = 100k, SOW = 80k. 4/312018 4/3/2018 1.00 COMPZ2 CASING RUNL P RIH w/ 4-112" 12.6# L-80 TXP-m 7,431.0 8,852.0 16:00 17:00 slotted/blank lower completion liner on 4" DP from derrick from 7,431' MD to 8,852' MD. Monitor displacement via trip lank. 4/3/2018 4/3/2018 0.50 COMPZ2 CASING -ETH-EQ P Shallow hole test SlimPulse tool @ 8,852.0 8,852.0 17:00 17:30 8,852' MD w/ 110 gpm, 480 psi, 10% flow out. Page 24164 ReportPrinted: 511 612 01 8 VNerations Summary (with Timelog Depths) 1H-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth Stat Time End Time our (hr) Phase Op Code AcMRy Code Time P -T -X Operation (ftKS) End Depth M(S) 4/3/2018 4/3/2018 4.25 COMPZ2 CASING RUNL P Continue to RIH w/4-1/2" 12.6# L-80 8,852.0 14,935.0 17:30 21:45 TXP-m slotted/blank liner on 4" DP from derrick from 8,852' MD to 14,935' MD. Monitor displacement via trip tank. PUW = 115k, SOW = 91 k. 4/3/2018 4/4/2018 2.25 COMPZ2 CASING HOBO P Bring on pumps to 112 gpm, 820 psi, 14,935.0 7,550.0 21:45 00:00 12% flow out & orient to 120 deg R & RIH past window to 15,037.4' MD. PU & orient to 28 deg L & set hook hanger on window. Take weight @ 15,031.93' MD. Set down 35k to ensure hook hanger set & see toolface snap to 6 deg R. Drop 29/32" ball & pump down @ 1.5 bpm, 490 psi, 7% flow out. Ball on seat @ 656 silks. Pressure up to 3,300 psi to release from hook hanger. PU 10', PUW = 142k, SOW = 117k. Pressure up to 4,560 psi w/ test pump to shear out ball seat. Rack back 2x aids to 7,550' MD & blow down topdrive. 4/4/2018 4/4/2018 0.50 COMPZ2 WELLPR OWFF P Monitor well for 30 min, fluid level 7,550.0 7,550.0 00:00 00:30 dropped 5" 4/4/2018 4/4/2018 4.75 COMPZ2 WELLPR TRIP P POOH from 7,550' MD to 55' MD. 7,550.0 55.0 00:30 05:15 Monitor displacement via trip tank. Perform SuperSlider maintenance - adjust collars and replace 13. 4/4/2018 4/4/2018 0.75 COMPZ2 WELLPR BHAH P LD liner running tools & SlimPulse 55.0 0.0 05:15 06:00 MWD per Baker & SLB. 4/4/2018 4/4/2018 0.75 COMPZ2 WELLPR BHAH P Clean & clear rig floor. 0.0 0.0 06:00 06:45 4/4/2018 4/4/2018 2.00 COMPZ2 WELLPR SLPC P Cut & slip 70' of 1.375' drilling line. 0.0 0.0 06:45 08:45 Calibrate Amphion system. Monitor wellbore via hole fill. SIMOPS: Expedite LEM BHA to rig floor. Complete derrick inspection. 4/4/2018 4/4/2018 0.50 COMPZ2 WELLPR SVRG P Service topdrive, drawworks, & crown. 0.0 0.0 08:45 09:15 SIMOPS: RU GBR power tong equipment. 4/4/2018 4/4/2018 0.25 COMPZ2 RWRID RURD P Install 4-1/2" elevators. RU GBR 0.0 0.0 09:15 09:30 torque tum equipment & calibrate same. 4/4/2018 4/4/2018 1.00 COMPZ2 RWRID PUTB P RIH w/ LEMIZXP Assembly per detail 0.0 241.0 09:30 10:30 to 241' MD. Monitor displacement via trip tank. 4/4/2018 4/4/2018 1.00 COMPZ2 RWRID PUTB P PU & MU ZXP liner top packer running 241.0 272.0 10:30 11:30 tools & SlimPulse MWD. Scribe as per Baker/SLB/CPAI rep. RIH from 241' MD to 272' MD. PUW = 43k, SOW = 51 k. Place Xanplex D (pal mix) into ZXP packer. 4/4/2018 4/4/2018 0.50 COMPZ2 RWRID RURD P RD GBR power tongs & lower via 272.0 27.0 11:30 12:00 beaver slide. 4/4/2018 4/4/2018 2.75 COMPZ2 RWRID RCST P RIH w/ LEM/ZXP assembly on 4" DP 272.0 4,924.0 12:00 14:45 from 272' MD to 4,924' MD. PUW = 89k, SOW = 80k. Monitor displacement via trip tank. Shallow hole test SlimPulse tool @ 2,166' MD @ 110 gpm, 430 psi, 10% flow out. Page 25154 Report Printed: 5116/2018 operations Summary (with Timelog Dupths) 1H-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur (hr) Phase Op Code Ac Mty Code Time P-T-% Operation (We) EM DepN(flKB) 4/4/2018 4/4/2018 1.75 COMPZ2 RWRID RCST P Continue to RIH w/ LEM/ZXP 4,924.0 7,681.0 1445 16:30 assembly on 4" HWDP from 4,924' MD to 7,681' MD. PUW = 136k, SOW = 111 k. Monitor displacement via trip tank. 4/4/2018 4/4/2018 0.75 COMPZ2 RWRID PACK P Wash down from 7,681' MD to 7,773' 7,681.0 7,773.0 16:30 17:15 MD & orient LEM to to 20 deg L of high side w/ 109 gpm, 705 psi, 10% flow out. PUW = 137k, SOW = 119k. 4/4/2018 4/4/2018 0.50 COMPZ2 RWRID PACK P Continue to RIH from 7,773' MD to 7,773.0 7,805.4 17:15 17:45 7,805' MD. Engage seal assembly & latch LEM in Hook Hanger on depth @ 7,606.69' MD. Observe LEM rotate to 2 deg L of high side. Set down 14k. PU to 152k to verify LEM is engaged. 4/4/2018 4/4/2018 1.00 COMPZ2 RWRID PACK P Drop 1.625" OD ball. Set down 25k & 7,805.4 7,805.4 17:45 18:45 pump down @ 1.5 bpm, 680 psi, 11% flow out. Ball on seat @ 530 stirs. Increase pressure to 2,750 psi & hold for 5 min. Observe hydraulic pusher tool stroke & set ZXP packer @ 2,250 psi. Increase pressure to 3,760 psi to neutralizer setting tool & release running tools & PU 7' per Baker. PUW = 143k, SOW = 119k. 4/4/2018 4/4/2018 0.25 COMPZ2 RWRID PRTS P RU & test ZXP liner top packer to 7,805.4 7,805.4 18:45 19:00 3,500 psi for 10 min charted (good). 35 stks to pressure up & 3.5 bbls bled back. Blow down & RD test equipment. 4/4/2018 4/4/2018 0.75 COMPZ2 RWRID CRIH P PU to 7,567' MD & spot 30 bbl Cl 7,805.4 7,567.0 19:00 19:45 brine. Chase w/ 62 bbls of mud @ 127 gpm, 400 psi. Blow down topdrive. 4/4/2018 4/4/2018 0.50 COMPZ2 RWRID OWFF P OWFF for 30 min, fluid level dropped 7,567.0 7,567.0 19:45 20:15 4" 4/4/2018 4/5/2018 3.75 COMPZ2 RWRID TRIP P POOH from 7,567' MD to 1,495' MD. 7,567.0 1,495.0 20:15 00:00 PUW = 62k. Monitor displacement via trip tank. 4/5/2018 4/5/2018 0.50 COMPZ2 RWRID TRIP P POOH w/ LEM running tools & 1,495.0 66.0 00:00 00:30 SlimPulse from 1,495' MD to 66' MD. Monirtor displacement via trip tank. 4/5/2018 4/5/2018 0.50 COMPZ2 RWRID BHAH P LD ZXP running tool & SLB SlimPulse. 66.0 0.0 00:30 01:00 4/5/2018 4/5/2018 0.50 COMPZ2 RWRID BHAH P Clear & clean rig floor. 0.0 0.0 01:00 01:30 4/5/2018 4/5/2018 0.50 PROD3 WHPST SHAH P Mobilize whipstock BHA components 0.0 0.0 01:30 02:00 to rig floor. 4/5/2018 4/5/2018 2.50 PROD3 WHPST BHAH P MU whipstock BHA as per Baker & 0.0 256.0 02:00 04:30 SLB reps to 256' MD. Monitor displacement via trip lank. 4/5/2018 4/5/2018 1.25 PROD3 WHPST TRIP P RIH on 4" DP from derrick from 256' 256.0 2,150.0 04:30 05:45 MD to 2,150' MD. Monitor displacement via trip tank. PUW = 76k, SOW = 77k. 4/5/2018 4!5/2018 0.25 PROD3 WHPST DHEQ P Shallow hole test MWD @ 220 gpm, 2,150.0 2,150.0 05:45 06:00 780 psi, 15% flow out. Page 26154 ReportPrinted: 511612018 %-t,erations Summary (with Timelog L-pths) 0 1H-103 li Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log seen oePm Stan Time End Time Writs) Phase op Code Aaivity Code Time P-T.XOPHaEon IN) EM Depth 173) 415/2018 4/5/2018 3.50 PROD3 WHPST TRIP P Continue to RIH on 4" DP from derrick 2,150.0 7,391.0 06:00 09:30 from 2,150' MD to 7,391' MD. PUW = 132k, SOW= 113k. Monitor displacement via trip tank. 4/5/2018 4/5/2018 0.50 PROD3 WHPST WASH P Wash down from 7,391' MD to 7,483' 7,391.0 7,483.0 09:30 10:00 MD & orient whipstock to 22 def L of high side w/ 250 gpm, 1581 psi, 19% flow out. PU 30.27' HWDP single from shed & RIH to 7,415.13' MD. 4!512018 4/512018 0.50 PROD3 WHPST WPST P Kelly up to std #78. Wash down @ 7,483.0 7,447.0 10:00 10:30 250 gpm, 1515 psi, 18% flow out to Lt liner top packer @ 7,546.05' MD & set down 4k. Slack off additional 5k to set anchor. Confirm set to 10k & overpull of 145k. Set down 27k and observe bolt shear @ 87k. Pick up to connfm released from slide. PUW = 133k. 4/5/2018 4/5/2016 1.50 PROD3 WHPST MILL P Mill window from 7,447' MD (TOW) to 7,447.0 7,449.5 10:30 12:00 7,449.5' MD w/ 250 gpm, 1427 psi, 18% Ifow out, 100 rpm, 1-6k tq, 1-3k WOB. PUW = 133k, SOW = 115k, ROT = 117k, 3k off bottom tq. 4/5/2018 4/5/2018 10.00 PROD3 WHPST MILL P Mill window from 7,449.5' MD to 7,474' 7,449.5 7,474.0 12:00 22:00 MD w1250 gpm, 1459 psi, 18% flow out, 100 rpm, 2-6k tq, 25k WOB. PUW = 133k, SOW = 115k, ROT = 117k, 3k off bottom tq. Pump hi vis sweep @ 7,455' MD. 4/5/2018 4/5/2018 1.50 PROD3 WHPST MILL P Continue to mill window & drill new 7,474.0 7,485.0 22:00 23:30 hole from 7,474' MD to 7,485' MD for 5' of gauge hole. 250 gpm, 1545 psi, 16% flow out, 100 rpm, 3.5k tq, 8k WOB. 415/2018 4/612018 0.50 PROD3 WHPST REAM P Ream window 2x (good). Work 7,485.0 7,485.0 23:30 00:00 through window with and without pump, see 2k drag. PUW = 136k, SOW = 114k. 4/6/2018 4/6/2018 1.25 PROD3 WHPST CIRC P Rack back stand to 7,413' MD. 7,485.0 7,382.0 00:00 01:15 Circulate while reciprocating from 7,413' MD to 7,325' MD. Pump 20 bbl hi vis sweep w/ 250 gpm, 1520 psi, 17% flow out. PUW = 141 k, SOW = 108k. MW in & out = 9.4 ppg. 3450 total stks pumped. 4/6/2018 4/6/2018 0.50 PROD3 WHPST OWFF P LD single & monitor well for 30 min, 7,382.0 7,382.0 01:15 01:45 static. 4/6/2018 4/6/2018 3.75 PROD3 WHPST TRIP P POOH from 7,382' MD to 157' MD. 7,382.0 157.0 01:45 05:30 Monitor displacement via trip tank. 4/6/2018 4/612018 0.75 PROD3 WHPST SHAH P LD milling BHA from 157' MD, upper 157.0 0.0 05:30 06:15 mill in gauge. Monitor displacement via trip tank. 4/6/2018 4/6/2018 1.00 PROD3 WHPST W W WH P Cycle rams & flush BOP stack of 0.0 0.0 06:15 - 07:15 milling debris. Blow down topdrive, choke & kill lines. SIMOPS: clear & clean dg floor. 4/6/2018 4/6/2018 0.25 PROD3 WHPST OTHR P Service wear bushing. 0.0 0.0 07:15 07:30 4/6/2018 4/6/2018 1.50 PROD3 WHPST SHAH P PU motor BHA (BHA #11) per SLB to 0.0 0.0 07:30 09:00 823' MD. Monitor displacement via pit #1. Page 27154 ReportPrinted: 511612018 Uperations Summary (with Timelog Depths) 1H-103 lip Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time Dur chn Ph— Op Code Activity Code TM P -T -x Operation M(B) End Depth (ItKB) 4/6/2018 4/6/2018 3.00 PROD3 WHPST TRIP P RIH w/ BHA #11 from 823' MD to 0.0 823.0 09:00 12:00 5,669' MD. Monitor displacement via pit #1. PUW = 1061k, SOW = 85k. Perform SHT @ 2,700' MD, good test. 41612018 4/6/2018 1.00 PROD3 WHPST TRIP P Continue to RIH w/ BHA #11 from 823.0 5,669.0 12:00 13:00 5,669' MD to 7,284' MD. Monitor displacement via trip tank. 4/6/2018 4/6/2018 1.00 PROD3 WHPST WASH P Bring on pumps to 244 gpm, 1520 psi, 5,669.0 7,485.0 13:00 14:00 17% flow out. Orient motor to 25 deg L. RIH without pump through window & tag bottom @ 7,485' MD w/ 51k. 4/6/2018 4/6/2018 4.00 PROD3 DRILL DDRL P Drill from 7,485' MD to 7,662' MD 1 7,485.0 7,662.0 14:00 18:00 3,970' TVD @ 230 gpm, 1470 psi, 16% flow out, 40 rpm, 5k tq, 9-15k WOB. Off bottom = 1260 psi, PUW = 112k, SOW = 89k, 4k off bottom tq. Max gas = 39 units. SPRs @ 7,566' MD / 3,973' TVD, MW = 9,1+ ppg, 16:25 hrs MP#1: 20 spm = 390 psi, 30 spm = 550 psi MP#2: 20 spm = 390 psi, 30 spm = 550 psi 4/6/2018 416/2018 1.25 PROD3 DRILL DDRL P Drill from 7,662' MD to 7,715' MD / 7,662.0 7,715.0 18:00 19:15 3,975' TVD @ 230 gpm, 1495 psi, 16% flow out, 40 rpm, 61k tq, 18k WOB. Off bottom = 1260 psi, PUW = 114k, SOW = 89k, ROT = 98k. Max gas = 39 units. ART = 1.73, ADT = 2.96, bit hrs = 6.31, jar hrs = 2.96. 4/6/2018 416/2018 0.75 PROD3 DRILL CIRC P CBU w/ rotation & reciprocation from 7,715.0 7,570.0 19:15 20:00 7,715' MD to 7,670' MD @ 230 gpm, 1250 psi, 16% flow out, 40 rpm, 4k tic. POOH on elevators to 7,570' MD. PUW = 114k, SOW = 93k. 41612018 4/6/2018 2.25 PROD3 DRILL PMPO P Pump OOH from 7,570' MD to 7,465' 7,570.0 7,465.0 20:00 22:15 MD & orient motor to high side. Wash concretion from 7,469' MD to 7,475' MD @ 227 gpm, 1175 psi, 16% flow out in 0.10' increments, keeping WOB to 1k. PUW = 112k, SOW = 95k, with no pump. 4/6/2018 4/6/2018 0.25 PROD3 DRILL TRIP P POOH through window to 7,387' MD 7,465.0 7,387.0 22:15 22:30 with no hang ups. PUW = 114k, SOW = 94k. 4/6/2018 416/2018 0.50 PROD3 DRILL OWFF P Monitor well for 30 min, static. 7,387.0 7,387.0 22:30 23:00 4/6/2018 4/7/2018 1.00 PROD3 DRILL TRIP P Pump 15 bbl slug & POOH w/ BHA 7,387.0 5,574.0 23:00 00:00 #11 from 7,387' MD to 5,574' MD. 4/7/2018 4/7/2018 1.75 PROD3 DRILL TRIP P Continue to POOH w/ motor BHA 5,574.0 824.0 00:00 01:45 (BHA #11) from 5,574' MD to 824' MD. Monitor displacement via trip tank. PW = 62k, SOW = 60k. 4/7/2018 4/7/2018 1.25 PROD3 DRILL BHAH P LD Baker magnets, rack back jar 824.0 0.0 01:45 03:00 stand & HWDP, & LD SLB tools & motor per SLB from 824' MD. Monitor j displacement via trip tank. 4/7/2018 4/7/2018 0.25 PROD DRILL BHAH P Clean & clear rig floor. 0.0 0.0 03:00 03:15 Page 26/54 ReportPrinted: 5/1612016 Uperations Summary (with Timelog D,pths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth stenr7 Entl Tune Dur(hr) Ptme Op Conte Activity Care TMP-T-x Operation (flKB) End DePM(BKB) 4/7/2018 4/7/2018 0.50 PROD3 WHDBOP W W WH P Pull wear bushing & flush stack w. 21 0.0 0.0 03:15 03:45 bpm, 150 psi. Blow down topddve. 4/7/2018 4/7/2018 1.25 PRODS WHDBOP KURD P PU 4.5' test jt & set test plug. RU test 0.0 0.0 03:45 05:00 equipment, Flood lines, & perform body test. 4/7/2018 4/7/2018 5.00 PROD3 WHDBOP BOPE P Test BOPE w/ 4" & 4-1/2" test jls to 0.0 0.0 05:00 10:00 250/3,500 psi for 5/5 min, charted. Test manual & Super Choke 250/2,000 psi for 5/5 min.Test witness waived by AOGCC Rep Adam Earl Test Sequence as follows: With 4.5' Test joint 1) Annular, Choke Manifold valves 1,12,13, 14, 4" Kill, and 4" XT39 dart valve 2) Choke Manifold valves 9, 11, Mem Kill, and 4" XT39 FOSV 3) Choke Manifold valves 8,10, & HCR Kill 4) Choke Manifold valves 6, 7, & Manual Kill 5) Manually Operated Choke and Hydraulic Super Choke tested to 2000 psi 6) Choke Manifold valves 2 & 5 7) Lower 3-1/2" x 6" VBRS Remove 4.5" Test A 8) Blind Rams, Choke Manifold valves , 3&4 With 4" Test Joint 9) Annular, HCR choke, & upper IBOP 10) Annular, Manual choke, & lower [BOP 11) Lower 3-12" x 6" VBRS Perform koomey drawdown test: System Pressure = 3,150 psi PSI after closure = 1,850 psi 200 psi Attained with 2 x electric pumps = 7 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 58 seconds N2 = 6 each @ 2,250 psi Tested all gas and 1-12S sensors, PVT and flow alarms both audio and visual. 4/72018 4/7/2018 0.50 PROD3 WHDBOP RURD P Blow down & RD test equipment. Blow 0.0 0.0 10:00 10:30 down topdrive & choke & kill lines. Pull test plug & install 9" ID wear bushing, RILDS x2. 4/7/2018 417/2018 1.50 PRODS DRILL OTHR P C/O XT39 saver sub. 0.0 0.0 10:30 12:00 Page 29154 ReportPrinted: 5/16/2018 Operations Summary (with Timelog Dtpths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Slad Dep" Time End Time Dur(hr) Phase Op Code Activity Code Time P -T -X Operation (RKB) End Dept(ftKB) 4/7/2018 4/7/2018 1.25 PROD3 DRILL WHAP PJSM, PU 6-3/4" production BHA to 0.0 305.0 12:00 13:15 305' MD as per SLB DD. Monitor displacement via trip tank. PUW = 53k, SOW = 55k. 4/7/2018 4/7/2018 0.75 PROD3 DRILL TRIP P RIH on 4" DP stds from derrick from 305.0 2,204.0 1315 14:00 305' MD to 2,204' MD. Monitor displacement via trip tank. 4/7/2018 4/7/2018 0.50 PROD3 DRILL DHEQ P Perform MWD shallow hole test @ 2,204.0 2,204.0 14:00 14:30 240 gpm, 990 psi, 17% flow out, good test. PUW = 76k, SOW = 79k. 4/7/2018 4/7/2018 2.00 PROD3 DRILL TRIP P Continue to RIH from derrick from 2,204.0 7,335.0 14:30 16:30 2,204' MD to 7,335' MD, filling pipe every 2000'. Monitor displacement via trip tank. 4/7/2018 4/7/2018 0.25 PROD3 DRILL TRIP P Fill pipe while RIH from 7,335' MD to 7,335.0 7,440.0 16:30 16:45 7,440' MD. PUW = 117k, SOW = 89k. 4/7/2018 4/7/2018 1.25 PROD3 DRILL WASH P Trip through window @ 7,447' MD 7,440.0 7,715.0 16:45 18:00 with no pump to 7,485' MD. Bring on pumps & MAD pass from 7,485' MD to 7,715' MD @ 240 gpm, 1425 psi, 17% flow out @ 300 fph. PUW = 117k, SOW = 89k. 417/2018 4/8/2018 6.00 PROD3 DRILL DDRL P Dri1-1-6 3/4 L2 production hole from 7,715.0 8,471.0 18:00 00:00 7,715' MD to 8,471' MD / 3,982' TVD @ 268 gpm, 1830 psi, 20% flow out, 160 rpm, 5k tq. 4k WOB. ECDs = 10.85 ppg, off bottom = 1825 psi, PUW = 116k, SOW = 90k, ROT = 99k, 4.5k off bottom tq. Max gas = 65 units. ADT = 4.26, bit firs = 4.26, jar firs = 7.22. SPRs @ 7,707' MD / 4,006' TVD/ MW = 9.1+ ppg, 18:00 firs MP#1: 20 spm = 390 psi, 30 spm = 550 psi MP#2: 20 spm = 370 psi, 30 spm = 540 psi 4/8/2018 4/8/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 8,471.0 9,215.0 00:00 06:00 8,471' MD to 9,215' MD / 3,962' TVD @ 269 gpm, 1980 psi, 20% flow out, 160 rpm, 6k tq, 2k WOB. ECDs = 11.20 ppg, off bottom 1960 psi, PUW = 119k, SOW = 86k, ROT = 11 Ok, 5k off bottom tq. Max gas = 50 units. ADT =4.35, bit firs =8.61, jar firs =11.57. Page 30154 ReportPrinted: 5/1 612 01 8 Operations Summary (with Timelog G.),ths) 1H-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SteM1 Depth Start Time End Time Dur (hr) Phase Op Code A vhy Cade Time P-T-X Operation (IIXB) End Depth (nxa) 4/8/2018 4/8/2018 6.00 PROD3 DRILL DDRL P Drill 6-314" L2 production hole from 9,215.0 9,839.0 0600 12:00 9,215' MD to 9,839' MD / 3,934' TVD @ 272 gpm, 2030 psi, 19% flow out, 140 rpm, 6.5k tq, 2k WOB. ECDs = 11.43 ppg, off bottom pressure = 2025 psi, PUW = 119k, SOW = 79k, ROT = 97k, 6k off bottom tq. Max gas = 141 units. ADT = 4.81, bit hrs = 13.42, jar hrs = 16.38. Perform 30% whole mud dilution @ 9,517' MD for MBT & ECD. SPRs @ 9,230' MD / 3,962' TVD. MW = 9.2 ppg, 06:05 hrs MP#1: 20 spm = 560 psi, 30 spm = 720 psi MP#2: 20 spm = 540 psi, 30 spm = 700 psi 4/8/2018 4/8/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 9,839.0 10,559.0 12:00 18:00 9,839' MD to 10,559' MD / 3,919' TVD @ 268 gpm, 2130 psi, 20% flow out, 160 rpm, 8k iq, 3k WOB. ECDs = 11.51 ppg, off bottom = 2120 psi, PUW = 124k, SOW = 77k, ROT = 94k, 7k off bottom tq. Max gas = 228 units. ADT = 4.18, bit hrs = 17.6, jar hrs = 20.56. 4/8/2016 4/9/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 10,559.0 11,400.0 18:00 00:00 10,559' MD to 11,400' MD / 3,934' TVD @ 271 gpm, 2160 psi, 160 rpm, 6.5k tq, 5k WOB. ECDs = 11.47 ppg, off bottom = 2150 psi, PUW = 131k, SOW = 78k, ROT = 96k, 6.5k off bottom tq. Max gas = 170 units. ADT = 4.04 hrs, bit hrs = 21.64, jar hrs = 24.6. Perform 60% whole mud dilution @ 10,915' MD for MBT & ECD. SPRs @ 10,653' MD / 3,981' TVD. MW = 9.1+ ppg, 18:30 hrs MP#1: 20 spm = 650 psi, 30 spm = 830 psi MP#2: 20 spm = 630 psi, 30 spm = 810 psi 4/9/2018 4/9/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 11,400.0 12,000.0 00:00 06:00 11,400' MD to 12,000' MD / 3,914' TVD @ 271 gpm, 2320 psi, 20% flow out, 160 rpm, 7k tq, 4k WOB. ECDs = 11.79 ppg, off bottom = 2310 psi, PUW = 139k, SOW = 76k, 99k, 6.5k off bottom tq. Max gas = 60 units. ADT = 4.3, bit hrs = 25.94, jar hrs = 28.9. SPRs @ 12,048' MD / 3,912' TVD. MW = 9.1+ ppg, 06:35 hrs MP#1: 20 spm = 720 psi, 30 spm = 860 psi MP#2: 20 spm = 700 psi, 30 spm = 850 psi Page 31154 ReportPrinted: 511612018 Operations Summary (with Timelog Depths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log slant rime End Torre Dur (hr) Phase op Code Ar dy Code Tore P -T -x Operation slaty Depm (N(9) EM Depth (WS) 4/9/2018 4/9/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 12,000.0 12,601.0 06:00 12:00 12,000' MD to 12,601' MD / 3,903' TVD @ 271 gpm, 2569 psi, 19%. flow out, 160 rpm, 8.5k tq, 5k WOB. ECDs = 12.07 ppg, off bottom = 2560 psi, PUW = 148k, SOW = 77k, ROT = 101 k, 7.5k off bottom tq. Max gas = 75 units. ADT = 4.66, bit hrs = 30.6, jar hrs = 33.56. 419/2018 4/9/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 12,601.0 13,245.0 12:00 18:00 12,601' MD to 13,245' MD 13,886 - 3,886'TVD TVD @ 271 gpm, 2755 psi, 19% flow out, 160 rpm, Sk tq, 4k WOB. ECDs = 12.34 ppg, off bottom = 2750 psi, PUW = 149k, SOW = 72k, ROT = 108k, 8.5k off bottom tq. Max gas = 156 units. ADT = 4.28, bit hrs = 34.88, jar hrs = 37.84. 4/9/2018 4/10/2018 6.00 PROD3 DRILL DDRL P Drill 6-3/4" L2 production hole from 13,245.0 13,759.0 18:00 00:00 13,245' MD to 13,759' MD 13,875' TVD @ 272 gpm, 2773 psi, 19% flow out, 120 rpm, 8k tq, 3k WOB. ECDs = 12.09 ppg, off bottom = 2770 psi, PUW = 159k, No SOW, ROT = 105k, 8k off bottom tq. Max gas = 40 units. ADT = 5, bit hrs = 39.88, jar hrs = 42.84. Perform 30% mud volume dump & dilute @ 13,628' MD and begin increasing lubes to 2.5%. SPRs @ 13,335' MD / 3,883' TVD. MW = 9.2 ppg, 18:50 hrs MP#1: 20 spm = 790 psi, 30 spm = 1000 psi MP#2: 20 spm = 800 psi, 30 spm = 1010 psi 4/10/2018 4/10/2018 5.25 PROD3 DRILL DDRL P Drill 63/4" L2 production hole from 13,759.0 14,165.0 00:00 05:15 13,759' MD to 14,165' MD 13,880' TVD @ 271 gpm, 2,680 psi, 20% flow out, 120 rpm, 8.5k tq, 4k WOB. ECDs = 12.01 ppg, off bottom = 2,670 psi, PUW = 171k, SOW = 60k, ROT = 110k, 8k off bottom tq. Max gas = 100 units. ADT = 3.87, bit hrs = 43.85, jar hrs = 46.71. Lube @ 2.5%. SPRs @ 14,162' MD /3,880' TVD. MW = 9.1+ ppg, 06:45 hrs MP#1: 20 spm = 680 psi, 30 spm = 880 psi MP#2: 20 spm = 660 psi, 30 spm = 840 psi 4/10/2018 4/10/2018 1.50 PROD3 CASING CIRC P Circ BU while Rot & Recip F/ 14,165' 14,165.0 14,165.0 05:15 06:45 MD T/ 14,075' MD @ 273 gpm, 2,380 psi, 18% FO, 120 rpm, 8k TO, ECD= 11.68 ppg, Total Stks- 4,990, PU - 169k, SO - 79k, ROT - 115k 4/10/2018 4/10/2018 0.50 PROD3 CASING - OWFF P Monitor well for 30 min (no flow)—.6 14,165.0 14,165.0 06:45 07:15 BPH static loss 4/10/2018 4/11/2018 16.75 PROD3 CASING BKRM P BROOH F/ 14,165'T/ 7,960' MD @ 14,165.0 7,960.0 07:15 00:00 270 gpm, 1,851 psi, 19% FO, 120 RPM, 4k TO, & 10.54 ppg ECD. Page 32/54 ReportPrinted: 5/1612018 Dril (iNerations Summary (with Timelog DtNths) IH-103 LonocoPhillips 61 i Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depm Stan Time I End T. Our(ty) Phase Op Cade Ae ity Code Time P-T-X Operation (m(a) End Depth(Po(6) 4/11/2018 4/11/2018 1.00 PRODS CASING BKRM P BROOH F/ 7,960' T/ 7,805' MD @ 271 7,960.0 7,805.0 00:00 01:00 gpm, 1,860 psi, 19% FO, 120 RPM, 4k TQ, 10.65 ppg ECD, & pulling @ 200 Whir 4/11/2018 4/1112018 1.00 PROD3 CASING 15—M —PO P Pump OOH F/ 7,805' T/ 7,331'@ 2 7,805.0 7,331.0 01:00 02:00 bpm, 440 psi, 8% FO, PU= 118k, SO= 96k, Observed —15 over pull F/ 7,668' T/ 7,630' wiped it clean 4111/2018 4/11/2018 1.25 PROD3 CASING CIRC P Circ while rot & recip pipe F/ 7,331'T/ 7,331.0 7,331.0 02:00 03:15 7,237' MD@ 240 gpm, 1500 psi, 18% FO, 46 rpm, 2.4k TO, 10.31 ppg ECD, total stks= 4,437, PU= 116k, & SO= 57k 4/11/2018 4/1112018 0.25 PROD3 CASING OWFF P Flow check (no flow) 7,331.0 j 7,331.0 03:15 03:30 4/11/2018 4/11/2018 3.25 PRODS CASING TRIP P POOH on elevators F/ 7,331' T/ 305' 7,331.0 305.0 03:30 06:45 MD. Monitor hole fill via TT. 4111/2018 4/11/2018F1.25 PRODS CASING BHAH P PJSM, OWFF 10 min (no flow), LD 305.0 0.0 06:45 08:00 BHA per SLB rep. 4/11/2018 4/11/2018 PRODS CASING BHAH P Clean floor of BHA tools & prep for PU 0.0 0.0 08:00 08:30 of whipstock retrieval 4/11/2018 4/11/2018 COMPZ3 FISH SVRG P Rig service TDS & inspect blocks 0.0 0.0 08:30 09:004/11/2018 4/11/2018 COMPZ3 FISH BHAH P PJSM, PU whipstock retrieval BHA as 0.0 158.0 09:00 10:00 per BHGE rep, scribe tools T/ 158' MD 4111/2018 4/11/2018 1.00 COMPZ3 FISH TRIP P RIH F/ 158' T/ 2,530' MD & monitor 156.0 2,530.0 10:00 11:00 displacement via TT 4/11/2018 4/11/2018 0.50 COMPZ3 FISH DHEQ P Shallow test MWD (test good 2,530.0 2,530.0 11:00 11:30 4/1112018 4/11/2018 2.25 COMPZ3 FISH TRIP P RIH F/ 2,530' T/ 7,379' MD, Monitor 2,530.0 7,379.0 11:30 13:45 displacement via TT 4/11/2018 4111/2018 0.75 COMPZ3 FISH FISH P Stage up pumps & oriented 158° R, 7,379.0 7,460.0 13:45 14:30 washed F/ 7,379' TI 7,460' MD (whipstock slide) @ 252 gpm, 1,360 psi, 16% FO, PU 139k, SO= 117k, oriented to 22°L, slacked off & engaged hook @ 7,451' MD w/ 10k set down, observed hook roll T/ 170° R, PU 30k over or 170k hookload 3 limes, PU T/ 189k jars fired & freed whipstock. PU= 145k 4/11/2018 4/11/2018 1.50 COMPZ3 FISH CIRC P Pump OOH T/ 7,374' MD, circ 2X BU 7,460.0 7,374.0 14:30 16:00 @ 250 gpm, 1,310 psi, 17% FO, & total stroks= 5,004. 