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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, May 24, 2021 P.I. Supervisor ��I I SUBJECT: Mechanical Integrity Tests Em US Operating Company Inc. 0113-03 FROM: Bob Noble NIKAITCHUQ 0113-03 Petroleum Inspector Src: Inspector Reviewed By: _ P.I. Supry NON -CONFIDENTIAL Comm Well Name NIKAITCHUQ 0113-03 API Well Number 50-029-23452-00-00 Inspector Name: Bob Noble Permit Number: 211-100-0 Inspection Date: 5/6/2021 - Insp Num: mitRCN210507170026 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 0113-03 Typ4Test - TVD 3529 _ Tubing 198 199 738 1653 - 199 199 1618 PTD i 2111000 TypT Test psi 1500 IA 1623 BBL Pumped: 32 eturned: a-2 OA 220 2ao 220 220 . Interval1---- _ aYxTST -- P/F P I Notes: Monday, May 24, 2021 Page I of I DATA SUBMITTAL COMPLIANCE REPORT 415/2019 Permit to Drill 2161000 Well NamelNo. HANSEN H-16XL05 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-64-00 MO 20743 TVD 6752 Completion Date 12/14/2018 Completion Status 1-011- REQUIRED -OILREQUIRED INFORMATION Mud Log ,D7(i Samples "5 41 DATA INFORMATION List of Logs Obtained: GR/RES/NEU/DEN, Mudlogs Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data ED C 30250 Digital Data Current Status 1 -OIL UIC No Directional Survey Yes / (from Master Well Data/Logs) Log Log Run Interval OH I Scale Media No Start Stop CH Received _ Comments 18734 20707 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- L05_EcoScopeImages _RM_LAS.Ias 18704 20742 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- 1-05_EcoScope_RM_LAS.Ias 1/15/2019 Electronic File: BlueCrest _H16A-L05_EcoScope Images_RM_DLISAlis 1/15/2019 Electronic File: BlueCrest _H16A-L05_EcoScope Images_RM_DLIS.html 1/15/2019 Electronic File: BlueCrest H16A- 1-05_EcoSoope_ RM_DL IS.dlis 1/15/2019 Electronic File: BlueCrest H16A- LOS_EcoSoope_ RM_DLI S.htm I 1/15/2019 Electronic File: BlueCrest_H16A- L05_EcoScope_2in_RM_MD. Pdf 1/15/2019 Electronic File: BlueCrest H16A- L05_EcoScope_2in_RM_ TVD. Pdf 1/15/2019 Electronic File: BlueCrest H16A- L05_EcoScope_5in_RM_M D. Pdf 1/15/2019 Electronic File: BlueCrest_H16A- L05_ EcoScope_5in_RM_T V D. Pdf 1/15/2019 Electronic File: BlueCrest H16A- L05_EcoSoope_Image_5in_RM_MD. Pdf 1/15/2019 Electronic File: BlueCrest_1-116A-1-05_DD Surveys final.pdf 1/15/2019 Electronic File: BlueCrest_1-116A-1.05_DD Surveys final.xlsx AOGCC Pagel of 4 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/512019 Permit to Drill 2181000 Well Name/No. HANSEN H -16A -LOS Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-64-00 MD 20743 TVD 6752 Completion Date 12/14/2018 Completion Status 1-0I1- Current Status 1 -OIL UIC No ED C 30250 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A-L05 Final Surveys.csv Log C 30250 Log Header Scans 0 0 2181000 HANSEN H-16A-LLOG HEADERS OS ED C 30250 Digital Data 0 0 Electronic File: H16A-L05 ASP Final Survey.pdf ED C 30250 Digital Data 0 0 Electronic File: H16A-1-05 ASP Final Survey.xlsx ED C 30548 Digital Data 14450 20790 4/3/2019 Electronic Data Set, Filename H16� =NAM ED C 30548 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors 11-11-18.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-12-18.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 11-13-18.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-LO5.dbf ED C 30548 Digital Data 4/3/2019 Electronic File: ht6a-105.hdr ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-LO5.mdx ED C 30548 Digital Data 4/3/2019 Electronic File: h16a-L05r.dbf ED C 30548 Digital Data 4/3/2019 Electronic File: hl6a-L05r.mdx ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-1-05_SCL.DBF ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-L05_SCL.MDX ED C 30548 Digital Data 4/3/2019 Electronic File: BLUE CREST ENERGY H -16A FINAL REPORT.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-L05 - Drilling Dynamics MD.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-Lo5 - Formation Log MD.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-LO5 - Gas Ratio MD.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-LO5 - LWD Combo MD.pdf ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-L05 - Drilling Dynamics MD.tif ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-L05 - Formation Log MD.tif ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-LO5 - Gas Ratio MD.tif ED C 30548 Digital Data 4/3/2019 Electronic File: H16A-L05 - LWD Combo MD.tif AOGCC Page 2 of 4 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permitto Drill 2181000 Well Name/No. HANSEN H -16A -L05 MD 20743 TVD 6752 Completion Date 12/14/2018 ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data ED C 30548 Digital Data Log C 30548 Log Header Scans Well Cores/Samples Information: Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-64-00 COM13letlon Status 1-0IL Current Status 1 -OIL UIC No 4/3/2019 Electronic File: H16A-L05 Show Report 31 19740-19865 page 1.pdf 4/3/2019 Electronic File: H16A-L05 Show Report 31 19740-19865 page 2.pdf 4/3/2019 Electronic File: H16A-L05 Show Report 32 19955-20085 page 1.pdf 4/3/2019 Electronic File: H16A-L05 Show Report 32 19955-20085 page 2.pdf 4/3/2019 Electronic File: H16A-L05 Show Report 33 20165-20372 page 1.pdf 4/3/2019 Electronic File: H16A-1-05 Show Report 33 20165-20372 page 2.pdf 4/3/2019 Electronic File: 1116A-1-05 Show Report 34 20410-20743 page 1.pdf 4/3/2019 Electronic File: H16A-L05 Show Report 34 20410-20743 page 2.pdf 2181000 HANSEN H-16A-LO5 LOG HEADERS Sample Interval Set Name Start Stop Sent Received Number 'Comments Cuttings 19500 20743 11/26/2018 1685 INFORMATION RECEIVED Completion Report Y Directional / Inclination Data YO Mud Logs, Image Files, Digital Data NA Core Chips Y / Production Test Information Y / �A Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files® Core Photographs Y /1 Geologic Markers/Tops DY Daily Operations Summary V Cuttings Samples �) NA Laboratory Analyses Y COMPLIANCE HISTORY Completion Date: 12/1412018 Release Date: 9/13/2018 Description Date Comments AOGCC Page 3 of 4 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2181000 Well Name/No. HANSEN H -16A-1-05 MD 20743 TVD 6752 Completion Date 12/14/2018 Comments: Complian< Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051.64.00 Completion Status 1-0I1 Current Status 1-0I1 UIC No AOGCC Page 4 of 4 Friday, April 5, 2019 21 81 00 30 54 8 Ae est n re BlueCrest Alaska Operating LLC 3301 CStreet, Suite 202 Anchorage, AK 99503 Tel: (907) 754-9550 Fax: (907) 677-0204 Transmittal Today's Date: 4/3/2019 Transmittal #: 2019-05 To: Ms. Meredith Guhl From: Andrew Buchanan Company: AOGCC Company: 1 BlueCrest Alaska Operating LLC `Re: Mud Logging Data -H16A Well: H16A-td5 Included Information: 8 CD's with Mud Logging Data for Well H 16A. Regards Andrew Buchanan BlueCrest Energy RECEIVED APR 0 3 2019 AOGCC 218100 30200 Schlumberger -Private STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil Q Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAGE WDSPL ❑ No. of Completions: 1b. Well Class:- `--` Development Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: BlueCrest Alaska Operating LLC 6. Date Comp., Susp., or Comp: 12/14/2018 14. Permit to Drill Number/ Sundry: 218-100 ' 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 7. Date Spudded: 11/11/2018 15. API Number: " 50-231-20051-64.00 4a. Location of Well (Governments[ Section): HI 6A - L05 Surface: 2408' FSL, 1509' FEL, Sec 2, T4S, R15W, SM Top of Productive Interval: 169' FSL, 177' FEL, Sec 29, T3S, R15W, SM Total Depth: 790' FSL, 1165' FEL, Sec 29, T3S, R15W, SM 8. Date TO Reached: 11/14/2018 16. Well Name and Number: H16A - L06 9. Ref Elevations: KB: 180.25' GL:145.81 RKB:180.4 17. Field / Pool(s): Hansen,Undefined Cosmopolitan Oil 10. Plug Back Depth MD/TVD: 20743' MD / 6752' TVD 18. Property Designation: Fee Hansen,ADL18790,ADL 384403 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 168861.855 y- 2144856.07 Zone- 4 TPI: x- 154580.74 y- 2153578.86 Zone- 4 Total Depth: x- 153610.04 y- 2154226.91 Zone- 4 11. Total Depth MD/TVD:. 