4/11/2018 4/11/2018 0.50 COMPZ3 FISH OWFF P 30 min flow check (no flow) 7,374.0 7,374.0 16:00 16:30 1 4/1112018 4/11/2018 4.75 COMPZ3 FISH PMPO P Pump OOH due to swabbing F/ 7,374' 7,374.0 4,054.0 16:30 21:15 T/ 6,565'@ 3 bpm, 450 psi, 9% FO, & PU= 128k 4/11/2018 4/11/2018 2.50 COMPZ3 FISH TRIP P POOH on elevators F/ 4,054' MD, T/ 4,054.0 257.0 21:15 23:45 257' MD, monitor fill via TT 4/11/2018 4/12/2018 0.25 COMPZ3 FISH BHAH P LD Whipstock retrievel BHA F/ Zbt T/ 257.0 203.0 23:45 00:00 1 I I 203'. Monitor fill via TT 4/12/2018 4/12/2018 1.75 COMPZ3 FISH BHAHP Continue LD Whipstock BHA per 203.0 0.0 00:00 01:45 1 I BHGE & clean & prep Rig floor 4/12/2018 4/1212018 0.75 COMPZ3 CASING RURD P PJSM, RU casing crew, bring tools to 0.0 0.0 01:45 02:30 1 rig floor, & verify pipe count Page 33154 ReportPrinted: 5/1612018 Gperations Summary (with Timelog Deaths) IH-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sre,t Depth Stan Time End Time Dur(hr) Phase Op Code ACWY Curie Tune P-T-X Operation (BKB) End DePIf") 4/12/2018 7.50 COMPZ3 CASING PUTS P RIH w/ 4 1/2" #12.6 L-80 TXP L2 0.0 6,662.0 02:30 10:00 slotted liner T/ 6,662', MU to 7,000 ft- 14/1212018 lbs, floating centralizers on every joint, PU=94k & SO=73k. 4/12/2018 4/12/2018 0.50 COMP CASING OTHR P CO elevators, MU hookhanger, PU 6,662.0 6,662.0 10:00 10:30 MWD & scribe tools 4/12/2018 4/1212018 0.75 COMPZ3 CASING RUNL P RIH 4 stds of 4" DP & monitor 6,662.0 7,420.0 10:30 11:15 displacement via TT 4/12/2018 4/12/2018 0.25 COMPZ3 CASING DHEQ P Shallow test MWD (test good) @ 111 7,420.0 7,420.0 11:15 11:30 gpm, 405 psi, 11 % FO, PU= 104k, & SO= 80k 4!12/2018 411212018 5.00 COMPZ3 CASING RUNL P Continune running slotted liner on 4" 7,420.0 13,917.0 11:30 16:30 DP F/ 7,420' T/ 13,917' MD, monitor displacement via TT, & fill every 20 stds 4/12/2018 4/12/2018 0.75 COMPZ3 CASING HOSO P Orient hook hanger 180° out, recip F/ 13,917.0 14,000.0 16:30 17:15 13,917' T/ 14,000' @ 121 gpm, 840 psi, 11 % FO, PU= 154k & SO= 93k 4/12/2018 4/1212018 0.75 COMPZ3 CASING HOSO P RIH T/ 14,102', wash down @ 120 14,000.0 14,097.0 17:15 18:00 gpm, 640 psi, 11 % F0,10' past window TI 14,141' MD, nothing seen while going past window, PU T/ 14,097'& orient hook hanger to 22° L 4/1212018 1411212018 0.50 CASING HOSO P RIH T! 14,133' MD, tag hang off point, 14,097.0 14,133.0 18:00 18:30 PU 10', SO verfify lag point & set JCOMPZ3 down 30k over. Hook hanger set depth @ 7,462.69 4/12/2018 4/12/2018 1.00 COMPZ3 CASING CIRC P Drop 0.9" ball, pump @ 2 bpm, 625 14,133.0 7,462.7 18:30 19:30 psi, pressure up to 850 psi, increased pressure T/ 3,300 psi, pressured T/ 3,500 psi, PU & release F/ hook hanger, PU= 148k, SO= 118k, pressure up T/ 4,424 psi to shear out of circ sub, & confirm shear out by pumping @ 1.5 bpm, 340 psi, & 9% FO. 4/12/2018 4112/2018 0.75 COMPZ3 WELLPR OWFF P POOH T/ 7,389'& perform 30 min flow 7,462.7 7,389.0 19:30 20:15 check (no flow) 4/1212018 4/12/2018 1.25 COMPZ3 P Slip & cut 73'of drill line 7,389.0 7,389.0 20:15 21:30 4/12/2018 4/13/2018 2.50 COMPZ3 TRIP P POOH w/ liner running tools racking 7,389.0 2,922.0 21:30 00:00 back 4" DP F/ 7,389'T/ 2,922'MD, & rWELLPRSVRG monitor fill via TT 4113/2018 4/13/2018 1.50 COMPZ3 TRIP P POOH F/ 2,922' T/ 76'MD & monitor 2,9220 76.0 00:00 01:30 well via TT 4!13/2018 4/13/2018 0.50 COMPZ3 BHAH P PJSM, LD hook hanger assemble per 76.0 0.0 01:30 02:00 BHGE rep 4113/2018 0.75 COMPZ3 WELLPR BHAH P Clean rig floor & RU casing crew 0.0 0.0 02:45 4/13/2018 2.00 COMPZ3 RWRID PUTB P MU L2 LEM, per tally, torque tum all 0.0 292.0 04:45 connections, MU 4 1/2" BTC to 7,000 r28 ft-lbs 4/13/2018 0.75 COMPZ3 RWRID RCST P Run L2 LEM on 4" DP F/ 292'T/ 292.0 1,581.0 05:30 1,581'MD PU- 72k & SO- 68k4/13/2018 050 COMPZ3 RWRID DHEQ P Fill pipe & pulse test MWD (test good) 1,581.0 1,581.0 06:00 @ 110 gpm, 370 psi, & 12% FO. Page 34154 ReportPrinted: 511612018 (-„erations Summary (with Timelog D-,jths) 11-1-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SW Depth Start Time EndTme Dur(hr) Phm Op Code AcMity Code 17me P -T -X Operation (ftKB) End Depth(OKB) 4/13/2018 4/13/2018 4.00 COMPZ3 RWRID RCST P Continue RIH on 4” DP F/ 1,581'T/ 1,581.0 7,325.0 06:00 10:00 7,325' MD, monitor displacement via TT, & fill every 20 stds 4/13/2018 4/13/2018 1.25 COMPZ3 RWRID HOSO P Orient to 93° L while recip pipe F/ 7,325.0 7,578.6 10:00 11:15 7,325'T/ 7,410' MD, 110 gpm, 670 psi, 10% FO, PU= 137k, SO= 115k, continue to wash down, engage seal assy, latch easy w/ 20k set down, toolface flopped T/ 39° L, unlatch & relatch, tooface flopped T/ 33° L. 4113/2018 4/1312018 0.75 COMPZ3 RWRID PACK P Drop 1.625" ball & pump down @ 2 7,578.6 7,299.0 11:15 12:00 bpm, 480 psi, 8% FO, for 445 stks, reduce TI 1.5 bpm, 370 psi, 6% FO, ball sealed on 505 stks, increased pressure T/ 1,000 psi, hold for 2 min, increased T/ 2,500 psi, observed ball shift, & increased pressure T/ 3,700 psi to release tool. 4/13/2018 4/13/2018 0.75 COMPZ3 RWRID PRTS P Pressure lest ZXP liner top packer T/ 7,299.0 7,299.0 12:00 12:45 3,500 psi F/ 10 min. 3.6 bbls pumped for test (good test) 4/13/2018 4/13/2018 1.00 COMPZ3 RWRID CRIH P Break circulation, pumped 30 bbls of 7,299.0 7,299.0 12:45 13:45 Cl brine @ 257 gpm, 850 psi, & 17% FO 4/13/2018 4/13/2018 0.50 COMPZ3 RWRID OWFF P BD TDS & flow check for 30 min (no 7,299.0 7,299.0 13:45 14:15 flow) 4/13/2018 4/13/2018 3.25 COMPZ3 RWRID TRIP P POOH on elevators F/ 7,299'T/ 74' 7,299.0 74.0 14:15 17:30 MD & monitor fill via TT 4/13/2018 4/13/2018 0.50 COMPZ3 RWRID BHAH P LD ZXP hanger tools per BHGE rep 74.0 0.0 17:30 18:00 4113/2018 4/13/2018 2.00 PROD4 WHPST BHAH P MU L3 whipshock/mill assy per BHGE 0.0 231.0 18:00 20:00 rep 4113/2018 4/1412018 4.00 PROD4 WHPST TRIP P RIH W/ L3 whipstock/mill assy at 231.0 6,200.0 20:00 00:00 reduced rate 90 fl/min, easy in & out of slips F/ 231'T/ 6,200'. Shallow test MWD @ 1,500- 4/14/2018 4114/2018 1.00 PROD4 WHPST TRIP P Continue RIH on 4" DP F/ 6,200'T/ 6,200.0 7,299.0 00:00 01:00 7,190', orient whipstock 22° L @ 226 gpm, 1,030 psi, PU- 113k, & SO - 133k. Tagged packer top @ 7,298.98' (planned top) 4/14/2018 4/14/2018 0.75 PROD4 WHPST WPST P Set down 1 O & shear anchor, pull 1 O 7,299.0 7,218.0 01:00 01:45 to confine set, set down 25k & sheared bolt. PU to free weight, rotate pipe @ 100 rpm, 3k TQ, ROT- 123k, inceresed to 270 gpm, & 1,485 psi 4/14/2018 4/1412018 4.25 PROD4 WHPST MILL P Mill L3 window F/ 7,218'T/ 7,223' MD, 7,218.0 7,223.0 01:45 06:00 2-5k WOB, 100 rpm, 4-10k TQ, 1,500 psi, PU- 133k, SO- 114k, & ROT - 123k 4114/2018 4/14/2018 6.00 PROD4 WHPST MILL P Mill L3 window F/ 7,223'T/ 7,236' MD 7,223.0 7,236.0 06:00 12:00 3,947 TVD, 271 gpm, 1,656 psi, 17% FO, 1 O WOB, 120 rm, & 4k TO 4/14/2018 4/14/2018 4.25 PROD4 WHPST MILL P Mill L3 window F/ 7,236'T/ 7,250' MD 7,236.0 7,250.0 12:00 16:15 3,950 TVD, 271 gpm, 1,680 psi, 17% FO, 1 Ok WOB, 120 rm, & 4k TO. Pumped 20 bbl Hi -Vis sweep while working mills through window v� TOW- 7,218' MD BOW- 7231.6' MD Page 35154 Report Printed: 511612018 Uperations Summary (with Timelog DtNths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten cepm Stan Time End Tena Dur (hr) Phase Op cote Actwey Code rime P -T -X P Operation Work mill through window 2X & no (fixe) I 7,250.0 End OepN(Wn 7,215.0 4/14/2018 4/14/2018 1.25 PROD4 WHPST REAM excess drag encountered. Shut off 16:15 17:30 pumpes and mills through window with no issues, PU- 140k, & SO- 1131k. 4/14/2018 4/14/2018 0.25 PROD4 WHPST OWFF P Monitor well for 15 min (no flow) 8 7,215.0 7,215.0 17:30 17:45 blow down TDS 4/14/2018 4114/2018 5.25 PROD4 WHPST TRIP P Pump slug & POOH on elevators F/ 7,215.0 151.0 17:45 23:00 7,215' MD TI 151' MD adjusting W WT SS's per rep. 4/14/2018 4/15/2018 1.00 PROD4 WHPST BHAH P LD milling BHA per BHGE rep, 151.0 0.0 23:00 00:00 cleaned magnets -5 gal of shavings, upper mill was not under gage. /15 412018 4/15/2018 1.00 PROD4 WHPST WWWH P Wash stack w/flushing tool, sery ice 0.0 0.0 00:00 01:00 wear bushing & reinstall, dean & prep rig floor 4/1512018 4/1512018 1.00 PROD4 WHPST BHAH P PJSM, MU motor assembly per SLB 0.0 99.0 01:00 02:00 rep & scrib tools 4/1512018 4.00 PROD4 WHPST TRIP P TI F/ 99' T/ 7,251' MD, one stand 99.0 7,251.0 02:00 06:00 above the window, oriented to 16' L, 14/15/2018 slack off through window (nothing encountered), PU-105k, & SO- 86k 4115/2018 4/15/2018 3.50 PROD4 DRILL DDRL P Drill 6 3/4" build section F/ 7,251'T/ 7,251.0 7,490.0 06:00 09:30 7,490' MD, 3,927' TVD @ 220 gpm, 1,270 psi, 16% FO, 40 RPM, 4.5k TO, off btm- 1,160 psi, PU- 116k, SO- 95k, ROT- 103k, 4k TO, max gas- 45 units, displaced w/ new 9.2 ppg mud, AST - 1.45 hrs, ART- 0.7 hrs, ADT- 2.15 hrs, Bit- 2.15 hrs, & Jars- 48.96 hrs. SPR's @ 7,484' MD, 3,927' TVD, MW - 9.2 ppg MP#1- 20 spm- 400 psi, 30 spm- 560 psi MP#2- 20 spm- 380 psi, 30 spm- 560 psi 4/15/2018 4/15/2018 0.75 PROD4 DRILL TRIP P Obtain final surveys, SPR's, orient 7,490.0 7,188.0 09:30 10:15 highside, & pull through window T/ 7,188' MD 4/1512018 4/15/2018 3.25 PROD4 DRILL TRIP P Pump slug & POOH on elevators F/ 7,188.0 823.0 10:15 13:30 7,188' T/ 823'. Monitor fill via TT 4/15/2018 411512018 1.25 PROD4 DRILL BHAH P LD BHA per BHGE rep, clean off 823.0 0.0 13:30 14:45 magnets, & clean rig floor. Monitor fill via TT 4/15/2018 4/15/2018 0.50 PROD4 DRILL SVRG P Rig service & instpect TDS 0.0 0.0 14:45 15:15 4/1512018 4/15/2018 1.00 PROD4 DRILL SHAH P PJSM, PU 6 3/4" RSS BHA per SLB 0.0 305.0 15:15 16:1 1 rep 4/15/2018 4/15/2018[2.25 1 PROEM DRILL TRIP P RIH w/ 4" DP T/ 2,200' MD, Monitor 305.0 2,200.0 16:15 17:15 displacement via TT 4/15/2018 4/15/2018 PROD4 DRILL DHEQ P Shallow test MWD tools (lest good) 2,200.0 2,200.0 17:15 17:30 4/15/2018 411512018 PROD4 DRILL TRIP P RIH on 4" DP F/ 2,200'MD T/ 7,250' 2,200.0 7,250.0 17:30 19:45 MD. One stand above window reduced rate and had no issues going hrough window. 4/15/2018 4/15/2018 PROD4 DRILL DLOG P Log formataion @ 300 fpm F/ 7,250' 7,250.0 7,490.0 19:45 21:15 T/ 7,490' MD Page 36154 ReportPrinted: 511612018 tr,,erations Summary (with Timelog G.,jths) 1 H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shad Time End Time Dir (hr) Phase op Code AcWy Cade Time P -T -X opeream S art Dep h MK6 End Depth (PKB) 4/15/2018 4/16/2018 2.75 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 7,490'T/ 7,490.0 7,726.0 21:15 00:00 7,726' MD, 3,922' TVD @ 263 gpm, 1,717 psi, 19% FO, 150 rpm, 5.5k TQ, 2-10k WOB, ECD's- 10.39 ppg, off btm- 1,700 psi, PU- 111 k, SO- 89k, ROT- 96k, 4k TQ, max gas- 60 unis. ADT- 1.75 hrs, Bit- 1.75 hrs, & Jars - 50.71 hrs SPR's @ 7,424' MD, 3,927' TVD, MW - 9.2 ppg MP#1: 20 spm- 390 psi, 30 spm- 580 psi MP#2: 20 spm- 380 psi, 30 spm- 560 psi 4/16/2018 4/16/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 7,726'T/ 7,726.0 8,330.0 00:00 06:00 8,330' MD, 3,934' TVD @ 263 gpm, 1,797 psi, 19% FO, 150 rpm, 6k TQ, 2 -1 Ok WOB, ECD's- 10.61 ppg, off btm- 1,737 psi, PU- 114k, SO- 85k, ROT - 97k, 4k TQ, max gas- 53 unis. ADT - 4.25 hrs, Bit- 6 hrs, & Jars 54.96 hrs 4/16/2016 4/16/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 8,330' TI 8,330.0 9,043.0 06:00 12:00 9,043' MD, 3,919' TVD @ 263 gpm, 1,875 psi, 19% FO, 150 rpm, 6k TQ, 2k WOB, ECD's- 10.82 ppg, off btm- 1,875 psi, PU-116k, SO- 84k, ROT - 99k, 4k TQ, max gas- 730 unis. ADT - 4.15 hrs, Bit- 10.15 hrs, & Jars- 59.11 hrs SPR's @ 8,378' MD, 3,934' TVD, MW - 9.2 ppg MP#1: 20 spm- 420 psi, 30 spm- 620 psi MP#2: 20 spm- 430 psi, 30 spm- 620 psi 4/16/2018 4/16/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 9,043' T/ 9,043.0 9,665.0 12:00 18:00 9,665' MD, 3,879' TVD @ 263 gpm, 1,970 psi, 19% FO, 150 rpm, 6,5k TQ, 3k WOB, ECD's- 11.20 ppg, off btm- 1,875 psi, PU- 124k, SO- 78k, ROT - 99k, 6k TQ, max gas- 80 unis. ADT - 3.88 hrs, Bit -14.03 hrs, & Jars- 62.99 hrs 4/16/2018 4/17/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 9,665'T/ 9,665.0 10,155.0 18:00 00:00 10,155' MD, 3,874' TVD @ 263 gpm, 1,968 psi, 18% FO, 150 rpm, 6-8k TQ, 2-12k WOB, ECD's- 11.0 ppg, off btm- 1,970 psi, PU- 130k, SO- 73k, ROT - 97k, 6k TO, max gas- 24 unis. ADT - 4.2 hrs, Bit- 18.23 hrs, & Jars- 67.19 hrs SPR's @ 9,707' MD, 3,887' TVD, MW - 9.2 ppg MP#1: 20 spm- 540 psi, 30 spm- 740 psi MP#2: 20 spm- 560 psi, 30 spm- 740 psi Page 37154 ReportPrinted: 5116/2018 h, Gaerations Summary (with Timelog Laths) Awl- 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log SWTine End TIme our (hr) Phase Op Code DRILL Activity Cade DDRL Time P-T-X P Open Dnll 1-3 6 3/4" Lateral F/ 10,155' T/ sten Depth (flKB) 10,155.0 End Depth(nKB) 10,784.0 4/17/2018 00:00 4117/2018 06:00 6.00 PROD4 10,784' MD, 3,864' TVD @ 263 gpm, 2,079 psi, 18% FO, 150 rpm, 6-9k TQ, 2-12k WOB, ECD's-11.23 ppg, off btm- 2,066 psi, PU- 133k, SO- 72k, ROT- 97k, 7k TQ, max gas- 19 unis. ADT- 4.39 hrs, Bit- 22.62 hrs, & Jars- 71.58 hrs 4/17/2018 4/17/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 10,784' 11 10,784.0 11,630.0 06:00 12:00 11,630' MD, 3,863' TVD @ 263 gpm, 2,215 psi, 19% FO, 150 rpm, 8k TQ, 3k WOB, ECUs- 11.62 ppg, off btm- 2,210 psi, PU- 130k, SO- 65k, ROT- 98k, 7k TQ, max gas- 27 unis. ADT- 4.27 hrs, Bit- 26.89 hrs, & Jars- 75.85 hrs SPR's @ 10,846' MD, 3,866' TVD, MW- 9.2 ppg MP#1: 20 spm- 560 psi, 30 spm- 740 psi MP#2: 20 spm- 560 psi, 30 spm- 700 psi 4/1712018 4/17/2018[6.00 PROD4 DRILL DDRL P Drill L36 314" Lateral F/ 11,630' T/ 11,630.0 12,240.0 12:00 18:00 12,240' MD, 3,648' TVD @ 263 gpm, 2,215 psi, 19% FO, 150 rpm, 9k TQ, 3k WOB, ECD's- 11.69 ppg, off btm- 2,210 psi, PU-139k, SO- 56k, ROT- 90k, 8k TQ, max gas- 25 unis. ADT- 4.7 hrs, Bit- 31.59 hrs, & Jars- 80.55 his 4/17/2018 4/1812018 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 12,240' T/ 12,240.0 12,808.0 18:00 00:00 12,808' MD, 3,868' TVD @ 263 gpm, 2,439 psi, 18% FO, 150 rpm, 9k TQ, 3k WOB, ECD's- 11.74 ppg, off btm- 2,400 psi, PU- 148k, SO- 55k, ROT- 94k, 7k TQ, max gas- 85 unis. ADT- 4.48 his, Bit- 36.07 hrs, & Jars- 85.03 his SPR's @ 12,347' MD, 3,842' TVD, MW- 9.2 ppg MP#1: 20 spm- 600 psi, 30 spm- 800 psi MP#2: 20 spm- 620 psi, 30 spm- 820 psi 4118/2018 4/18/2018 5.50 PROD4 DRILL DDRL P Drill L36 3/4" Lateral F/ 12,808' TI 12,808.0 13,362.0 00:00 05:30 13,362' MD, 3,819' TVD @ 264 gpm, 2,640 psi, 18% FO, 130 rpm, 8k TQ, 2 -14k WOB, ECUs- 11.86 ppg, off btm- 2,600 psi, PU- 163k, SO- 49k, ROT- 101k, 7k TQ, max gas- 40 unis. ADT- 4.03 his, Bit- 40.1 hrs, & Jars- 89.06 hrs 4118/2018 4/18/2018 0.50 PROD4 DRILL SVRG P Rig service: service TDS & washpipe 7,3620 13,362.0 05:30 06:00 Page 38154 ReportPrinted: 5/1612018 Summary (with Timelog G, Liths) 1 H-103 lipL.,,erations Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Sian Depth Slav Tlme EM Tme Dta(h) Phase op Cone Activity Code Time P -T -X operation (Pool) End Deplh(IIKS) 4/18/2018 4/18/2018 6.00 PROD4 DRILL DDRL P Drill 1-3 6 3/4" Lateral F/ 13,362'T/ 13,362.0 14,196.0 06:00 12:00 14,196' MD, 3,817' TVD @ 264 gpm, 2,755 psi, 18% FO, 150 rpm, 8k TO, 5.5k WOB, ECD's- 12.21 ppg, off btm- 2,745 psi, PU- 167k, SO- N/A, ROT - 106k, 8.7k TQ, max gas- 60 unis. ADT - 3.7 hrs, Bit- 43.8 hrs, & Jars- 92.76 his . SPR's @ 13,548' MD, 3,812' TVD, MW- 9.2 ppg MP#1: 20 spm- 750 psi, 30 spm- 960 psi MP#2: 20 spm- 700 psi, 30 spm- 920 psi 4/18/2018 4/18/2018 6.00 PROD4 DRILL DDRL P Drill L3 6 3/4" Lateral F/ 14,196'T/ 14,196.0 14,949.0 12:00 18:00 14,949' MD, 3,828' TVD @ 264 gpm, 2,875 psi, 19% FO, 140 rpm, 10.5k TQ, 5k WOB, ECD's- 12.17 ppg, off btm-2,870 psi, PU- 171 k, SO- N/A, ROT- 109k, 10k TQ, max gas- 60 unis. ADT- 4.25 hrs, Bit- 48.05 hrs, & Jars -97.01 hrs SPR's @ 14,949' MD, 3,828' TVD, MW- 9.2 ppg MP#1: 20 spm- 720 psi, 30 spm- 940 psi MP#2: 20 spm- 720 psi, 30 spm- 920 psi 4/18/2018 4/18/2018 1.50 PROD4 CASING CIRC P Obtain final survey, circ BU w/ ROT & 14,949.0 14,949.0 18:00 19:30 Reap F/ 14,949' T/ 14,868' MD @ 264 gpm, 2,600 psi, 18% FO, 120 rpm, 8k TO, PU- 163k, SO- NA, ROT -119k, & SIMOPS diluted FloPro mud per MI 4/18/2018 4/1812018 0.50 TROIA OWFF P 30 min flow check (no flow) & service 14,949.0 14,949.0 19:30 20:00 TOS 4/18/2018 4/19/2018 4.00 PROD4 CASING BKRM P BROOH F/ 14,949 T/ 13,479' MD @ 14,949.0 13,479.0 20:00 00:00 130 rpm & 264 gpm. 4/19/2018 4/19/2018 6.00 PROD4 CASING BKRM P BROOH F/ 13,479'to 10729' MD, 13,479.0 10,729.0 00:00 06:00 Pump @ 264 gpm= 1950 psi, 17% FO. Rotate @ 130 rpm's w/ 6K Tq, Pulling @ 1000 fph, slow down 500 fph for fault @ 11,050' MD. 4/19/2018 4/19/2018 7.25 PROD4 CASING BKRM P Cont to BROOH F/ 10729 MD' to 10,729.0 7,431.0 06:00 13:15 7431' MD, Pump @ 264 gpm= 1720 psi, 17% FO. Rotate @ 130 rpm's w/ 6K Tq, Pulling @ 1000 fph, slow down 500 fph for fault @ 9065' MD and 3 stands before casing window. P/U= 114K, S/0= 89K, 4/19/2018 4/19/2018 0.50 PROD4 CASING PMPO P POOH wl pump @ 3 bpm f/ 7431' MD 7,431.0 7,142.0 13:15 13:45 to 7142' MD. BHA pulled though window with no overpull or issues observed. Shoot survey as per SLB when sensor was at the BOW @ 7231.60' MD 4/19/2018 4/19/20181.25 PROD4 CASING CIRC P Circulate casing clean, pump @ 300 7,142.0 7,047.0 1345 15:00 gpm= 2065 psi, Rotate @ 40 rpm's. Pumped a total of 4398 strokes. P1U=113K, S/0= 95K, Page 39164 ReportPrinted: 511612018 k -„orations Summary (with Timelog L,-,jths) IH -103 • coPhillips Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log stat Depm siert Tine End Too Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (W13) End DepN (flKB) 4/19/2018 4/19/2018 0.25 PROD4 - CASING OWFF P OWFF for 15 min (No flow) 7,047.0 7,047.0 15:00 15:15 4/19/2018 4/19/2018 2.50 PROD4 CASING TRIP P Pump slug & POOH on elevators F/ 7,047.0 305.0 15:15 17:45 7,047'T/ 305' 4/19/2018 4/19/2018 1.25 PROD4 CASING SHAH P PJSM, LD RSS BHA per SLB rep & 305.0 0.0 17:45 19:00 clean rig floor 4/19/2018 4/19/2018 1.00 PROD4 WHDBOP RURD P Drain stack, pull wear bushing, flush 0.0 0.0 19:00 20:00 stack, & BD TDS 4/19/2018 4/19/2018 0.50 PROD4 WHDBOP RURD P Set test plug, RU testing equip, & fill 0.0 0.0 20:00 20:30 lines 4/19/2018 4/20/2018 3.50 PROD4 WHDBOP BOPE P Test BOPE wl 4” and 4-1/2" test joints 0.0 0.0 20:30 00:00 to 250/3500 psi, 5/5 min, charted. Witnessed by AOGCC rep Bob Noble Test Sequence as follows: Install 4-1/2" test joint 1) Annular, Choke valves #1, 12, 13, & 14, 4" Kill, and 4" XT39 Dart valve. 2) Choke valves #9 and 11, Me=nine Kill valve, and 4" XT39 FOSV. 3) Choke valves #8 and 10, and HCR Kill 4) Choke valves #6 and 7 and Manual Kill 5) Manual and Super chokes (tested to 2000 psi) 6) Choke valves #2 ,5 and Upper IBOP 7) Lower 3-1/2" x 6" rams, & lower IBOP Remove test joint 8) Blind rams, Choke valves #3 and 4, and 6. Install 4" test joint 9) Annular and HCR choke 10) Manual choke 11) Lower 3-1/2" x 6" rams Perform koomey drawdown test: System Pressure = 2950 psi PSI after closure = 1850 psi 200 psi Attained with 2 x electric pumps = 6 seconds Full Pressure attained with 2 x electric and 2 x air pumps = 56 seconds 6 bottle N2 avg = 2,200 psi Tested all gas and H2S sensors, PVT and flow alarms both audio and visual, and functioned primary and remote BOP controls - all good. 4/20/2018 4/20/2018 0.75 PROD4 WHDBOP RURD P Break out testing equip, blow down all 0.0 0.0 00:00 00:45 lines, pull test plug & install wearbushing 4/20/2018 4/20/2018 1.75 COMPZ4 FISH BHAH P PJSM, MU whipstock hook BHA per 0.0 158.0 00:45 02:30 BHGE & scribe tools Page 40154 Report Printed: 511612018 Operations Summary (with Timelog Dupths) 11-1-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depenim' Stan Time Encinme Dur(hn Phase Op Cade Activity Code Time P -T -X Operation (fl(a) End DepN(flKB) 4/20/2018 4/20/2018 3.00 COMPZ4 FISH TRIP P RIH w/ whipstock retrieval BHA, 158.0 7,120.0 02:30 05:30 shallow test MWD (test good) F/ 158' to / 7120' MD. P/U= 132K, S/O= 11 OK. 4/20/2018 4/20/2018 1.00 COMPZ4 FISH FISH P Establish Circulation and stage pumps 7,120.0 7,222.0 05:30 06:30 up to 230 gpm= 1887 psi. Orient to 160 deg R, wash out retrieval slot on whipstock as per Baker. Re -Orient to 20 deg L and hook whipstock on the 2nd pass. PIU to 30K over then set down 20K twice to confirm good hook. PIU to 30K over and bleed jar, cont to PIU to 83K over to unset anchor. POOH to 71 80'MD w/ 6K extra P/U Wt. 4/20/2018 1.00 COMPZ4 FISH CIRC P Circulate to confirm no gas under 7,222.0 7,120.0 06:30 07:30 whipstock @ 250 gpm= 1250 psi. Lost 14120/2018 49 bbls when CBU X 2 alter pulling whipstock. 4120/2018 4/202018 0.50 COMPZ4 FISH OWFF P OWFF, static to sligh losses. Dropped 7,120.0 7,120.0 07:30 08:00 5' below flowline. 4/20/2018 41202018 4.50 COMPZ4 FISH TRIP P POOH @ 60 fpm w/ whipstock as per 7,120.0 165.0 08:00 12:30 Baker. Lost 15 bbis while POOH. 420/2018 420/2018 2.00 COMPZ4 FISH BHAH P PJSM, LD Whipstock BHA per BHGE 165.0 0.0 12:30 14:30 1 1 rep 420/2018 4/20/2018 1.25 COMPZ4 CASING RURD P RU casing running tools, count pipe, & 0.0 0.0 14:30 15:45 1 1 prep for liner run 4'20/2018 4120/2018 7.75 COMPZ4 CASING PUTS P PU & RIH w/4-1/2" 12.6# L-80 L3 0.0 7,549.0 15:45 23:30 slotted liner per tally Tl 7,549' MD. No issues or porblems finding L3 window w/ liner 4/20/2018 4/212018 0.50 COMPZ4 CASING OTHR P MU hook hanger, PU MWD, & scribe 7,549.0 7,659.0 23:30 00:00 tools. 421/2018 4/21/2018 7.00 COMPZ4 CASING RUNL P Run liner on 4" DP F/ 7,659' T114722'. 7,659.0 14,722.0 00:00 07:00 MD. Shallow test MWD @ 1800' MD, pump @ 130 gpm=570 psi. (good test) RIH, monitor displacement via TT, & fill pipe every 20 stands. 4/212018 4/21/2018 0.50 COMPZ4 CASING RUNL - P Establish circulation @ 2.5 bpm= 680 14,722.0 14,815.0 07:00 07:30 psi, Orient hook hanger to 150 deg R. Observing tight hole, work liner down to 14815' MD. P/U= 163K, S/O= 83K. Page 41154 ReportPrinted: 5116/2018 Gverations Summary (with Timelog D,,jths) 1H-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Tme End Tim our(M) Phew Op Cade Acti*Code Tim P-T-XOperatlon Start Depth (WJ3) End Depth links) 4/21/2018 3.00 COMPZ4 CASING HOSO P Cord to wash down@ 3 bpm= 828 psi 14,815.0 14,903.7 07:30 10:30 f/ 14815' MD to 14904' MD, confirm orientation @ 150 R. Work hook hanger down six feet past BOW while dealing with tight hole conditions. P/U and orient hook hanger to 30L and attempt to hook hanger on BOW. Set down 25K @ 14899' MD but did not see loolface roll, due to tight hole. P/U and continue to work liner until and circulate, hole conditions greatly improved. Orient hook to 40L and slack off to 14903.69' MD, set down 30K and observe tool face roll to 16L, 4 feet deep. P/U and Orient to 4L and slack off to 14903.69' MD, set down 30K and observe tool face roll to 16L again. Hook hanger hooked 4' deep, confirm with town that hook hanger is properly hooked 4/21/2018 4/21/2018 0.75 COMPZ4 CASING CIRC P Release running tool f/ Hook hanger, 14,903.7 14,903.7 10:30 11:15 drop 29/32th ball and pump down @ 2 bpm= 540 psi. Reduce pump rate 1.5 bpm= 430 psi. Ball on seat @ 540 strokes. Pressure up to 3300 psi to release, P/U 10' and confirm release w/ P/U wt. of 142K. Pressure up to 3706 psi to blow ball seat. 4/21/2018 4/21/2018 0.25 COMPZ4 WELLPR TRIP P POOH w/ pump @ 2 bpm=314 psi to 14,903.7 14,815.0 11:15 11:30 14815' MD to get running tools out of hanger. 4/21/2018 4121/2018 0.50 COMPZ4 WELLPR OWFF P OWFF, static. 14,815.0 14,815.0 11:30 12:00 4/21/2018 4121/2018 4.00 COMPZ4 WELLPR TRIP P POOH on elevators F/ 7,196'T/ BHA. 14,815.0 100.0 12:00 16:00 Monitor fill via TT 4121/2018 4/21/2018 1.00 COMPZ4 WELLPR SHAH P LD liner running tools per BHGE rep & 100.0 0.0 16:00 17:00 clean rig floor 4/21/2018 4/21/2018 1.50 COMPZ4 WELLPR ' SVRG P Slip & cut drill line 73' 0.0 0.0 17:00 18:30 4/21/2018 4/21/2018 1.00 COMPZ4 RWRID RURD P RU casing handling tools & prep dg 0.0 0.0 18:30 19:30 floor for LEM run 4/21/2018 4/21/2018 1.75 COMPZ4 RWRID PUTS P PJSM, PU L3 LEM, torque tum all 0.0 314.0 19:30 21:15 connections, & scribe tools 4/21/2018 4/22/2018 2.75 COMPZ4 RWRID RCST P RUN L3 LEM on DP F/ 314' T14,108'. 314.0 4,108.0 21:15 00:00 Shallow test MWD @ 3,400' good test 4/22/2018 4/222018 2.00 COMPZ4 RWRID TCST P Cont TIH F/ 4,108' T/ 7,155' MD, fill 4,108.0 7,155.0 00:00 02:00 pipe every 20 aids, & monitor fill via TT. PU 136k & SO -115k 422/2018 4/222018 2.00 COMPZ4 RWRID HOSO P Orient stand to 40' L. RIH, observed 7,155.0 7,331.9 02:00 04:00 no toolface roll. PU 10k over, popped out of hanger, oriented to 112` L, SO 10k over, ovserved toolface roll T/ 70° L, PU to just under pop out (140k), SO 10k over, observed toolface roll T/ 64° L, PU T/ 140k, confirmed latch, & SO to neutural weight. Page 42/54 Report Printed: 511 612 01 8 Gperations Summary (with Timelog Depths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sled oapm Stas Time Eml Tine Our (M) 1.00 Please COMPZ4 Op Cade RWRID Activity Oode PACK Time P -T -X P Operation Set ZXP liner top packer, drop ball (N(B) 7,331.9 EM DTII pIKB) 7,031.0 4/22/2018 04:00 4/22/2018 05:00 and pump down @ 120 gpm= 772 psi, slow pumps to 1.5 bpm @400 strokes. Ball on seat @ 486 strokes. Pressure up to 2700 psi, observed set at 2400 psi. Pressure up to 4250 psi to release, pick up 6' and confirm release. Slack off T and confirm top of ZXP w/ dogs out, set down 15K. 4/22/2018 4/22/2018 0.50 COMPZ4 RWRID PRTS P Pressure to ZXP liner top packer to 7,031.0 7,031.0 05:00 05:30 3500 psi f/ 10 min on chart, good test. RID testing equipment. 4/22/2018 4/22/2018 0.50 COMPZ4 RWRID CRIH P POOH w/ pump spotting in 23 bbls of 7,031.0 6,989.0 05:30 06:00 Cl brine from top of ZXP to 6800' MD as per MI. Balance Cl brine w/ 733 stokes. 4/22/2018 4/22/2018 0.25 COMPZ4 RWRID OWFF P OWFF, static. 6,989.0 6,989.0 06:00 06:15 4/22/2018 4122/2018 0.25 COMPZ4 RWRID CIRC P Pump dry job and blow down. 6,989.0 6,989.0 06:15 06:30 4/22/2018 4/22/2018 3.50 COMPZ4 RWRID TRIP P POOH on elevators f/ 6989' MD to 50' 6,989.0 50.0 06:30 10:00 MD. P/U= 134K, S10= 116K. SIMOPS, mobilize Baker fishing BHA to rig floor and prep for whipstock run. 4122/2018 4/22/2018 0.50 COMPZ4 RWRID SHAH P UD Baker running tool and SLB 50.0 0.0 10:00 10:30 Slimpulse. 4/22/2018 4/2212018 0.50 COMPZ4 RWRID SHAH an 0.0 0.0 10:30 11:00 4122/2018 4122/2018 2.00 PROD5 WHPST BHAH hipstock/Milling BHA as per 0.0 294.0 11:00 13:00 T_::� M/U milling stand to MWD, ( 355 deg tool face offset) and back. Build Whipstock as Y and IN mill stand to whipstock as ker. 4/22/2018 4/2212018 4.50 PROD5 WHPST TRIP P RIH W/ L4 Whipstock F/ 29_4'T/6,896 294.0 6,895.0 13:00 17:30 MD. Shallow test MWD @ 1,715' MD, test good. 4/22/2018 4/22/2018 0.50 PR0D5 WHPST WASH P Tie in & orient T/ 22° L highside, @ 6,895.0 6,980.0 17:30 18:00 200 gpm, 1,104 psi, 14% FO. Wash F/ 6,895' T/ 6,980' PU- 132 & SO- 112k 4/22/2018 4/22/2018 0.75 PROD5 WHPST TPST RIH F/ 6,980' T/ 7,031'@ 220 gpm, 6,980.0 7,031.0 18:00 18:45 1,081 psi, PU- 134k, SO- 1112. Set whipstock @ 22° L, set down 10k to set anchor, PU 10k over to confirm set, set down 25k to shear bolt, & PU to confirm free PU- 132k & SO- 111 k 4/22/2018 4/23/2018 5.25 PROD5 WHPST MILL P Mill L4 window F/ 6,895 TI 6,903' MD 6,895.0 6,903.0 18:45 00:00 @ 250 gpm, 1333 psi, 80-100 rpm, 2- 3k WOB, PU- 138k, SO -117k, & ROT 119k 4/23/2018 4/23/2018 6.00 PRODS WHPST MILL P Mill L4 window F/ 6,903' TI 6,913' MD 6,903.0 6,913.0 00:00 06:00 @ 250 gpm, 1333 psi, 80-100 rpm, 2- 3k WOB, PU- 138k, SO- 117k, & ROT -119k 4123/2018 4/23/2018 6.00 PROD5 WHPST MILL P Mill L4 window FI 6,913' T/ 6,933' MD 6,913.0 6,933.0 06:00 12:00 @ 250 gpm, 1333 psi, 80-100 rpm, 2- 3k WOB, PU- 138k, SO- 117k, & ROT 119k Page 43154 Report Printed: 5/1612018 Uperations Summary (with Timelog DeNths) 11-1-103 • Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Shat oapui start Time End Time Dur(hr) Phase Mvity Cork Time PJA Opeafion 08) End Depth(AKB) 4/23/2018 4/2312018 1.00 PRODS REAM P Work mills through window @ drilling 6,933.0 6,840.0 12:00 13:00 rate 3X. Work millls w/ pumps off 2X. PU- 137k & SO -14k 4/23/2018 4/23/2018 1.00 PRODS CIRC P RecippipeF/ 6840' T16,745' MD @ 6,840.0 6,840.0 13:00 14:00 300 gpm, 1,717 psi, 20% FO, & total stks- 2601 4/23/2018 4/23/2018 0.75 PRODS FH FIT P RU for FIT. Performed 13.0 ppg equiv 6,840.0 6,840.0 14:00 14:45 @ 750 psi, 1 bbl pumped & 1 bbl back /23/2018 4123/2018 0.75 PRODS OWFF P OWFF for 30 min (well static), LD 6,840.0 6,840.0 14:45 15:30 single & pump slug 4/23/2018 4/2312018 4.25 PRODS TRIP P POOH on elevators F/ 6,840'T/ 158' 6,840.0 158.0 15:30 19:45 MD. Monitor fill via TT 4123/2018 4/23/2018 0.75 PRODS BHAH P PJSM, LD milling BHA per BHGE rep, 158.0 0.0 19:45 20:30 clean, & dear rig floor 4/23/2018 4/23/2018 0.50 PRODS WHPST WWWH P Wash wellhead & flush stack 0.0 0.0 20:30 21:00 4/23/2018 4/23/2018 1.25 PRODS WHPST BHAH P PJSM, PU 1.5" bent motor assy per 0.0 99.0 21:00 22:15 SLB rep 4/23/2018 4/24/2018 1.75 PRODS WHPST TRIP P TIH with motor assy F/ 99' T/ 4,697' 99.0 4,697.0 22:15 00:00 1 MD. Monitor dislpacement via TT. 4/24/2018 4/2412018 1.25 PRODS WHPST TRIP P Cont to RIH w/ motor BHA f/ 4697' MD 4,697.0 6,850.0 00:00 01:15 to 6922' MD 4/24/2018 4/2412018 0.50 PRODS WHPST TRIP P Establish circulation @ 230 gpm= 6,850.0 6,933.0 01:15 01:45 1500 psi, orient motor to 22L. Slack off though the window f/ 6895' MD to BOW @ 6908.7' MD. No issue while tripping though window. Cont to trip to bottom @ 6933' MD, 4/24/2018 4124/2018 4.25 PRODS DRILL DDRL P Drill ahead L4 6 3/4" Lateral w/ motor 6,933.0 7,066.0 01:45 06:00 f/ 6933'MD to 7066' MD, 3861' TVD. Pump @ 232 gpm= 1590 psi on, 1460 psi off w/ 17% FO. Rotate 80 rpm's w/ 6K Tq on, 41K Tq off, 22K WOB. P/U= 138K, S/O= 112K, ROT= 118K. ART= .78, AST= 2.06, ADT= 2,84 hrs, Bit hrs= 11.3, Total Jar hrs= 99.85 4/24/2018 4/24/2018 2.50 PRODS DRILL DDRL P Drill ahead L4 6 3/4" Lateral w/ motor 7,066.0 7,170.0 06:00 08:30 f/ 7066' MD to 7170' MD, 3843' TVD. Pump @ 232 gpm= 1508 psi on, 1480 psi off w/ 17% FO. Rotate 40 rpm's w/ 41K Tq on, 3K Tq off, 2-12K WOB. P/U= 138K, S/O= 112K, ROT= 118K. ART= 1.53, AST= .81, ADT= 2,34 Inns, Bit hrs= 13.64, Total Jar hrs= 102.19 SPR's @ 7170' MD, 3843' TVD, MW - 9.2 ppg MP#1: 20 spm- 340 psi, 30 spm- 500 psi MP#2: 20 spm- 340 psi, 30 spm- 500 psi 4/24/2018 4/24/2018 0.50 PRODS DRILL CIRC P CBU, pump @ 250 gpm= 1591 psi, 7,170.0 7,095.0 08:30 09:00 Rotate @ 80 rpms w/ 3-4K Tq, P/U= 140K, SIO= 114K, ROT= 118K. 4/2412018 4124/2018 1.00 PRODS DRILL CIRC P PUH witness no overpull across 7,095.0 6,814.0 09:00 10:00 window. UP WT = 114K. OWFF / pump slug and BD Top drive. Page 44/54 Report Printed: 5/1612018 G,,erations Summary (with Timelog D�,yths) IH -103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log am Dept, Stmt Time Entl Time Da(hr) phase Op Dena' A ty Dot% Time P -T -x Operatlon (f") End Depth ifKB) 4/24/2018 4/24/2018 2.50 PRODS DRILL TRIP P POOH on elevators from 6,814' to 6,814.0 630.0 10:00 12:30 630' MD monitoring disp via TT. UP WT = 114K. 4/24/2018 4/24/2018 1.00 PRODS DRILL BHAH P Lay down BHA # 23 as per SLMB 630.0 0.0 12:30 13:30 from 630' monitoring displacement via TT. 4/24/2018 4/24/2018 0.50 PRODS DRILL BHAH P Clean rig floor and prep to RBIH with 0.0 0.0 13:30 14:00 BHA #24. 4/24/2018 4/24/2018 0.50 PRODS DRILL W W WH P Flush stack at 900 GPM, 89 PSI with 0.0 0.0 14:00 14:30 38% F/O 60 RPM. BD TD. 4/24/2018 4/24/2018 0.50 PRODS DRILL SVRG P Service top drive and crown. 0.0 0.0 14:30 15:00 4/24/2018 4/24/2018 1.00 PRODS DRILL BHAH P Pick up BHA #24 L4 lateral As per 0.0 350.0 15:00 16:00 DD. to 305' MD monitor Disp via TT. 4/24/2018 4/24/2018 3.25 PRODS DRILL TRIP P Continue to RIH with BHA #24 from 350.0 6,920.0 16:00 19:15 350' MD - 6,920' MD. Shalow pulse test MWD @ 1,725' MD with 255 GPM @ 1,147 PSI DPP at 17% F/O. 138K UP WT 112K DWN WT. 4/24/2018 4/24/20181.50 PRODS DRILL DLOG P MADD PASS while RIH from 6,920' 6,920.0 7,170.0 19:15 20:45 MD to 7,170' MD @ 350 FPH max. 260 GPM @ 1,600 PSI DPP. 4/24/2018 4/25/2018 3.25 PRODS DRILL DDRL P DDRIL 63/4" hole from 7,170'MD 7,170.0 7,500.0 20:45 00:00 3,843' TVD - 7,500' MD 3,839' TVD. 260 GPM @ 1,600 PSI DPP, 18% F/O @100 RPM with 4-5K TQ. 2-1 OK WOB with ECD's at 10.3 PPG EMW. Off BTM 1,580 PSI. UP WT = 105K. DWN WT = 87K. ROT - 98K. 4K TQ. Max gas = 20 units ADT 2.39. Bit HRs 2.39. Jar his 104.58. SPR's @ 7,170' MD, 3,864' TVD with MW 9.2 PPG 20:40 MP1 - 20 SPM 300 PSI 30 SPM 480 PSI MP2 - 20 SPM 310 PSI 30 SPM 480 PSI 425/2018 4/25/2018 6.00 PRODS DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/ 7050' 7,500.0 8,011.0 00:00 06:00 MD to 8011, 3850' TVD. Pump @ 270 gpm= 1730 psi on, 1720 psi off w/ 18% FO. Rotate 100 rpm's w/ 5K Tq on, 4K Tq off, 2-1 OK WOB, ECD= 10.35 ppg EMW, Max gas= 68 P/U= 11 OK, S/0= 85K, ROT= 98K. ADT= 4.74 hrs, Bit hrs= 7.13, Total Jar hrs= 109.32 Page 45154 Report Printed: 5/1 612 01 8 Uverations Summary (with Timelog DtNths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log start Dept, SWn-nm End Time MW (hr) 6.00 Phase PROD5 Op Code DRILL Activity Code DDRL Tim P -T -x P Operation Drill ahead L4 6 3/4" Lateral f/ 8011' (flKB) 8,011.0 End Depth (WEI) 8,313.0 4/25/2018 06:00 4/25/2018 12:00 MD to 6313, 3851' TVD. Pump @ 270 gpm= 1785 psi on, 1776 psi off w/ 18% FO. Rotate 100-150 rpm's wl 5- 8K Tq on, 4K Tq off, 2-14K WOB, ECD= 10.41 ppg EMW, Max gas= 197 P/U= 112K, S/0= 85K, ROT= 100K. ADT= 5.61 hrs, Bit hrs= 12.29, Total Jar hrs= 114.48 SPR's @ 8092' MD, 3851' TVD, MW - 9.2 ppg MP#1: 20 spm- 380psi, 30 spm- 600 psi MP#2: 20 spm- 400 psi, 30 spm- 620 psi 4/25/2018 4125/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral 1/8313, 8,313.0 8,609.0 12:00 18:00 3851' TVD - 8,609' MD 3,856' TVD. Pump @ 270 gpm= 1838 psi on, 1832 psi off wl 18% FO. Rotate 90-150 rpm's w/ 4-6K Tq on, 4K Tq off, 3-1 OK WOB, ECD= 10.48 ppg EMW, Max gas= 23.5 P/U= 113K, S/0= 83K, ROT= 97K. ADT= 4.35 hrs, Bit hrs= 16.64, Total Jar hrs= 118.83 4/2512018 4/26/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 314" LalemI f/8,609' 8,609.0 8,888.0 18:00 00:00 MD 3,656' TVD - 8,888' MO 3,847' TVD. Pump @ 270 gpm= 1813 psi on, 1800 psi off w/ 18% FO. Rotate 60- 150 rpm's w/ 4-6K Tq on, 4K Tq off, 3- 15K WOB, ECD= 10.43 ppg EMW, Max gas= 19 PN= 116K, S10= 81 K, ROT= 96K. ADT= 4.52 hrs, Bit hrs= 21.16, Total Jar hrs= 123.35 SPR's @ 6850' MD, 3834' TVD, MW - 9.2 ppg 22:41hrs MP#1: 20 spm -400 psi, 30 spm -600 psi MP#2: 20 spm- 420 psi, 30 spm- 620 psi 4/26/2018 4/26/2018 6.00 PROD5 DRILL DDRL P Drill ahead L463/4"Lateral f/8,888' 8,888.0 9,354.0 00:00 06:00 MD to 9354' MD, 3821 TVD. Pump @ 270 gpm= 1943 psi on, 1930 psi off w/ 18% FO. Rotate 60-150 rpm's w/ 5 -6K Tq on, 5K Tq off, 3-15K WOB, ECD= 10.76 ppg EMW, Max gas= 32 PIU= 117K, S/0= 78K, ROT= 96K. ADT= 4.36 hrs, Bit hrs= 25.52, Total Jar hrs= 127.71 Page 46/54 ReportPrinted: 511612018 L,,erations Summary (with Timelog G.,jths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (lir) Phase Op Code Adrvily Code Time P-T-X Open Won swa Depm (tKB) End Depth (MKB) 4/26/2018 4/26/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f19354' 9,354.0 9,601.0 06:00 12:00 MD to 9601' MD, 3816 TVD. Pump @ 270 gpm= 1970 psi on, 1960 psi off w/ 18% FO. Rotate 60-150 rpm's w/ 2 -1 OK Tq on, 5-71K Tq off, 3-15K WOB, ECD= 10.85 ppg EMW, Max gas= 992 PIU= 121K, S/0= 78K, ROT= 97K. ADT= 4.47 hrs, Bit hrs= 29.99, Total Jar hrs= 131.68 SPR's @ 9421' MD, 3817' TVD, MW- 9.2+ ppg MP#1: 20 spm- 450psi, 30 spm- 650 psi MP#2: 20 spm- 440 psi, 30 spm- 640 psi 4/26/2018 4/26/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/9601' 9,601.0 9,895.0 12:00 18:00 MD, 3816 TVD - 9,895' MD 3,807' TVD. Pump @ 268 gpm= 2000 psi on, 1985 psi off w/ 19% FO. Rotate 90- 120 rpm's w/ 5-6K Tq on, 5-71K Tq off, 1.5-5K WOB, ECD= 10.85 ppg EMW, Max gas= 992 PIU= 120K, S/O= 77K, ROT= 97K. ADT= 4.51 hrs, Bit hrs= 34.5, Total Jar hrs= 136.19 4/26/2018 427/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/ 9,895' 9,895.0 9,972.0 18:00 00:00 MD 3,807' TVD - 9,972' MD 3,805' TVD. Pump @ 268 gpm= 1,907 psi on, 1900 psi off w/ 19% FO. Rotate 90-120 rpm's w/ 5-61K Tq on, 5-7K Tq off, 2-15K WOB, ECD= 10.73 ppg EMW, Max gas= 68 PIU= 120K, S/O= 77K, ROT= 97K. ADT= 4.62 hrs, Bit hrs= 39.12, Total Jar hrs= 140.81 4/27/2018 4/27/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/ 9972' 9,972.0 10,557.0 00:00 06:00 MD to 10557' MD', TVD= 3791'. Pump @ 268 gpm= 2100 psi on, 1986 psi off w/ 19% FO. Rotate 90-120 rpm's w/ 6-7K Tq on, 5K Tq off, 2-11 K WOB, ECD= 11.21 ppg EMW, Max gas= 35 P/U= 120K, S10= 72K, ROT= 95K. ADT= 4.78 hrs, Bit hrs= 43.90, Total Jar hrs= 145.59 Page 47154 ReportPrinted: 5116/2018 Uperations Summary (with Timelog DtNths) 11-1-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sten Depth sten Time End Time Der(hr) Phase op Code Activity Cede Time P-T-X Operation (ftKB) End Depth(ftl(B) 4/27/2018 4/27/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/ 10557' 10,557.0 11,038.0 06:00 12:00 MD to 11038' MD', TVD= 3796'. Pump @ 268 gpm= 2105 psi on, 2100 psi off w/ 19% FO. Rotate 120 rpm's w/ 6 -81K Tq on, 6.51K Tq off, 2-14K WOB, ECD= 11.09 ppg EMW, Max gas= 121 P/U= 127K, S/0= 66K, ROT= 98K. ADT=4.41 hrs, Bit hrs= 48.31, Total Jar hrs= 150.00 SPR's @ 10654' MD, 3790' TVD, MW - 9.3 ppg MP#1: 20 spm- 560psi, 30 spm- 780 psi MP#2: 20 spm- 580 psi, 30 spm- 800 psi 4/27/2018 4/27/2018 6.00 PROD5 DRILL DDRL P Drill ahead L463/4" Lateral f/11038' 11,038.0 11,605.0 12:00 18:00 MD', TVD= 3796'- 11,605' MD 3,849' TVD. Pump @ 267 gpm= 2198 psi on, 2100 psi off w/ 20% FO. Rotate 120 rpm's w/ 6-8K Tq on, 6.51K Tq off, 4-11 K WOB, ECD= 11.32 ppg EMW, Max gas= 42 P/U= 130K, S/O= 71 K, ROT= 102K. ADT=4.21 hrs, Bit hrs= 52.52, Total Jar hrs= 154.21 4/27/2018 4128/2018 6.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/11,605' 11,605.0 12,450.0 18:00 00:00 MD 3,849' TVD - 12,240' MD 3,823' TVD. Pump @ 268 gpm= 2350 psi on, 2340 psi off w/ 20% FO. Rotate 100 rpm's w/ 6-8K Tq on, 7.6K Tq off, 2K WOB, ECD= 11.45 ppg EMW, Max gas= 45 P/U= 140K, S/0= 56K, ROT= 102K. ADT=4.08 hrs, Bit hrs= 56.6, Total Jar hrs= 158.29 4/28/2018 4/28/2018 6.00 PROD5 DRILL DDRL P Drill. ahead L4 6 314" Lateral f/12450' 12,450.0 13,166.0 00:00 06:00 MD to 13166' MD', TVD= 3813'. Pump @ 268 gpm= 2345 psi on, 2340 psi off w/ 20% FO. Rotate 100 rpm's w/ 8.5K Tq on, 8K Tq off, 3K WOB, ECD= 10.04 ppg EMW, Max gas= 25 PN= 158K, S/0= N/A, ROT= 105K. ADT=4.12 hrs, Bit hrs= 60.72, Total Jar hrs= 162.00 i 4/28/2018 4/28/2018 1.50 PROD5 DRILL DDRL P Drill ahead L46 3/4" Lateral f/ 13166' 13,166.0 13,350.0 0600 07:30 MD to 13350' MD', TVD= 3812'. Pump @ 268 gpm= 2321 psi on, 2318 psi off w/20% FO. Rotate 100 rpm's w/ 8.5K Tq on, 81K Tq off, 3K WOB, ECD= 11.09 ppg EMW, Max gas= 35 P/U= 162K, We N/A, ROT= 108K. SPR's @ 13258' MD, 3813' TVD, MW - 9.2+ ppg MP#1: 20 spm- 500 psi, 30 spm- 750 psi MP#2: 20 spm- 490 psi, 30 spm- 740 psi Page 48154 ReportPrinted: 511612018 (.Nerations Summary (with Timelog D,,jths) IH -103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Stan Depth StartTime I EndTme Dur(hr) Phage op Code Adivty Coe Tins P -TA operation MKa) Ertl Depth (WS) 4/28/2018 4/28/2018 0.50 PROD5 DRILL SVRG P Service rig, grease top drive traction 13,350.0 13,350.0 07:30 08:00 motor. 428/2018 4/28/2018 4.00 PROD5 DRILL DDRL P Drill ahead L4 6 3/4" Lateral f/ 13350' 13,350.0 13,901.0 08:00 12:00 MD to 13901' MD', TVD= 3812'. Pump @ 268 gpm= 2366 psi on, 2363 psi off w/ 20% FO. Rotate 100 rpm's w/ 9K Tq on, 8K Tq off, 3K WOB, ECD= 10.41 ppg EMW, Max gas= 177 P/U= 164K, S/0= N/A, ROT= 116K. ADT=3.37 hrs, Bit hrs= 64.09, Total Jar hrs= 165.78 4/28/2018 4/28/2018 5.25 PRODS DRILL DDRL P Drill ahead 1-4 6 3/4" Lateral f/ 13901' 13,901.0 14,501.0 12:00 17:15 MD', TVD= 3812'- 14,501' MD 3,808' TVD. Pump @ 264 gpm= 2531 psi on, 2530 psi off w/ 19% FO. Rotate 100 rpm's w/ 9.5K Tq on, 8K Tq off, 1K WOB, ECD= 10.44 ppg EMW, Max gas= 145 P/U= 164K, S/0= N/A, ROT= 124K. ADT=3.37 hrs, Bit hrs= 67.37, Total Jar hrs= 165.78 4/28/2018 4/28/2018 0.75 PROD5 CASING CIRC P Circulate and condition mud from 14,501.0 14,501.0 17:15 18:00 14,500' MD - 14,451' MD. 264 GPM @ 2,505 PSI. 100 RPM 9-1 OK TO with 19% F/O. ECD = 11.44 PPG EMW. 4/28/2018 4/28/2018 2.50 PROD5 CASING CIRC P R/B on estand and continue to 14,501.0 14,447.0 18:00 20:30 circulate while rotating + recipricating from 14,447'- 14, 360' MD. 265 GPM @ 2,515 PSI DPP. 19% F/O, 100 RPM with SK TO. 11.36 ECD. Perform 580 BBL dump and dilute with total strokes pumped 10,700. MW in = 9.2 MW out =9.1. UP WT=168K. OWN WT = 50K. ROT= 114K. Take SPR's. SPR's @ 14,552' MD, 3808' ND, MW- 9.2+ ppg 2030 hr MP#1: 20 spm- 610 psi, 30 spm- 850 psi MP#2: 20 spm- 620 psi, 30 spm- 860 psi 428/2018 4/28/2018r3.00 PRODS CASING OWFF P OWFF 30 min. dropped 8". 14,447.0 14,447.0 20:30 21:00 4/28/2018 4/292018 PROD5 CASING BKRM P BKRM OOH from 14,552 MD - 13, 14,447.0 13,171.0 21:00 00:00 171'MD. 265 GPM 2,280 PSI DPP. 17% F/O. 110 RPM with 7K TO. ECD =10.96. UP WT=153K. OWN WT72K. 4/29/2018 4/29/2018 PROD5 CASING BKRM P BROOH f/ 13171' MD to 11000' MD, 13,171.0 11,000.0 0000 06:00 pump @ 268 gpm=1900 psi, rotate @ 100 rpm's w/ 6K Tq. Pull @ 700 fph, slow pulling speed to 500 fph thought mud stone/ fault area and over 8deg dog legs. ECD= 10.67. P/U= 125K, S/0= 69K. Page 49/54 ReportPrinted: 5116/2018 Operations Summary (with Timelog Dopths) IH -103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log span Depm Stat Tne End Time Dur(hr) Phase Op Code AcWity Code Time P -T -X Operafon (RKB) End NO (Me) 4/29/2018 4/29/2018 6.00 PROD5 CASING BKRM P BROOH U 11000' MD to 9140' MD, 11,000.0 9,140.0 06:00 12:00 pump @ 268 gpm=1805 psi, male @ 100 rpms w/ 5K Tq. Pull @ 700 fph, slow pulling speed to 500 fph thought over 8d eg dogs legs. ECD= 10.38. P/U= 120K, S/0= 80K. 4/29/2018 4129/2016 6.00 PROD5 CASING BKRM P BROOH (/9140' MD - 7,241' MD, 9,140.0 7,241.0 12:00 18:00 pump @ 268 gpm=1635 psi, roate @ 100 rpms w/ 4K Tq. Pull @ 700 fph, slow pulling speed to 500 fph thought over 8d eg dogs legs. ECD= 10.13. P/U= 120K, S/0= 80K. 4/29/2018 4129/2018 1.00 PROD5 CASING PMPO P Pump OOH from 7,241' MD - 6,765' 7,241.0 6,765.0 18:00 19:00 MD no overpull witnessed coming through window. 2 BPM @ 310 PSI with 6% F10. UP QT = 112K. DWN WT = 89K. 4/29/2018 4/29/2018 1.25 PROD5 CASING CIRC P Circulate 2X BU while recip / rotate 6,765.0 6,665.0 19:00 20:15 from 6.755' MD - 6,665' MD. UP WT = 107K DWN WT=92K. 268 GPM@ 1,640 PSI DPP. 60 RPM with 18% F/O. 3K TQ. 10.29 ECD. MWI=9.2 MWO = 9.2 PPG. 4/29/2018 4/29/2018 0.25 PROD5 CASING OWFF P OWFF. sattic. 6,665.0 6,665.0 20:15 20:30 4/29/2018 4/30/2018 3.50 PROD5 CASING PULD P Pump dry fob 10.8# POOH ID singles 6,665.0 3,536.0 20:30 00:00 from 6,665' MD - 3,536' MD. Monitor Disp via TT. UP WT = 93K DWN WT = 86K. 4/30/2018 4/30/2018 2.50 PROD5 CASING PULD P Continue POOH with L4 drilling string 3,536.0 305.0 00:00 02:30 to BHA depth. Monitor disp via TT. 4/3012018 4/30/2018 1.00 PROD5 CASING BHAH P LD BHA #24 from 305' as per DD. 305.0 0.0 02:30 03:30 Monitor BHA via TT. Pictures on S drive. 4/30/2018 4/30/2018 0.50 PR0D5 CASING SHAH P Clean dg floor and prep for whipstock 0.0 0.0 03:30 04:00 retrival BHA. 4/30/2018 4/30/2018 0.75 COMPZ5 FISH BHAH P MU whipstock retrieval BHA as per 0.0 158.0 04:00 04:45 Baker fishing hand to 158' MD. Scribe MWD, and monitor disp via TT. 4/30/20184/3012018 1.25 COMPZ5 FISH TRIP P Trip in hole monitoring disp via TT. 158.0 2,057.0 04:45 06:00 from 158'-2000' prep for shallow hole test. 4/30/2018 4/30/2018 3.50 COMPZ5 FISH TRIP P Contine to trip in hole from 2,057' - 2,057.0 6,840.0 06:00 09:30 6,840' MD. UP WT= 138K. DWN WT = 115K. Monitor disp via TT. 4/30/2018 4/30/2018 0.50 COMPZ5 FISH FISH P Wash down from 6,840' MD to 6,907' 6,840.0 7,031.0 09:30 10:00 MD. 205 GPM @ 1600-2100 PSI DPP. F/O = 16%. Orient tool to 22L wash out slot as per BOT rep. UP WT = 133k DWN WT = 112K. Roo] into slot and set down 5K. PU 60K over. Then cont to PU to 220K - 85K over safety disconnect. UP WT = 140K - 71K over WT. 4/30/2018 4130/2018 0.50 COMPZ5 FISH PULD P POOH from 7,031' MD to 6,935' MD. 7,031.0 6,935.0 10:00 10:30 RIB stand and lay down single. Page 50154 Report Printed: 5116/2018 Operations Summary (with Timelog Dtwpths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth Start Tone EMTime Dur Mr) Ptiess Op Code Activity Code Time P -T -X Operation (ftKB) End Deph(ftKB) 4/30/2018 4/30/2018 1.50 COMPZ5 FISH CIRC P circulate 2X bottoms up at 211 GPM 6,935.0 6,935.0 10:30 12:00 915 PSI DPP. 13%F/0. Monitor bottoms up for solids and possible gas. UP WT = 140K. DWN WT = 87K. 4/30/2018 4/3012018 0.50 COMPZ5 FISH OWFF P Blow down top drive and monitor well 6,935.0 6,935.0 12:00 12:30 1 for 30 min. 4/30/2018 4/30/2018 5.50 COMPZ5 FISH TRIP P POOH from 6935' MD to 235' MD to 6,935.0 235.0 12:30 18:00 retrieve whipstock. Pumped slug and installed wiper rubber. Monitor well pulling speeds due to swabbing. 4/30/2018 4/30/2018 1.25 COMPZ5 FISH BHAH P Lay down whipstock and fishing 235.0 0.0 18:00 19:15 assym as per BOT rep. Pictures taken and installed on S drive. 4/30/2018 4/30/2018 0.50 COMPZ5 FISH RURD P Clean rig floor from drilling mud and 0.0 0.0 19:15 19:45 debris. 4/30/2018 4130/2018 1.25 COMPZ5 CASING RURD P Rig up to run liner and verify pipe in 0.0 0.0 19:45 21:00 shed. Mobilize cross overs to dg floor and GBR. Hold prejob. 4/30/2018 51112018 3.00 COMPZ5 CASING PUTS P RIH with 4 1/2" 12.6# L-80 IBT/TXP L4 0.0 2,577.0 21:00 00:00 lower completion as per plan to 2,577' MD. TQ IBT connections to 4.51K FT/LB. TXP to 71K FT/LB. install 6.125 cent as per plan. Monitor disp via TT. UP WT=70K. DEN WT=68K. 5/1/2018 5/1/2018 5.50 COMPZ5 CASING PUTB P Continue to RIH with L4 4 1/2" 12.6# 2,577.0 7,517.0 00:00 05:30 liner from 2,577' MD to 7,517' MD. TQ all IBT connections to 4.5K FT/LBS. TXP conections to 7K FT/LBS. Install 6.125" cent as per detail while monitoring disp via TT. UP WT = 94K DWN WT= 72K. Total centrilozers installed = 184 (181 installed at rig site 3 installed by venders) / Stop rings = 6. 5/1/2018 5/1/2018 0.50 COMPZ5 CASING SRVY P MtU hook hanger assym / slim pulse 7,517.0 7,517.0 05:30 06:00 and scrib same. 5/1/2018 5/1/2018 1.75 COMPZ5 CASING RUNL P Continue to RIH with 4" DP pushing 7,517.0 8,970.0 06:00 07:45 L4 liner 4 1/2" 12.6# L-80 IBT/TXP from 7,517'-8,970 MD. Monitor disp via TT. UP WT=96K DWN WT=72 5/1/2018 5/1/2018 0.75 COMPZ5 CASING DHEQ P Shallow hole test MWD. @ 8,970' MD 8,970.0 8,970.0 07:45 08:30 221 GPM @ 450 PSI DPP 12% F/0. 285 units gas in returns. test good. 5/1/2018 5/1/2018 5.00 COMPZ5 CASING RUNL P Continue to RIH with 4" DP pushing 8,970.0 14,325.0 08:30 13:30 12.6# L-80 IBT/TXP L4 liner from 8,970' - 14,342' MD. Monitor disp via TT. UP WT=121 k. DWN WT=76K. top off DP every len stands. 5/1/2018 5/1/2018 2.50 COMPZ5 CASING HOSO P Circulate to orient tool lace to 180 deg 14,325.0 14,340.0 13:30 16:00 out. Work pipe from 14,325' to 14,340' MD PU stand 74 and roll tool face to 32 deg L. 127 GPM @ 720 PSI DPP. 11% F10. cycle pipe to gain proper tool face for setting hook hanger at 6,913.3' MD. Page 51/54 ReportPrinted: 6/16/2018 Overations Summary (with Timelog Nigths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log sren Dees, Sran Tlme End Time Our (hr) Phase Op Code Aclift Code Time P -T -X Operation (MB) Ertl Depth (flKm 5/1/2018 5/112018 1.25 COMPZ5 EASING CIRC P Drop ball and circulate @ 3 BPM 680 14,340.0 6,913.3 16:00 17:15 PSI DPP. slow down to 1 BPM 300 PSI to 517 STKS. Ball on seat and shear at 2,900 PSI. PU 150K proving hanger not released. Drop emergency ball and circ down at 3 BPM 395 PSI DPP. slow pumps down to 1 BPM 263 PSI with ball on seat at 474 stks and pressure up to 3,500 PSI. Hold pressure then pick up to confirm hanger released. UP WT = 138. Good to go. 5/1/2018 5/1/2018 COMPZ5 WELLPR PULD P Lay down stands 73174 via mouse 6,913.3 6,843.0 17:15 17:30 hole and blow down top drive. 5/1/2018 5/1/2018 COMPZ5 WELLPR OWFF P Observe well for flow. Static 6,843.0 6,843.0 17:30 17:45 5/1/2018 5/1/2018 F4.50 COMPZ5 WELLPR TRIP P POOHform6,843'MDto100'MD. 6,8430 100.0 17:45 22:15 Monitor hole via TT. 511/2018 5/212018 COMPZ5 WELLPR SHAH P Lay down liner running tools as per 100.0 0.0 22:15 00:00 BOT rep. Monitor well and clean dg floor. RU to run ZXP / LEM. Ship tools to rig floor. 5/2/2018 5/2/2018 1.75 COMPZ5 RWRID PUTS P Inspect and make up ZXP / LEM 0.0 308.0 00:00 01:45 assembly to 308' MD. 5/2/2018 512/2018 1.25 COMPZ5 RWRID RCST P RIH with LEM assembly on DP from 308.0 2,204.0 01:45 03:00 308'. MD - 2,204' MD monitoring disp via TT. 5/2/2018 5/2/2018 0.50 COMPZ5 WWWRID DHEQ P Shallow hole test MWD. Passed. 2,204.0 2,204.0 03:00 03:30 Blow down top drive. 5/2/2018 5/2/2018 3.75 COMPZ5 RWRID RCST P Continue running in hole with LEM / 2,204.0 6,897.0 03:30 07:15 ZXP from 2,204' MD to 6,897' MD filling pipe every 20 stands. 113K UP WT DWN WT = 133K. 5/2/2018 5/2/2018 0.75 COMPZ5 RWRID CIRC P Circulate to orient BHA TF 120 GPM 6,897.0 6,897.0 07:15 08:00 @ 685 PSI DPP, NO = 10%. UP WT = 114K OWN W T= 133K. 5/2/2018 5/2/2018 2.25 COMPZ5 RWRID PACK P Pick up single and circulate at 121 6,897.0 7,062.7 08:00 10:15 GPM 680 PSI DPP, 10% F/O, UP WT = 114K. OWN WT = 133K. Wash down to orient tool face to 52DEG L. latch and set down 1 OK. Pick up to verify latch x2. set down total of 15K drop 1.625" ball and circulate at 3 BPM 175 PSI DPP, Ball on seat at 476 stks. Lel LTP at 2,641 PSI and continue to pressure up to 3,500 PSI for 10 min. Good test. Bleed off then PU to 138K UP WT, 118K OWN WT. rotate 20 RPM to 4K TQ then slack off to 75K and tag liner top packer with 3K. Set dog sub. UP WT = 134K. laydown stand 72 in mouse hole. 5/2/2018 5/2/2018 0.25 COMPZ5 RWRID SFTY P Pre -job safety meeting for circulation 7,062.7 6,754.0 10:15 10:30 displacement to 9.4 BBG brine. Page 52154 ReportPrinted: 5116120181 Operations Summary (with Timelog DLvths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Siert Depth EM Time Dur(hr) Mase Op Code Activity Code Time P -T -X Operation (flKB) End Depth (tl(B) 5/2/2018 1.25 COMPZ5 RWRID DISP P Displace well over to 9.4 PPG brine 6,754.0 6,684.0 11:45 while reciprocating from 6,684'MD - 6,754'MD. pump 20 BBL spacer then r512/2018 brine. 510 GPM@ 3,375 PSI DPP. Final circulation pressure = 3,281 PSI. F/O%=28. UP WT=123K. OWN WT = 116K. pumped total of 4,358 stks. 5/2/2018 0.25 COMPZ5 RWRID OWFF P Observe well for flow. 6,684.0 6,684.0 11:45 12:00 5/212018 5/2/2018 10.25 COMPZ5 RWRID PULD P POOH sideways with 4" DP from 6,684.0 308.0 12:00 22:15 6,684' MD to surface while removing super sliders. UP WT=123K, OWN WT=116K. Monitor disp via TT. 5/2/2018 5/3/2018 1.75 C0MPZ5 RWRID SHAH P LD ZXP running tools and MWD as 308.0 0.0 22:15 00:00 per service reps. Clear and clean rig floor of all BKR tools, flush stack, BD top drive and pull wear bushing. 5/3/2018 5/3/2018 2.50 COMPZ5 RPCOMP RURD P Rig up to run tubing. Bring spooler to 0.0 0.0 00:00 02:30 rig floor and reassemble same. 250 full clamps along with 12 half clamps staged on rig floor. load pipeshed with upper completion tubing simops S&C 102' drill line. 5/3/2018 5/3/2018 1.25 COMPZ5 RPCOMP PUTB P PJSM & RIH with 4 1/2" 12.6# L-80 0.0 92.0 02:30 03:45 TXP tubing to 92' MD. Connect pressure gauge tech wire and test. 5/3/2018 5/3/2018 9.25 COMPZ5 RPCOMP PUTS P Continue to RIH with 4 1/2" 12.6# TXP 92.0 6,795.0 03:45 13:00 tubing from 92'to 6,795' MD To all connections to 7K FT/LBS. Installing Cannon clamps on all Connections with monitoring disp via TT. UP WT = 93K DWN WT=77K. 5/3/2018 5/3/2018 0.50 COMPZ5 RPCOMP HOSO P Make up head pin on joint 162 and 6,795.0 6,808.9 13:00 13:30 circulate down to locate SBR. 1 BPM 17 PSI. Observe pressure increase and lost returns 32.5' in on joint 162. 