20743' MD / 6752' TVD 19. DNR Approval Number: LOCI 14-007 12. SSSV Depth MDrrVD: 543' MD / 542' TVD 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes Ld (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 19,525' MD / 7,063' TVD (11-05-KOP) 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary ALL LOGS WERE SLB LWD: GR-Res--Den-Neu-PWD Final Mudlogging Report / Mud Log / Lithology Log (Nabors-CanRig) Formation Log / LWD Combo Log / Gas Ratio Log / Drilling Dynamics Log 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 0.500" wall A525 41 187 41 187 Driven N/A - Rotary Drilled/Driven N/A 13.375 72 L-80 40.5 4177 40.5 3175 17.5" 588 bbls Lead / 198 bbls Tail N/A 9.625 47 P-110 40.6 13161 40.6 6688 12.25" N/A WA 9.625 53.5 P-110 13161 14767 6688 7083 12.25" 178 bbls 15.8 ppg G -Tail N/A 4.5 15.2 P-110 14381 21510 7070 7068 8.5" Slotted Liner - no cement N/A 3.5 9.3 L80 26.46 14435 26.46 7076 N/A Production Tubing String N/A 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Laterals L01 through L07 completed barefoot and left uncased. I L11411t7 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/'TVD) 3.5" 14435' MD 14381' MD / 7070' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No t Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift. etc.): Date of Test: Hours Tested Production for Test Period Oil -Bbl: Gas -MCF: water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (torr): Form 10.407 Revised 5/2017 d, CONTINU D ON PAGE 2 (� Submit ORIGINtAL 0 � 28. CORE DATA Conventional Cot ets): Yes ❑ No Q Sidewall Cores: . as ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 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. Hemlock 20396 6886 t Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. TPI / KOP 19525 7063 Formation tops above are for the H 16A - L05 Lateral Formation at total depth: lHemlock 31. List of Attachments: Operations Summary, Actual Wellbore Diagram, List of Formation Tops, Mud Wt vs. Depth Data, Final Definitive Directional Surveys, Slotted Liner String Tally (4-1/2'), Tubing String Tally (3-1/2"), Wellhead & Tree Schematic, Pressure Test Results Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Larry Burgess Contact Name: Tom McKay Authorized Title: Alaska Manager Contact Email: tom.mckav(o)bluecrestenerov.com Authorized©��dN Zo(� Contact Phone: 907-754-9566 /7 Signature: Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Altemating-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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or Inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only lue est Energy 3301 C Street, Suite 202, Anchorage, AK 99503 Thomas McKay, PE Phone: (907) 754-9566 Email: tom.mckay@bluecrestenergy.com January 9, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Well Completion Report Form 10-407: Horizontal / Multilateral "Fishbone" Production Well H16A — L05 Lateral PTD No. 218-100 API No. 50-231-20051-64-00 Dear Commissioners, BlueCrest Alaska Operating LLC hereby submits a completed Form 10-407 Well Completion Report with Attachments for the onshore horizontal / multilateral production well H16A— L05 Lateral. This well was sidetracked, drilled, and completed using BlueCrest Rig #1. The well is currently undergoing an extended flow test on gas lift after installing the 4-1/2" slotted liner completion. Note that the flow test results, etc., as per AOGCC request, will be covered under a subsequent 10-407 package, along with other required well production tests and reports. Please find attached for the review of the Commission, the completed Form 10-407, and the information required by 20 ACC 25.070 for this wellbore, covering the sidetracking, drilling, and completion of the "fishbone" multilateral, including a separate report for each barefoot lateral L01 through L07; and the running of the upper 3-1/2" tubing string. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office phone). Sincerely, 7Z"ti ( / 4Z Larry Burgess Alaska Manager nue est Energy BlueCrest Energy Alaska Cosmopolitan Project H1 6A — L05 — Form 10-407 Well Completion Report List of Attachments AOGCC Item No. Description A Cover Letter 1 AOGCC Form 10-407 Well Completion Report (2 pages) 2 Operations Summary (Daily Running Summary) 3 Actual Wellbore Schematic (as completed with slotted liner & tubing string) 4 Detailed List of Formation Tops / Geologic Markers (Box 29) 5 Mud Weight vs Depth Data Table 6 Definitive Wellbore Survey (Directional Survey) Formation Tops X Y Z MD TVD H16A Hemlock 156984.01 2151923.68 -6896.49 16605 7076.92 H16A Hemlock 152764.05 2154807.92 -6887.87 21720 7068.3 H16A-LO1 none H16A-LO2 Hemlock 155887.24 2152665.21 -6755.34 17944 6935.77 H16A-L03 Hemlock 155158.83 2153186.22 -6691.86 18851 6872.29 H16A-LO4 Hemlock 154480.46 2153630.53 -6687.77 19660.15 6868.2 H16A-LO5 Hemlock 153878.37 2154053.2 -6705.58 20396.49 6886.01 H16A-LO6 Hemlock 153397 2154395.54 -6776.29 20974 6956.72 H16A-LO7 Hemlock 152985.49 2154666.24 -6849.88 21459.92 7030.31 T. McKay, 31Dec2018 20" Conductor @ 187' BGL 13-3/8" 72# L80 BTC @ 4177' M D 3-%" 9.2# ELIE 8RD Production Tubing 4-%" x 9-5/8" Liner Hanger & Liner Top Packer H16A Lower Lateral ACTUAL Completion with Slotted Liner in Mainbore and Seven (7) Open Hole Fishbone Ribs NOTE: Well was sidetracked off a whipstock set at 14538' MD top of window in the 9-5/8" casing 9-5/8" 47.0/53.5# P110 H563 @ 14767' M D Zu ksr " Eni6v Fishbone ribs are 8-Y2" open holes spaced approx every 800' with 4-Y2" slotted liner run in the mainbore after the seven ribs are drilled; ribs are drilled in order from LO1 to L07 using open hole sidetracks to initiate each rib; ribs penetrate all layers of Starichkof and Hemlock pay sands LO1 L02 L03 L04 LOS L06 L07 4-Y2" 15.2# H563 Slotted Liner @ 21,510' MD WeliView BC - Daily Recap Well Name: H16A Well Name APIAIWI Surface Legal Location License# H16A 231-20051-01-00 2408'FSL, 1509' FEL,SEC.02T4S,R15W SM 218-095 Spud Data Rig Release Date Ground Elevation (fl) KB�Grountl Distance (fl) - Well SuDypa 10/16/2018 23:00 145.81 34.43 . Fish bone Daily Operations Start Dale ErM Date Spud Date ToleF. ) 9/26/2018 Survey Data MD (flKB) Incl (°) ND (flKB) VS (fl) N$ (R) EW (fl) DLS (°/1008) Dale 21,587.58 89.79 302.69 7,068.24 18,791.47 9,44 .39 -16,246.95 0.46 21,681.42 90.35 303.05 7,068.13 18,885.19 9,493.32 -16,325.76 0.71 21,774.79 89.90 303.32 7,067.93 18,978.41 9,544.43 -16,403.97 0.56 Rigs ConVacror Rig Number Daily Operations Rpt# Start Data End Data Summary 1.0 9/26/2018 9/27/2018 Repair annular BOP 2.0 9/27/2018 9/2812018 skid rig 3.0 9/2812018 9/29/2018 center dg over hole 4.0 912912018 913012018 hook up lines from pits to sub base 5.0 9/3012018 101112018 SET STAIRS ON SUB BASE AND PITS 6.0 10/1/2018 101212018 set berms for dg and pits/ mats for pits and set cuttings tanks 7.0 10/212018 10/312018 CENTER TOP DRIVE RAIL Finish pit liners around rig 8.0 10/3/2018 10/412018 Start up boilers and function test top drive 9.0 10/4/2018 101512018 Working on boilers) preparing the pipe shed for picking up DP and stand it back. Taken some fresh water in the mud pits and test the mud pumps an high pressure mud lines. 