6,791' MD. Remove head pin and PU joint 163. No Go at 6808.9'MD 5/3/2018 5/3/2018 2.50 COMPZ5 RPCOMP HOSO P Space out 4 1F292 tubing with 6,808.9 6,806.6 13:30 16:00 X/O's and install hanger / landing joint. Install head pin on landing joint. Total clamps run 164 full 19 half clamps. Final gauge reading 1,841 psi at 76 Deg. Bottom of mule shoe at 6806.06 5/3/2018 5/3/2018 0.25 COMPZ5 RPCOMP SFTY P PJSM spot Cl brine. 6,806.6 6,806.6 16:00 16:15 5/3/2018 5/3/2018 1.00 COMPZ5 RPCOMP CRIH P Spot Cl brine as per plan. Circulate 6,806.6 6,806.6 16:15 17:15 38 BBLS of Cl brine at 4 BPM 175 PSI DPP, 10% F/O. Sim ops LD GBR pipe handeling equipment. Strip tech wire and run through hanger. 5/3/2018 5/3/2018 1.50 COMPZ5 RPCOMP THGR P Drain stack and land hanger. RILDS - 6,806.6 6,806.6 17:15 18:45 test upper / lower sealsto 5K witnessed by Rock. RD tech wire sheave LD GBR elevators. Page 53154 ReportPrinted: 511612018 Operations Summary (with Timelog Depths) 1H-103 Rig: DOYON 142 Job: DRILLING ORIGINAL Time Log Start Depth stall Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (111<13) End Depth (ftKB) 5/3/2018 5/3/2018 2.25 COMPZ5 RPCOMP PRTS P Pressure test IA to 1000 PSI for 5 min. 6,806.6 6,806.6 1845 21:00 Good, 1 318" ball and rod with 2 1/4" rollers (four) top slot missing roller and and a 1 3/8" FN on top. DAL 8.72'. RU head pin and test tubing to 3,500 PSI for 30 min (PASSED). Bleed tubing to 2,000 PSI and test IA to 3,500 PSI for 30 min (PASSED). bleed of tubing and sheared out SOV as planned. 5/3/2018 5/3/2018 1.00 COMPZ5 WHDBOP MPSP P RD head pin and BD lines. Set HP 6,806.6 0.0 21:00 22:00 BPV as per Vetco rep. Test BPV from below to 2,500 PSI. 5/3/2018 5/4/2018 2.00 COMPZ5 WHDBOP NUND P BD chokes, Kill line, hole fill &jet lines. 0.0 0.0 2200 00:00 1 PUI riser. Prep to pull BOPE. 5/4/2018 5/4/2018 6.00 COMPZ5 WHDBOP NUND P ND BOPE. NU Tree and test same. 0.0 0.0 00:00 06:00 Witness pressure test of body, hanger seals, voids, Termination of DH pressure gauge, test tree to 250/5000 PSI passed. RD test equipment and pull BPV. Rig up LR for freeze protect. Test line to tank w/ air. Test Little Red lines to 3500 psi. 5/4/2018 5/4/2018 1.50 COMPZ5 WHDBOP FRZP P Little Red pump diesel @ 2.5 bpm w/ 0.0 0.0 06:00 07:30 25 bbis away 400 psi, 50 away =500 psi, 75 bbls away 500 psi, 100 bbls away 350 psi, 111 bbls away =200 psi. Blow down lines and rig down. Pumping through Cameo KBMG 4- 112" x 1" GLM w/ SOV @ 2677.62'. Surface to surface volume 111 bbls. 5/4/2018 5/4/2018 COMPZ5 WHDBOP MPSP P Mobilize lubricator to the floor. Install 0.0 0.0 07:30 08:45 lubricator on wellhead. Test to 1500 psi -good. Set BPV, rig down lubricator. 5/4/2018 5/4/2018 F1.25 DEMOB MOVE RURD P Install jewlery-Guages on Voice 0.0 0.0 08:45 10:00 horizontal tree. Secure well. Final tubing pressure 200 psi, 7" x 4- 1/2" IA = 100 psi, 10-314" x 7" OA = 0 psi. Clean and clear cellar. 5/4/2018 5/4/2018 2.00 DEMOB MOVE MOB P Prepare to move f/ 1 H-103 to 1 H-117. 0.0 0.0 1000 12:00 Clean and clear cellar. Move rockwasher and pipe shed. Rig released @ 1200 hrs 5/4/2018 for move fl 1H-103 to iH-117. Page 54154 ReportPrinted: 5/1612018 Cement Detail Report a 1H-103 String: Conductor Cement Job: DRILLING ORIGINAL, 3/121201811:00 Cement Details DescriptionCementing Start Date Cementing End Date Wellbore Name 111-1-103 Conductor Cement 1111 /2016 06:30 11/1/2016 08:30 Comment 10 yards (5.5 MTlaggregate ration of 564!3520 per yard. Cement Stages Stage # 1 Description Objective Top Depth (RKB) Bottom Depth (RKB) Full Return? Vol Cement... Top Plug? stm Plug? Conductor Cement 39.0 119.0 No No No Q Pump Init (bbUm... O Pum ump Avg (bbU... P Pump Final (psi) P Plug Bump (Psi) Recip? Stroke (R) I Rotated? I Pipe RPM (rpm) Na No Tagged Depth (RKB) ag MethodDepth Plug Drilled Out To (RKB) I Drill Out Diameter (in) 1,Ln cement poured into backside by AFC. CMT/aggregate ration of 564/3520 per yard. Cement Fluids & Additives Fluid Fl Fluid Description Estimated Top (RKB) Est Bnn (RKB) Amount (sacks) Class Volume Pumped (bDl) ... Free Water (%) Density (Ib/gal) Plastic Viscosity (cP) Thickening Time (hr): CmprStr t (psi) Additives Add :-. TYPe Concentration Conc Unit label Page 111 ReportPrinted: 6/301201 8 NADConversion Kuparuk River Unit Kuparuk 1H Pad IH -103L1 1H -103L1 ConocoPhillips Definitive Survey Report 31 May, 2018 Final Definitive Survey Verified and Signed -off AN targets and/or well position objectives have been achieved. M Yes ❑ No 1 have checked to the best o/ my ability that the following data is correct: 17 Surface Coordinates R Declination & Convergence O GRS Survey Corrections [2] Survey Tool Codes Brandon Temrt��le Digitallysigned by8randon Temple SLBIE D M Date: 2018.06.010335:37-08'00' Kelsey Shumway orimr+v-lM�=rA�'M' Client Representative P Date. 6/1/2018 ConocoPhillips I ConocoPhiilips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-103 Project: Kuparuk River Unit TVD Reference: 1H-103 actual @ 93.03usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 111-103 actual @ 93.03usft (Doyon 142) Well: 1H-103 North Reference: True Wellbore: 11H-1031-1 Survey Calculation Method: Minimum Curvature - Design: 11H-1031-1 Database: OAKEDMP2 Iroject Kuparuk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level iso Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor Won 1H-103 Date Well Position +N/S 0.00 usft Northing: 5,980,722.55 usft ' Latitude: 70' 21'29.220 N +E/ -W 0.00 usft Easting: 549,573.20 usft Longitude: 149" 35' 50.536 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: . 54.10 usft Wellbore 1H-1031-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ('1 11) (1171 BGGM2017 4/1/2018 17.18 80.93 57,473 Design 1H-10311 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL The On Depth: 7,611.00 Vertical Section: Depth From (TVD) -NIS +E1 -W Direction Gymdata cont.drillpipe mis (usft) (usft) (usft) (') MWD+IFR-AK-CAZ-SC 38.93 0.00 0.00 0.00 nay Program Date From To Map Vertical MD (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 89.19 275.81 IH -103 Srvy 3-GD_GYD-CT-DMS(1H-1 GYD-CT-DMS Gymdata cont.drillpipe mis 3/14/2018 1:53! 301.66 1,798.351H-103 Srvy 2-SLB_MWD+GMAG(111- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/13/2018 1:58: 1,896.33 7,611.001H-103 Srvy 4- SLB _MWD+GMAG(1 H- MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/14/2018 8:47: 7,624.65 7,745.951H-1031-1 Srvy 2 -SLB -MWD -INC Only MWD-INC_ONLY MWD-INC_ONLY_FILLER 3/29/2018 8:58: 7,840.38 15,042.891H-1031.1 Srvy 3 - SLB-MWD+GMAG (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3/29/2018 8:58: - Survey 5/9112018 1:49:22PM Page 2 COMPASS 5000.14 BuBd 85 Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section Nam r) 11 (usft) (usft) (usft) (usft) (111 (fq r/1001 (ft) Survey Tod Name 38.93 000 0.00 38.93 54.10 0.00 0.00 5,980,722.55 549,573.20 0.00 0.00 UNDEFINED 69.19 0.03 118.71 69.19 5.84 -0.01 0.01 5,980,722.54 549,573.21 0.06 -0.01 GYD-CT-DMS(1) 182.05 0.28 112.94 182.05 89.2 -0.11 0.24 5,980,722.45 549,573.44 0.27 411 GYD-CT-DMS(1) 275.81 1.23 128.33 275.80 182.77 -0.82 1.24 5,980,721.74 549,574.45 1.03 -0.82 GYD-CT-DMS(1) 301.66 1.85 128.35 301.64 208.61 -1.25 1.79 5,980,721.31 549,575.00 2.40 -1.25 MWD+IFR-AK-CAZ-SC (2) 394.71 3.16 128.04 394.60 301.57 5.76 4.99 5,980,718.82 549,578.21 1.41 5.76 MWD+IFR-AK-CAZ-SC (2) 486.33 5.02 128.69 485.98 392.95 -7.83 10.10 5,980,714.79 549,583.35 2.03 -7.83 MWD+IFR-AK-CAZ-SC (2) 578.99 7.33 128.93 578.10 485.07 -14.07 17.87 5,980,708.60 549,591.16 2.49 -14.07 MWD+IFR-AK-CAZSC (2) 672.22 9.71 128.92 670.29 577.26 -22.75 28.61 5,980,699.99 549,601.96 2.55 -22.75 MWD+IFR-AK-CAZSC(2) 766.94 12.24 129.71 763.27 670.24 54.19 42.55 5,980,688.65 549,615.97 2.68 -34.19 MWD+IFR-AK-CAZSC(2) 5/9112018 1:49:22PM Page 2 COMPASS 5000.14 BuBd 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-103 Project: Kupamk River Unit TVD Reference: 1H-103 actual (d1 93.03usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: 1H-103 actual @ 93.03usft (Doyon 142) Well: 1H-103 North Reference: True Wellbore: 1H-103LI Survey Calculation Method: Minimum Curvature Design: 1H-1031-7 Database: OAKEDMP2 Survey 57312018 1.49:22PM Page 3 COMPASS 5000.14 Build 85 Map Map Vertical MD Inc AN TVD TVDSS +WS +FJ -W Northing Besting DLS Section (usft) 0 (') (usft) Well) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 861.51 13.04 131.53 855.55 762.52 47.67 58.25 5,980,675.27 549,631.76 0.94 47.67 MWD+IFR-AK-CAZSC (2) 955.53 17.86 12898 946.15 853.12 -63.60 77.55 5,980,659.47 549,651.16 5.22 63.60 MWD+IFR-AK-CAZSC(2) 1,050.05 20.61 125.58 1,035.39 942.36 62.22 102.50 5,980,641.01 549,676.23 3.04 52.22 MWD+IFR-AK-CAZSC(2) 1,144.29 20.32 125.40 1,123.68 1,030.65 -101.35 129.33 5,980,622.06 549,703.18 0.31 -101.35 MWD+IFR-AK-CAZSC(2) 1,238.39 23.17 124.57 1,211.07 1,118.04 -121.33 157.89 5,980,602.28 549,731.88 3.05 -121.33 MWD+IFR-AK-CAZ-SC (2) 1,332.05 26.31 122.22 1,296.13 1,203.10 -142.85 190.63 5,980,580.97 549,764.76 3.51 -142.85 MWD+1FR-AK-CAZ-SC(2) 1,428.24 28.43 120.62 1,381.55 1,288.52 -165.88 228.38 5,980,558.20 549,602.65 2.33 -165.88 MWD+IFR-AK-CAZSC(2) 1,522.26 29.22 120.27 1,463.92 1,370.89 -188.85 267.4(1 5,980,535.49 549,841.88 0.86 -188.85 MWD+IFR-AK-CAZSC(2) 1.616.26 29.50 119.22 1,545.84 1,452.81 -211.72 30747 5,980,512.89 549,882.04 0.62 -211.72 MWD+IFR-AK-CAZSC(2) 1,7W.82 29.66 118.03 1,627.21 1,534.18 -233.84 348.01 5,980,491.04 549,922.72 0.65 -233.84 MWD+IFR-AK-CAZSC (2) 1,798.35 30.48 117.03 1,703.82 1,610.79 -254.34 387.35 5,980,470.81 549,962.19 1.09 -254.34 MWD+IFR-AK-CAZSC(2) 1,896.33 34.50 116.06 1.786.45 1,693.42 -277.83 434.43 5,980,447.63 550,009.42 4.14 -277.83 MMAFR-AK-CAZSC (3) 1,990.18 38.16 117.31 1,862.05 1,769.02 502.82 484.09 5,980,422.97 550,059.23 3.98 502.82 MWD+11FR-0K-CAZSC(3) 2,084.67 41.81 118.51 1,934.44 1,841.41 331.25 537.72 5,980,394.89 550,113.05 3.95 -331.25 MWD+IFR-AK-CAZ-SC (3) 2,160.23 45.42 119.98 2,003.61 1,910.58 363.48 595.21 5,980,353.06 550,170.74 3.92 -353.48 MWD+IFR-AK-CAZ-SC(3) 2,274.85 49.08 120.99 2,067.83 1,974.80 -398.73 655.80 5,980,328.20 550,230.83 395 -398.73 MWD+IFR-AK-CAZ-SC(3) 2,369.36 52.99 122.22 2,127.25 2,034.22 437.25 717.62 5,98,290.10 550,293.63 4.26 437.25 MWD+IFR-AK-CAZSC(3) 2,464.04 55.04 121.95 2,182.88 2,089.85 477.94 782.53 5,980,249.84 560,358.80 2.18 477.94 MWD+IFR-AK-CAZSC(3) 2,558.01 55.28 122.45 2,236.56 2,143.53 519.04 847.80 5,980,209.18 550,424.33 0.51 519.04 MWD+IFR-AK-CAZSC(3) 2,653.33 55.38 122.68 2,290.79 2,197.76 561.24 913.87 5,980,167.42 650,490.67 0.22 561.24 MWD+IFR-AK-CAZSC (3) 2,747.45 55.46 121.75 2,344.21 2,251.18 602.55 979.43 5,98,126.55 550,556.50 0.82 602.55 MWD+IFR-AK-CAZ-SC (3) 2,842.32 55.42 121.98 2,398.02 2,304.99 643.80 1,045.78 5,980,085.75 550,623.12 0.20 643.80 MWD+IFR-AK-CAZ-SC (3) 2,936.63 55.56 122.62 2,451.45 2,358.42 685.32 1,111.47 5,98,044.67 550,689.07 0.58 685.32 MWD+IFR-AK-CAZ-SC(3) 3,031.32 55.51 122.11 2,505.04 2,412.01 -727.11 1.177.41 5,98,003.32 550,755.28 0.45 -727.11 MWDAFR-AK-CAZSC (3) 3,126.00 55.46 122.47 2,558.69 2,435.66 -768.79 1,243.36 5,979,962.08 550,821.50 0.32 -768.79 MWD+1FR-AK-CAZSC(3) 3,220.30 55.42 121.82 2,612.18 2,519.15 610.11 1,309.11 5,979,921.20 550,867.52 0.57 610.11 MWD+IFR-AK-CAZSC(3) 3,315.04 55.37 121.83 2,665.99 2,572.8(1 551.23 1,375.37 5,979,880.53 5W,954.04 0.05 651.23 MWD+IFR-AK-CAZSC(3) 3,409.69 56.27 120.87 2,719.16 2,626.13 69196 1,442.24 5,979,840.24 551,021.17 1.27 591.96 MWD+IFR-AK-CAZSC(3) 3,503.96 58.21 119.09 2,770.17 2,677.14 531.56 1,510.91 5,979,801.10 551,090.09 2.60 531.56 MWD+IFR-AK-CAZSC (3) 3,598.78 59.71 116.46 2,819.07 2,726.04 -969.40 1,582.78 5,97,763.74 551,162.21 2.85 -%9.40 MWDAFR-AK-CAZ-SC(3) 3,693.65 60.42 112.39 2,866.43 2,773.40 -1,OD137 1,657.62 5,979,730.26 551,237.26 3.79 -1,003.37 MWD+IFR-AK-CAZ-SC(3) 3,788.28 62.66 109.37 2,911.53 2,818.50 -1,033.00 1,735.34 5,979,701.16 551,315.17 3.67 -1,033.00 MWD+IFR-AK-CAZSC (3) 3,883.85 65.24 106.29 2,953.50 2,860.47 -1,05926 1,817.07 5,979,675.44 551,397.06 3.% -1,059.26 MWD+1FR-AK-CAZSC(3) 3,978.46 67.37 103.22 2,991.53 2,898.50 -1,081.30 1,900.83 5,979,653.96 55tA80.80 3.73 -1,081.30 MWD+IFR-AK-CAZSC(3) 4,073.35 68.88 101.17 3,026.88 2,933.85 -1,099.89 1,986.89 5,979,635.94 551,567.14 2.56 -1,099.69 MWDHFR-AK-CAZSC(3) 4,167.81 71.15 100.95 3,059.17 2,966.14 -1,116.92 2,074.01 5,979,619.49 551,654.36 2.41 -1,116.92 MWD+IFR.AK-CAZSC(3) 4,262.61 71.60 100.68 3,089.44 2,996.41 -1,133.77 2,162.25 5,979,603.22 551,742.70 0.55 -1,133.77 MWD+IFR.AK-CA7-SC(3) 4,357.17 71.46 101.22 3,119.40 3,026.37 -1,150.81 2,250.31 5,979,586.77 551,830.85 0.56 -1,150.81 MWD+IFR-AK-CAZ-SC(3) 4,451.69 71.40 101.04 3,149.50 3,056.47 -1,168.11 2,338.22 5,979,570.80 551,918.87 0.19 -1,168.11 MWD+IFR-AK-CAZ-SC(3) 4,545.99 71.44 101.37 3,179.55 3,086.52 -1,185.47 2,425.90 5,979,553.27 552,006.66 0.33 4,185.47 MWD+IFR-AK-CAZSC(3) 57312018 1.49:22PM Page 3 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 1H-103 Project: Kuparuk River Unit TVD Reference: 1H-103 actual @ 93.03usft (Doyon 142) Sib: Kuparuk 1 H Pad MD Reference: 1H-103 actual @ 93.03usft (Doyon 142) Well: 1H-103 North Reference: True Wellbore: 1 H-1030 Survey Calculation Method: Minimum Curvature Design: 1 H-1 030 Database: OAKEDMP2 Survey 51312018 1:49:22PM Page 4 COMPASS 5000.14 Build 85 Map Map vertical MD Inc Aid TVD TVDSS +N/ -S +EI -W Northing Easting DLS Section Wan) 1*1 C) Will Wait) (usft) Will (ft) (ft) (-1100') (ft) Survey Tool Name 4,639.89 71.39 101.36 3,209.48 3,116.45 -1,203.01 2,513.16 5,979,536,31 552,094.02 0.05 -1,203.01 MWD+IFR-AK-CAZSC(3) 4,734.64 71.75 101.29 3,239.43 3,146.40 -1,220.67 2,601.30 5,979,519.24 552,182.27 0.39 -1,220.67 MV4)+IFR-AK-CAZSC(3) 4,829.67 71.71 102.01 3,269.22 3,176.19 -1,238.89 2,689.66 5,979,501.61 552,270.76 0.72 -1,238.89 MWD+IFR-AK-CAZSC(3) 4,924.04 71.80 102.22 3,298.77 3,205.74 -1,257.70 2,777.31 5,979,483.38 552,358.50 0.23 -1,257.70 MWD+IFR-AK-CAZ.SC(3) 5,019.23 71.82 102.64 3,328.48 3,235.45 -1,277.16 2,865.62 5,979,464.50 552,446.93 0.42 -1,277.16 MWD+IFR-AK-CAZSC(3) 5,113.86 72.29 102.00 3,357.64 3,264.61 -1,297.05 2,953.42 5,979,445.20 552,534.86 0.55 -1,297.05 MWD+IFR-AK-CAZSC(3) 5,208.19 72.44 102.37 3,386.22 3,293.19 -1,316.70 3,091.15 5,979,426.14 652,622.70 0.54 -1,316.70 MWDAFR-AK-CAZ-SC (3) 5,304.42 71.97 101.27 3,415.63 3,322.60 -1,335.46 3,130.83 5,979,407.96 552,712.49 1.19 -1,335.46 MWD+IFR-AK-CAZ-SC (3) 5,397.78 72.54 100.05 3,444.08 3,351.05 -1,351.91 3,218.21 5,979,392.10 552,799.97 1.39 -1,351.91 MWO+IFR-AK-CAZSC (3) 5,492.18 72.26 99.67 3,472.62 3,379.59 -1,367.32 3,306.86 5,979,377.28 552,888.72 048 -1,367.32 MWD+IFR-AK-CAZ-SC(3) 5,587.17 73.20 97.40 3,500.83 3,407.80 -1,380.78 3,396.56 5,979,364.42 552,978.49 2.49 -1,380.78 MWD+IFR-AK-CAZSC (3) 5,681.72 73.35 94.63 3,528.04 3,435.01 -1,390.26 3,486.60 5,979,355.63 553,068.58 2.81 -1,390.26 MWD+IFR-AK-CAZ-SC (3) 5,775.85 74.16 89.93 3,554.39 3,461.36 -1,393.85 3,576.87 5,979,352.54 553,158.87 4.87 -1,393.85 MWD+IFR-AK-CAZSC (3) 5,870.98 73.90 85.31 3,580.57 3,487.54 -1,390.05 3,668.22 5,979,366.94 553,250.18 4.68 -1,390.05 MWD+IFR-AK-CAZSC(3) 5,965.45 75.06 84.46 3,605.85 3,512.82 -1,381.94 3,758.88 5,979,365.65 553,340.78 1.50 -1,381.94 MWD+IFR-AK-CAZSC (3) 6,060.00 76.79 81.77 3.628.85 3,535.82 -1,370.94 3,849.92 5,979,377.25 553,431.73 3.31 -1,370.99 MWD+IFR-AK-CAZSC(3) 6,154.71 77.03 78.51 3,650.31 3,557.28 -1,355.14 3,940.79 5,979,393.65 553,522.49 3.36 -1,355.14 MWD+IFR-AK-CAZSC(3) 6,249.44 76.80 75.62 3,671.76 3,578.73 -1,334.49 4,030.71 5,979,414.89 553,612.26 2.98 -1,334.49 MWD+IFR-AK-CAZSC(3) 6,344.19 77.26 75.66 3,693.02 3,599.99 -1,311.59 4,120.16 5,979,438.38 553,701.54 0.49 -1,311.59 MWD+IFR-AK-CAZSC(3) 6,439.44 7].56 77.33 3,713.78 3,620.75 -1,289.88 4,210.54 5,979,460.68 553,791.78 1.74 -1,289.88 MWD+IFR-AK-CAZSC(3) 6,533.88 77.46 77.91 3,734.19 3,641.16 4,270.11 4,300.61 5,979,481.05 553,881.70 0.61 -1,270.11 MWD+IFR-AK-CAZSC(3) 6,628.84 76,85 76.68 3,755.29 3,662.26 -1,249.75 4,390.92 5,979,502.00 553,971.87 1.43 -1,249.75 MWD+IFR-AK-CAZSC(3) 6,723.11 75.92 75,22 3,777.48 3,684.45 -1,227.51 4,479.80 5,979,524.83 554060.59 1.80 -1,227.51 MW0+1FR-AK-CAZSC (3) 6,817.56 75.83 74.81 3,800.53 3,707.50 -1,203.83 4,568.28 5,979,549.9 554,148.90 0.43 -1,203.83 MWD+1FR-AK-CAZSC(3) 6,912.19 75.97 75.42 3,823.58 3,730.55 -1,180.26 4,656.96 5,979,573.25 564,237.43 0.64 -1,18026 MWD+IFR-AK-CAZSC(3) 7,006.64 75.90 76.21 3,846.54 3,753.51 -1,157.80 4,745.80 5,979,596.29 554,326.10 0.61 -1,157.80 MW3+1FR-AK-CAZ-SC(3) 7,101.42 75.97 76.03 3,869.57 3,776.54 -1,135.75 4,835.06 5,979,616.93 554,415.20 0.20 -1,135.75 MWD+IFR-AK-CAZ-SC (3) 7,196.49 75.86 75.76 3,892.71 3,799.68 -1,113.28 4,924.49 5,979,641.99 554,504.47 0.30 -1,113.28 MWD+IFR-AK-CAZSC (3) 7,290.28 75.97 75.81 3,915.53 3,822.50 -1090.94 5,012.67 5,979,664.91 554,592.50 0.13 -1,090.94 MWD+IFR-AK-CAZ-SC (3) 7,385,72 75.91 74.43 3,938.72 3,845.69 -1,067.16 5,102.15 5,979,689.28 554,681.80 1.40 -1,067.16 MWD+IFR-AK-CAZ-SC (3) 7,479.80 75.74 74.59 3,961.76 3,868.73 -1042.80 5,190.05 5,979,714.22 554,769.53 0.24 -1,042.80 MWD+IFR-AK-CAZ-SC (3) 7,574.46 75.88 74.19 3,984.96 3,891.93 -1,018.11 5,278.44 5,979,739.49 554,857.74 0.44 -1,018.11 MWD+IFR-AK-CAZ-SC (3) 7,611.00 • 75.86 73.66 3,993.88 • 3,900.85 -1,008.30 5,312.49 5,979,749.53 554,891.73 1.40 -1008.30 MWD+IFR-AK-CAZ-SC (3) 7,624.65 77.79 72.93 3,996.99 3,903.96 -1,004.48 5,325.21 5,979,753.43 554,904.43 15.05 -1,004.48 MWD -INC -ONLY (4) 7,647.47 77.13 72.90 4,001.95 3,908.92 -997.93 5,346.51 5,979,760.12 554,925.67 2.90 -997.93 MWD4NC ONLV(4) 7,745.95 81.22 71.40 4,020.44 3,927.41 568.28 5,438.55 5,979,790.37 555,017.51 4.41 -968.28 MWD4NC ONLV(4) 7,840.38 S&W 73.29 4,031.06 3,938.03 -939.84 5,527.94 6,979,819.40 555,106.70 5.30 -939.84 MWD+IFR-AK-CAZ.SC (5) 7,939.32 88.99 68.15 4,035.51 3,942.48 507.22 5,621.19 5,979,852.64 555,199.72 6.08 -90722 MWD+IFR-AK-CAZ-SC (5) 8,030.45 88.61 67.00 4,037.42 3,944.39 $72.46 5,705.41 5,979,887.95 555,283.70 1.33 -872.46 MWD+IFR-AK-CAZSC(6) 8,126.66 88.63 66.94 4,039.74 3,946.71 -834.83 5,793.93 5,979,926.16 555571.96 0.07 -834.83 MWD+IFR-AK-CAZ-SC(5) 51312018 1:49:22PM Page 4 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 11-1-103 Project: Kuparuk River Unit TVD Reference: 1 H-103 actual @ 93.03usft (Doyon 142) Site: Kuparuk 1H Pad MD Reference: 1 H-103 actual (a) 93.03usft (Doyon 142) Well: 1H-103 North Reference: True Wellbore: 1 H -1 03L1 Survey Calculation Method: Minimum Curvature Dnlgn: 1 H-1 03L1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +Ef-W Northing Easting OLS Section (waft) (•) (•) (11311) (usft) (usft) (us11) (f) (ft) (91001 (f1) Survey Tool Name 8,220.73 90.45 67.80 4,040.49 3,947.46 -79864 5,880.75 5,979,962.92 555,458.53 2.14 -798.64 MWD+IFR-AK-CAZ-SC(5) 8,316.08 90.20 67.35 4,039.95 3,946.92 -762.27 5,968.88 5,979,999.87 555,546.42 0.54 -762.27 MM+IFR-AK-CAZSC(5) 8,410.67 89.64 65.44 4,040.08 3,947.05 -724.39 6,055.55 5,980,038.32 555,632.83 2.10 -724.39 MWD+IFR-AK-CAZSC (5) 8,505.64 89.17 63.99 4,041.07 3,948.D4 583.83 6,141.42 5,980,079.44 555,718.41 1.60 S .83 MWD+1FR-AK-CAZ-SC 15) 8,600.69 89.80 61.53 4,041.92 3,948.89 -640.33 6,225.92 5,980,123.50 555,802.61 2.67 540.33 MWD+IFR-AK-CAZ-SC (5) 8,695.72 91.22 58.43 4,041.08 3,948.05 -592.80 6,308.18 5,980,171.57 555,884.55 3.59 592.80 MWD+IFR-AK-CAZSC (5) 8,790.79 89.88 52.58 4,040.16 3,947.13 538.98 6,386.50 5,980,225.90 555,962.50 6.31 538.98 MWD+IFR-AK-CAZSC (5) 8,885.73 91.36 47.52 4,039.14 3,946.11 478.04 6,459.25 5,980,287.31 556,034.84 5.55 478.04 MWD+IFR-AK-CAZSC(5) 8,980.53 92.92 40.41 4,035.59 3,942.56 -009.91 6,524.97 5,980,355.87 556,100.11 7.67 409.91 MWD+IFR-AK-CAZ-SC(5) 9,075.81 91.06 34.T7 4,032.28 3,939.25 -334.49 6,583.03 5,980,431.67 556,157.66 6.23 -334.49 MWD+IFR-AK-CAZ-SC(5) 9,170.32 90.04 32.07 4,031.37 3,938.34 -255.61 6,635.08 5,960,510.88 556,209.18 3.05 -255.61 MWD+IFR-AK-CAZ-SC(5) 9,265.89 92.52 30.86 4,029.24 3,936.21 -174.12 6,684.95 5,980,592.69 556,258.50 2.89 -174.12 MWDAFR-AK-CAZSC(5) 9,360.75 94.17 30.09 4,023.70 3,930.67 -92.51 6,732.97 5,980,674.61 555,305.98 1.92 -92.51 MWD+IFR-AK-CAZSC (5) 9,455.10 94.94 26.28 4,016.21 3,923.18 -9.63 6,777.39 5,980,757.77 556,349.84 4.11 -9.63 MWD+IFR-AK-CAZSC (5) 9,550.48 94.49 25.62 4,008.37 3,915.34 75.64 6,81 B.98 5,980,843.51 656,390.87 0.84 75.84 MWD+IFR-AK-CAZSC(5) 9,645.34 90.86 25.21 4,003.94 3,91D.91 161.42 6,859.64 5,980,929.34 556,430.96 3.85 161.42 MWD+IFR-AK-CAZ-SC (5) 9,740.53 90.06 22.92 4,003.18 3,910.15 248.32 6,898.45 5,981,016.49 556,469.19 2.55 248.32 MWD+IFR-AK-CAZ-SC(5) 9,835.18 88.82 18.80 4,004.10 3,911.07 336.74 6,932.15 5,981,105.13 556,502.29 4.55 336.74 MWD+IFR-AK-CAZ-SC(5) 9,930.19 90.10 14.07 4,005.00 3,911.97 427.84 6,959.02 5,981,196.39 556,528.56 5.16 427.84 MWD+IFR-AK-CAZ-SC(5) 9,955.82 90.77 13.20 4,004.80 3,911.77 452.75 6,965.06 5,981,221.34 556,534.44 4.28 452.75 MWD+IFR-AK-CAZ-SC(5) 10,025.40 92.04 11.16 4,003.10 3,910.07 520.73 6,979.74 5,981,289.41 556.548.66 3.45 520.73 MWD+IFR-AK-CAZSC(5) 10,119.79 93.03 4.87 3,998.92 3,905.89 614.06 6,992.88 5,981,382.82 556,561.18 6.74 614.06 MWD+IFR-AK-CAZSC(5) 10,160.% 92.08 2.13 3,997.11 3,904.08 654.51 6,995.35 5,981,423.28 556,563.39 7.14 654.51 MWD+IFR-AK-CAZSC(5) 10,215.18 91.63 358.21 3,995.33 3,902.30 709.29 6,995.52 5,981,478.05 556,563.19 7.19 709.29 MWD+IFR-AK-CAZSC (5) 10,310.05 91.60 356.41 3,992.66 3,899.63 804.02 6,991.06 5,981,572.74 556,558.11 1.90 804.02 MWD+IFR-AK-CAZSC(5) 10,404.62 91.76 355.46 3,989.89 3,896.86 898.31 6,984.36 5,981,666.97 556,550.79 1.02 898.31 MWD+IFR-AK-CAZ-SC(5) 10,498.87 90.63 354.64 3,987.76 3,894.73 992.18 6,976.23 5,981760.78 555,542.04 1.32 992.18 MWD+IFR-AK-CAZ-SC(5) 10,594.63 91.98 353.22 3,985.41 3,692.38 1,087.37 6,966.11 5,981,855.89 566,531.29 1.91 1,087.37 MWD+IFR-AK-CAZ-SC(5) 10,689.05 91.79 352.31 3,982.30 3,889.27 1,180.99 6,954.23 5,981,949.42 556,518.78 0.98 1,180.99 MWD+IFR-AK-CAZ-SC(5) 10,784.00 91.00 352.33 3,979.99 3,886.96 1,275.06 6,941.54 5,982,043.39 556,505.48 0.83 1,275.6 MWD+IFR-AK-CAZSC(5) 10,878.58 89.62 352.57 3,979.48 3,886.45 1,368.81 6,929.11 5,982,137.05 556,492.43 1.48 1,368.81 MWD+IFR-AK-CAZSC(5) 10,973.50 90.42 351.46 3,979.45 3,886.42 1,462.81 6,915.93 5,982,230.95 556,478.63 144 1,462.81 MWD+IFR-AK-CAZSC(5) 11,068.51 91.88 351.24 3,977.54 3,884.51 1,556.72 6,901.64 5,982,324.76 556,463.72 1.55 1,556.72 MWD+IFR-AK-CAZSC (5) 11,163.84 91.72 353.16 3,974.55 3,881.52 1,651.11 6,88871 5,982,419.06 556,450.17 2.02 1,651.11 MWD+IFR-AK-CAZSC(5) 11.243.16 91.13 354.75 3,972.57 3,879.54 1,729.97 6,880.36 5,982,497.84 556,441.29 2.14 1,729.97 MWDAFR-AK-CAZSC(5) 11,299.21 88.73 355.66 3,972.64 3,879.61 1,785.82 6,875.68 5,982,553.65 556,436.24 4.58 1,785.82 MWD+IFR-AK-CAZ-SC(5) 11,353.66 85.97 357.22 3,975.16 3,882.13 1840.9 6,872.30 5,982,607.90 556,432.50 5.82 1,840.07 MWD+IFR-AK-CAZ-SC(5) 11,448.73 88.41 359.00 3,979.82 3,886.79 1,934.99 6,869.17 5,982,702.77 556,428.75 3.18 1,934.99 MWD+IFR-AK-CAZ-SC(5) 11,543.22 90.93 359.11 3,980.36 3,887.33 2,02946 6,867.61 5,982,797.21 556,426.56 2.67 2,029.46 MWD+IFR-AK-CAZSC(5) 11,638.95 90.28 354.62 3,979.35 3,886.32 2,125.01 6,862.38 5,982,892.72 556,420.70 4.74 2,125.01 MWD+IFR-AK-CAZSC(6) 5312018 1:49:22PM Page 5 COMPASS 5000.14 Build 85 ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1 H-103 Project: Kuparuk River Unit TVD Reference: 1H-103 actual @ 93.03usft (Doyon 142) Site: Kupamk 1 H Pad MD Reference: 1 H-103 actual @ 93.03usft (Doyon 142) Well: 1H-103 North Reference: True Wellbore: 1H-1031-1 Survey Calculation Method: Minimum Curvature Design: 1 H -103L1 Database: OAKEDMP2 Survey 5/3112018 1:49: 22PM Page 6 COMPASS 5000.14 Build 85 Map Map vertical MD Inc AZI TVD TVOSS +NIS +E/ -W Northing Fasting DLS Section (uaft) (9 (') (uaft) (uaft) (waft) (uaft) (ft) Ift) (°11001 (ft) Survey Tool Name 11733.99 90.37 354.51 3,978.81 3,885.78 2,219.62 6,853.38 5.982,987.26 556,411.07 0.15 2,219.62 MWD+IFRAK-CAZSC(5) 11,829.07 90.26 355.14 3,978.29 3,885.26 2,314.31 6,844.80 5,983,081.89 556,401.87 0.67 2,314.31 MWD+IFRAKCAZ-SC (5) 11,923.47 93.29 355.35 3,975.37 3,882.34 2,408.33 6,836.99 5,983,175.84 556,393.44 3.22 2,408.33 MWD+IFRAK-CAZ-SC (5) 12,018.22 93.45 355.37 3,969.80 3,876.77 2,502.61 6,829.34 5,983,270.05 556,385.17 0.17 2,502.61 MWD+IFR-AK-CAZ-SC (5) 12,113.44 93.82 356.95 3,963.76 3,870.73 2,597.42 6,822.98 5,983,364.82 556,378.18 1.70 2,597.42 MWD+IFR-AK-CAZSC(5) 12,20B.82 93.42 356.22 3,957.74 3,864.71 2,692.44 6,817.31 5,983,459.79 556,371.88 0.87 2,692.44 MWD+IFRAK-CAZSC(5) 12,298.83 93.24 353.74 3,952.51 3,859.48 2,781.95 6,809.45 5,983,549.23 556,363.43 2.76 2,781.95 MWD+IFR-AKCAZSC(5) 12,389.30 91.98 353.35 3,948.39 3,855.36 2,871.75 6,799.29 5,983638.95 556,352.67 1.46 2,871.75 MWD+IFR-AK-CAZSC(5) 12,480.70 93.38 349.70 3,944.11 3,851.08 2,962.04 6,785.84 5,963,729.14 566,338.63 4.27 2,962.4 MWD+IFR-AK-CAZSC(5) 12,572.94 95.28 34512 3,937.15 3,844.12 3,051.88 6,766.27 5,983,818.85 556,318.46 4.77 3,051.88 MWD+IFR-AK-CAZ-SC (5) 12,663.71 95.95 343.13 3,928.26 3,835.23 3,138.89 6,742.02 5,983,905.69 556,293.64 2.93 3,138.89 MWD+IFR-AK-CAZ-SC(5) 12,754.99 96.31 339.71 3,918.51 3,825.48 3,224.91 6,713.10 5,983,991.W 556,264.16 3.75 3224.91 MWD+1FRAK-CAZ-SC(5) 12,846.91 94.26 338.52 3,910.05 3,817.02 3,310.42 6,680.47 5,984076.78 556,230.97 2.58 3,310.42 MWD+IFR-AK-CAZSC (5) 12,938.99 91.32 336.99 3,905.57 3,812.54 3,395.53 6,645.66 5,984,161.65 556,195.60 3.60 3,395.53 MWD+IFR-AKCAZSC(5) 13,031.91 93.10 336.60 3,901.98 3,808.95 3,480.87 6,609.08 5,984246.74 556,158.45 1.96 3,480.87 MWDAFRAKCAZSC(5) 13,124.17 92.81 337.42 3,897.23 3,804.20 3,565.6B 6,573.09 5,984,331.31 556,121.91 0.94 3,565.68 MWD+IFRAK-CAZ-SC (5) 13,216.95 90.97 336.08 3,894.17 3,801.14 3,650.88 6,536.49 5,984,416.25 556,084.75 2.45 3,650.88 MWD+IFR-AK-CAZ-SC (5) 13,309.42 90.92 332.63 3,892.64 3,799.61 3,739.21 6,496.48 5,984,499.31 556,044.19 3.73 3,734.21 MWD+IFRAK-CAZSC (5) 13,401.47 93.61 330.61 3,889.00 3,795.97 3,815.13 6,452.77 5,984579.93 555,999.95 3.65 3,815.13 MWD+IFRAK-CAZSC(5) 13,493.32 93.27 328.56 3,883.49 3,790.46 3,894.19 6,405.35 5,984,658.67 555,953.02 2.26 3,894.19 MWD+IFRAKCAZSC(5) 13,585.35 90.69 325.59 3,880.31 3,787.28 3,971.38 6356.37 5,984735.52 555,902.53 4.27 3,971.38 MWD+IFR-AKCAZSC(5) 13,677.43 89.81 323.52 3,879.91 3,786.88 4,046.38 6,302.98 5,984,810.16 555,848.65 2.44 4,046.38 MWD+IFRAK-CAZSC(5) 13,770.34 89.20 319.89 3,880.71 3,787.68 4,119.29 6,245.41 5,984882.68 555,790.61 3.96 4,119.29 MWD+IFR-AK-CAZ-SC 15) 13,882.00 88.71 316.62 302.38 3,789.35 4,187.66 6,184.40 5,984,950.63 555,729.15 3.61 4,187.66 MWD+IFR-AK-CAZ-SC (5) 13,953.64 88.60 312.26 3,884.54 3,791.51 4,251.79 6,119.00 5,985,014.32 555,663.34 4.76 4,251.79 MWD+IFRAK-CAZSC(5) 14,045.29 89.25 308.79 3,886.26 3,793.23 4,311.32 6,049.36 5,985,073.39 555,593.31 3.85 4,311.32 MWD+IFRAKCAZSC (5) 14,136.70 89.15 307.47 3,887.53 3,794.50 4,367.75 5,977.47 5,985,129.34 555,521.05 1.45 4,367.75 MWD+IFRAK-W-8C(5) 14,228.31 89.57 306.48 3,888.56 3,795.53 4,422.85 5,904.29 5,985,183.94 555,447.51 1.17 4,422.85 MWD+IFR-AKCAZ-SC(5) 14,320.60 90.24 305.90 3,888.71 3,795.68 4,477.34 5,829.80 5,985,237.99 555,372.68 0.