10.0 1015/2018 101612016 Install bell nipple, choke and kill lines. Install koomey lines and secure stack tie downs. 71.0 1016/2018 101712018 Drilling line was slipped on and top drive quit working 72.0 10/7/2018 101812018 Install new 3%d' x 5%" VBR's in bottom ram, Install 3%" solid body style in top ram. Change out top drive IBOP valve, and -re-test. Witnessed by AOGCC Jeff Jones. 13.0 1018/2018 101912018 PU 348 joints of 5 %' XT 54 DP via mouse hole and stand back. This pipe will stay in the casing while drilling. Torque all connections to 49,000 Nibs. 74.0 1019/2018 10/10/2018 Pick up a total of 154 stands of 5%" XT54 DP. Bull head 80 bible 100° water down IA. Bull head 140 bible down tubing. 100° water. Unseat hanger with 180k up weight. Free travel (� 160k. Tum on hole fill pump as hanger was coming up. Measure high levels of methane gas on rig floor, no pressure high volume, Re -land hanger, and bull head 100 bbls pill with 2.5# bbl 20 micron CACI, Followed by 100 bbis water. bleed gas oft IA. Pull hanger to floor. Well dead, no gas readings. Prepare to lay down tubing. 75.0 1011012018 10/11/2018 Kill well, 18 PSI on backside.Bullhead tubing volume plus 10 bible, bullhead 200bb1s down IA, bleed residual gas off to production bleed tank. Lay down landing joint, hanger and pup. Open SSSV. Run chem line and I- Wire through sheaves, POOH laying down 3%" EUE 9.3# L-80 tubing from joint if461 to joint #282. Retreive _ " all cannon clamps. Fill hale with Sx's displacement every 10 joints. 16.0 10/11/2018 10/12/2018 Complete tubing pull operations. 461 joints of 3%" EUE 9.3# L-80, 3 GLM's, SSSV, Chem injection sub, seal assembly. All joints and equipment to be inspected prior to re -running. Remove casing bails, and GBR 75 ton tubing elevators, install drilling bails and drilling elevators. 17.0 1011212018 10/13/2018 Rig down GBR tubing running equipment, remove long bails, 75 ton elevators, cannon clamps, GLM's, all completion equipment from rig floor and pipe shed. Rig down and release Carrico spoolers, GBR. Strap 3 spiral DC's, 18 HWDP, TIH with Halliburton EZ drill SVB packer on XT 54 5%" DP. 18.0 10/13/2018 10/14/2018 Trip in hole with Halliburton F1 Drill Packer. Set (� 14620'. Mid joint. Fluid pack well with water. Circulate gas out through poor boy degassr. 920 units gas max down stream of degasser. 19.0 10/14/2018 10/15/2018 Circulate surface to surface 4BPM through open super choke & poor boy degasser. 920 Units max gas. Conduct casing test to 3500 psi, 30 mins, Charted. Good. Dispose of excess fluids in pit system. Displace well to 9.2 ppg OBM. Pump dry job. POOH strapping pipe. 20.0 1011512018 10/16/2018 TOOH from 4598' to surface. Lay down "Mechanical setting tool" ager Halliburton CIBP run. Clean and clear rig Floor. Pick up whipstock assembly with MWD tool. Orient. TIH to 1500'. Pulse test MWD tool. Mud pumps #2 & #3 were used. Both experienced pressure losses. Three cycles of pump pressure were recorded. Both pumps were isolated, and the cap gaskets were not properly installed. Both pumps put back together as per specification. Tested flowing through the choke manifold with 1500 PSI back pressure. Good. Decide to trip out for back up " Mufti cycle by-pass tool". POOH to surface change out tools. Orient. TIH @ 45'/minute lowering speed. Trip to 1327'. crew change. 21.0 10/76/2018 10117/2018 Shallow pulse test MWD tool (r� 1325' MD. TIH W/ BHA#2 whipstock I Mill assembly to 3766'. Failed solenoid top drive elevators closing function. Replace solenoid. TIH to 6282'. Failed solenoid top drive handler function. Replace. TIH to 14551', stand #147. Orient Whipstock 38 right. Failed solenoid top drive pipe handler rotational locking device. Replace. Set whipstock Q 14,563' bottom of tool. TOW=14,538', BOW= 14,552'. Begin milling @ 14,538'. 22.0 10/17/2018 10/18/2018 Milled window 14,535' to 14,543'. At 14,543'a pressure loss of 275psi was observed and milling torque fell . POOH to inspect the BHA and mills. UD Drill collars, MWD, as well. Varied parameters and made Vin 7hrs HWDP Flex, running tool, and Mill. www.peloton.com Page 115 Report Printed: 1212612018 . POOH to inspect the BHA and mills. UD Drill collars, MWD, HWDP Flex, running tool, and Mill. WellView' Well Name: H16A BC - Daily Recap Daily Operations Rpt # Start Date End Date Summary 23.0 10/18/2018 10/19/2018 UD BHA#2(bottom tri -mill badly junk damaged and 1/4" under gauge). P/U BHA#3(new tri -mill easy). RIH to 14,543" and Mill/Drill window and new formation to 14,569'- Pump sweep and circulate hole clean with 9.2 ppg mud wt in and out. POOH above window- R/U to perform FIT - 24.0 10/19/2018 10/20/2018 Circulate for FIT, R/U and perform FIT, formation broke down @ 1470 psi - R/D FIT assemably and monitored well on TT. High losses and began mixing LCM pill, pumped same, continued monitoring while mixing other LCM pill. Spotted 2nd pill and monitored losses. Began milling @ 15, 569' to 15,582'- Mill quit drilling - Observed well for losses - Pump out of hole 25.0 10/20/2018 10/21/2018 -C/O the grabber dies on the topdrive. -Pumped out of the hole 13,838'to 12,263'. -Pipe handler on the topdrive not functioning. Found a loose connection on a hydraulic line, tightened the connection and checked OK. -Pumped out of the hole 12,263'to 9,720'. -Serviced the rig. -Pumped out of the hole 9,720' to 3,171'. -Serviced the rig. -Average losses while pumping out 2BPH. 26.0 10/21/2018 10/22/2018 -Pumped out of the hole 3171' to 2983' -Pull out of the hole on elevators 2983' to 576'. -UD 18jnts of 5.5" HWDP. -UD mill easy, bottom 2 mills 1/4" under gauge. -Clean and clear the rig floor. -P/U the wash tool and wash the BOPE stack. Recovered 1 l of metal. -Pull the wear bushing and run the test plug and 5.5" lest joint. -Test BOPE on 5.5" and 5" lest joint 250/3500 psi 5 min. -Pull the test plug and install the wear ring. -C/O the solenoid for the top drive compensator valve. -C/O topdrive washpipe from Tesco to mechanical. -P/U the motor BHA with crane assist. 27.0 10/22/2018 10/23/2018 -P/U 6 joints of 5.5" HT -55 drill pipe while RIH to 328'. -installed the mechanical washpipe. -Troubleshoot the topdrive grabber problem and installed a shorter saver sub and checked hydraulic pressure to the ram(OK). Verified that the saver sub could be broken out OK. -RIH to 2109' and filled the pipe and tested the MWD OK. -Continued to RIH to 7823' and serviced the rig - Trip in hole f/ 7823' to 14,485'- Slip and cut 110' Drilling line - Adjusted COM - Calibrated block height - Trip in to TOW @ 14,538 take SCR's orient tools and run through the window. Open under gauge hole to 14,582'- drill new hole to 14,622" 28.0 10/23/2018 10/24/2018 - Rotary Drill and Slide f/ 14,622' to 14,735'- WOB = 20/30K - 40 GPM = 1950 psi - 40 RPM - P/U WT = 305K - S/O WT = 150K - ROT/WT = 210K - Average losses = 13 BPH - Backream OOH F/ 14, 735' to BOW @ 14, 552' - Oriented the motor and pumped out through window with 30 GPM with no excess drag - P/U WT 330K with 30 GPM - Begin dean up cycles and slowly bled in LCM pill 3. - 450 GPM @ 1750 PSI - 80 RPM - Torque = 26K - P/U Wt = 220 K - Service