% 4,477.34 MWD+IFR-AK-CAZSC (5) 14,412.90 90.54 305.14 3,888.0B 3,795.05 4,530.97 5,754.68 5,985,291.06 555,297.21 0.89 4,530.97 1OWDAFRAK-CAZ-SC(5) 14,504.79 90.79 305.45 3,887.01 3,793.98 4,584.05 5,679.69 5,985,343.65 555,221.87 0.43 4,584.05 MWD+IFR-AK-CAZSC (5) 14,595.18 90.65 305.26 3,885.88 3,792.85 4,636.35 5,605.97 5,985,395.45 555,147.82 0.26 4.636.35 MND+IFR-AKCAZSC(5) 14,687.47 91.72 305.66 3,883.97 3,790.94 4,689.88 5.530.82 5,985,448.47 555,072.32 1.24 4,689.88 MWD+IFRAK-CAZ-SO(5) 14,779.59 90.68 307.02 3,882.4 3,789.01 4,74.46 5,456.63 5,985,502.55 554,997.78 1.86 4,744.46 MWD+IFR-AK-CAZSC(5) 14,872.02 89.33 305.59 3,882.03 3,789.00 4,799.83 5,382.63 5,985,557.43 554,923.42 1.53 4,799.B3 MWD+IFRAK-CAZ-SC(5) 14,964.28 89.52 305.87 3,882.96 3,789.93 4,855.W 5,308.69 5,985,612.10 554,849.13 0.37 4,855.00 MND+IFRAK-CAZ-SC(5) 15,042.89 89.4 307.32 3,88367 3,790.64 4,902.41 5,245.99 5,985,659.09 554,786.12 0.58 4,902.41 MND+IFRAK-CAZSC(5) 15,103.00. 89.4 307.32 3,884.26. 3,791.23 4,938.85 5,198.19 5,985,695.22 554,738.08 0.00 4,938.85 PROJECTED to TO 5/3112018 1:49: 22PM Page 6 COMPASS 5000.14 Build 85 Cement Detail Report IH -103 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3112/201811:00 Cement Details DescriptionCementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 3/75/2018 00:30 3/15/2018 0350 1 H-103 Comment Line up to SLB, pump 5 hors freshwater, a ssure test lines to 3,500 psi - good test. Pump 40 bbis Chemwash CW 100 at 4.2 bpm, 80 psi, 10% F/O. Pump 80 bbis 10.5 ppg MudPush II spacer at 5 bpm, 710 psi, 12% F/O. Drop DHP bottom plug. Bach up lead slurry, cement wet at 0119 his. Pump 360 hors 11.0ppg LiteCrete lead slurry at 5.4 bpm, 180 psi, 18% F/O. Observe bottom plug land out at 169 bbis of lead cement pumped. Batch up tail slurry and pump 64.4 bbls 12.0ppg LiteCrete tail slurry at 4.7 bpm, 231 psi, 12% F/O. Drop DHP top plug. SLB pump 9.9 bbis freshwater at 6.7 bpm, 280 psi, 18% F/0. Reciprocate pipe 20' while SLB pumping, PUW 126k, SOW 113k. Swap to rig and displace cement with 9.5ppg spud mud Q 8 bpm, drop rate to 3 bpm 10 bbls from humping plug, FOP 303i. Bump plug on calculated at 1612 strokes. Pressure up to 827 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Stop reciprocating pipe once it started getting sticky just after rig started displacing cement. Cement in place at 03:50 his. Observed 62 bbis of good 11.0ppg lead cement back to surface. No losses observed throughout Cement job. Cement Stages Stage # 1 DescriptionObjective Top Depth (ftKB) Bottom Depth (ftKB) Full Retum? Vol Cement... Top Plug? Bbn Plug? Surface Casing Cement Cement to surface 42.9 1,877.0 Yes 86.0 Yes Yes Q Pump [nit (bbl/m... Q Pump Final (boll... Q Pump Avg (bbl/... P Pump Final (psi)P Plug Bump (psi) Recip7 Stroke (ft) Rotated? Pipe RPM (rpm) 4 8 7 303.0 827.0 Yes 12000 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Line up to SLB, pump 5 bbis freshwater, and pressure test lines to 4000 psi - good test. Pump 40.1 bbis 8.34 ppg Chemwash CW100 at 4.2 bpm, 108 psi, 17% F/O. Pump 80 bbis MudPush II spacer at 5.5 bpm, 130 psi, 18% F/O. Drop DHP bottom plug. Bach up lead slurry, cement wet at 14:48 hrs. Pump 323.2 bbis 11 oppg LileCrele lead slurry at 6.5 bpm, ICP, 170 psi, FOP 253 psi, 19% F10. Observe bottom plug land out at 173.5 bbis of lead cement pumped. Batch up tail slurry, observe line packoff in pump truck, clear line, and pump 59.7 bbls 12.0ppg LiteCrete tail slurry at 4.8 bpm, 225 psi, 17% F/O. Drop DHP top plug. SLB pump 10.2 bbis freshwater at 4.8 bpm, 240 psi, 17% F/O. Reciprocate pipe 20' while SLB pumping, PUW 1291k, SOW 95k. Swap to dg and displace cement with 9.5ppg spud mud using mud pump #1 at 8 bpm, ICP 419 psi, FOP 538 psi for 154 bbls, then drop rate to 3 bpm, ICP 280 psi, FOP 290 psi. Bump plug on calculated at 1629 strokes. Pressure up to 850 psi and hold for 5 minutes. Bleed off and check floats - floats holding. Stop reciprocating pipe once it started getting sticky just after rig started displacing cement. Cement in place at 17:37 hrs. Observed 86 bbis of good 11.0ppg lead cement back to surface. No losses observed throughout cement job. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class 1 Volume Pumped (bbl) Freshwater I I 1 5.0 Yield (ft'7seck) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 6.34 Additives Additive Type Concentration Conic Unit label Fluid _ Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ft(B) Amount (sacks)Class Volume Pumped (bbl) Chemwash CW 100 40.1 Yield (h'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density JlWgal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 8.34 Additives Additive Type Concentration Conic Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) 1 Amount (sacks) Class 1 Volume Pumped (bbl) MudPush II Spacer I I I 80.0 Yield (ft -/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 0.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluitl Description Estimated Top (ftKB) Est arm (ftKB) Amount (sacks) Class Votume Pumpetl (bbl) Lead Cement I 42.9 1,377.0 1,060 LiteCrete 360.0 Yield (IPisack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) 1.91 6.73 11.00 5.13 Additives Additive Type Concentration I Cone Unit label Page 1/2 ReportPrinted: 5T3-012018 Cement Detail Report 11-1-1103 String: Surface Casing Cement Job: DRILLING ORIGINAL, 3/12/201811:00 Cement Fluids 8 Additives id Description Estimated Top (ttNB) .. ( Amount (sacks) 1,377.0 0. - ME Class LiteCrete Volume Pumped (bbl) 64.4 Thickening Ti me (hr) CmprStrl (psi) Free Water (%) ity lcP) 3.35 Additives Concentration Conc Unit label Page 212 Report Printed: 513012011 Cement Detail Report 11-1-103 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 3/12/2018 11:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 3/21/2018 00:45 3/2112018 0400 1 H-103 Lin pump 5.1 J pressure test lines to the floor. Pressure up to 500 psi low / 4000 psi high - good test. Drop bottom plug (Davis Lynch Lap/N anti-rotation). Schlumberger batch MudPush to 12.5 ppg. Pump 47.5 bbls of MudPush II @ 3.8 bpm w/ FCP 120 psi. Recip w/ 200k up and 105 k down weight. Drop bottom plug (Davis Lynch Lap/N anti-rotation). Schlumberger clean tub, then mix cement to 15.8 ppg. Pump 250.2 bbls cement slurry averaging 6 bpm wl FCP of 243 psi. Drop top plug (Davis Lynch LapM anti-rotation). Schlumberger pump 10 bbls of water behind plug. Swap to rig pumps to displace w/ 9.1 ppg LSND. Reciprocated pipe until 220 bbls were pumped by the dg, set on hanger w/ 46 k last down weight. Continued displacing @ 6 bpm un01 348 bbls pumped, slowed to 3 bpm and bumped plug wl 358.5 bbls of mud (3567 strokes). Pressure up 512 psi over (1912 psi), held 5 minutes, bled off pressure, shut in and confirmed no pressure buildup. Perform casing test to 3500 psi, charted same. Pumped 5.5 bbls, Bleed off pressure @ 0434 him (bled back 5.3 bbls). Check floats and all good. No downhole losses throughout cement job. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement Intermediate 3,565.0 8,112.0 Ves Yes Yes Cement casing Q Pump Init (Iaullm.. Q Pump Final (bull... Q Pump Avg (bbtl... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 8 6 1,400.0 1,912.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To IRKS) Drill Out Diameter (in) Comment Line up to Schlumberger and pump 5.1 bbls of water to pressure test lines to the floor. Pressure up to 500 psi and observe pressure fall off rapidly. Identify a 3" gale valve on mud manifold on the floor leaking. Blow down line to SLB and fix leaking valve. Line up Schlumberger and pump 3.9 bbls bbls of water to fill lines. Pressure test to 500 psi low / 4000 psi high - good test. Schlumberger batch MudPush to 12.5 ppg. Pump 50.1 bbls of MudPush II @ 4.5 bpm w/ FCP 52 psi. Recip w/ 179k up and 120 k down weight. Drop bottom plug (Davis Lynch Lap/N anti-rotation). Schlumberger clean tub, then mix cement to 15.8 ppg. Pump 175.6 bbls cement slurry averaging 6 bpm wl FCP of 278 psi. Drop top plug (Davis Lynch LapM anti-rotation). Schlumberger pump 10.1 bbls of water behind plug. Swap to rig pumps to displace wl 9.4 ppg LSND. Reciprocated pipe until 195.4 bbis were pumped by the rig, set on hanger wl 98 k last down weight (lost 25k on last recip stroke). Continued displacing @ 8 bpm until 287 bbls pumped, slowed to 3 bpm and bumped plug w/ 300.9 bbls of mud (2988 strokes). Pressure up 650 psi over (1700 psi), held 5 minutes. bled off pressure, shut in and Confirmed no pressure buildup. Perform casing test using mud pump #1 to 3500 psi, charted same. Pumped 5.3 bbls, Bleed off pressure @ 0434 him (bled back 5.3 bbls). Check floats and all good. Cement in place @ 04:35 hrs 11129/2017. No downhole losses throughout cement job. Cement Fluids & Additives Fluid Fluid Type Fluid ion- F5Top (ftKB) Est 'I'm (ftKB) Amount (sacks) Class volume Pumped (bbl) Mud Push 2,266.0 3,565.0 47.5 Yield jWlsack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosfry lcPl Thickening Time (hr) CmprStr 1 (psi) 2.50 Additives Additive Type Concentration Cont Unit tabs/ Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Blm (ftKB) Amount (sacks) class Volume Pumped (bW) Cement 3,565.0 8,112.0 1,210 G 250.0 Yield (felsack) Mix H2O Ratio (gal/sa... Free Water I%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) Cmprstr 1 (psi) 1.16 5.12 15.80 4.15 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 513012018 pTo aiF —Out- Loepp, Victoria T (DOA) From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Friday, March 23, 2018 11:11 AM To: Loepp, Victoria T (DOA) Cc: Bearden, 1 Daniel; Brunswick, Scott A Subject: RE: [EXTERNAL]KRU 11-1-103 Ll, L2, L3 (PTD 218-004, 005, 006) FIT Waiver Follow Up Flag: Follow up Flag Status: Flagged Thank you. Kelsey From: Loepp, Victoria T (DOA) (mailto:victoria.loepp@alaska.gov] Sent: Friday, March 23, 2018 11:00 AM To: Hallford, Kelsey <Kelsey.Hallford@conocophilIIps.com> Cc: Bearden, J Daniel <J. Daniel. Bearden@conocophillips.com>; Brunswick, Scott A <Scott.A. Bru nswick@conoco phi ll ips.com> Subject: [EXTERNAL]KRU 1H-103 L1, L2, L3 (PTD 218-004, 005, 006) FIT Waiver Kelsey, A waiver is granted to eliminate FIT/LOT testing on the next three laterals (218-004, 218-005, 218-006) on KRU 11-1-103 L1-1-3 laterals, and conduct the final planned FIT on the shallowest lateral (PTD 218-007) KRU 11-1-1031-4. 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. LoeopCo)a laska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without First saving or forwarding It, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria Loeoo@alaska g4v_ From: Hallford, Kelsey <Kelsey.Hallford@conocophillips.com> Sent: Friday, March 23, 2018 10:41 AM To: Loepp, Victoria T (DOA) <victoria.loeppPalaska.eov> Cc: Bearden, J Daniel <J. Daniel. Bearden @conocophi Ilips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Subject: RE: [EXTERNAL]RE: PTD# 218-004,005, 006 FIT Waiver THE STATE °fALASKA 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.00gcc.olaska.gov Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H -103L1 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-004 Surface Location: 5260.48' FNL, 768.38' FEL, Sec. 28, T12N, R10E, UM Bottomhole Location: 292.7' FNL, 834.72' FEL, Sec. 27, T12N, R10E, UM Dear Mr.Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well Permit No. 218-003, API No. 50-029- 23593-00-00. Production should continue to be reported as a function of the original API number stated above. 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, Hollis S. French 4\\ Chair DATED this_day of February, 2018. STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISoiON PERMIT TO DRILL 20 AAC 25 005 JAN 0 5 2018 AOGCC 1a. Type of Work: d 1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG Service - Disp ❑ 1c. 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 Bond No. 59-52-180 " KRU 1H -103L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14904' TVD: 3893' Kuparuk River Field West Sak Oil Pool - 4a. Location of Well (Governmental Section): 7. Property Designation: �n7 ABL_$553" ADL025638 �d �L O2Stv34 Surface: 5260.48' FNL, 768.38' FEL, Sec 28, T 12N, R010E, UM 8. DNR Approval Number: ,,I z rf 13. Approximate Spud Dale: KTL Top of Productive Horizon: 980.56 FNL, 865.06 FEL, Sec 34, T12N, R010E, UM LO/NS 80-261 & 931695000 2/ 3 1 Z 1 9. Acres in Property: 14.VI-stance to NearestProperty: Total Depth: 292.7 FNL, 834.72 FEL, Sec 27, T1 2N, R010E, UM 2560 &2560 . 957' to ADL025636 41b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 93 - 15. Distance to Nearest Well Open Surface: x-.55474233' 5"k7S7y3 59&57-25:58' s`(uV7'ne- 4 GL / BF Elevation above MSL (ft): 54 • to Same Pool: 589' t0 1 H-105 16. Deviated wells: D I `72,' 10 Kickoffdepth: k,/, 704 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) I- Maximum Hole Angle: 94 degrees Downhole: 1764 psi Surface: 1367 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# H40 Welded 80 Surface Surface 80 80 Existing, cement to surface 13.5" 10.75" 45.5# L-80 H563 1850 Surface Surface 1850 1741 951 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# L-80 H563 7705 Surface Surface 7705 3977 1187 sx 15.8 Class G 6.75" 4.5" 12.6# L-80 IBTM 7349 7555 3874 14904 3893 N/A: Un -cemented slotted liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑ No ❑✓ 20. Attachments: Property Plat ❑ etch Drilling ot B B20 Shallow Hazard ysis 25.050 B✓ DivertOer Sketch ✓ Report Drilling Fluid Program AAC requiremlents 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be Kelsey Hallford deviated from without prior written approval. Contact Name: Authorized Name: G. Alvord Contact Email: else .h d C0 . Authorized Title: Alaska Drilling Manager Contact Phone: 1-907-265-1577 Date: 44-1LD re, Authorized Signature: L_. Commission Use Only Permit to Drill Number: HU-� API Number: 50-�z%-Z35�%3'�'�f-� Permit Approval Date: See cover letter for other requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, as hydrates, or gas contained in shales: r-� Other: a�Q �rst f..o SIJ O 5 / Samples req'd: Yes ❑ o Mud log req'd: Yes,❑_,/Nou U p No❑ Directional svy req'd: Yes Ljv No❑ H S measures: Yes 21 iFvlrLvtar f-fve"trLr j �0 25- 75'1 qq Yes ❑ No� Inclination -only svy req'd: Yes ❑ NoEr F / T WCc % p r l vy �� UC Spacing excepnon req'd: Post initial injection MIT mq'd: Yes ❑ No Er e0n,51dC/--elf C4f-tlr �vnJ`rrrn�d/�i>�r C4e'k"e-j,? bb pvn-lpr4 a"CJ po.S-�-Job l-?-1vc - 5L4-- 1'Hrd 7"o iV& CC , APPROVED BY (•-��, I Approved by: `l COMMISSIONER THE COMMISSION Date:Z (.�) 'F-�"r �` z- ! �1 ^ �1 Submit Form an p�\^ \`corm 10-401 Revised 5/2017 Th permit lies valid fob 24 fjq/�t�sCZA a f pproval per 20 AAC�51,9) Attach�ts in Duplicate �r Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-1577 Email: kelsev hallford(cDconocophillips.com January 4, 2017 Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Producer, KRU 1H -103L1 Dear Commissioner: Application for Permit to Drill, Well 11-1-1031-1 Saved: 3 -Jan -18 Conoc6MH ips ConocoPhillips Alaska, Inc. hereby applies for a permit to drill a grass roots onshore producer, a penta-lateral horizontal well in the West Sak A2, A3, A4, B and D sands. The expected spud date for this well is February 7, 2018. It is planned to use rig Doyon 142. A 13-1/2" surface hole will be drilled on diverter & 10-3/4" surface casing will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The intermediate hole section will drill a 9- 7/8" hole with 7-5/8" casing run to total depth & cemented in place. The second IH -103L1 6-3/4" production lateral will be geo-steered in the West Sak A3 and A4'sands and lined with 4-1/2" slotted liner. A separate PTD application will be submitted for each lateral: 11-1-103, 1H -103L1, 11-1-1031-2, 1H-]031-3, and 1H -103L4 laterals. 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 Kelsey Hallford at 265-1577 (kelsev.haliford(a),conocoohillips.com) or Chip Alvord at 265-6120. 'ncerely, Kee H rd Drilling Engineer Application for Permit to Drill Documew Kuparuk Well 1 H-1 03L1 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 1H -103L1 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 itemm except for an item already on file with the commission and identified in the application.' (2) a plat identifying the properly and the property='s ovners and shoving (A)rhe 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 tire National Oceanic and Almospheric Administration; (C) the proposed depth of the rvell at the top of each objective formation and at total depth: Location at Surface5260.48' FNL, 768.38' FEL, Sec 28, T 12N, ROlOE, UM NGS Coordinates Northings: 5980722.55' Eastings: 549573.2' RKB Elevation 93'AMSL Pad Elevation 54' AMSL Location at Surface Casing 224.64' FNL, 361.56' FEL, Sec 33, T12N, R010E, UM NGS Coordinates Northings: 59804801.13' Eastings: 549982.13' I Measured Depth, RKB: 1850' 1 Total Vertical Depth, RKB: 1741' Total Vertical Depth, SS: 1648' Location at Window Exit 1921.77 FNL, 649.92 FEL, Sec 34 T12N, R010E, UM NGS Coordinates Northings: 5979941.18' Eastings: 555407.03' Measured Depth, RKB: 7705' Total Vertical Depth, RKB: 13977' Total Vertical Depth, SS: 1 3884' Location at Total Depth 1292.7 FNL, 834.72 FEL, Sec 27 T12N, R010E, UM NGS Coordinates Northings: 5985725.98' Eastings: 554742.33' Measured De th, RKB: 14904' Total Vertical Depth, RKB: 3893' Total Vertical Depth, SS: 1 3800' and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) 1fa well is to be intentionally deviated the application fora Permit to Drill (Forut 10-401) must (1) include a plat drown to a suitable scale. shoeing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed cell: Please see Attachment: Directional Plan And (2) for all wells within 200feet of the proposed wellbore (A) list the names of the operators of those .vells, 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 rite application by certified nail; or (B) slate that the applicant is the only affected owner. The Applicant is the only affected owner. r Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applumlion fora Permit to Drill nual be accompanied b)each of site following items. except for an item already on file with the conndssion and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 75.035, 10 AAC 35.036, or 70 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. Due to lower reservoir pressure in the West Sak a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations, graphic attached. 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 follmving items. except for an item already on file with the commission and identified in the application: (4) information on drilling hazards. including (A) the nasinnan downhole pressure that nia)' be encountered, criteria used to determine a. and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP) while drilling 1H -103L1 is calculated using an estimated maximum reservoir pressure of 1723 psi (based on 1H -05A pressure at a 4005.2' TVD reference datum), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak A3 sand at 3965' TVD: A3 Sand Estimated. BHP A3 Sand estimated depth Gas Gradient Hydrostatic of full gas column MPSP = BHP — gas column (B) data on potential gas zones: = 1,764 psi ' = 3,965' TVD = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) = 397 psi (3,965' TVD * 0.10 psi/ft) = 1,367 psi (1,764 psi — 397 psi) ✓ The wellbore is not expected to penetrate any shallow gas zones. And (C) data caserning potential causes of hole problems such as abnormally geo-pressured strata, last circulation zones, and sones that hare a propensity for differential sticking: See attached 1H -103L1 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of die following items. except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conductingforniation integrity tests. as required under 30 AAC 15,0300: A procedure is on file with the commission for performing FIT/LOT's. The FITILOT will be performed on the motherbore of the 1H-103 penta-lateral well (1H-103). ConocoPhillips requests a waiver on subsequent laterals FIT/LOT (1H -103L1, 1H -103L2, IH -103L3, & 1H-1031,4). If any of the below mentioned criteria are not met, performing an FIT/LOT of the upper laterals will be undertaken. 1. Primary cement job pumped as per design with no issues. 2. WellView cement report submitted to AOGCC for review of job before 2nd lateral is drilled (1H -103L1). 3. No abnormal pressure is discovered while drilling the motherbore well (lowest lateral). 4. Kill weight fluid is confirmed using a static flow check at the shoe for 30 minutes post TD of the 1H-103 motherbore. 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 die following items except for an ilem 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 any slotted linerpre-perforated liner. or screen to be installed Casing and Cement Program 18. Casing ogram Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 42" 20" 94# 1-440 Welded 80 Surface Surface 80 80 Existing, cerrent to surface 13.5" 10,75" 45.5# 1 L-80 H563 1850 Surface Surface 1850 1741 951 sx 11.0 Lead, 145 sx 12.0 Tail 9.875" 7.625" 29.7# L-80 H563 7705 Surface Surface 7705 3977 1187 sx 15.8 Class G 6.75" 4.5" 12 6# 1 L-80 ETM 7349 7555 3874 14904 • 3893 WA: Un -cemented slotted liner Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application fora Permit to Drill muss be accompanied by each ofthe follmring items, except for an item already on file will; the commission and ident fed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2), Rig will be on BOP while drilling 1H -103L1; diverter schematic supplied with 1H-103 PTD application. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied b) each of the follmring items. except jor an item already on file unh the commission and identified in the application: (8) a drilling Auld program, including a diagram and description of the dnging fluid system, as required by 20 AAC 25033,• 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. Abnormally Pressured Formation Information Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConoccPhillips Alaska, Inc. is on file with the Commission. Surface Intermediate Production 13-1/2" Hole 9-7/8" Hole 6-3/4" Hole 10-3/4" Casing 7-5/8' Casing 4-112" Liner Mud System Spud (WBM) LSND FloPro (WBM Density 8.8-9.5 9.0-9.5 9.0-9.5 ' PV ALAP ALAP ALAP YP 30-80 20-30 15-20 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD N/A N/A Initial Gel 30-50 9-11 7-11 10 minute Gel 30-50 < 20 8-16 API Filtrate NC <6 <6 HTHP Fluid Loss at 160 F N/A <10 <10 H 10.8-11.2 9.5-10.0 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. Abnormally Pressured Formation Information Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConoccPhillips Alaska, Inc. is on file with the Commission. 