TDS, drawworks, blocks, crown, clutches, upper bearing quill, choke, and IR - Monitoring well on TT with no losses - Pump out of hole as per K & M procedures F/ 14,209' to 7,983'. @ 9962' Attempted to adjust the topdrive grabber box lower limit. Found a washed out valve. Changed the safety chain on the topdrive grabber box. 29.0 10/24/2018 10125/2018 - Pumping out of hole F/ 7983'T/3853" - Continue POOH on elevators F/ 3853' to 130' as per K & M Trip schedule - R/U and UD BHA with crane - Remove wear bushing - Install test plug and test BOPE to 250 PSI Low & 3500 PSI High - Remove test plug - Install Wear bushing - P/U New BHA - 30.0 10/25/2018 10/26/2018 - RIH picking up HT 55 Drill pipe to 2063'- Shallow test Directional tools with 460 GPM and 975 PSI - RIH picking up HT 55 DP to 3071'- Service Rig - Losses @ 1 BPH - P/U HT 55 DP to 5760' ( total jts picked up = 174) Filled pipe every 20 Stds - Trip in hole from derrick @ controlled speed as per K & M Tripping schedule T/ 14,500'- CBU - Take SCRs - RIH through Window to 14,640'- Begin Rotating from 14, 640 to 14,727'- Drilled New hole to 14,795' - Unable to hold Tool Face due to erratic torque - Rotate and reciprocate pipe while conditioning mud 31.0 10/26/2018 10/27/2018 - Circulate and condition mud - Drill F/ 14,795' to 14,838'- Torque erratic - Tool Face control on the RSS was lost - Circulate and add Lube to active mud system to 0.5%- Drilling F/ 14,838' to 16,336' 32.0 10/27/2018 10/28/2018 - Drilling from 16,336' to 17,440' as per DD and K&M Schedule - Back Ream F/ 17,440' T/ 16,213' as per K&M Back Reaming Schedule - Service Rig - UD (3) As DP with excessive wear - RIH F/ 16,213' to 16,375' - Trenching and Time Drilling as per DO F/ 16,375' T/ 16,377' 33.0 10/28/2018 10/29/2018 - Time Drilling F/ 16,377' T/ 16,397'- Drilling ahead F/ 16,397'to 18,214' on Lateral # 2 34.0 10/29/2018 10/30/2018 Worked Stuck pipe Free with applying torque in string and worked down, observed string free with 30K Torque - Clean hole back reaming F18,213' T 18,122'- Drilling L02 F/ 18,213'to 18,390' (TD of Lat 02 - Back ream F/ 18,390; to 18,213' - Trouble shoot HPU for Overheating - Service rig - Back Ream F/ 18,213' to 117,390'- 35.0 10/30/2018 10/31/2018 - Time Drilling F/17,138' T/ 17,143'- Drilling Main Bore F/ 17,143'T/17,746'- Service TDS - Drilling F/17,746' T/18,592'- ( KOP F/ Lateral 03 17,933') Service Draw Works and ST 100 - Change Grabber dies www.peloton.com Page 215 ReportPrinted: 12126/2018 WeliView° Well Name: H16A BC - Daily Recap Daily Operations Rpt4 Start Date End Date Summary 36.0 10/31/2018 11/1/2018 Directional Drill 8%' hole from 18,592'to 19,268'. TD of L03. Change out grabber dies in top drive. Back ream out to 17,950'. Hole in good shape. Begin troughing from 17,975' to 18,000' MD for L04. 37.0 11/1/2018 11/2/2018 Directional work. Low side sidetrack. trench from 17,975' to 18,000' MD. Time drill to 18,045'. Began pushing on BHA @ 18,045', WOB increased to 10k, and inclination dropped. Successful sidetrack. 38.0 11/2/2018 11/3/2018 Directional Drill 8%" hole with Exceed rotary steerable system from 18,122 to 19,249' MD. Drilling in L04. 39.0 11/3/2018 11/4/2018 Directional Drill 8%" hole with Exceed rotary steerable system from 19,249' to TO of L04 @ 20,020' MD. CBU 5x's while back reaming. Back ream out to 19,280' MD 40.0 11/4/2018 11/5/2018 BROOH from 19,280'to the whipstock @ 14552' BOW. Pull slow into casing, no rotary. CBU 2x's inside rasing. Service rig. Back ream one more full bottoms up. POOH pumping 100 GPM, no rotary, from 14,552' to 12,148' MD. Good hole fill. 41.0 11/5/2018 11/6/2018 Pump out of the hole 100 GPM, 350 PP, from 12,148'to 5930'. CBU 2x's. Pump dry job. Trip out of the hole laying down singles. HT 55 drill pipe. From 5930' to Surface. Begin to lay down BHA#5. Constant hole fill using trip tank. 42.0 11/6/2018 11/7/2018 Lay down BHA#5. Lay down 180 joints of HT 55, and 360 joints of XT 54 from derrick and prepare for Premium Inspectors to machine on new hard banding. 43.0 11!7/2018 11/8/2018 Lay down 5%' XT 54 drill pipe for hard banding. Repair HPU,inslall new fire rated hose coverings for Koomey room lines as per AOGCC. Install new XT 54 saver sub. Pull wear bushing, Install test plug. Begin testing BOPE with 5" TJ. 44.0 11/8/2018 11/9/2018 Conduct Bi -Weekly BOPE lest W/ AOGCC Inspector. 5" and 5Y2" test joints. Rig down test equipment. PIU and stand back 78 joints of 5%" XT 54. ODS. Discover out of spec XO provided for new 5" XT DP. (Wall thickness below minimum. 3.5 ID versus 2.813", junk XO). Rig up and test BOPE W14%" TJ to enable Rig Team to use XT 46 string. Pick up BHA#6. Single in hole with 5 joints HT 55. Repair broken hydraulic hose on top drive, adjust clamps on bails to reach mouse hole. 45.0 11/9/2018 11/10/2018 Single in the hole with 246 joints of HT 55 OP. Fill pipe every 60 joints. Cross over to XT 46 DP. Continue strapping, drifting all pipe, and singling in the hole monitor the well on the trip tank. 120 joints of 4%" in hole @ midnight. 46.0 11/10/2018 11/11/2018 Continue to single in the hole with 41/V XT 46 from 10977' to 13,347'. Well Bore began to U-tube. Circulate bottoms up. Balance well. Single in remaining XT 46 pipe to 14,063'. 195 JTS total. Pick up and stand back 29 stands of XT 54 DP via mouse hole Slip and cul 120' of drill line. TIH to 14,434'. CBU, Downlink to Exceed tool. Record up and down weights. Trip past whip stock, and RIH to 15,194' MD. 47.0 11/11/2018 11/12/2018 TIH fr. 15,194' to 16,219'. Ream to 17,160'. Inadvertently entered build of L2. Pull back to 17,120', steer down with 70% deflection to stay in Mother bore. Ream to 17,160'. TIH on elevators to 17,873'. Lose down weight. Ream from 17,873'to 18,770'. Sidetrack from 18,770' to 18,800'. First attempt to sidetrack was unsuccessful, second time drill sequence was good. Drilling ahead @ 18,860' MD. 48.0 11/12/2018 11/13/2018 Directional drill L05 W1 Exceed rotary steerable system, 8%" hole from 18,860' to 20,538' MD. 49.0 11/13/2018 11/14/2018 Directional drill L05 WI Exceed rotary steerable system, 8%" hole from 20,538' to 20,743' MD. BROOH slow, perform clean up cycle. Pick up and stand back 6 stands of newly hard banded XT54 DP. BROOH to 19,500. Trough from 19,500 to 19,525'. Time drill to 19545', Begin drilling L06 from 19,525'to 19,881' MD. 50.0 11/14/2018 11/15/2018 - Drilling 8 1/2" hole L06 with Exceed Rotary steerable assembly F/ 19,881' 7/21,340' - Circulate and clean hole, P/U 6 stds of DP while circulating - BROOH T/ 20,350' 51.0 11/15/2018 11/16/2018 - Back Ream F/20,350' T/20,257' @ 15 FT/MIN - Service Rig - Troubleshoot and repair Reminder, Trenching as per DD F/20,250' 7/20,270' - Time Drilling as per DO F/ 20,270'T/ 20,295'- Drilling 8 1/2" hole as per DO & K&M parameters F/20,295' TI 20,925' 52.0 11/16/2018 11/17/2018 -Drilling 8 1/2" hole F/ 20,925' T/ 21,092'- Replaced Wash Pipe seals in TO -Drilling FI 21,092' 7/21,850' - Service Rig 53.0 11/17/2018 11/18/2018 - Drilling F/21,850' T/ 21,660' TD for L07 - Begin Clean up cycle and Pick up 5 STDS of XT 54 DP and Rack in Derrick - Back Ream F/ 21,745'T/ 21,146'- Begin trenching F/ 21,145' T/ 21,165' - Time Drilling F/ 21,165' T121,194' - Drilling L08 F/ 21,194'T/ 21,850' 54.0 11/18/2018 11/19/2018 - Drilled 8 1/2" hole L08 as per DD & K&M Parameters F/ 21,850'T/ 22,310' TD - Performed Clean up cycle as per K&M Parameters - Flow check after the first cleanup cycle, no