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 follows. Please refer to attachment for proposed well schematic. Note: Previous operations are covered under the IH -1 03 Application for Permit to Drill. 1. With 6-3/4" bit, motor, GR/Res, and magnets, and drill —200' of new hole in the A3 sand. POOH. 2. Pick up 6-3/4" RSS lateral drilling assembly with GR, Res, periscope and RIH. 3. Drill lateral to A3 Sand, geosteering to the A4 sand and reach TD per directional plan. 4. BROOH to window and circulate clean before coming out and laying down BHA. 5. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 6. Run 4.5" slotted liner with hook hanger and MWD for orientation. POOH with running tools. 7. Make up and run in hole to install LEM (lateral entry module) with ZXP packer. POOH with running tools. 8. Run & set Baker whipstock system, placing the top of the window just below the top of the A4 sand orienting with MWD. 9. Mill 6-3/4" window until top mill across face & clean up window. 10. POOH with milling BHA. 11. PU 6-3/4" bit, motor, MWD (GR/Res), and magnets to perform a clean out run & land the well. 12. RIH, orient through window and tag bottom. 13. End IH -103L1 PTD & begin 1H-1031-2 PTD. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill music be accompanied by each of the follmving items. except for an item already on file with the commission and identified in the application: (14) a general description of how the operalor plmu to dispose of drilling nwd and cuttings and a statement of whether the operator intends to request aulhori_ation 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 11 disposal well at the 1 B Facility. 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 (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placement Attachment 2 Well Schematic Attachment 3 Directional Plan Attachment 4 Drilline Hazards Summary Attachment 5 Cement Summaries Fixed BOP configuration for West Sak Operations Ann Fixed Blind v all Wellhead /T', 5, Head /Trn. 1H Producer Schematic InsulatM GOMuctm 13d/6"s4--'/.", 5,000 ksi Caang, 20",940, DRAFT K55x 12" Tubing Strung 4-1/2", 1360, L-80 TXP WT@ +/-8O MD Gas Lift Ma Artl, 4-12" s V w/dummy valve Ga, Lift MaMrel, 4-i2" a l" of SOV 10-3/4", 45.50, 4`G"SSD wiW 3.812"DB Nipple profile L-80, Hyd563 Permmmr Down Hole Gauge Tubing Scut Aomembly ;e ZXP Packer Landing nipple pmflc 'a—L4"D'Sand Window r 4-Irz",11.60 LBO, 6 -MCD sand lateral Sloncd. \� ------------------------------------------------- rn ,, - L3 "B" Sand Window So'rh Packers l 63W" B sand la¢ral _ 4 Stacked Baker Hook Hanger q.@•Liner, 1164 LN0 [- Lecel 3 Junction Systems______________________________________________________________________________ ___ _____________________•V ZXP Pocker •. L2"A4"SaM Window 63/4"A4 sand Iowal... L I'AY Sand Window \ ••`•, • Laend En, Module \ 4-12'Line, 1160 L80 &W A3 saM lateral _____________ ___________________________________________________________________•, k iTubing Seal Aa..bly •.................... .................. ...........___._._........___. ' g LaAing nipple prafle •. 4-12" Gner, 11.6# LBO 6-3/4" A2 sand 6kra1 ZXP paler Z3/8". 2910, L.M. Hyd563, C5%____________________ 8:28, December 29 2017 1 H -103L1 wp25 c a o pfro u9a e o N 0 10-3/4 330 30 2 . F ^o 0 2000 u9a ' Nja3 330 30 I u9c ugb-- - - .1 6000 9000 12000 Measured Depth Plan: T 54.1+39 @ 93.10usft (Doyon 142) I I 4000 m 00 m 80qA^700 m m 7-5/8" x 9-7/8'jDeoartt a N o L4 ^ Permit Pack 1 p I a n Summa Measured Depth From Depth To aunrey/PMn Tool 39.00 1500 DO 1H-103wy25 (Plan: 1H-103) GYD-GC-SS 1500 UU 18W.00 1 H-103wp25(Plan: 111-103) MWD' IFR -AK-CA-31- 185080 7703.50 11-10% 25 (Man: 111-103) MWD' IFR -AK-CA -aC P0350 800000 1H-109L1wp25 (Plain 1H-ID;LIMWO-INC ONLY 800000 9500.00 111-10311w,25 (Plan. IH-103L1MWD 0000.0014904.31 1H-103L1wp25 (Plan: 1H-103L1MWD+IPR-AK-CAZSC Sec MD Inc 1 7703.50 78.02 2 7716.30 79.93 3773630 79.93 4 7933.26 86.00 5 8074 73 87.00 6 806744 87.51 7 8265.12 87.51 8 9606 70 94.00 99871 94 91.13 1010874.69 91.13 1110903.55 90.00 1210947.62 88.29 1311049.96 68.29 1411135.64 90.00 181239.61 92.08 102214.11 92.08 171227949 92.75 102309.29 92.95 191243377 92.95 202792.83 90.90 2113411.99 90.00 203749.17 90.00 234058.46 90.75 2414216.60 91.27 254904.31 91.27 Minor Risked 3979.54 3983.04 4007.16 401580 4016.41 4024.14 4005.10 3993.19 3973.39 3973.10 3973.76 3976.82 3978.10 3976.21 3940.85 3938.10 3936.62 3930.22 3918.10 3913.15 3913.13 3911.10 3908.31 3893.10 Pad Elevation: 54.10 mu� 87704.50 7 -Sar' x 9 04904.31 41/2" x 6 SECTION DETAILS Target 27 a 330 30 300 6 .1 0 90 240 120 pie 4q rrst '.rr uN�•` 1H-103wp25 13"0 13BJ0 1"20 180 1"20 14904 Magnetic Model & Date: BGGM2017 01 -Apr -18 Magnetic North is 17.18' East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.93° 57472nT LiBialogy Column Annotation KOP: 15.9.1100' DLS, -20° TF, for 12.8' Hold for 20' Start 4°/100' DLS, 40° TF, far 196.98' a°' Adjust TF to -80°, for 14147' „pfro AO1ust TF to -1.16°, for 12.7' Hold for 177.89' t3 Start 4°/100' DLS, -83.18° TF, for 1341.58' 111-1031-1 T03121217 RP Adust TFto-10541-lor26524' m7.e 1 W1 0311 T04 121217 RP 1H-10311 TOS 121217 RP 114-1031-1 TOO 121217 RP iH-1031-1 T07 121217 RP 1H-10311 TOB 121217 RP 1H-10311 709121217 RP i for 1002]5' t 4.1100' DLS, 168.72° TF, for 28.86' isl TF to 165.4-, for 44.07' I for 102.34' t 2.1100' DLS, 0.18° TF, for 85.67' ,at TF to 0.54', for 103.97' I for 974.5' t 3.5°/100 DLS, -72 91° TF, for 65.38' Ist TF to -79.03-, for 29.81' I for 12448' t 4°/100' DLS, -97.92° TF, for 359.06' Ist TF to -91.95°, for 619.16 1 for 337.18' t 3°/100' DLS, -85.36° TF, for 309.29' ,at TF to -83 7', for 158.14' I for 687.71' 14904.31' MD, 3893.1' TVD By 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 collision avoidance plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all taraets have a 100 feet lateral tolerance. V. Osara I lHuv Bui AM I Erik Sterk k15 Compass Workspace 7cr :0 "eC t' 1H-103L1wp25 7703.50 To 14904.31 Spider r10 -04L 03`� 10-04 1 R -O6 1R-05 OW -W IR`9Rb6AL1-O i /1Y-27 —\j 71H-SOUTH R01BL i-011R-21ZB1iR-27 1�f�-Z9�1-07 \1R- 1H,1.L239. 11NN-11(ML43 i1�9a1'Hi 1 01 dd H-19AL1 �7 =1RjL WajP3wp25 H-17 iG-07 H-17 1tk'I%A 1 iH- 19w 22 �j 1H 105 }� L UN 46A B1 IH 4 1H-19AL 1H AL1 7 ilit15wp2 G-108PB1 1H-03 1H 6 1 1N 16wp21 1 - 09wp21 1H-113] 1 4L1-0 1 I-12 11 1H-110wp26 0 L2 p-04 N-13 1G-11 1G -12L SLI 1H• 1p6v 1C- 71C- 0 B- 0G-12 1R -084L1 1H-02 cil®-i1H11#1C 8�11 ; �$ IA -18 1B-14 -10 8-09 PB EasGng (3500 0 10-23 1R --06A 896 1G 16 Q-06 08L a iE 1G IG - 10 -05 0 0 i /1Y-27 —\j 71H-SOUTH R01BL i-011R-21ZB1iR-27 1�f�-Z9�1-07 \1R- 1H,1.L239. 11NN-11(ML43 i1�9a1'Hi 1 01 dd H-19AL1 �7 =1RjL WajP3wp25 H-17 iG-07 H-17 1tk'I%A 1 iH- 19w 22 �j 1H 105 }� L UN 46A B1 IH 4 1H-19AL 1H AL1 7 ilit15wp2 G-108PB1 1H-03 1H 6 1 1N 16wp21 1 - 09wp21 1H-113] 1 4L1-0 1 I-12 11 1H-110wp26 0 L2 p-04 N-13 1G-11 1G -12L SLI 1H• 1p6v 1C- 71C- 0 B- 0G-12 1R -084L1 1H-02 cil®-i1H11#1C 8�11 ; �$ IA -18 1B-14 -10 8-09 PB EasGng (3500 0 1 H-103L1wp25 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 6000 1H -103L1 T09 121217 P /63/'4"' 4 1 �y°j --- 1H -103L1 T08 121217 P 4500 1H -103L1 T07121217 P � 000 1 H-103 Flt - ----- 1H -103L1 T06 121217 0 0 LO_ 1 H -103L1 705 121217 * 1H-103 Flt --- 0 500 ? 1H -103L1 T04 121217 L ^Qpm o --- 1H -103L1 T03121217 PIP 0 20" Y dT ryoo "� 10-3/4" x 13-1/ o -1H- o 103L1 T02 121217 P o -1500 o 1H -103L1 T01 121217 P -3000 -1500 0 1500 3000 4500 6000 7500 9000 West( -)/East(+) (1500 usft/in) 1H-103L1wp25 Section View 20"x47"" 0° 700- 1000 y1400 30° , 3S° n r 10-3/4" x 13-1/ ?000 a2100- 2100?28004000 -22800- -1000 a j M fd 3500 00 60�o O O Z N O 4 1126 6-3114" 7-5/8" x 9-7/8" -1400 -700 0 700 1400 2100 2800 3500 4200 4900 Vertical Section at 0.00° (700 usft/in) 1H-103L1wp25 Section View 3840 _ 0 w r 9 N 3880 4 1/2" x 6-3/4" N o0 A 223920 o 0 3 w � o cn o .off.. 7-5/8" x 9-7/8" 2 t o 0 X3960 0 0 r o =4000 o q p O O O 4040- 040 40801 4080 700 0 700 1400 2100 2800 3500 4200 4900 Vertical Section at 0.000 (700 usft/in) ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: IH -103 Plan: 1 H-1031-1 Plan: 1H-103L1wp25 Report 28 December, 2017 Schlumberger Report Company: ConowPhillips (Alaska) Inc. -Kupl Local Co-ordinate Reference: Well Plan: 1 HA03 Project: Kupawk River Unit TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) . Site: Kupawk 1H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan: 1H-103 North Reference: True - Wellbore: Plan: 1H-1031-1 Survey Calculation Method: Minimum Curvature , Design: 1 H-103L1wp25 Database: OAKEDMP2 Project Kupawk River Unit, North Slope Alaska, United States 73.96 Map System: Phase: System Datum: Mean Sea Level Vertical Section: Depth From (TVD) -NI-S Using Well Reference Point Geo Datum: (usft) (usft) (usft) (°) Map Zone: 39.00 0.00 Using geodetic scale factor Site Kupauk 1H Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 ' Survey Tool Program Date 12/28/2017 From To (usft) (usft) Survey (Wellbore) 39.00 1,500.00 1H-103wp25 (Plan'. IH -103) 1,500.00 1,850.00 1 H-1 03wp25 (Plan: 1 H-1 03) 1,850.00 7,703.50 1 H-1 03wp25 (Plan: 1 H-103) 7,703.50 8,000,00 1H-103L1wp25(Plan: 1H-1031-1) 8,000.00 9,500.00 1 H-1 03LI wp25 (Plan: 1 H-1031-1) 8,000.00 14,904.31 1 H-1 03L I wp25 (Plan: 1 H-1031-1) Planned Survey Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MD Wellbore Well Plan: 1H-103 (usft) (°) (true north_azim Magnetics Model Name Sample Date Well Position +N/S usft Northing: usft Latitude: +E/ -W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: usft Ground Level: - 54.10 usft Survey Tool Program Date 12/28/2017 From To (usft) (usft) Survey (Wellbore) 39.00 1,500.00 1H-103wp25 (Plan'. IH -103) 1,500.00 1,850.00 1 H-1 03wp25 (Plan: 1 H-1 03) 1,850.00 7,703.50 1 H-1 03wp25 (Plan: 1 H-103) 7,703.50 8,000,00 1H-103L1wp25(Plan: 1H-1031-1) 8,000.00 9,500.00 1 H-1 03LI wp25 (Plan: 1 H-1031-1) 8,000.00 14,904.31 1 H-1 03L I wp25 (Plan: 1 H-1031-1) Planned Survey Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MD Wellbore Plan: 1H-1031-1 (usft) (°) (true north_azim Magnetics Model Name Sample Date Declination Dip Angle Field Strength 0.00 7,704.50 78.17 74.61 7-518" x 9-7/8" BGGM2017 4/1/2018 -20.00 17.18 80.93 57,472 Design 1H-103L1wp25 Hold for 20' -19.99 Audit Notes: 7,736.30 79.93 73.96 Version: Phase: PLAN Te On Depth: 7,703.50 Vertical Section: Depth From (TVD) -NI-S +EI -W Direction (usft) (usft) (usft) (°) 39.00 0.00 0.00 0.00 Survey Tool Program Date 12/28/2017 From To (usft) (usft) Survey (Wellbore) 39.00 1,500.00 1H-103wp25 (Plan'. IH -103) 1,500.00 1,850.00 1 H-1 03wp25 (Plan: 1 H-1 03) 1,850.00 7,703.50 1 H-1 03wp25 (Plan: 1 H-103) 7,703.50 8,000,00 1H-103L1wp25(Plan: 1H-1031-1) 8,000.00 9,500.00 1 H-1 03LI wp25 (Plan: 1 H-1031-1) 8,000.00 14,904.31 1 H-1 03L I wp25 (Plan: 1 H-1031-1) Planned Survey Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MD Inc Azi (usft) (°) (true north_azim 7,703.50 78.02 74.67 KOP: 15.9°1100' DLS, -20' TF, for 12.8' 0.00 7,704.50 78.17 74.61 7-518" x 9-7/8" 15.90 -20.00 7,716.30 79.93 73.96 Hold for 20' -19.99 27.90 7,736.30 79.93 73.96 Tool Name Description GYD-GC-SS Gyrodata gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD -INC -ONLY MWD-INC_ONLY_FILLER MWD MWD- Standard MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC TVD TVDSS DLeg TFace Lat. Error (usft) (usft) ('Mo0usft) (°) (usft) 3,977,10 3,884 00 0.00 0.00 27.90 3,977.30 3,884.20 15.90 -20.00 27.90 3,979.54 3,886.44 15.90 -19.99 27.90 3,983.04 3,889.94 0.00 0.00 27.90 122&2017 12:48:38PM Page 2 COMPASS 5000.14 Build 85 Company: ConomPhillips (Alaska) Inc. -Kupt Project: Kuparuk River Unit Stte: Kuparuk 1 H Pad Well: Plan: 11-1-103 Wellbore: Plan: 1H -103L1 Design: 1H-103L1wp25 Manned Survey 8,000.00 86.47 MD Inc Azi (usft) (°) (true_north azim 7,800.00 81.89 72.31 7,842.02 83.18 7122 a2 87.51 Start 4°1100' DLS, -83.18° TF, for 1341.58' 7,900.00 84.97 69.74 7 933 26 8600 68.89 Adjust TF to -80°, for 141.47' 8,000.00 86.47 8,074.73 87.00 Adjust TF to -1.16°, for 12.7' (usR) 8,087.44 87.51 Hold for 177.69' 3,993.10 8,100.00 87.51 8,200.00 87.51 8,265.12 87.51 Start 4°1100' DLS, -83.18° TF, for 1341.58' 8,300.00 87.67 8,400.00 88.16 8,500.00 88.65 8,600.00 89.15 8,700.00 89.65 8,800.00 90.16 8,900.00 90.66 9,000.00 91.16 9,100.00 91.66 9,200.00 92.15 9,300.00 92.62 9,400.00 93.09 9,500.00 93.54 9,600.00 93.97 9,606.70 94.00 Adjust TF to -106.41°, for 265.24' 9,700.00 93.00 9,800.00 91.92 9,871.94 91.13 Hold for 1002.75' 3,937.28 9,900.00 91.13 10,000.00 91.13 10,100.00 91.13 10,200.00 91.13 10,300.00 91.13 10,400.00 91.13 10,500.00 91.13 10,600.00 91.13 10,700.00 91.13 In Ann nn 91.13 66.26 63.31 63.30 63.30 63.30 63.30 61.92 57.94 53.97 50.00 46.03 42.07 38.10 34.13 30.16 26.19 22.21 18.23 14.25 10.27 10.00 6.40 2.54 359.77 359.77 359.77 359.77 359.77 359.77 359.77 359.77 359.77 359.77 359.77 Schlumberger Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 1H-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usit (Doyon 142) True Minimum Curvature OAKEDMP2 TVD TVDSS DLeg TFace Lat. Error (usR) (usR) (°1100usft) (°) (usR) 3,993.10 3,900.00 4.00 -40.00 27.55 3,998.56 3,905.46 4.00 -39.74 27.40 4,004.54 3,911.44 4.00 -39.60 27.40 4,007.16 3,914.06 4.00 -39.44 27.60 4,011.54 3,918.44 4.00 -80.00 27.69 4,015.80 3,922.70 4.00 -79.83 27.35 4,016.41 3,923.31 4.00 -1.16 27.44 4,016.96 3,923.86 0.00 0.00 27.53 4,021.31 3,928.21 0.00 0.00 28.28 4,024.14 3,931.04 0.00 0.00 28.81 4,025.60 3,932.50 4.00 -83.18 28.69 4,029.24 3,936.14 4.00 -83.13 28.29 4,032.03 3,936.93 4.00 -82.98 27.84 4,033.95 3,940.85 4.00 -82.87 27.34 4,034.99 3,941.89 4.00 -82.79 26.80 4,035.15 3,942.05 4.00 -82.75 26.23 4,034.44 3,941.34 4.00 -82.75 25.62 4,032.84 3,939.74 4.00 -82.77 24.98 4,030.38 3,937.28 4.00 -82.84 24.33 4,027.05 3,933.95 4.00 -82.94 23.67 4,022.89 3,929.79 4.00 .83.07 23.02 4,017.90 3,924.80 4.00 -83.23 22.38 4,012.12 3,919.02 4.00 -83.43 11.26 4,005.57 3,912.47 4.00 -83.66 10.47 4,005.10 3,912.00 4.00 -83.92 10.43 3,999.40 3,906.30 4.00 -105.41 10.02 3,995.11 3,902.01 4.00 -105.63 9.93 3,993.19 3,900.09 4.00 -105.80 10.12 3,992.64 3,899.54 0.00 0.00 10.17 3,990.67 3,897.57 0.00 0.00 10.29 3,988.69 3,895.59 0.00 0.00 10.43 3,986.71 3,893.61 0.00 0.00 10.61 3,984.74 3,891.64 0.00 0.00 10.82 3,982.76 3,889.66 0.00 0.00 11.05 3,980.79 3,887.69 0.00 0.00 11.30 3,978.81 3,885.71 0.00 0.00 11.59 3,976.84 3,883.74 0.00 0.00 11.89 3,974.86 3,881.76 0.00 0.00 12.21 1228201712:48:38PM Page 3 COMPASS 5000.14 Build 85 Schlumberger Report Company: ConocoPhillips (Alaska) Inc. -Kupi Local Coordinate Reference: Well Plan: 1H-103 Project: Kupawk River Unit TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan'. IH -103 North Reference: True Wellbore: Plan'. 1H -103L1 Survey Calculation Method: Minimum Curvature Design: 1 H-103Liwp25 Database: OAKEDMP2 Planned Survey MD Inc Azi TVD TVDSS DLeg TFace Lat. Error (usft) (°) (true -north azim (usft) (usft) (°1100usft) (') (usft) 10,874.69 91.13 359.77 3973.39 3,880.29 0.00 0.00 12.47 Stan 4°1100' DLS, 168.72° TF, for 28.86' 10,900.00 90.14 359.97 3,973.10 3,880.00 4.00 168.72 12.52 10,903.55 90.00 0.00 3,973.10 3,880.00 4.00 168.72 12.53 Adjust TF to 166.4°, for 44.07' 10,947.62 88.29 0.41 3,973.76 3,880.66 4.00 166.40 12.56 Hold for 102.34' 11,000.00 88.29 0.41 3,975.33 3,882.23 0.00 0.00 12.64 11,049.96 88.29 0.41 3,976.82 3,883.72 0.00 0.00 12.83 Stan 2°/100' DLS, 0.18° TF, for 85.67' 11,100.00 89.29 0.42 3,977.88 3,884.78 2.00 0.18 13.01 11,135.64 90.00 0.42 3,978.10 3,885.00 2.00 0.18 13.14 Adjust TF to 0.64°, for 103.97' 11,200.00 91.29 0.43 3,977.38 3,884.28 2.00 0.54 13.39 11,239.61 92.08 0.44 3,976.21 3,883.11 2.00 0.54 13.55 Hold for 974.5' 11,300.00 92.08 0.44 3,974.02 3,880.92 0.00 0.00 13.78 11,400.00 92.08 0.44 3,970.39 3,877.29 0.00 0.00 14.19 11,500.00 92.08 0.44 3,966.77 3,873.67 0.00 0.00 14.61 11,600.00 92.08 0.44 3,963.14 3,870.04 0.00 0.00 15.04 11,700.00 92.08 0.44 3,959.51 3,866.41 0.00 0.00 15.48 11,800.00 92.08 0.44 3,955.88 3,862.78 0.00 0.00 15.93 11,900.00 92.08 0.44 3,952.25 3,859.15 0.00 0.00 16.39 12,000.00 92.08 0.44 3,948.62 3,855.52 0.00 0.00 16.85 12,100.00 92.08 0.44 3,945.00 3,851.90 0.00 0.00 17.32 12,200.00 92.08 0.44 3,941.37 3,848.27 0.00 0.00 17.80 12,214.11 92.08 0.44 3,940.85 3,847.75 0.00 0.00 17.87 Start 3.5°/100' DLS, -72.91° TF, for 66.38' 12,279.49 92.75 358.25 3,938.10 3,845.00 3.50 -72.91 17.85 Adjust TF to -79.03°, for 29.81' 12,300.00 92.89 357.54 3,937.09 3,843.99 3.50 -79.03 17.85 12,309.29 92.95 357.22 3,936.62 3,843.52 3.50 -79.07 17.85 Hold for 124.48' 12,400.00 92.95 357.22 3,931.95 3,838.85 0.00 0.00 18.25 12,433.77 92.95 357.22 3,930.22 3,837.12 0.00 0.00 18.41 Start4°/100' DLS, -97.92° TF, for 359.06' 12,442.13 92.90 356.89 3,929.79 3,836.69 3.99 -97.92 18.38 a3 12,500.00 92.58 354.60 3,927.02 3,833.92 4.00 -97.93 18.38 12,600.00 92.01 350.63 3,923.01 3,829.91 4.00 -98.04 18.40 12,700.00 91.44 346.67 3,920.00 3,826.90 4.00 -98.20 18.60 12,792.83 90.90 343.00 3,918.10 3,825.00 4.00 -98.32 18.93 Adjust TF to -91.96°, for 619.16' 12,800.00 90.89 342.71 3,917.99 3,824.89 4.00 -91.95 18.97 12,900.00 90.75 338.72 3,916.55 3,823.45 4.00 -91.95 19.50 13,000.00 90.61 334.72 3,915.37 3,822.27 4.00 -92.01 20.17 12/28/2017 12:48:38PM Page 4 COMPASS 5000.14 Build 85 Company: Con000Phillips (Alaska) Inc. -Kupl Well Plan: 1H-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature OAKEDMP2 Project: Kuparuk River Unit TVD TVDSS Site: Kupawk 1H Pad TFace Lat. Error Well: Plan: 11-1-103 (usft) (°/t00usft) Wellbore: Plan: 1H -103L1 (usft) 3,914.43 Design: 1 HA 03L1wp25 4.00 -92.06 Planned Survey 3,91374 3,820.64 MD Inc Azi 21.79 (usft) V) (true _north azim 13,100.00 90.47 330.72 13,200.00 90.32 326.72 13,300.00 90.17 322.73 13,400.00 90.02 318.73 13,411.99 90.00 318.25 Hold for 337.18' 23.88 3,913.14 13,500.00 90.00 318.25 13,600.00 90.00 318.25 13,700.00 90.00 318.25 13,749.17 90.00 318.25 Start 3'/100' DLS, $5.36° TF, for 309.29' 0.00 13,800.00 90.13 316.73 13,900.00 90.37 313.74 14,000.00 90.61 310.75 14,058.46 90.75 309.00 Adjust TF to -83.7°, for 188.14' 0.00 14,100.00 90.89 307.76 14,200.00 91.21 304.78 14,216.60 91.27 304.28 Hold for 687.71' 14,300.00 91.27 304.28 14,400.00 91.27 304.28 14,500.00 91.27 304.28 14,600.00 91.27 304.28 14,700.00 91.27 304.28 14,800.00 91.27 304.28 14,900.00 91.27 304.28 14,904.31 91.27 304.28 TD: 14904.31' MD, 3893.1' TVD - 41/2" x 6-3/4" A Schlumberger Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 1H-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature OAKEDMP2 3.00 TVD TVDSS DLeg TFace Lat. Error (usft) (usft) (°/t00usft) (°) (usft) 3,914.43 3,821.33 4.00 -92.06 20.94 3,91374 3,820.64 4.00 -92.09 21.79 3,913.32 3,820.22 4.00 -92.12 22.70 3,913.15 3,820.05 4.00 -92.14 23.64 3,913.15 3,820.05 4.00 -92.14 23.76 3,913.14 3,820.04 0.00 0.00 23.88 3,913.14 3,820.04 0.00 0.00 24.04 3,913.14 3,820.04 0.00 0.00 24.22 3,913.13 3,820.03 0.00 0.00 24.31 3,913.08 3,819.98 3.00 -85.36 24.67 3,912.65 3,819.55 3.00 -85.36 25.36 3,911.79 3,818.69 3.00 -85.37 26.05 3,911.10 3,818.00 3.00 -85.40 26.44 3,910.51 3,817.41 3.00 -83.70 26.71 3,908.67 3,815.57 3.00 -83.72 27.35 3,908.31 3,815.21 3.00 -83.77 27.46 3,906.47 3,813.37 0.00 -132.52 27.55 3,904.26 3,811.16 0.00 0.00 27.68 3,902.04 3,808.94 0.00 0.00 27.81 3,899.83 3,806.73 0.00 0.00 27.96 3,897.62 3,804.52 0.00 0.00 28.12 3,895.41 3,802.31 0.00 0.00 28.30 3,893.20 3,800.10 0.00 0.00 28.48 3,893.10 3,800.00 0.00 0.00 28.49 121282017 12: 48: 38PM Page 5 COMPASS 5000.14 Build 85 Company: ConowPhillips (Alaska) Inc. -Kupl Project: Kupamk River Unit Site: Kupawk 1H Pad Well: Plan: IH -103 Wellbore: Plan: iH-10311 Design: 1H-103L1wp25 Casing Points Formations Schlumberger Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 11-1-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature OAKEDMP2 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (usft) (usft) 7,704.50 3,977.30 7-5/8" x 9-7/8" 7-5/3 9-7/8 14,904.31 3,893.10 41/2"x6-3/4" 4-1/2 8-3/4 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology, 12,442.13 3,929.79 a3 7,842.02 3,998.56 a2 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/4 +E/.W (usft) (usft) (usft) (usft) Comment 7,703.50 3,977.10 -938.99 5,400.68 KOP. 15.9°/100' DLS, -20° TF, for 12.8' 7,716.30 3,979.54 -935.59 5,412.78 Hold for 20' 7,736.30 3,983.04 -930.15 5,431.70 Start 4°/100' DLS, -40°TF, for 196.96' 7,933.26 4,007.16 -867.88 5,616.84 Adjust TF to -80°, for 141.47' 8,074.73 4,015.80 -810.70 5,745.88 Adjust TF to -1.18°, for 12.7' 8,087.44 4,016.41 -805.00 5,757.22 Hold for 177.69' 8,265.12 4,024.14 -725.25 5,915.81 Start 4°/100' DLS, -63.18° TF, for 1341.58' 9,606.70 4,005.10 311.76 6,688.02 Adjust TF to -105.41°, for 265.24' 9,871.94 3,993.19 575.39 6,710.53 Hold for 1002.75' 10,874.69 3,973.39 1,577.94 6,706.58 Start 4°/100' DLS, 168.72° TF, for 28.86' 10,903.55 3,973.10 1,606.79 6,706.52 Adjust TF to 166.4°, for 44.07' 10,947.62 3,973.76 1,650.86 6,706.68 Hold for 102.34' 11,049.96 3,976.82 1,753.16 6,707.42 Start 2°/100' DLS, 0.18'TF, for 85.67' 11,135.64 3,978.10 1,838.81 6,708.05 Adjust TF to 0.54°, for 103.97' 11,239.61 3,976.21 1,942.76 6,708.83 Hold for 974.5' 12,214.11 3,940.85 2,916.59 6,716.30 Start 3.5°/100' DLS,-72.91"TF, for 65.38' 12,279.49 3,938.10 2,981.90 6,715.55 Adjust TF to -79.03°, for 29.81' 12,309.29 3,936.62 3,011.64 6,714.38 Hold for 124.48' 12,433.77 3,930.22 3,135.81 6,708.36 Start 4°/100' DLS, -97.92° TF, for 359.06' 12,792.83 3,918.10 3,488.41 6,646.87 Adjust TF to -91.95°, for 619.16' 13,411.99 3,913.15 4,023.75 6,345.52 Hold for 337.18' 13,749.17 3,913.13 4,275.30 6,120.99 Start 3°/100' DLS, -85.36° TF, for 309.29' 14,058.46 3,911.10 4,488.45 5,897.35 Adjust TF lo -83.7', for 158.14' 14,216.60 3,908.31 4,582.79 5,770.52 Hold for 687.71' 14,904.31 3,893.10 4,970.07 5,202.43 TO: 14904.31' MD, 3893.1' TVD I Checked By: Approved By: Date: 1212812017 12: 48 38P Page 6 COMPASS 5000.14 Build 85 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-103 Plan: 11-1-1031_1 50103xxxxx00 1H-103L1wp25 ConocoPhillips Clearance Summary Anticollision Report 29 December, 2017 Subject wellbore 1H-1031_1 has close approach on Motherbore 1H-103 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk lH Pad -Plan: 1H -103 -Plan: 1H-1031-1-1H-103L1wp25 Well Coordinates: Datum Height: Plan: 51.1+39@ 93.10usf1( Doyon 142) Scan Range: 7,703.50 to 14,904.31 usfl. Measured Depth. Scan Radius is 1,686.53 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: All Wrellpams Within 20U+ 10011000 of reference Scan TYPe: 25.00 ConocoPhillips E.:: (. 1.... ConocoPhillips Anticollision Report for Plan: 111403 -1 H-103L1wp25 ConocoPhillips (.Alaska) Inc. -1ji Kuparuk River Unit Tran. Cylinder North Proximity sun on Current survey Data (North Reference) 1018.08 13,584.85 863.16 Reference Design: Kuparok lH Pad -Plan: 114 -103 -Plan: 1H-103L1-111-1031.1Wp25 6.572 Clearance Factor Pass - Scan Range: 7,703.50 to 14.904.31 usft. Measured Depth. 14,901.95 1,657.05 14,01.95 Scan Radius is 1,686.53 usft. Clearance Factor Cutoff Is Unlimited. Max Ellipse separation is UnOmtted 11675.00 9.273 Measured Minimum ®Measured Ellipse QMeasured 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 I Pad 1 H45 -1H -105-1H-105 1H-102-1H-1021.1-iH-10211 1H -111-1H-111-11+111 1H -13-1H-13-1013 Plan: 11 -1 -103 -Plan: 114103-111.103wp25 Plan: 1H-103- Plan :11+103 - IH403wp25 Plan: iH-104 - Plana H-104 -111-1 Wwp21 Plan :1 H -IDA- Plan :11+104L1- 114-1041.1wp22 Plan:111-IDA-Man:1H-104L3-1H-104L3wp22 Plan: 11+110 -Plan: 11-1-110 -1H.110"26 Plan: 11+110 -Plan: IH -110 -1 1-1-1100p26 Plan: 11.113 -Plain 11+113-111-113wp22 Plan: 111 -113 -Plan 11+113 -1 H-113wp22 Plan: 1 H-115 - P Wm:1 & 115 -1 H-115wp21 Plan 1 H-115 - Plan: 11+115 -1 H-115w1a21 Plan: iH-116-Plan; I1+l16-1H-116Wp21 13,584.85 1018.08 13,584.85 863.16 9,025.00 6.572 Clearance Factor Pass - Major Risk 14,901.95 1,657.05 14,01.95 1,478.35 11675.00 9.273 Clearance Factor Pass - Major Risk 9411.23 735.65 9411.23 597.99 8050.00 5.344 Clearance Factor Pass - Major Risk 7,707.93 1,185.70 7,707.93 1.016.66 770.00 7.015 Clearance Factor Pass - Major Risk 8,01963 38.51 8.019.63 29.07 8,025.00 4.082 Centre Distance Pass - Major Risk 11,514.07 79.20 11,514.07 11.48 11,70.00 1.169 Cleamnce Factor Pass - Major Risk 7,707,29 1,672.48 7,70739 1,400.80 10.57500 8,725 Clearance Factor Pass - Major Risk 7.708.58 1,673.80 7,708.58 1,480.96 10,575.00 8.680 Clearance Factor Pass - Major Risk 7,706.13 1,684.85 770.13 1473.54 10,575.00 7.973 Clearance Factor Pass - Major Risk 8,174.71 704.03 8,174.71 55737 8,375.00 3.458 Centre Distance Pass - Major Risk 8,265.12 784.79 8,265.12 552.70 8,475.00 3.381 Clearance Factor Pass - Major Risk 9,693.20 557.37 9,693.20 449.94 8,550.00 5.188 Centre Distance Pass - Major Risk 9,696.32 $57.76 9,695.32 449.69 8,575.00 5.161 Clearance Factor Pass - Major Risk 11,502.63 255.19 11,502.63 145.67 8,900.00 2.330 Centre Distance Pass - Major Risk 11,510.46 255,54 11,510.46 143.94 0,925.00 2.290 Clearance Factor Pass - Major Risk 11,207.31 868.76 11,207.31 756.49 0250.00 7.603 Clearance Factor Pass -Major Risk 29Docent 017- 823 Papa 20f5 COMPASS ConocoPhillips Anticollision Report for Plan: 1 H-103 -1 H-1O3L1wp25 Survey tool oroaram From To SurveylPlan Survey Tool Was) luanl 39.00 1,500.00 GYDG S 1,500.00 1,850Ao MND+IFR-AK-CAZSC 1,850.00 ].703.50 MWD+IFR-AK-CAZSC 7,703.50 8,000.00 1W10311,vaH MWD4NCONLY a00D.00 9500.0 1&10311"25 MWD B4OOo.OU 14,904.31 1131031-1wp25 MWD+IFR-AK-CAZSC Ellipse emor terms are wmNated names survey tool tleo-on points. Calculated ellipse incorporate surface emirs. Sepration is the actual distance beheaen stipends. Distance Between centres is the sunlight line distance betvreen wellbore canoes. Clearance Factor= Distance Between profiles I (Distance Beemsen Prpfles- Ellipse Separation). All station woNinates were calculated using the Minimum Curvature method. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 29 Decembeq 2017- 833 Page 3 f COMPASS ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-103 Plan: 1H -103L1 50103xxxxx00 1H-103L1wp25 ConocoPhillips Clearance Summary Anticollision Report 29 December, 2017 Trsv. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Besig¢ Kuparuk 1 Pad - Plan :1H -003 -Plan: 1H-103L1-1H-10311wp25 Well Coordinates: Datum Height: Plan: 56.1+39@091)Doyon 142) Scan Range: 7,703.50 to 14,904.31 haft. Measured Depth. Scan Radius is 1,686.53 heft. Clearance Factor today is Unlimited. Max Ellipse Separation is Unlimited Geodetic Sale Factor Applied Version 5000.14 Build: 85 Scan Type: GLOBAL FILTER APPLIED: NI aiellpethi vnthin 200'+ 10011000 of reletence Scan Type: 25.00 Minor Risked Motherbore 1H-103 minor risked 1/50 ConocoPhillips ConocoPhillips Anticollision Report for Plan: 11-1-103-1H-103L1wp25 ConocaPkillips (Alaska) Inc. -Kupl Kuparuk River Unit Tmv. Cylinder Narth Proximity Scan on Common Survey Data (North Reference) 1,01808 13,584.85 863.16 Reference Design: sutures 1H Pad - Plan: 1111-103. Plan: 11-1-1031.1 - 11+10 311%,25 6.572 Cannan. Factor Pass - Major Risk Scan Range: 7,703.501. 14,90,1311 ua& Measured Depth. 14,901.95 1,657.05 14,901.95 Scan Radius is 1,886.53 ust. Clearance Factor Cutoff R Unllmi.E. Max Ellipae Separation is Unlimited 11,675.00 9.273 Clearer. Factor Measured Minimum @Measured Wines @Measured distance Summary Rased on She Name Depth Distance Depth Separml.. Depth Fodor Minimum separation Warning Comparison Well Name - Wellbore Name - Design lust) lain) (..ft) (usft) man Kuparuk I Pad 1H -05-1H-105-1 H-105 1H -102 -1H -102L1 -1H -102L1 1H-111 -1 H-111 -1H-111 1H-13-iH-13-1H-13 Plan: 1H -103 -Plan: 1 H-103-iH-103vry25 Plan : 11-1-104-PIan: 1H-104-1H-101vg21 Plan : l HAA- Plan:1 H -104L1-1 H-104L1%p22 Plan :1H-104- Plan :1H -104L3 -1H-1041_3%,22 Plan: 11.110 -Plan: 11-1-110 -1 HAl0%p26 Plan : 1H-110-PIan:1H-110-iH-110%p26 PIan. 11.113-PIam1H-113-1H-113"22 Plan : 11-113-PIan: 1H -113-1H-113%,22 PIan:1 H-115 - P1an:1 HA l5 -1 H-115.,21 Plan: 1H-115-Pkn:1H-115-1H-115vg21 Plan : 11-116 - Plan: t H-116 -1H-116%,21 Survey toot oroorarn 13,584.85 1,01808 13,584.85 863.16 9,025.00 6.572 Cannan. Factor Pass - Major Risk 14,901.95 1,657.05 14,901.95 1,478.35 11,675.00 9.273 Clearer. Factor Pass - Major Risk 1141031.1un25 9,411.23 735.65 9,411.23 597.99 8,050.00 5344 Clearance Factor Pass - Major Risk 7,70793 1,185]0 7,707.93 1.016.66 7,700.00 7.015 Clearance Factor Pas. - Major Risk 8,019.63 38.51 8,019.63 34.22 8,025.00 8.988 Clearance Fader Pass - Minor 1150 IGar M4kN 7,707.29 1,672.48 7.707.29 1,480.80 10,575.00 8.725 Clearance Factor Pass - Major Risk 7,708.58 1,673.80 7,708.58 1,480.96 10,575.00 0.680 Clearance Factor Pass - Major Risk 7,70613 1,684.85 7,706.13 1,473.54 10,575.00 7.973 Clearance Fodor Pass - Major Risk 8,174.71 784.03 8,174.71 557.27 8,375.00 3.458 Gere Distance Pass - Major Risk 8,265.12 784.79 0,265.12 552.70 8,475.00 3.381 Clearance Fodor Pass - Major Risk 9,693.20 557.37 9,693.20 449.94 8,550.00 5.188 Centre Distance Pass - Major Risk 9.696.32 557.76 9,696.32 449.69 8,575.00 5.161 Clearance Factor Pass - Major Risk 11,502.63 255.19 11,502.63 145.67 6900.0 2.330 Cant. Distance Pass - Major Risk 11,510.48 255.54 11,510.48 143.94 6925.00 2.290 CMa.n. Factor Pass - Major Risk 11,207.31 868]6 11,207.31 754.49 8,250.00 7.603 Clean. Packer Pass - Major Risk From To loan) (ustl 39.00 1,500.00 1,500.00 1,850.00 1,850.00 7.703.50 7]03.50 8,000.00 1141031.1un25 8,00600 9,500.00 11140311%,25 8.000.00 14,904.31 1141031.1%p25 SumeylPMn Surrey Tool GYOGCSS MWWIFR-AK-CPZSC MW9+IFR-AK-CPZSC Maui ONLY Mm MM.IFR-AK-CAL-SC 290ecembe, 2017- 8:21 Pan i5 COMPASS ConocoPhillips Anticollision Report for Plan: iH-103-1H-103L1wp25 Ellipse errortetms arc [malates ace as survey loci lie -on paints. Celmlated antes. incorporate surface enors. Separation is Me actual distance Canteen ellipsoids. Distance Between centres is Me straight line distance between wellbore centres. Clearance Factor= Distance Bentsen Perles / (Distance Between Proles- Ellipse Separation). All station worainates were calculated using Me Minimum Curatum method. ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit 29 Decamber, An - 8.21 Page 3 05 COMPASS 12A1,D .Mler 28201] 1 H -103L1 wp25 Ladder View N d N m O h _ 300— .2 i00 m U c m U 0 2100 c v U 0 8550 9500 10450 11400 12350 13300 14250 Measured Depth SURVEY PROGRAM CASING ETAILS Depth FrdDepth To Survey/Plan Tool TVD MD Name 39.00500.00 1H-103wp25 (Plan: 11H©103�GC-SS 3977.x'804.50'-5/8" x 9-7/8" 1500.00850.00 1H-103wp25 (Plan: 1HRA'0M+IFR-AK-CAZ-SC 389341904.3141/2"x6-3/4" 1850.00703.50 1H-103wp25 (Plan: 1HM22P+IFR-AK-CAZ-SC 7703.50000.00 1H-103L1wp25 (Plan: MWDaUQ_ONLY 8000.00500.00 1H-103L1wp25 (Plan: MWD31-1) 8000.04904.31 1H-103L1wp25 (Plan: MWD -3 HF1 -AK-CAZ-SC N 6 3 O J 1 060 I m n at ro c N 030 � I N Equivalent Magnetic Distance 8100 8550 9000 9450 9900 10350 10800 Partial Measured Depth CA o cemtrer 29 201: 1 H -103L1 wp25 Ladder View N Minor Risked N N S y 30 - o `1200 n c 1 � U 0 0100_ 1 U - 0 8550 9500 10450 11400 12350 13300 14250 Measured Depth SURVEY PROGRAM ASING DETAILS Depth Frobepth To Survey/Plan Tool TVD MD Name 39.00500.00 1H-103wp25 (Plan: 1H©'66JtGC-SS 3977.2x04.50? -5/8" x 9-7/8" 1500.00850.00 1H-103wp25 (Plan: 1HMVIP+IFR-AK-CAZ-SC 389391304.314 1/2" x 6-3/4" 1850.00703.50 1 H-103wp25 (Plan: 1 HMVM+IFR-AK-CAZ-SC 7703.50000.00 1H-103L1wp25 (Plan: MWDabp—ONLY 8000.08500.00 1H-103L1wp25 (Plan: MiND31-1) 8000.@9904.31 1H-103L1wp25 (Plan: MM33M-AK-CAZ-SC N N d 3 M O 060 1 1 GoQ W IE 030 0 d y Equivalent Magnetic Distance 0- 8100 8550 9000 9450 9900 10350 10800 Partial Measured Depth �•�. '•,• :111 11• 11 11 . • �. •• .•� •• • • :111 i.Er•1• . ; ... ,:. •• 1• 1 1 1 1, 1• •1 :•1 :1 1 1/ •1 .1 :1 1 .1 .1 1 •1 1 •1 1 / 1 •111 1 • 11 IRWIN- • 11 1 'J 4Awo �r moi.....•..,---_ �.�•,.,, r�1JY�Lw.N♦ , . 9•,�� a � ,..,,Agm ?5 •j��,,•�•,o•;p:• ,:••=••,�•II',� ''''�i'a j �►e� ►l 1 %I►'�l vl''l I �'�I,�I 11rV �i,1,, I,1��,�'If+,�,,_�.�. �.. icv _........ 1 1 111 �►. lrlh,.illl ,.; ,AN DEEPER, ,�.•� ,1,l��� X1/ . �M� ` 4 3 �1�p,`� \ R, •�� Y��` e,�1 e • 1 : 1 S l �I,�\.����1��•�;,�� �,I♦y.�.\ ���I�i�i,��I�I��•I%I�1�11,1���• `,S/��m�.11��411�7 m f�V1lIPlAls��a�•iO A�1 wi'.:!v �� � . 1 1 Y,�lilt _ 1 13440 1 . � ' wv�wvvvvv v♦ O� a.Miss 13440 13930 13930 14420 o\ 1 / • 1 1 „... —� �p 1 :1 B:JJ, December Z9 20tt 1 H -103L1 wp25 TC View SURVEY PROGRAM MD Inc Av TVD Dleg TFace Target Annotation Depth Frol®epth To TOOT 7703.50 78.02 74.67 3977.10 0.00 0.00 KOP: 15.9°/100DLS, -20° TF, for 12.8' 39.00 500.00 GYD-GC-SS 7716.30 79.93 73.96 3979.54 15.90 -20.00 Hold for 20' 7736.30 79.93 73.96 3983.04 0.00 0.00 Start 4°/100' DLS, -40' TF, for 196.96' 1500.001850.00 MWD+IFR-AK-CAZ-SC 7933.26 86.00 68.89 4007.16 4.00 -40.00 Adjust TF to -80°, for 141.47' 1850.007703.50 MWD+IFR-AK-CAZ-SC 8074.73 87.00 63.31 4015.80 4.00 -80.00 Adjust TF to -1.16°, for 12.7 8087.44 87.51 63.30 4016.41 4.00 -1.16 Hold for 177.69' 7703.503000.00 MWD -INC ONLY 8265.12 87.51 63.30 4024.14 0.00 0.00 Start 4-1100'DLS, -83.18°TF, for 1341.8 8000.008500.00 MWD 9606.70 94.00 10.00 4005.10 4.00 -83.18 1H-103LI T03121217 RP Adjust TF to -105.41°, for 265.24' 9871.94 91.13 359.77 3993.19 4.00 -105.41 Hold for 1002.75' 8000.01(11904.31 MWD+IFR-AK-CAZ-SC 874.69 91.13 359.77 3973.39 0.00 0.00 Start 4'/100'DLS, 168.72* TF, for 28.86 903.55 90.00 0.00 3973.10 4.00 168.72 1H-1031-1 704121217 RP Adjust TF to 166.4°, for 44.07' 947.62 88.29 0.41 3973.76 4.00 166.40 Hold for 102.34' 049.96 88.29 0.41 3976.82 0.00 0.00 Start 2'/100' DLS, 0.18° TF, for 85.67' 135.64 90.00 0.42 3978.10 2.00 0.18 1H-1031-1 705 121217 RP Adjust TF to 0.54°, for 103.97' 239.61 92.08 0.44 3976.21 2.00 0.54 Hold for 974.5' 214.11 92.08 0.44 3940.85 0.00 0.00 Start 3.5'/100' DLS, -72.91° TF, for 65.3 ' 279.49 92.75 358.25 3938.10 3.50 -72.91 iH-1031-1 T06121217 RP Adjust TF to -79.03°, for 29.81' 309.29 92.95 357.22 3936.62 3.50 -79.03 Hold for 124.48' 433.77 92.95 357.22 3930.22 0.00 0.00 Start 4°/100' DLS, -97.92° TF, for 359.0 792.83 90.90 343.00 3918.10 4.00 -97.92 iH-1031-1 T07121217 RP Adjust TF to .91,95', for 619.16' CASING DETAILS 411.99 90.00 318.25 3913.15 4.00 -91.95 Hold for 337.18' 749.17 90.00 318.25 3913.13 0.00 0.00 Start 3'/100' DLS, -85.360 TF, for 309.2 ' 058.46 90.75 309.00 3911.10 3.00 -85.36 iH-1031-1 T08121217 RP Adjust TF to .83.7', for 158.14' TVD MD Name 4216.60 91.27 304.28 3908.31 3.00 -83.70 Hold for 687.71' 3977.287704.50 7-5/8" x 9-7/6" 904.31 91.27 304.28 3893.10 0.00 0.00 1H-10311709121217 RP TD: 149D4.31'MD, 3893.1'TVD 3893.1D4904.31 4 1/2" x 6-3/4" Minor Risked 0 330 30 0 7704 12 7704 - 7890 7890 - 8070 300 90 60 8070 - 8260 8260 - 8440 8440 - 8630 60 8630 - 8810 8810 9000 3 9000 - 9250 9250 9500 270 90 9500 - 9750 9750 - 10000 10000 10250 3 10250 - 10500 10500 - 10750 60 10750 - 11000 11000 - 11490 11490 - 11980 240 120 11980 - 12460 IH -103W 2 12460 12950 P 12950 -- 13440 WmrRlNtad 13440 13930 13930 14420 210 150 150 14420 - 14904 180 1H-103L1wp25 7703.50 To 14904.31 AC Wells Only Easting (2000 usRNn) AC Flipbook 1 H-103L1wp25 7703.50 To 8500.00 AC Flipbook SURVEY PROGRAM 0 7704 pih FronDe TO Tool 39.00150000 .00 GYD-GC Minor Risked 7704 7890 1500.001850.00 MWD+IFR-AK-C 0 1850.007703.50 MWD -IFR -AK -CA; 7690 8070 7703.508000.00 MWD -INC ONLY 90 8000.009500.00 MWD 8000.004904.31 MWD+1FR-AK-C 330 30 6070 - 8260 8260 8440 8440 - 8630 CASING DETAILS 60 8630 - 8810 TVD MD Name 3977 287704.50 7-5/8"x 9-7/8" 300 60 3893 .10904.31 4 1/2" x 6-3/4- 8810 - 9000 9000 - 9250 VID Azi TFac 30 9250 9500 7703.50 74.67 0.00 7716.30 73.96 20+00 9500 - 9750 7736.30 73.96 0.00 7933.26 68.89 -40.00 8074.73 63.31-80+00 9750 -1000 8087.44 63.30 -1.16 270 90 8265.12 63.30 0.00 10000 - 1025 9606.70 10.00 -83.18 9871.94359.77105.41 10250 -1050 10874.69 359.77 0.00 10903.55 0.00168.72 10500 - 1075 10947.62 0.41166.40 11049.96 0.41 0.00 11135.64 0.42 0.18 '240 30 )120 10750 -1100 11239.61 0.44 0.54 12214.11 0.44 0.00 11000 -1149 12279.49358.25-72.91 12309.29357.22 -79.03 11490 -1198 12433.77357.22 DIM 12792.83343.00 -97.92 60 11980 -1246 13411.99 31&25 -91.95 13749.17318.25 0.00 14058.46 309.00 -85.36 12460 -1295 14216.60304.28 -83.70 14904.31304.28 0.00 210 150 12950 1344 90 13440 1393 160 13930 1442 1H-103wp2 -14904 14420 e:m, oaame.. as ian 1H-103L1wp25 8400.00 To 11800.00 AC Flipbook SURVEY PROGRAM 0 7704 pth FmnDepth To Tool 39.001500.00 GYD-GC-ss FMinor Risked 7704 - 7890 1500.001850.00 MWD+IFR-AK-C 0 1850.007703.50 MWD+IFR-AK-C 7890 - 8070 7703.508000.00 MWD -INC -ONLY 90 8000.00 9500.00 MWD 8000.004904.31 MWD+IFR-AK-C 330 30 8070 - 8260 8260 - 8440 60 8440 - 8630 8630 8810 CASING DETAILS TVD MD Name 3977 297704.50 7-518" x 9-71W 300 60 3893.1[11904.31 4 1/2" x 6314" 8810 9000 9000 - 9250 MD TP 3 9250 9500 67 0..0000ace 7703.50 74..67 7716.30 73.96 -20.00 7736.30 73.96 0.00 9500 - 9750 7933.26 68.89 -40.00 8074.73 63.31 -80.00 9750 1000 8087.44 63.30 -1.16 270 90 8265.12 63.30 0.00 10000 1025 9606.70 10.00 -83.18 9871.94359.77105.41 10250 -1050 10874.69 359.77 0.00 10903.55 0.00168.72 10947.62 0.41166.40 10500 - 1075 11049.96 0.41 0.00 30 11135.64 0.42 0.18 10750 -1100 11239.61 0.44 0.54 12214.11 0.44 0.00 11000 - 1149 12279.49358.25-72.91 240 120 12309.29357.22 -79.03 11490 -1198 12433.77357.22 0.00 12792.83343.00 -97.92 60 11980 -1246 13411.99318.25 -91.95 13749.17318.25 0.00 14058.46 309.00 -85.36 12460 -1295 14216.60 304.28 -83.70 14904.31 304.28 0.00 7H-103wp2 10 150 12950 - 1344 90 13440 1393 180 13930 1442 14420 - 1490 eJ'ofiecc''oeD2- 1H-103L1wp25 11700.00 To 14905.00 AC Flipbook SURVEY PROGRAM 0 7704 pth FmnDepth To Tool 39.001500.00 GYD-GC-SS Minor Risked 7704 7890 1500.007850.00 MWD+IFR-AK-C 0 1850.007703.50 MWD+IFR-AK-C 7890 8070 7703.508000.00 MWD -INC ONLY 90 8000.00 9500.00 MWD 8000.004904.31 MWD+IFR-AK-C 330 30 8070 - 8260 8260 8440 60 8440 - 8630 8630 - 8810 CASING DETAILS TVD MD Name 3977 297704.50 7-5/8"x9-7/8" 3893.=904.31 4 1/2" x 6-3/4" 3OO 60 8810 9000 9000 - 9250 MD Azi TFace 3 9250 9500 7703.50 74.67 0.00 7716.30 73.96 -20.00 9500 - 9750 7736.30 73.96 0.00 7933.26 68.89 -40.00 8074.73 63.31 -80.00 9750 1000 8087.44 63.30 -1.16 2 70 90 8265.12 63.30 0.00 10000 1025 9606.70 10.00 -83.18 9871.94359.77105.41 10250 -1050 10874.69 359.77 0.00 10903.55 0.00168.72 10500 - 1075 10947.62 0.41 166.40 '240 30 11049.96 0.41 0.00 11135.64 0.42 0.18 )120 10750 -1100 11239.61 0.44 0.54 12214.11 0.44 0.00 11000 -1149 12279.49 358.25 -72.91 12309.29 357.22 -79.03 11490 -1198 12433.77357.22 0.00 12792.83 343.00 -97.92 60 11980 -1246 13411.99318.25 -91.95 13749.17318.25 0.00 14058.46 309.00 -85.36 12460 - 1295 14216.60304.28 -83.70 14904.31304.28 0.00 210 150 12950 - 1344 s0 13440 1393 160 13930 - 1442 14420 - 1490 ConocoPhillips (Alaska) Inc. -Kupl Kuparuk River Unit Kuparuk 1H Pad Plan: 1 H-103 17ETMI7bPICIM1• Plan: 1 H-103L1wp25 Report - Errors 29 December, 2017 Company: ConocoPhillips (Alaska) Inc. -Kupl Project: Kuparuk River Unit Site: Kuparuk 1H Pad Well: Plan: 1H-103 Wellbore: Plan: 1H-10311 Design: 1 H-10311wp25 Schlumberger Report - Errors Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well Plan: 1H-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature OAKEDMP2 Project Kupamk 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 1 H Pad Site Position: Northing: usft Latitude: From: Map Easting: usft Longitude: Position Uncertainty: 0.00 usft Slot Radius; 0.. Grid Convergence: 0.37 ' Well Plan: 1H-103 Well Position +N/ -S usft Northing: usft Latitude: +E/ -W usft Easting: usft Longitude: Position Uncertainty usft Wellhead Elevation: usft Ground Level: 54.10usft Wellbore Plan: 11H-1031-1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) n (nn BGGM2017 4/1/2018 17.18 80.93 57,472 Design 1H-103L1wp25 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,703.50 Vertical Section: Depth From (TVD) -NI-8 +E/ -W Direction (usft) (usft) (usft) (I 39.00 0.00 0.00 0.00 Survey Tool Program Date 12/29/2017 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 1,500.001H-103wp25(Plan: 11-1-103) GYD-GC-SS Gyrodata gyro single shots 1,500.00 1,850.00 1H-103wp25(Plan: 11-1-103) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1,850.00 7,703.50 IH-103wp25(Plan: 11-1-103) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,703.50 8,000.00 IH-103L1wp25(Plan: 1H-103Li) MWD-INC_ONLY MWD -INC _ONLY -FILLER 8,000.00 9,500.00 1H-103L1wp25(Plan: 1H -103L7) MWD MWD -Standard 8,000.00 14,904.31 IH-103Liwp25(Plan: 1H -103L1) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Lat. Error Hoe Error (usft) (usft) (°) (°) lush) (ush) (usft) (usft) 7,703.50 13.71 78.02 99.85 3,884.00 9.02 27.90 9.96 KOP: 15.9°/100' DLS, -20° TF, for 12.6' 7,704.50 13.71 78.17 99.85 3,884.20 9.02 27.90 9.96 7.518" x 9-718" 7,716.30 13.71 79.93 99.85 3,886.44 9.02 27.90 9.96 Hold for 20' 7,736.30 13.71 79.93 99.85 3,889.94 9.02 27.90 9.96 Start 4°1100' DLS, -40° TF, for 196.96' 12292017 8:50:46AM Page 2 COMPASS 5000.14 Build 85 Schlumberger Report - Errors Company: ConowPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well Plan: 1 H-103 Project: Kupawk River Unit TVD Reference: Plan: 54.1+39 ® 93.10usft (Doyon 142) Site: Kupawk 1H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan: 11-1-103 North Reference: True Wellbore: Plan: 1H-1031-1 Survey Calculation Method: Minimum Curvature Design: 1H-103L1wp25 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert Error Let Error Hom Error (usft) (usft) (°) (°) (usft) Will (usft) (usft) 7,800.00 14.60 81.89 99.80 3,900.00 9.02 27.55 9.79 7,842.02 15.94 83.18 99.12 3,905.46 9.04 27.40 9.51 a2 7,900.00 15.94 84.97 99.12 3,911.44 9.04 27.40 9.51 7,933.26 16.37 86.00 98.54 3,914.06 9.05 27.60 9.42 Adjust TF to -80°, for 141.47' 8,000.00 17.54 86.47 97.54 3,918.44 9.06 27.69 9.39 8,074.73 18.84 87.00 97.02 3,922.70 9.07 27.35 9.36 Adjust TF to -1.16°, for 12.7' 8,087.44 18.87 87.51 96.93 3,923.31 9.07 27.44 9.30 Hold for 177.69' 8,100.00 18.87 87.51 96.83 3,923.66 9.07 27.53 9.31 8,200.00 18.88 87.51 96.04 3,928.21 9.10 28.28 9.33 8,265.12 18.88 87.51 95.48 3,931.04 9.13 28.81 9.36 Start4°1100' DLS, -83.18° TF, for 1341.68' 8,300.00 19.51 87.67 95.17 3,932.50 9.14 28.69 9.36 8,400.00 21.32 88.16 94.21 3,936.14 9.20 28.29 9.37 8,500.00 23.09 88.65 93.14 3,938.93 9.27 27.84 9.39 8,600.00 24.83 89.15 91.97 3,940.85 9.35 27.34 9.43 8,700.00 26.53 89.65 90.72 3,941.89 9.45 26.80 9.48 8,800.00 28.17 90.16 89.39 3,942.05 9.56 26.23 9.55 8,900.00 29.76 90.66 87.99 3,941.34 9.68 25.62 9.64 9,000.00 31.27 91.16 86.54 3,939.74 9.82 24.98 9.76 9,100.00 32.72 91.66 85.04 3,937.28 9.97 24.33 9.90 9,200.00 34.09 92.15 83.50 3,933.95 10.12 23.67 10.06 9,300.00 35.37 92.62 81.93 3,929.79 10.29 23.02 10.25 9,400.00 36.58 93.09 80.32 3,924.80 10.47 22.38 10.47 9,500.00 33.33 93.54 92.36 3,919.02 9.47 11.26 9.47 9,600.00 33.70 93.97 91.88 3,912.47 9.52 10.47 9.57 9,606.70 33.72 94.00 91.85 3,912.00 9.52 10.43 9.58 Adjust TF to -105.41°, for 265.24' 9,700.00 33.96 93.00 91.41 3,906.30 9.58 10.02 9.58 9,800.00 34.09 91.92 90.97 3,902.01 9.64 9.93 9.61 9,871.94 34.10 91.13 90.65 3,900.09 9.68 10.12 9.66 Hold for 1002.75' 9,900.00 34.10 91.13 90.54 3,899.54 9.70 10.17 9.67 10,000.00 34.10 91.13 90.14 3,897.57 9.76 10.29 9.74 10,100.00 34.10 91.13 89.75 3,895.59 9.83 10.43 9.81 10,200.00 34.11 91.13 89.36 3,893.61 9.90 10.61 9.88 10,300.00 34.11 91.13 88.96 3,891.64 9.98 10.82 9.95 10,400.00 34.11 91.13 88.55 3,889.66 10.05 11.05 10.03 10,500.00 34.11 91.13 88.15 3,887.69 10.13 11.30 10.11 10,600.00 34.11 91.13 87.73 3,885.71 10.21 11.59 10.19 10,700.00 34.11 91.13 87.32 3,883.74 10.30 11.89 10.27 10,800.00 34.11 91.13 86.89 3,881.76 10.38 12.21 10.36 12/292017 8:50:46AM Page 3 COMPASS 5000.14 Build 85 Schlumberger Report - Errors Company: ConowPhillips (Alaska) Inc. -Kup1 Local Coordinate Reference: Well Plan: 11-1-103 Project: Kuparuk River Unit TVD Reference: Plan: 54.1+39 @ 93.10usit (Doyon 142) Site: Kupamk 1H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan: 1H-103 North Reference: True Wellbore: Plan: 1H -103L1 Survey Calculation Method: Minimum Curvature Design: 1H-103L1wp25 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert Error Lat. Error Hora. Error (usft) (usft) (') (°) (usft) (usft) (usft) (usft) 10,874.69 34.11 91.13 86.57 3.880.29 10.45 1247 10.43 Start 4'1100' DLS, 168.72' TF, for 28.86' 10,900.00 34.10 90.14 86.47 3,880.00 10.47 12.52 10.47 10,903.55 34.10 90.00 86.46 3,880.00 10.48 12.53 10.48 Adjust TF to 166.4°, for 44.07' 10,947.62 34.05 88.29 86.31 3,880.66 10.52 12.56 10.63 Hold for 102.34' 11,000.00 34.05 88.29 86.10 3,882.23 10.56 12.64 10.67 11,049.96 34.05 88.29 85.88 3,883.72 10.61 12.83 10.72 Start 2'1100' DLS, 0.18' TF, for 85.67' 11,100.00 34.07 89.29 85.65 3,884.78 10.66 13.01 10.69 11,135.64 34.08 90.00 85.49 3,885.00 10.69 13.14 10.69 Adjust TF to 0.54°, for 103.97' 11,200.00 34.09 91.29 85.20 3,884.28 10.75 13.39 10.73 11,239.61 34.09 92.08 85.02 3,883.11 10.79 13.55 10.77 Hold for 974.6' 11,300.00 34.09 92.08 84.73 3,880.92 10,85 13.78 10.83 11,400.00 34.09 92.08 84.26 3,877.29 10.95 14.19 10.93 11,500.00 34.09 92.08 83.77 3;873.67 11.05 14.61 11.03 11,600.00 34.09 92.08 83.27 3,870.04 11.15 15.04 11.14 11,700.00 34.09 92.08 82.75 3,866.41 11.26 15.48 11.24 11,800.00 34.10 92.08 82.21 3,862.78 11.37 15.93 11.35 11,900.00 34.10 92.08 81.66 3,859.15 11.48 16.39 11.46 12,000.00 34.10 92.08 81.10 3,855.52 11.59 16.85 11.57 12,100.00 34.10 92.08 80.51 3,851.90 11.70 17.32 11.68 12,200.00 34.10 92.08 79.90 3,848.27 11.81 17.80 11.80 12,214.11 34.10 92.08 79.81 3,847.75 11.83 17.87 11.81 Start 3.6°1100' OLS, -72.91° TF, for 65.38' 12,279.49 34.26 92.75 79.38 3,845.00 11.90 17.85 11.91 Adjust TF to -79.03", for 29.81' 12,300.00 34.30 92.89 79.24 3,843.99 11.93 17.85 11.95 12,309.29 34.32 92.95 79.18 3,843.52 11.94 17.85 11.96 Hold for 124.48' 12,400.00 34.33 92.95 76.59 3,838.85 12.05 18.25 12.07 12,433.77 34.33 92.95 78.37 3,837.12 12.09 18.41 12.11 Start 4-M00' DLS, .97.92° TF, for 359.06' 12442.13 34.48 92.90 77.94 3,836.69 12.16 18.38 12.18 a3 12,500.00 34.48 92.58 77.94 3,833.92 12.16 18.38 12.18 12,600.00 34.64 92.01 77.31 3,829.91 12.28 18.40 12.29 12,700.00 34.69 91.44 76.68 3,826.90 12.41 18.60 12.41 12,792.83 34.65 90.90 76.12 3,825.00 12.52 18.93 12.52 Adjust TF to -91.95°, for 619.16' 12,800.00 34.65 90.89 76.07 3,824.89 12.53 18.97 12.53 12,900.00 34.50 90.75 75.48 3,823.45 12.65 19.50 12.65 13,000.00 34.25 90.61 74.91 3,822.27 12.78 20.17 12.78 121292017 S50:46AM Page 4 COMPASS 5000.14 Build 85 Schlumberger Report - Errors Company: ConocoPhillips (Alaska) Inc. -Kupl Local Coordinate Reference: Well Plan: 1H-103 Project Kuparuk River Unit TVD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Site: Kuparuk 1 H Pad MD Reference: Plan: 54.1+39 @ 93.10usft (Doyon 142) Well: Plan'. 1H-103 North Reference: True Wellbore: Plan: 1H -103L1 Survey Calculation Method: Minimum Curvature Design: iHA031-1wp25 Database: OAKEDMP2 Planned Survey MD MD Error Inc Ellipse Inc TVDSS Vert. Error Let Error Hom Error (usft) (usft) (') (°) (usft) (usft) (usft) (usft) 13,100.00 33.92 90.47 74.37 3,821.33 12.91 20.94 12.91 13,200.00 33.50 90.32 73.88 3,820.64 13.03 21.79 13.04 13,300.00 33.00 90.17 73.44 3,820.22 13.16 22.70 13.17 13,400.00 32.43 90.02 73.05 3,820.05 13.29 23.64 13.29 13,411.99 32.36 90.00 73.00 3,820.05 13.31 23.76 13.31 Hold for 337.18' 13,500.00 32.36 90.00 72.71 3,820.04 13.43 23.88 13.43 13,600.00 32.36 90.00 72.39 3,820.04 13.56 24.04 13.56 13,700.00 32.36 90.00 72.07 3,820.04 13.69 24.22 13.69 13,749.17 32.36 90.00 71.91 3,820.03 13.76 24.31 13.76 Start 3°7100' DLS, 45.36° TF, for 309.29' 13,800.00 32.15 90.13 71.75 3,819.98 13.83 24.67 13.83 13,900.00 31.73 90.37 71.44 3,819.55 13.96 25.36 13.97 14,000.00 31.28 90.61 71.21 3,818.69 14.10 26.05 14.12 14,058.46 31.01 90.75 71.10 3,818.00 14.18 26.44 14.20 Adjust TF to -83.7°, for 158.14' 14,100.00 30.82 90.89 71.04 3,817.41 14.24 26.71 14.27 14,200.00 30.35 91.21 70.95 3,815.57 14.38 27.35 14.42 14,216.60 30.27 91.27 70.94 3,815.21 14.40 27.46 14.45 Hold for 687.71' 14,300.00 30.27 91.27 70.94 3,813.37 14.52 27.55 14.56 14,400.00 30.27 91.27 70.97 3,811.16 14.66 27.68 14.70 14,500.00 30.27 91.27 71.05 3,808.94 14.80 27.81 14.84 14,600.00 30.27 91.27 71.17 3,806.73 14.94 27.96 14.99 14,700.00 30.27 91.27 71.34 3,804.52 15.08 28.12 15.13 14,800.00 30.27 91.27 71.57 3,802.31 15.23 28.30 15.27 14,900.00 30.27 91.27 71.88 3,800.10 15.37 28.48 15.42 14,904.31 30.27 91.27 71.89 3,800.00 15.38 28.49 15.42 TD: 14904.31' MD, 3893.1' TVD - 4112" x 6.34" 12/29/2017 8,50:46AM Page 5 COMPASS 5000.14 Build 85 Company: Project: Site: Well: Wellbore: Design: Formations ConocoPhillips (Alaska) Inc. -Kupt Kupawk River Unit Kupsruk lH Pad Plan: 1H-103 Plan: 1H-1031-1 1H-103L1wp25 7,704.50 14,904.31 Measured Depth (usft) 2,198.92 1,901.58 6,841.70 1,694.10 7,135.23 7,291.37 5,440.02 5,801.37 7,048.47 7,475.60 7,842.02 4,639.55 6,284.20 Plan Annotations Measured Depth (usft) 7,703.50 7,716.30 7,736.30 7,933.26 8,074.73 8,087.44 8,265.12 9,606.70 9,871.94 10,874.69 10,903.55 10,947.62 11,049.96 11,135.64 11,239.61 12,214.11 12,279.49 12,309.29 12,433.77 12,792.83 13,411.99 13,749.17 14,058.46 14,216.60 14,904.31 3,977.28 7-5/8" x 9-7/8" 3,893.10 4 1/2" x 6-3/4" Vertical Depth (usft) Name 2,007.76 k15 1,783.60 t3 3,798.21 d 1,613.29 pfro 3,859.14 b 3,891.55 a4 3,454.92 ugb 3,564.05 uga 3,841.13 c 3,929.79 a3 3,998.56 a2 3,204.11 u9c 3,662.49 N Vertical Depth (usft) 3,977.10 3,979.54 3,983.04 4,007.16 4,015.80 4,016.41 4,024.14 4,005.10 3,993.19 3,973.39 3,973.10 3,973.76 3,976.82 3,978.10 3,976.21 3,940.85 3,938.10 3,936.62 3,930.22 3,918.10 3,913.15 3,913.13 3,911.10 3,908.31 3,893.10 Schlumberger Report - Errors Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Local Coordinates -NIS +E/ -W (usft) (usft) -938.99 5,40068 -935.59 5,412.78 -930.15 5,431.70 -867.88 5,616.84 -810.70 5,745.88 -805.00 5,757.22 -725.25 5,915.81 311.76 6,688.02 575.39 6,710.53 1,577.94 6,706.58 1,606.79 6,706.52 1,650.86 6,706.68 1,753.16 6,707.42 1,838.81 6,708.05 1,942.76 6,708.83 2,916.59 6,716.30 2,981.90 6,715.55 3,011.64 6,714.38 3,135.81 6,708.36 3,488.41 6,646.87 4,023.75 6,345.52 4,275.30 6,120.99 4,488.45 5,897.35 4,582.79 5,770.52 4,970.07 5,202.43 Well Plan: 1H-103 Plan: 54.1+39 @ 93.10usft (Doyon 142) Plan: 54.1+39 @ 93.10usft (Doyon 142) True Minimum Curvature OAKEDMP2 4-1/2 Dip Lithology (°) Comment KOP: 15.9°/100' DLS, -20° TF, for 12.8' Hold for 20' Start 4°1100' DLS, -40° TF, for 196.96' Adjust TF to -80°, for 141.47' Adjust TF to -1.16°, for 12.7' Hold for 177.69' Start 4°/100' DLS, -83.18° TF, for 1341.58' Adjust TF to -105.41', for 265.24' Hold for 1002.75' Start 4°1100' DLS, 168.72° TF, for 28.86' Adjust TF to 166.4°, for 44.07' Hold for 102.34' Start 2°/100' DLS, 0.18° TF, for 85.67' Adjust TF to 0.54°, for 103.97' Hold for 974.5' Start 3.5°1100' DLS, -72.91' TF, for 65.38' Adjust TF to -79.03°, for 29.81' Hold for 124.48' Start 4°/100' DLS, -97.92° TF, for 359.06' Adjust TF to -91.95°, for 619.16' Hold for 337.18' Start 3°1100' DLS, -85.36° TF, for 309.29' Adjust TF to -83.7°, for 158.14' Hold for 687.71' TD: 14904.31' MD, 3893.1' TVD 9-7/8 6-3/4 Dip Direction (°) Checked By: Approved By: Date: J 12,29/2017 8:50:46AM Page 6 COMPASS 5000.14 Build 85 Pool Report -•� 10:42, December 292077 1H-103L1 wp25arVo m.IWu mR aln7 Rv RP_aAI1;0 xea.lo cue oam..:lmaol Grtl.I WEwx ITA.W) �WLI R@1E111]RP ;„jmLl ;2127 0 GINe IRadu¢'.IN,p1) Quarter Mile View IX�1a TI]txlxl]RP INANLI lL8131117RP Y10.10 ]8]8.10 Clrcle lFMlui.1W 0>) Grtle IRaGIua:1 W,Wl Ik1WL1M;x1]RP .1W1001.1111 RP <M'.10 M70.10 Grth lRWxu:IW.WI Grc#(flaEIIn:IW.WI IXIWLI TOI Ix1117F1 INNW F01 eVD.10 Grey lRaEW¢ 1W.W1 Polygn N�1WL11C. fY.11i RP - -. 