flow. Circulating Bottoms up x 6 and while back reaming @ 1 1/2 FT/MIN F/2 22,310'T/ 21,753'- Back reamed F/ 21,753'T/21,475'@ 15 FT/MIN - Serviced Rig 55.0 11/1912018 11/20/2018 - Back Reamed out of hjole F/ 21,475' TI 19,787'- Worked through tight spot F/ 20,843'T/ 20,833'- Back Reamed F/ 19,787'T/ 18,660'- Service Rig Equipment - Back Reamed out of hole F/ 18,660' T/ 17,110' - RIH ( Had to rotate) T/ 1721 1'and took survey to confirm still in Main Bore OK - Back Reamed F/ 17,211' TI 15,003'- SLM 56.0 11/20/2018 11/21/2018 - Replace IBOP Actuator due to bearing seizure(flow check, no gain/loss) - Back Reamed out of hole as per K&M Parameters FI15,003' T/ 14,672" - POOH with BHA through window with 100/GPM & No Rotation F/ 14,672' TI 14,510' - Back Reamed while performing Clean up Cycle to 14,165'- Changed out Saver Sub to - XT 46 foriflow check no gain/loss) pulling 4 112" Drill Pipe - Pumped out of hole F/ 14165'T/ 9,933'- SLM - Serviced Rig www.peloton.com Page 315 Report Printed: 1 212 612 01 8 WellView' Well Name: H16A BC - Daily Recap Daily Operations Rpt# Start Date Ertl Date Summary 57.0 11/21/2018 11/22/2018 - PJSM - Pumped out of hole as per K&M Parameters F19,933' T/ 8,047'- SLM - Break out XOs and M/U Safety valve - Changed out Saver Sub From XT 46 To HT 55 - Monitored Well on TT - Static - Pumped out of hole as per K&M Parameters F/ 8,047'T/ 6,600'- Serviced Rig and monitored well on TT - Static - Pumped out of hole as per K&M Parameters F/ 6,600'T/ 5,832'- Back Reamed out of hole while performing Clean up Cycle @ 1.5 FT/MIN F/ 5,832'T/ 5,732'- POOH on elevators as per K&M Trip Schedule F15,732' T/ 3,525' - Monitor well displacement on TT - Back Reaming out of hole as per K&M Parameters while performing Clean Up Cycle F/ 3,525'T/ 3,430'- POOH on elevators as per K&M trip Schedule F/ 3,430'T/ 163' - Lay down BHA 58.0 11/22/2018 11/23/2018 - Clean and organize Rig Floor - PIU 3 1/2" test joint - Made up Wear Bushing running tool and retrieve Wear Bushing - Made up 3 1/2" test assembly and tested BOPE to 25013500 Psi for 5 MIN - RID 3!/2" Test assembly and M/U 5 1/2" Test Assembly - Test BOPE To 250/3500 PSI for 5 MIN - Test Gas Alarms - Remove test plug - Install Wear Bushing - Rig down Test assembly and clear off rig Floor 59.0 11/23/2018 11/24/2018 - PJSM - RIH Picking up 4 1/2" Liner T/ 7,917' - Steam out ice on collars - Inspect box/pin - Graph monitor make up torque - Monitored displacement on Trip lank - Static - Change elevators - PIU and Make up PBR assembly - Service Rig and monitor well on TT - Remove long bails and elevators - Install short bails and Hydraulic elevators - M/U Liner Hanger and RIH to 8,085'- Establish circulation - RIH with 4 1/2" Liner on HT 55 Drill Pipe from derrick F/ 8,085' TI 14,424'- Drifting each stand after # 36 - Monitor displacement on Trip Tank 60.0 11/24/2018 11/25/2018 - PJSM - Changed Saver Sub, Grabber dies, & installed bell guide and safety wire - Broke out XO from TIW - Made up Stand and checked Parameters - Brake circulation - RIH No drag passing through whip stock window - RIH T/ 17,140'- Hole taking weight - Made attempts to pass through - Made up TDS and rotated F/ 17,040' T/ 18,390' ( End of L02 ) POOH on elevators as per K&M Parameters F/ 18,390'T/ 17,055' - Monitored well on Trip tank - RIH with 4 1/2" Liner as per K&M Parameters F/17,055'TI 18,390'- ( End of L02 ) - Rotated as necessary - Monitored well on Trip Tank - POOH on elevators F/ 11,390'T/ 16,021' - Monitor well on Trip Tank - Service Rig 61.0 11/25/2018 11/26/2018 - PJSM - POOH with 4 1/2" Liner as per K&M trip Schedule F/ 16.021'T/ 7,992'- Monitored well on Trip Tank - Changed out Bails and Elevators to Lay down Liner - Serviced Rig - 62.0 11/26/2018 11/27/2018 - Clean Rig Floor of Base Oil and Inspect tools - PJSM - POOH Laying down 4 1/2" Liner as per K&M trip schedule F/ 4,852'T/ 4,157'- Break connections with rig tongs until 4,300'- Inspected each Box and Pin with Tenaris Rep - Monitored well on Trip Tank - Had Safety Stand down Meeting with crews - POOH Laying down 4 1/2" Liner as per K&M trip Schedule F/ 4,157'T/1,732'- Using GBR Tubing Tongs to break all Joints after 4,300'- Inspected each Joint with Tenaris Rep - Monitored well on Trip tank - Serviced Rig and monitored well on Trip Tank - POOH Laying down 4 112" Liner as per K&M trip schedule F/ 1,732' TI Surface - Inspected each Joint with Tenaris Rep - Monitored well on Trip Tank - Cleaned OBM from Rig Floor - Changed bails and elevators - Monitored Well on Trip Tank - Picked up BHA and RIH T/ 149' - RIH with HT 55 Drill Pipe checking each connection with Premium for wear - Ran in Hole with 20 Stands - POOH with 20 Stands culling out bad Joints under 4 3/4" 63.0 11/27/2018 11/28/2018 - PJSM - POOH laying down 5 1/2" Drill Pipe - Monitor well on Trip Tank - RIH with 5 1/2" HT 55 Drill Pipe from derrick F/ 149'T/ 2,068'- Break Circulation and shallow test MWD tools - RIH with 5 1/2" Pipe from derrick F/ 2,068'T/ 3,775' inspecting each connection with Premium Rep - Monitor well on Trip Tank - Service Rig - RIH with 5 112" HT 55 Drill Pipe from derrick F13,775' T/ 5,691' inspecting each connection with Premium Rep -Cull out bad joints - Monitor well on Trip Tank - PJSM - RIH Picking up 73 joints of HT 55 Pipe from pipe shed F/ 5,691' T/ 8,038' - Drift each joint in V -Door- Fill Pipe every 20 Stands - Monitor well on Trip tank while RIH - Make up XO - change elevator inserts to 4 1/2" - RIH with XT -46 Pipe F/ 8,038'T/ 14,145'- Monitor well on Trip Tank - Fill Pipe every 20 Stands - Changed elevator inserts to 5 1/2" - RIH with XT 54 Pipe T/ 14,424'- Break circulation with 100/GPM - P/U WT 295k - SIC, WT 140k - Service Rig 64.0 11/28/2018 11129/2018 Slip and cul 1 10'of drill line. Inside casing @ 14,442'. Monitor well on TT. Static. TIH. Observe 5 to 10k drag as first two reamers crossed ramp. The third reamer required working the string to drop through. TIH on elevators from whipstock to 16,109' MD. Down weight 100k. Begin reaming. Ream to 16,389'. TO grabber dies changed out. Ream to 16,948'. Service rig. Ream from 16, 948'to 17,205'. L02 exit point. Command rotary steerable tool to 100% lowside deflection, bring pumps up to 450 GPM, from 400 GPM, Increase RPM from 120 to 160 RPM. Work area from 17,208 to 17,285'. Hole unloaded with unconsolidated sand on first BU. Ream from 17,285'to 19,105' MD. MW=9.2 PPG in/out. 65.0 11/29/2018 11/30/2018 Ream to 21,826' MD. CBU W/ 500 GPM, 120 RPM. Service rig. BROOH from 21,826'to 19,291' MD. 15' per minute, adding 5 BPH LVT, maintain 9.2 PPG MW in/out. Wellbore is static without ECD's applied, seepage losses remain around 1 BPH while pumping. SIMOPS: Rebuild liner tally. 192 good joints ready to go. 98 slotted, 94 solid. 66.0 11/3012018 12/1/2018 Continue to BROOK Slight pact o8 in known coal seam. 19,200'to 19,000'. Back ream to 17,605'. Install new grabber dies in top drive. Monitor well on TT. Static. BROOH to L02 exit point. Mimic liner run dropping back in 200 feet. Stayed in Mother Bore, Seismic Event: 7.2 Eath Quake centered 8 miles NW of ANC. Descion made to go back to bottom. Ream back in the hole from 17,100' to 21,264' MD. 67.0 12/1/2018 12/2/2018 Ream to 21,826'. CBU W/ 500 GPM, 120 RPM on first stand. Begin BROOH from 21,737' to 17,130'. Mimic liner run past L02 exit point. Wellbore smooth. Continue to BROOH to 15,441' MD. Inadvertently add LVT to active. Monitor well, weight active back to 9.2 PPG. 68.0 12/2/2018 12/372018 Bring active pit volume back to 9.2 PPG MW. Circulate. 