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To:- Datum: NAD83 Region jalaska Datum: NAD27 Region: alaska f Latitude/Longitude IDecimalDegiees C Latitude/Longitude IDecimalDegrees r UTM Zone: 1 — r South C UTM Zone: True r South f• State Plane Zone: r� Units: us -ft r State Plane Zone: q Units: us -ft r Legal Description (NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: X: 1694475.95 Ending Coordinates: X: 1554444.24465335 Y: 15979420.45 Y: 5979668.57505064 Transform � Quit Help 1H-103L1wp25 TD CPAI Coordinate Con:•erter ` � 'I 1 I VIII. Datum: NAD83 Region: alaska t' Latitude/Longitude IDecimaiDegfees f UTM Zone: r South C• State Plane Zone:q Units: us -ft r Legal Description (NAD27 only) AD27 Region: a Datum: Flaska r Latitude/Longitude IDecimalDegrees r UTM Zone: True r South G State Plane Zone:q . Units: us -ft r Legal Description (NAD27 only) Starting Coordinates:Ending Coordinates: X: 1694774.00 X: 554742.333516845 Y: 15985478.00 Y: 15985725.97555582 '-Transform :_ Quit Help 1H-103L1wp25 Surface Location o From: To: Datum: DB3 Region: alaska NA Datum: D27 D Region: alaska NA C Latitude/Longitude IDecimalDegrees C Latitude/Longitude IDecimalDegrees, C UTM Zone:1 — r South C UTM Zone: True r South C� State Plane Zone: q Units: FuT—it.-j State Plane Zone: q Units: us -k D C Legal Desrription (N.AD27 only) G Legal Description (NAD27 only) Starting Coordinates: X: 11689604.82 Legal Description Township: 012 N , Range: 010 E Y: 15980474.36 Meridian: U Section:28 FNL 5260.47B9 FEL - 768.38344 -TransFnrrn- Quit Help 1H-103L1wp25 Surface Casing I� CPAI Coordinate Converter From: - To: ---- - Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska C Latitude/Longitude IDecimalDegrees C LatitudelLongitude Decimal Degrees C UTM Zone: 1 — r South C UTM Zone: True r South • State Plane Zone: F--:-] Units: us -f - C State Plane Zone: 1' -,3 Units: us -ft C Legal De::criptiorf (.NAD27 only) r Legal Description (NAD27 only) Starting Coordinates: X: 11690013.76 Legal Description Township: 012 F':-:] Range: 010 E Y: 15980232.94 Meridian:U Section: 33 FF224.63930 FEL 361.55813 Transform Quit Help 1H-103L1wp25 Top of Window Cl CPA] Coordinate Converter I...II. Datum: NAD83 - Region: jalaska Latitude/Longitude Decimal Degrees (' UTM Zone: I — r South * State Plane Zone: F Units: us -ft * Legal Description (NAD27 only) Starting Coordinates: X: 1695011.03 Y: 5979570.95 1 H -103L1 wI Q CPAI Coordinate Datum:NAD27 Region: aask la • Latitude/Longitude Decimal Degrees • UTM Zone: True r South r State Plane Zone: rq Units: us -ft C- Legal Description (NAD27 only) - Legal Township: 012 N - Range: 010 F-] Meridian: U Section:34 FNL 921.77440 FEL 649.92436 _.. e.................Transform.,,.,,,.....__.- Quit Help of Production Horizon - A3 -nom. Datum: INAD83 7 Region: jalaska f Latitude/Longitude IDecimaiDegiees t' UTM Zone: F_ r South C State Plane Zone: I' �:] Units: us -ft r Legal Descriplion (NAD27 only) Starting Coordinates: X: 11694796.44 Y: 15979510.59 Datum:NAD27 Region: alaska C` Latitude/Longitude IDecimalDegrees J f UTM Zone: True r South * State Plane Zone:q Units: us -ft f• Legal Description (NAD27 only) -Legal Township: 012 FN—, -1 Range: 010 E Meridian:U Section:34 FNL � 980.56108 FEL . 865.05577 ! Transform Quit Help 1H-103L1wp25 Top of Production Horizon -A4 ❑, CPAI Coordinate Converter From: To: Datum: NAD83 Region: alaska Datum: NAp27 Region: jalaska 7 C Latitude/Longitude Decimal Degrees C Latitude/Longitude IDecimaiDegrees C UTM Zone: r— (— South i UTM Zone: True r South R State Plane Zone: q Units: us -ft !' State Plane Zone: �� Units: us -ft fi Legal Description (NAD27 only) f• Legal Description (NAD27 only) Starting Coordinates: X: 1694622.97 Legal Description Township: 012 N , Range: 010 E Y: 15979461.8 Meridian: U Section:34 FNL 1028.0854 FEL 1038.9646 i.................Transform._,..._......,.) Quit Help ILI' 1H-103L1wp25 Top of Production Horizon - B m B CPAI Coordinate Converter From: -- To: Datum: NAD 83 Region: alaska Datum: NAD27 Region: alaska [- Latitude/Longitude Decimal Degrees i' Latitude/Longitude Decimal Degrees —_-j C UTM Zone: 1 — r South r UTM Zone: True r South G State Plane Zone:q Units: us•ft � t•' State Plane Zone: 4 Units: us -ft l" Legal Description (NA.D27 only) Legal Description (NAD27 only) Starting Coordinates: Legal Description X: 1694475.95 Township: 012 N ; Range: 010 E Y: 15979420.45 Meridian: U Section:34 FNL 1068.3741 FEL . 1186.3544 Quit Help I H-1 03L1 ® CPI.- Coordinate Converter Datum: NAD83 � Region: jalaska jj C Latitude/Longitude IDecimalDegrees r UTM Zone: F—r South State Plane Zone:q Units: us -ft f Legal Description (NA[127 onl5yl Starting Coordinates: X: 11694774.00 Y: 15905470.00 .Ig) - To: Datum: NAD27 Region: jalaska C Latitude/Longitude Decimal Degrees C UTM Zone True r South f State Plane Zone:q Units: us -ft C•` Legal Description (NAD27 only) uescnpuon Township: 012 N Range: 010 E Meridian:U Section: F27 FNL 292.69642 FEL - 834.72435 Transformer Quit Help Tollerable Collision Risk Worksheet Cotiilor_cPh'fflips Alaska ATolerable Collision Risk Worksheet based on Rev, t - 2e Jul tie Use this sheet to describe a well Interference scenado where ORA may be applicable. Check first that the scenado really 13 different from those described on existing worksheets. Prepared by: Kelsey Halilord sot: Authorized by: Dan Bearden h L. ConocoPhillips Alaska, Inc Drilling Anti -Collision Management Generic name of scenario: Collislon with other laterals In multi -lateral well (A3 With A2, A4 with A3 and A2, a with A4. As, and A2. D with B. A4, A3 and AZ Description: (Be spedOc. include all factors which affect either the cosi of collision or the cast of re ludo the dsk Well iH-1 W A3. A4, B end O laterals fail anti collision with one another in the horizontal legs of the well base on WP25. The four upper laterals will be geosteered using periscope so risk of leaving the zone is minimal. ThereIs no Immediate danger to life or Impact on the environment if well 1H- ID3lnterserJs itself. If IH -103 intersects itself there would be damage to the liner and swell packets. No risk of awe]] carrot Issue exists because well IH -103 lateral that Is being drilled Is above the previous placed laterals (upper laterals have the same or slightly higher PP) and is being drilled from the main We with kill weight mud in the hole. The laterals fail with the mother bore at the kick off point, but we are Intentionally aide tracking. We Will be kicking on with motors Io keep us in the target sands. r Do the consequences Are the .1 of collision include a consequences ae -n dsk to personnel or the of collision environment? - List all the consequences of I Ions / collision and the necessary remedial action: No HSE risks exist with 1 HAW Intersecting itself while ddlling. An economic concern exists and it would be the cast of damage to the completion equipment that has already been placed in the lower laterals prior to drilling the upper laterals and the Impact it may have on future production from the well If necessary the lateral that had been chilled into can be isolated and production shut off (loss of lateral) which Is worst rase scenario. The biggest chance of getting "lost' is when crossing faults, there are three fault crossings in 111-103, but since the lower laterals will have already dolled across the fault the exact throw of the fault will be known so the fault crossing can be planned for. If we do gel out of zone we can determine what zone we are In band orl real time logs and callings and then steer back Into the correct zone. How could the probability of collision or the severity of the consequences be reduced? How might this impact the drilling operation? Cost: substantially reducing V = $0 the risk Given the uncertainty In the above estimates, by how many limes must the savings made from not reducing the risk outweigh he risk Itself? (Guldeline = 20) M = 20 F=1/M= 0.05 — I C = $7,000,000 Is there a practical way Estimate the NPV of to substantially reduce Q+o Q'g the tanned well either the probability of collision or the severity V= $14,360,000 of the consequences? Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you Prepared to tolerate? (Guideline = 0.05) F = 0.01 VF/C= 0.020514286 If V F 1 Nen close approach tolerances need not be set C If VF C < 1 hien Tolerable Collision Risk = I in C / V F Tolerable Collision Risk= 1 in4g substantially reducing V = $0 the risk Given the uncertainty In the above estimates, by how many limes must the savings made from not reducing the risk outweigh he risk Itself? (Guldeline = 20) M = 20 F=1/M= 0.05 — I C = $7,000,000 Is there a practical way Estimate the NPV of to substantially reduce Q+o Q'g the tanned well either the probability of collision or the severity V= $14,360,000 of the consequences? Accepting a finite risk of collision will reduce the NPV of the planned well. What reduction, as a fraction of the total NPV, are you Prepared to tolerate? (Guideline = 0.05) F = 0.01 VF/C= 0.020514286 If V F 1 Nen close approach tolerances need not be set C If VF C < 1 hien Tolerable Collision Risk = I in C / V F Tolerable Collision Risk= 1 in4g As -built I� EV I DATE I BY I CK APP r DESCRIPTION REV DATE BY r CK APP DESCRIPTION 1 2/05/0 MRT I CC I IRev. Per K05014ACS 12 102/01/11 JAH I LGM MONUMENTATION PER LOUNSBURY & ASSOC. Rev. Per K170005ACS N25 2. COORDINATES SHOWN ARE ALASKA STATE 30 29 26 27 25 PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. 36 KCS 31 T"2 19 33 34 3536 ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, X20 T11N OE UMIAT MERIDIAN, ALASKA. 019 •11 6 5 4 3 2 1 010 0120 1-31-17 FIELD BOOKS L16-35, L16-40, A 06 ASP GRID NORTH 0119 2 7 s CPFI 10. �Oq 013 0118 ALL DISTANCES SHOWN ARE GROUND. 61 B 9 1 t 12 0117 •7 a •18 0116 GRAPHIC SCALE 0115 16 17 16 15 14 17 •8 0114 •4 A LEGEND 0113 0112 'F 1 inch = 200 ft. 3D 21 2 & 3 FOR COORDINATE TABLE LOUNSBURY 24 19 20 21 2 23 0 AS—BUILT CONDUCTOR 0111 ®110 WR TORS 6NCMEM PLWN&49 J* "u VICINITY MAP • EXISTING CONDUCTOR 0109 ConocoPhilli„S SCALE: 1" = 2 MILES DS1H 0104 M WELL CONDUCTOR Alaska, Inc. 0108 ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. 0103 PART: REV: IKR1nRds1 28 27 I CFA—DIHX-6108D31 1 1 OF 3 1 2 33 34 0102 0106 0101 NOTES: 1. BASIS OF LOCATION AND ELEV. IS DS1H MONUMENTATION PER LOUNSBURY & ASSOC. DS1 H 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. •UGNU 01 4• ALL CONDUCTORS ARE LOCATED WITHIN •14 PROTRACTED SECTIONS 28 AND 33, TOWNSHIP 12 NORTH, RANGE 10 EAST, X20 • 5 5 UMIAT MERIDIAN, ALASKA. 019 •11 5. DATES OF SURVEY: 12-26-16 THRU 922 010 1-31-17 FIELD BOOKS L16-35, L16-40, 917 06 L17-02 & L17-03. *16 •21 •15 013 6. ALL DISTANCES SHOWN ARE GROUND. 61 •9 •2 •7 •3 •18 GRAPHIC SCALE 0 100 200 400 •8 •4 1 inch = 200 ft. SEE SHEET 2 & 3 FOR COORDINATE TABLE LOUNSBURY & ASSocurss, 1KC. WR TORS 6NCMEM PLWN&49 J* "u AREA: 1H MODULE: XXXX UNIT: Di ConocoPhilli„S DS1H M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATIONS CADD FILE NO. DRAWING NO. PART: REV: IKR1nRds1 9/ns/n5 I CFA—DIHX-6108D31 1 1 OF 3 1 2 1 1 102/01/171 JAH I LGM I ICreate Per K170005ACS I I I I I I CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28, T. 12 N.. R. 10 E.. UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geo ra hic Coordinates Section Offset. Elev. Y X Lot. Long. F.S.1- F.E.L. O.G. PAD *103 5,980,722.55' 549,573.20' N 70* 21' 29.220" W 149' 35' 50.536" 19' 768' 48.0' 54.1' *104 5,980,782.43' 549,568.74' N 70' 21' 29.809" W 149' 35' 50.655" 79' 772' 48.0' 54.1' *108 5,980,752.52' 549,570.98' N 70' 21' 29.515" W 149' 35' 50.595" 49' 770' 48.0' 54.0' *109 5,980,812.20' 549,566.50' N 70' 21' 30.102" W 149' 35' 50.714" 109' 774' 48.0' 54.0' *110 5,980,842.21' 549,564.40' N 70' 21' 30.398" W 149' 35' 50.770" 139' 776' 48.0' 54.0' *111 5,980,872.05' 549,562.21' N 70' 21' 30.691" W 149' 35' 50.828" 169' 778' 48.0' 54.1' *112 5,980,902.08' 549,559.94' N 70' 21' 30.987" W 149' 35' 50.889" 199' 780' 48.0' 54.0' *113 5,980,932.00' 549,557.76' N 70' 21' 31.281" W 149' 35' 50.947" 229' 782' 48.0' 54.0' *114 5,980,961.86' 549,555.50' N 70' 21' 31.575" W 149' 35' 51.006" 259' 784' 48.0' 54.1' *115 5,980,991.68' 549,553.43' N 70' 21' 31.868" W 149' 35' 51.062" 289' 1 786' 48.0' 54.1' *116 5,981,021.61' 549,551.58' N 70' 21' 32.163" W 149' 35' 51.110" 319' 787' 48.0' 54.1' *117 5,981,051.73' 549,548.80' N 70' 21' 32.459" W 149' 35' 51.185" 349' 790' 48.0' 54.0' *118 5,981,081.22' 549,546.95' N 70' 21' 32.750" W 149' 35' 51.234" 378' 791' 48.0' 54.0' *119 5,981,111.42' 549,544.52' N 70' 21' 33.047" W 149' 35' 51.299" 408' 794' 48.0' 54.2' *120 5,981,141.33' 549,542.48' N 70' 21' 33.341" W 149' 35' 51.353" 438' 795' 48.0' 54.1' * CONDUCTOR ASBUILT THIS SURVEY 0 "....... 1� SURVEYOR'S CERTIFICATE 1� I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND 49th 'v 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 =MIAH F. CORNELL � A THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION mr LS -12663 C ARE CORRECT AS OF JANUARY 31, 2017. 'hillips Alaska, Inc. 1H LOUNSBURY A35oC1ATE8, INC. SII YOR9 RNGWMR9 PLWNRRS DS1 H WELL CONDUCTOR ASBUILT LOCATIONS )D FILE NO. DRAWING NO. PART: REV: LK610801 12/27/16 1 CEA-D1HX-6108D31 1 3 OF 3 01 IH -103 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Washouts / Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with, gyro survey to ensure survey accuracy. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strat Running Sands and Gravels Low Maintain planned mud parameters, increase mud weight, use weighted sweeps. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight. Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out. 6-3/4" Oven Hole / 4-1/2" Liner Intervals Hazard Risk Level Mitigation Strategy Abnormal Reservoir Pressure Low Stripping drills, shut-in drills increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools monitoring and analysis, decreased mud weight if possible if pipe does get stuck. Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program, keep pipe moving when able. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out or backreamin . Fault Crossings and Concretions Moderate Use developed best practices for concretion drilling. Anti -Collision Moderate Follow real time surveys very closely, shut in nearby wells that we have collision concerns with. IH -102 only has AC challenges between its laterals, we will be utilizing periscope to maintain eolo ical certain to stay within zone. Casing wear Moderate Maintain low dog legs in the surface interval and utilize super sliders for drilling, milling, and liner running operations to minimize casing wear. Consider logging casing thickness to calibrate casing wear model. Getting Liner to Bottom Moderate Properly clean hole on the trip out with the BHA, perform clean out run if necessary, utilize super sliders for weight transfer, monitor for ue and dra . Whipstock Retrieval Moderate A dedicated clean out run prior to attempting to pull whipstock can be used to reduce the risk of fishing operations. 05 Attachment - IH -103 Drilling Hazards Summary.doc 1/4/2018 9:09:45 AM IH -103 Cement Calculations Hole Size ft (TOC) ft (Bottom) OD ID ppt 4239 80 20 18.5 94 13.5 39 1850 10.75 9.95 45.5 9.875 3650 8158 7.625 6.875 29.7 Surface Cement: Surface to 1,850' MD Cement from 8,158' MD to 3,650' MD Capacities Lead 1.91 ft3/ sx of 11.0 ppg DeepCRETE OH 0.177045 Tail 2.28 ft3/ sx of 12.0 DeepCRETE Permafrost(PF)depth 1704 ft 13-1/2" x 10-3/4" 0.064783 XS% Lead 250% 20" x 10-3/4" 0.220213 XS% Tail 50% 10-3/4" 0.096175 Tail Cement 2 x 0.095 x 1.4 0.27 bbls Length 500 ft 1 3.67 bbls Total 500 x 0.065 x 1.5 48.6 bbls Shoe Track 80 ft 1377 ft3 80 x 0.096 x 1 7.7 Open Hole 10 x 0.177 x 1.5 2.7 Total 59 bbl 331 ft3 145 sx Lead Top Tail Cement to Conductor 1350 ft 1350 x 0.065 x 3.5 306.1 bbl Conductor Length 80 ft 80 x 0.220 17.6 bbl Total: 324 bbl 1817 ft3 951 sx Intermediate Cement: Cement from 8,158' MD to 3,650' MD Capacities: Slurry: 9-7/8" x 7-5/8" 0.03825 15.8ppg Class G yielding 1.16W3/sk XS%for open hole and annulus: 40% 9-7/8" OH 0.094731 7-5/8"ST 0.045916 Annulus Cement 4508 x 0.038 x 1.4 241.41 bbls Rathole Cement 2 x 0.095 x 1.4 0.27 bbls Shoe Track 80 x 0.046 x 1 3.67 bbls Total 245 bbls 1377 ft3 Loepp, Victoria T (DOA) From: Bearden, 1 Daniel <1.Daniel.Bearden@conocophillips.com> Sent: Wednesday, January 31, 2018 5:14 PM To: Loepp, Victoria T (DOA) Subject: KRU - 11-1-109 PTD (West Sak) Follow Up Flag: Follow up Flag Status: Completed Good afternoon Victoria, Due to waterflood voidage management at Kuparuk 1H NEWS, the West Sak reservoir engineering team has recommended accelerating the spud of additional injection wells and push back our next penta-lateral producer. We have run and cemented our surface casing on 1H-119 (PTD 214-178). As such, I wanted to update AOGCC of the revised spud date for our next planned well (1H-109) for timely PTD approval. I believe the PTD's for 1H-109 & 1H-116 were submitted on January 23rd. I understand this submission/approval timeframe is shorter than required. If there is anything my team or I can do to ensure this PTD is reviewed/approved prior to February 10`h, please let me know. Well Duration Start 1H-119 15.0 days 1/26/2018 1H-109 15.0 days 2/10/2018 1H-116 15.0 days 2/25/2018 iH-103 57.5 days 3/12/2018 Thank you, Daniel Bearden Supervising Drilling Engineer ConocoPhillips, Alaska 907-263-4864 work 907-602-7068 cell TRANSMITTAL LETTER CHECKLIST WELL NAME: (,#— (6-3 L I PTD: "Development Service _Exploratory _ Stratigraphic Test Non -Conventional FIELD aGL Lf POOL: 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. Z/i"3 — 003 API No. (If last two digits Production should continue to be reported as a function of the original V/ 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 ( t 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. sero 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 (Com an 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 (Conn)M 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: KUPARUK RIV UNIT 1H-1031_1 Program DEV Well bore seg PTD#:2180040 Company CONOCOPHILLIPS ALASKA. INC. Initial Class/Type DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration '17 Nonconven, gas conforms to AS31,05,030G.1.A),0.2.A-D) - - _ - .. NA Co mi loner Date IF S 1 Permit fee attached ----------- ------------- -- NA -_ 1�'1 2 Lease number appropriate . . . . ...................... . . ..... . . . . Yes - - Surf Loc, -Top PI & TO lie within ADL025039; Portion of Productive Interval lies. in ADL025638, 3 Unique well. name and number .... _ - - - - - - - - - Yes - - - - - - - 4 Well located in a. defined.pool - - - - _ - - - - _ - _ - - .... Yes .. Kuparuk River, West$ak Oil Pool - 490150, govemed by CO 406G 5 Well located proper distance from drilling unit boundary . . . . . . . .... . .......... . Yes - CO 406C, Rule 3: no restrictions as to well spacing except that no pay shall be opened ins well closer - - - - - - 6 Well Jocated proper distance from other wells - - - --- - ----- - - - - - - - - - - - Yes - than 500 feet to an externalpropertyline where ownership or landownership changes_. 7 Sufficient acreage. available in drilling unit.. - - - - - - - - - - - - - - - - - - Yes Well is more than500feet from an external property line...... 8 If deviated, is wellbore platincluded- - - - - - - - - - - - - - - - - - - - - - - - ---- - - - Yes 9 Operator only affected party. - - - - - _ .... . .. . . ...... . Yes 10 Operator hasappropriatebond in force .. ......... - _ - Yes Appr Date t i Permit coon be issued without conservation order - - - - _ - - - - - _ - _ - - Yes 12 Permit can be issued without administrative approval - - - - - - Yes SFD 1/12/2018 .......... - - - 13 Can permit be approved before 15 -day wait. .... - .... - _ - Yes - ------- - - - - - - - - - - - - - - - - _ - - - - 14 Well located within area andstrataauthorized by Injection Order # (put 10# incomments)(For- NA - - - ----- 15 All wellewithin 114.mite area.of review identified (For service well only)- - - - - - - - - - ----NA ....... - _ 16 Pre -produced injector: duration of pre production less than 3 months, (For serv(ce welt only) - - NA . . . . . . . . ............. . . 18 Conductor stringprovided. . . . . . .. ........................ . . . . . . . NA - - - . - - . Conductorprovidedfor KRU 1 H-103 Engineering 19 Surface casing protects all known USDWs . . . . .. . . . ......... . . . . . . . . . . . . NA .... _ .. Surface casing will be set in KRU IH -103 . 20 CMT. vol adequate. to oirculate on conductor & surf.csg ... .... _ - - - - ....NA...... _ - Surface casing will be cemented to surface in KRU 111-103 21 CMT vol adequate to tie-in long string to surf csg_ - - - - _ - - - - ....... NA - - - - - - - - - - - - - - - - ---- - - - - - - - - - - - ............. - 22 CMT will cover all knownproductivehorizons. _ _ - _ _ - _ - _ _ _ _ - _ No - - _ _ Productive, interval will be completed with uncemented slotted liner - - - 23 Casing designs adequate for O,. T, B.& permafrost - - - . _ Yes ----- - - - - - - - - - - - - - - - - - 24 Adequate tankage or reserve pit - ..... - ..... - - - _ - - Yes Rig has steel tanks; all wastetoapproved disposal wells_ 25 If. a, re -drill, has a 10-40$ for abandonment been approved - - - - - - - - - - - - - - - ---NA 26 Adequate wellbore separation proposed- - _ - - - - _ _ - - - - - - - _ Yes - _ Anti -collision analysis complete; no major risk failures - - - - - - 27 If diverter required, does it meet regulations . . . . . ... . . . .... . - - - - - - - - - - _ NA- - - - - - - _ I - Appr Date 28 Drilling fluid program schematic .& equip list adequate- - - - - - - - - - - - - .. Yes .... _ Max formation pressure is. 1764 psig(8.4 ppg EMW ); will drill w/ 8.8-9.5 ppg EMW. - - - VTL 2/22/2018 29 BOPEs,-do they meet regulation - - - - - - - - - .. Yes - - - - - - - 30 BOPE.press rating appropriate: test to -(put psig in comments)- _ - - - _ .... - - .. Yes - - - - - - _ MPSP is 1367 prig; will test BOPs_to 3500-psig.. . . ......... . . . . . . 31 Choke manifold complies w/APl RP -53 (May 84) . . . . . . . . . ..... - - - - _ - - Yes 32 Work will occur without operation shutdown_ .. - - - - - _ Yes ---- 33 Js presence of 1-12S gas probable--- - - - - - - - - - - - - - - -- - - - - - - - - .... Yes 112S measures required.. - 34 Mechanical.condition of wells within AOR verified (For service well only) - - - _ NA - - - _ - - - - - - - - - - - - 35 Permit coo be issued w/o hydrogen sulfide measures _ - - - - - - - - - .........RO - - - H2S measures required. Well 1H-102_mesured 20 ppm H2S on November 20,-2017.. Geology 36 Data. presented on potential overpressure _zones - - _ - Yes _ - _ _ _ .. Expected res. pressure is -8.4 ppg EMW; will be drilled with 8.8 - 9.5 ppg mud... APP- Date 37 c analysis of shallow gas - zones . - Seismic - ................... ....... - N A ......... - - _ .... I .. ... . ---- -----.. -------...... SFD 1/12/2018 38 Seabed condition survey (if off -shore) - - - _ - - _ - NA . ... . ......... . . . . . . . . . . .......... . . . . . . . . . . . 39 Contactname/phone for weekly.progress reports -[exploratory only]- Geologic Engineering Public Commissioner: Date: Date Co mi loner Date IF S 2. ( f ��� tXvcq ZCoommissioner: Q 2846 Z 1�'1