500 GPM, 120 RPM, 2480 PP, 28K TO, BIRCH slow. Circ light fluid into annulus. Depth 15,457'. BROOH to window. 14,710' Circulate 10 mins. Pull first string reamer into casing with 100 GPM. Second reamer required 25 RPM, 400 GPM. Pulled last reamer and bit into window with 400 GPM no rotary. CBU inside casing. 14,430'. Pump out of the hole from 14,430' to 9144' MD. 100 GPM, 350 PSI, 50 to 607min. www.peloton.com Page 4/5 Report Printed: 12126/2018 WeliView' Well Name: H16A BC - Daily Recap Daily Operations Rpt # Start Date EM Date Summary 69.0 12/3/2018 12/4/2018 Pump Out of the hole to the top to the XT 46. 9144' to 8036'.0/O saver sub to HT 55. Grease wash pipe. Change out inserts to 5Ya". Pump out of the hole to 5800'> CBU Pump dry job. Drop 2.75" drift with wireline on stand #57. POOH on elevators to BHA. 70.0 12/4/2018 12/5/2018 C/O saver from HT 55 to XT 64 for liner run. Rig up and conduct Bi -weekly BOPE test. Witness waived by AOGCC. One fail/pass on the upper IBOP. Change out and retest. Rig down from test. Set wear bushing.Rig up long bails for liner run, rig up GBR power longs, load 30 joints of liner in shed. 71.0 12/5/2018 12/6/2018 Pre job safety meeting. Rig up and run 4'h" 15.2# P-110 HYD 563 liner to 7071'. 184 joints. Ave TQ=7,000 fl/lbs. Premium Seal Guard dope used. All odd joints solids, all even joints slots. Every joint centralized. (Solid body spiral). Pick up PBR / Hanger assembly. TIH Wt 5W' DP to the Whipstock. 14,538'. record up/down weights. Rotate weight. TIH to 15,090'. 72.0 12/6/2018 12/7/2018 Run slotted liner to 18,390'. Entered L02. Pumped OOH to 17,060'. Able to slide past L02 with no rotation. Began rotating again @ 17,154'. Rotate 15 RPM. Torque limiter set @ 28k Nlbs. Run liner to 21,510' MD. Drop ball to set hanger. Pressure up to 1500 PSI 12200 PSI 13000 PSI. Blew ball through seat. Hanger and Packer set on depth. Shoe depth 21,510'. Top of liner @ 14,380.52'. 157.48' liner lap. 73.0 12/7/2018 12/8/2018 Pull dogs out of liner packer. Set packer. Rig up and test casing & liner top packer to 2500 PSI. Charted for 30 mins. Good test. Displace to 9.2 PPG brine. Capture MOBM in tank farm. Lay down singles from 14,254' to 5100' MD. 74.0 12/8/2018 12/9/2018 Continue to lay down drill pipe from 5100 to surface, all of the HT 55. TIH with remaining HT 55 and XT 5410 1817. Lay down singles to surface. Vacuum foam ball through each joint, monitor well on the trip tank. SIMOPS: Cleaning pits. TIH with XT 46 DP to 6045'. Lay down singles to 2480'. Monitor well on the TT. Wellbore is static. 75.0 12/9/2018 12/10/2018 Complete the task of lying down the XT 46 singles from 2480 to surface. Pull wear ring. Remove power tongs for linerjob, bring GBR power tongs for tubing run to floor. Inspect two pre-installed control line sheaves in derrick from Work over. Lubricate same. Make up landing joint & hanger. Make'dummy run' with hanger, mark LJ and lay down in pipe shed. Measure 35.45' ULDS distance. Change out drilling elevators and drilling bails to casing bails, and 334' YT elevators. Hang 3rd sheave in derrick. String all three control line spools through sheaves in derrick. Load pipe shed with completion jewelry and 3W" 9.3# L-80 Hyd 503 tubing. Make up seal assembly and run tubing tally as per Completion Eng tally from seal assembly to 3333'. 102 joints of 454 in the hole. 76.0 12/10/2018 12/11/2018 RIH W/ 3Y:" tubing from 3333'to 9716' as per tally. Joint # 308. Stopped going in hole due to lost handling pup. It was discovered that a 1.69' pup had been left on the bottom of nipple #1. Begin to trip out of the hole. Nipple # 1 depth 764'. 77.0 12/11/2018 12/12/2018 PJSM: Change in plans. Discuss tripping out and standing back tubing. POOH Fr 9685'to 6560'. Continue to trip out to 1550'. 607min racking back stands in derrick. 95k Up Wt. Crew change, continue to trip out with 3%" tubing fir 1550'to 760'. remove 1.69' handling pup from bottom of X Nipple assembly #1. The box end of pup was handy. TIH from 760' to 1551'. Reconnect control line for chemical injection sub, continue to trip in with stands to 4107'. 78.0 12/12/2018 12/13/2018 - RIH F/Derrick 3 1/2" Completion Tubing F/ 4,107'T/ 9,716' as per Tally Instructions - Install Cannon Clamp on each Connection - Install X -Nipple - Rig up and fill pipe with Trip Tank Pump - RIH with Completion Tubing F/ Pipe Shed F/ 9,716'T/13,903' filling pipe on the fly and topping off every 45 As - Continuous monitoring of the well - WU SSSV - SLB functioned x 3 and tested to 5000 PSI 15/MIN - RIH T/ 14,270' - Take P/U WT 138k - SIO WT115k - RIH and tag @ 14,434' with 101k - Space out and M/U Hanger - Conned control lines and test to 5000 PSI 10/Min - Continuous monitoring well on Trip Tank. Simultaneous operations: Set the 4 upright tanks for the mud plant extension. Moved the welding shop to the north side of the pad. Set the roof over the resistor bank for the lop drive back break. 79.0 12/13/2018 12/14/2018 - PJSM - Prepare all lines and valves for testing Tubing while connecting control lines to Hanger - Test lines to Hanger to 5000 psi - Land Hanger into wellhead - Energize lockdowns - R/U Testing assembly - Pressure test lines to 3500 psi - Test Tubing to 2500 psi for 10 minutes - Test through Annulus to 2000 psi for 10 minutes - Bring up Pump slowly and shear SO @ 2469 psi - Close SSSV with Schlumberger - Tested SSSV to 1500 psi for 10 minutes - Open SSSV and broke circulation - Spotl5bbls of LVT in casing X tubing annulus for freeze protection. Remove Landing A and Install BPV - Blow Down hoses and choke manifold - R/D Tubing longs and equipment - Change out bails - Remove all Tubing equipment from Rig Floor - Bleed Pressure from Accumulator - N/D Choke and Kill Lines - Cleaning Rig Floor for Rig Move - Pressure wash BOP and Mouse Holes - UD Mouse Holes - Remove SLB sheaves from derrick - Flush Mud Pumps - Continue Cleaning Pits - Fill Test Pump with 4/1 Water/Methanol - Nipple Down BOPE and set on stand - Secure same - Continue preparing for Rig Move www.peloton.com Page 5/5 ReportPrinted: 1 212 612 01 8 lueC.riest H16A-1-05 Survey Geodetic Report Schlumberger Energy (Def Survey) .._._...._. client- ____,..__.._.__._ _..._.- Blue .., __.._,._____....____... Vertical Section Azlmutn: ........._...__.._._._.___.I._I 300.000°(True Norm) Field: Co,nad oMan Unit Valli Section Origin: 0.000 ft, 0.000 B / Sbf: a0 / 441 ($g0�114�� IND Refonanc um N-01" Bons le HIS 1.11 � 5186 IND TG1RreluRaftna nd elevation:etvatl0n: 145.610 ft above MSL lia9rrotic Declination: 14.523 ° Survey Nem.: H16A-105 Total Gravity Field Strength: 1001.2613mW (9.80665 Based, Suety Data: November 13, 2018 Gravity Medal: DDX Tort / AHD / DDI I EM RMio: 2]3.010 ° 1179315.323 It 17.15812.527 Total Magnetic Field Strength: 55103.991 nT Coordinate Reference Syahi NAD27 A"" %ane, Zone 04. US Feel Magnetic Dip Angle: ]2.8]6 ° Location Lel I Long: N 59° 51' 32.00254°, W 151° 48' 5.09692' Declination Date: Oclober 31, 2018 Location Grid NM Y/X: N 2144851.950 ftUS. E 168857.790 ftU5 Magnetic Dedinetlon Model: HDGM 2017 CRS and Convergence Angle: -1.6580 ° North Refemnce: Tete NOM Grid Seale Fader. 1.00002411 Grid Convergence Used: 00000 ° Version / Patch: 2.10.544.0 Total Cort Meg Non ,>True North: 14.5230 ° MD Incl AMM Tete TVD88 TVD VSEC AHD Closure NS EW Ms N-01" Eason Lothude, Longitude Comment. ft fl ft -/lam MIS RTE 0.00 0.00 0.00 -180.46 0.00 0.00 0.00 0.00 0.00 0.00 WA 2144851.95 188857.79 59.85680960 -151.80141581 0.03 0.00 0.00 -180.43 0.03 0.00 0.00 0.00 0.00 0.00 0.00 2144851.95 168857.79 59.85808960 -151.80141581 34.65 0.00 0.00 -145.81 34.65 0.110 0.00 0.00 0.00 0.00 0.00 214485595 166851.79 59.85800960 -151.80141581 100.03 0.43 249.54 -80.43 100.03 0.16 0.25 0.25 4.09 -0.23 0.66 2144651.87 188857.56 59.85888936 -151.80141106 200.3 1.02 252.78 19.56 200.02 1.0 1.51 1.51 4.40 -1.43 0.59 2144851.51 168856.35 59.86688020 -151.80142380 300.03 2A2 320.54 119.52 299.98 3.50 4.23 3.73 0.89 -3.62 2.24 2144852.93 188854.19 59.85889202 -151.80143552 400.03 5.40 333.89 219.28 39914 9.47 11.02 9.75 6.74 -7.04 3.10 2144850.88 188850.94 59.05690804 -051.80145409 500.03 7.61 323.52 318.63 499.09 19.44 22.31 20.81 16.29 -13.05 249 2144860.59 188045.19 59.85093417 -151.80148671 600.03 9.91 303.00 417.48 597.94 34.11 37.39 35.75 26.31 -24.20 3.85 2144878.91 160834.31 59.85896157 -151.80154145 700.03 11.4 287.80 515.79 696.25 52.32 55.12 53.10 34.00 4D.79 3.13 214486] 05 168811.94 59.85896262-151.801071PI 800.03 10.96 272.57 813.92 794.38 70.37 74.95 70.42 37.43 -59.65 2.96 2144890.99 188799.18 59.85899201 -151.80174023 900.03 9.37 273.40 712.35 892.81 86.08 92.60 66.26 30.34 4).27 1.60 2144892.38 180781.59 59.851199449 -151.80183609 1000.03 10.13 294.04 810.93 991.39 102.12 109.35 102.61 42.41 .3.43 3.56 2144896.89 168785.54 59.85900562 -151.80192400 1100.03 13.86 30129 908.n 1009.23 in.88 129.94 123.14 52.13 -111.56 3.83 2144907.09 168741.68 59.85903221 -151.80202260 1200.03 16.58 303.80 1005.30 1185.76 14en 166.D1 149.03 66.20 -133.51 2.99 2144921.76 160726.12 59.85907071 -151.80214200 1245.20 17.30 305.85 1048.51 1228.97 161.64 169.17 162.05 73.72 -144.31 207 2144929.57 188715.53 59.85909128 -151.80220074 1344.32 19.34 305.59 1142.60 1323.06 192.84 200.33 192.91 91.91 .169.61 2.06 2144940.44 160690.74 59.85914103 -151.80233032 1435.98 21.29 301.72 1228.56 1409.02 224.50 232.14 224.61 109.49 -196.11 2.58 2144961 188804.12 59.85918913 -151.80248247 1529.07 23.68 301.02 1314.57 1495.03 280.11 267.74 260.18 128.01 -226.51 2.56 2144986.08 188634.84 59.85923981 -151.00284782 1623.26 25.95 300.11 1400.06 1580.52 299.70 307.26 299.70 148.12 -260.54 244 2145007.10 168601.37 59.85929481 .151.80283291 1717.56 26.63 300.05 1484.80 1605.6 341.46 349.03 341.47 169.07 -296.67 0.72 2146029.03 168565.82 59.85935213 .151.80302944 1811.44 27.53 300.20 1568.19 1748.65 384.20 391.77 384.20 19D.52 x33.84 0.90 2145051.46 1011529.45 59.85941061 -151.6,11=049 1905.45 28.86 299.14 1651.13 1831.59 428.47 436.04 428.48 212.43 -312.11 1.31 2145074.43 168491.58 59.115947075 .151.80343976 1999.50 30.32 298.11 1132.99 1913.45 474.75 482.33 474.76 234.60 412.75 1.65 2145097.69 168451.56 59.85953139 -151.60366079 2093.56 32.53 297.94 1813.24 1993.70 523.76 531.37 52318 257.64 456.04 2.35 2145121.90 168408.92 59.85959441 -151.80389825 21811.00 35.54 296.74 1891.50 2072.02 576.59 584.27 576.64 281.91 503.03 325 2115147.44 168362.60 59.85986082 .151.80415187 2296.00 37.49 296.42 1978.30 2158.76 MD.69 648.48 640.79 310.64 -560.46 1.82 2145177.72 168305.97 59.85973940 -151.80446424 2376.60 39.21 297.75 2041.57 2222.03 690.66 698.54 690.82 333.44 505.02 2.36 2145201.12 168262.05 59.859801]/ -151.80470661 2473.39 42.17 299A0 2114.89 2295.35 753.70 Mi.58 753.86 36&62 -660.37 3.26 2145233.39 168207.54 59.85988432 -151.80500761 2563.50 44.14 299.50 2180.62 2381.08 815.33 023.21 815.49 393.92 414.03 2.19 2145265.15 16815471 59.85996721 -151.80529958 2657.45 45.62 296.11 2247.20 2427.65 881.57 1109.49 881.76 425.12 -172.51 2.62 2145297.93 168097.11 59.86005257 .151.60561763 2751.44 47.92 295.03 2311.57 2492.03 949.87 957.97 950.15 454.98 -034.13 2.77 2145329.45 168036.32 59.86013425 -151.80595280 CosmopotDan llniMosmoplitan Pal:RH18 MM16 Drilling Offim 2.10.302.0 Schlumberger -Private 1/7/2019 3:30 PM Page 1 of 6 Comments MD M Incl f9 Asim Tru. (1) TVDss (m TVD ml VSEC 161 AHD fN) Cbaum On NS On EW (N) DL6 1°110081 Northing (flus) EaWng ("M Lathu" LOn90u6e 1°I 1.1 2845.15 50.92 294.28 2372.53 2552.99 1020.72 1029.13 1021.15 484.66 -890.81 126 2145360.88 167972.47 59.86021543 -151.80630462 2938.% 53.66 293.61 2429.90 2610.36 1094.51 1103.34 1095.15 514.77 -966.63 2.97 2145392.82 167905.49 59.86029779 -151.80867354 3033.00 56.06 295.10 2484.03 2664.49 1171.03 1180.23 1171.90 546.49 -1036.67 2.86 2145426.44 167836.33 59.86038456 -151.80705454 3126.75 59.20 296.19 2534.21 2714.67 1249.97 1259.41 1251.02 580.77 -1100.04 3.49 2145462.64 167/65.93 59.86047832 -151.80744273 3220.66 61.70 297.76 2560.53 2760.99 1331.55 1341.09 1332.70 617.83 -1180.83 3.03 2145501.67 167694.17 59.88057970 -151.80783868 3315.24 63.38 296.93 2624.14 2804.60 1415.43 1425.01 1416.61 657.68 -1254.68 2.09 2145543.52 167621.42 59.86068869 -151.80824042 3406.17 64.84 299.90 2664.72 2845.18 1499.D2 1508.61 1500.17 698.74 -1327.50 1.83 2145586.54 167549]4 59.8608D101 -151.80863653 3502.99 84." 299.49 2705.63 2888.09 1584.56 1594.15 1585.66 741.12 -1401.81 0.93 2145630.93 167476.62 59.86091692 -151.80904073 3596.91 64.56 299.09 2746.36 2926.82 1869.19 1670.70 1670.27 782.52 -1475.62 0.67 2145674.32 167403.96 59.86103016 -151.80944223 3690]6 64.59 298.04 2786.65 297.11 1753.92 1763.64 1756D2 023.05 -1550.06 1.01 2145716.86 167330.64 59.66114101 -151.80984717 3764.55 65.08 296.94 2826.53 3006.99 1638.72 1848.43 1839.90 062.23 -1625.36 1.18 214758.7 17256.43 59.86124818 -151.8102568D 387659 64.0 295.53 2866.44 3046.90 1923.69 1933.58 1925.D2 099.87 -1701.74 1.42 2145797.78 17101.11 59.86135113 -151.8107228. 3972.35 64.14 206.20 2906.93 3087.39 2008.04 2010.15 2009.54 938.7 -17.4.84 0.80 2145836.73 17106.04 59.86145203 -151.01108623 4066.28 64.20 296.30 2947.85 3128.31 2092.40 2102.0 2094.06 974.21 -1853.64 0.18 214576.22 167031.28 59.661554" -151.81149857 _ 4126.10 64.99 295.88 2973.51 3153.97 2146.32 2156.73 2148.07 998.01 -1902.15 1.52 2145901.33 166903.43 59.86161952 -151.81176247 13..48- 4175.03 65.51 296.63 2994.00 3174.46 2190.66 2201.17 2192.49 1017.67 -1942.00 1.76 2145922.07 166944.13 59.86167329 -151.6117925 4215.22 65.94 297.25 3010.52 3190.96 2227:24 2237.80 2229.12 1034.27 -1974.66 1.76 2145939.55 168911.93 59.86171869 -151.81215692 4261.49 66.12 2%.74 3029.32 3209.8 2269.46 228D.00 2271.40 1053.46 -2012.33 1.08 2145959.76 16674.80 59.66177117 -151.81236185 4355.37 66.26 297.61 307.22 3247.66 2355.25 2365.97 2357.29 1092.68 -2086.74 0.86 2146001.05 16799.48 59.86187645 -151.81277751 "48.65 66.36 297.51 3104.70 3285.16 2440.59 2451.39 2442.71 1132.21 -2164.47 0.15 2146042.61 16724.86 59.86198654 -151.01318946 4542.46 66.7 296.7 3142.53 3322.99 2526.32 2537.23 2528.54 1171.30 -2240.89 0.68 2146083.7 166649.52 59.86209345 -151.81360521 4638.44 65.95 296.08 3180.74 3361.20 2612.04 2823.09 2614.40 1209.96 -2317.55 0.24 2146124.52 166573.94 59.66219923 -151.81402222 4730.30 66.30 297.19 3218.73 3399.19 2697.76 2700.92 2700.22 1248.99 -2394.00 0.48 2146165.60 166498.68 59.06230592 -151.81443811 4824.27 65.97 Mae 3256.75 3437.21 2783.62 2 9 .06 2786.16 1288.76 -2470.16 0.65 214627.45 166423.52 59.86241474 -151.81485246 4916.15 66.24 298.97 3294.78 3475.24 2869.42 2880.69 2871.98 1329.1 -2545.61 1.01 2146250.41 166349.21 59.86252665 -15181526292 5012.24 66.06 298.87 3332.82 3513.28 2955.46 2966.75 2958.01 1371.32 -2620.94 0.21 2146294.06 166275.05 59.86284046 -151.81567270 5106.32 66.64 299.19 3370.56 3551.02 3041.62 3052.92 3044.16 1413.14 -2696.29 0.69 2146337.91 166200.86 59.86275482 -151.61608263 520019 65.82 299.27 3408.40 3588.86 3127.52 3130.83 3130.04 1455.09 -2771.25 0." 2146381.88 166127.06 59.06286954 -151.81649047 5294.81 66.16 299.72 3446.89 3627.35 3213.96 3225.27 3216.44 1497.65 -2846.49 0.58 2146426.47 166053.01 59.86298593 -151.81689979 5388.14 65.79 299.73 3484.7 3665.33 3299.21 3310.52 3301.64 1539.92 -2920.52 0.42 2146470.74 165950.15 59.86310152 -151.81730256 5681.25 65.86 299.86 3523.00 3703.46 3304.15 3395.47 3386.53 1582.14 -2994.23 0.17 2146514.95 16597.61 59.86321698 -151.817703% 5575.30 66.01 299.57 3561.35 3741.81 3470.03 3481.34 3472.36 1624.72 -3088.81 0.34 2146559.55 165034.22 59.86333342 -151.81810929 5669.34 66.32 299.52 3599.35 3779.81 3558.04 357.36 3558.35 1667.14 -3143.64 0.33 2146603.90 165760.57 59.863"941 -151.81851643 5763.67 66.91 299.25 363679 3817.25 3642.62 3653.94 36".90 1709.62 -3219.08 0.68 2146648.50 165688.31 59.88356550 -151.8189267 5857.71 66.26 299.29 374.16 3854.62 3728.91 3710.24 731.17 1751.81 -3294.36 0.69 2146692.73 16561230 59.86368095 -151.81933643 5951.71 66.29 299.63 3711.98 3892.44 3814.96 3826.29 3817.20 1794.14 4369.29 0.33 214737.7 165538.45 59.86379668 -151.8197009 6045.74 66.35 299.18 3749.75 3930.21 3901.7 3912.41 3903.29 1636.42 -34".31 0.44 214781.38 165464.61 59.86391229 -151.82015224 6139.71 66.95 299.30 3786.99 397.45 397.33 3990.60 3989.55 1878.56 -3519.59 0.65 2146825.55 165390.50 59.86402753 -151.82D56102 6233.57 67.33 299.20 3023.46 4003.92 4073.81 4085.17 476.02 1920.87 -3595.02 0.41 2146869.90 165316.24 59.116414322 -151.8209722: 6327.30 7.19 299.53 3859.72 4040.18 416D.33 4171.68 4162.51 1963.35 -370.39 0.29 2146914.41 165242.05 59.66425937 -151.8213823E 6421.39 67.60 299.49 3895.85 476.31 4247.14 4258.47 4249.28 2006.10 4745.92 0." 2146959.20 165167.71 59.66437626 -151.82179324 6515.39 68.04 299.46 3931.34 4111.00 4334.15 4345.52 4336.30 2048.93 -3821.70 0.47 2147004.08 165093.13 59.8609337 -151.82220554 6609.28 68.21 298.39 3966.32 4146.76 442t26 "32.65 "23.42 2091.07 -387.96 1.7 2147048.27 165018.04 59.86460859 -151.82262045 6703.25 67.43 298.24 4001.80 4182.26 450824 4519.66 4510." 2132.34 -3974.56 0." 2147091.62 184942.58 59.864721" -151.82303725 796.52 67.19 298.45 4037.78 4218.24 4594.26 4605.71 4596.49 2173.20 4050.30 0.33 2147134.52 164867.99 59.66483314 -151.823"931 6890.99 67.49 290.37 4074.17 4254.63 4681.40 4692.89 4663.66 2214.67 4126.98 0.33 2147178.06 164792.46 59.06494654 -151.82386652 605.40 67.65 298.27 4110.19 4290.65 4760.63 4780.16 477D.93 2256.7 4203.80 0.20 2147221.54 164716.79 59.86505973 -151.82428451 7077.95 7.22 298.39 4145.71 1326.17 4854.06 4865.62 4856.40 2296.63 4279.03 0.48 2147264.13 164642.69 59.86517061 -151.82469383 7171.18 7." 290.54 4181.64 4362.10 4940.05 4951.0 4942.42 2337.63 4354.65 0.26 214737.17 184588.21 59.86528271 -151.82510532 7265.18 7.94 296.21 4217.33 4397.79 5026.90 5038.61 5029.38 2378.96 4431.17 0.62 2147350.56 IW92.84 59.86539570 -151.82552165 7359.15 67.57 297.73 4252.90 "33.36 5113.91 5125.59 5116.36 2419.75 4507.98 0.62 2147393.43 18"17.16 59.8555082 -151.82593962 7452.94 67.45 297.57 4288.70 4469.24 5200.49 5212.25 5203.01 2459.97 4584.5 0.20 214743532 164341.52 59.86561716 -151.8263728 7546.93 67.26 297." 4324.95 4505.42 527.15 5298.99 5289.75 2500.03 4661.68 0.24 2147477.86 164265.70 59.88572668 -151.8277592 7640.96 67.49 297.84 4361.14 4541.60 5373.87 5365.78 5376.54 2540.29 4738.57 0.46 2147520.20 164189.93 59.8858375 -151.82719429 7735.00 7.36 298.41 4397.24 477.70 5460.86 548.62 5463.37 2581.23 -4815.15 0.56 2147563.20 164114.49 59.86594865 -151.8761099 7828.92 67.39 298.11 "33.37 4613.83 5547.31 5559.31 5550.06 2622.27 4891.51 0.30 2147606.31 164039.27 59.86606066 -151.82802640 Cosmopolitan UnH\Casmoplitan Pad\H76\M6\H16 Drilling Office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:30 PM Page 2 of 5 cemn»me MD Incl Azint hue TVD00 TVD VBEC AHD M... Ns EW DLB Latitude Lon98ude 8016.85 67.60 298.16 4505.0 4685.92 5720.78 6732.5 5723.62 2704.40 -5044.40 DAD 2147692.% 163088.67 59.86628537 -151.82885042 8110.80 67.29 290.56 4541.44 4721.% 5MT53 5819.65 5810.40 2745.62 -5120.78 0.57 2147745.85 163813.4 59.86639806 -151.82927399 0204.75 67.33 298.81 4577.68 4758.14 5894.19 506.33 5687.08 2787.23 -51%.82 0.25 2147779.51 163738.56 59.86651180 -151.82%8777 8290.84 67.25 298.84 4614.00 4794.46 5%0.97 5993.12 5903.87 2829.% -5272.% 0.09 2147823.41 163863.68 59.M%2619 -151.83010155 8392.78 67.30 298.92 4650.29 030.75 6057.60 6079.77 6070.51 2870.92 -5348.73 0.09 2147867.31 163508.97 59.86674059 -151.83051441 8485.76 67.25 298.52 40(k21 4%6.67 6153.34 6165.53 6156.27 2912.14 5423.94 0.40 2147910.55 163514.91 59.0%85324 -151.83092360 8579.76 67.37 298.57 4722.47 4902.93 6240.04 6252.26 6242.99 2953.58 5500.12 0.14 2147954.05 163439.88 59.56%652 -151.0133824 8673.68 67.17 290.21 4758.76 4939.22 6326.63 6338.80 6329.62 2994.77 -5576.33 0.41 2147997.29 163384.82 59.86707911 -151.83175293 8767]1 67.30 297.52 4795.15 4975.61 013.27 0425.59 6416.32 3035.29 -5652.% 0.69 2148039.89 163289.30 59.%710980 -151.83217004 0%1.52 67.10 297.36 4831.50 5011.% 6499.% 6512.07 6502.79 3075.14 -5729.73 0.26 2148081.81 163213.66 59.%729880 -151.83258769 0955.40 67.11 297.35 4868.03 51348.49 650.% 6598.55 6589.27 3114.08 -509.55 0.01 2148123.63 163137.95 59.%740742 -151.83300568 9049.36 67.35 297.49 49134.39 MUM 6672.61 %85.19 %75.90 3154.78 -5883.45 0.29 2146165.60 163%2.16 59.%751647 -151.83342418 9143.37 67.% 297.47 4940.43 5120.89 6759.35 6"2.62 6762.72 3194.84 -59%.48 OM 2148207.75 1629%.24 59.%762597 -151.0384335 _ 9237.5 66.90 290.11 4976.81 5157.27 6845.95 68M.5 %49.38 3235.25 4037.15 0.94 2148250.22 162910.70 59.M"3641 -151.83426057 9331.34 67.10 297.82 5013.53 5193.% 6932.40 6945.19 6935.89 3275.81 -6113.55 0.35 2148292.85 162835.42 59.%784720 -151.03467637 "25.31 67.59 297.74 5049.73 5230.19 7019.05 7031.91 7022.60 3316.23 8190.28 0.53 2148335.34 162759.02 59.%795"5 -151.%509390 %19.14 67.55 297]0 5085.53 $265.99 7105.72 7118.64 7109.33 33%.63 8267.03 0.9 21483..81 162664.20 59.068013816 -151.81551158 %13.00 67.12 297.95 5121.70 5302.16 7192.27 7205.25 7195.94 3397.11 8343.60 0.49 2140420.36 16208.76 59.%81780 -151.0592025 97M.89 67.11 297.99 5150.21 5338.67 7278.72 7291.75 7282.4 3437.68 8419.99 0." 214846299 162533.49 59.868289% -151.03634400 9800.85 67.08 290.20 5194.78 %75.24 7385.22 7378.30 7300.99 3478.49 -64%.32 0.29 2148505.86 162458.30 59.86040122 -151.03675936 %94.74 67.13 298.35 5231.31 5411.77 7451.60 7464.80 7455.49 3519.52 -6572.46 0.08 2148548.95 162383.30 59.86851334 -151.0717375 9%8.50 67.37 298.74 5267.57 5148.03 708.12 7551.26 7541.95 350.04 8648.42 OA6 2148592.31 162300.50 59.86%2627 -151.8379711 1092.44 67.13 298.78 5303.89 5484.35 7624.73 7637.89 7628.58 3602.52 8724.36 0.26 214%36.05 162233.71 59.%874018 -151.8380042 10176.40 67.50 290.59 5340.13 5520.59 7711.39 7724.9 7715.26 36%.13 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-151.07238928 17857.58 %.38 304.02 6885.77 7066.23 15%9.72 15100.02 15070." 7417.37 -13110.60 1.83 2152623.43 155945.41 59.07916238 -151.87281119 Cosmopolitan Unit\Cosmoplitan Pad\Hi6\Hi6\H16 Drilling Office 2.10.302.0 . Schlumberger -Private IM2019 3:30 PM Page 4 of 5 Cosmopolitan Unit\Cosmoplitan Pad"6\H16\Hi6 Drilling Office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:30 PM Page 5 of 5 MD Incl As. T. TVDSS TVD VSEC AHD Closure NS EW DLS NoMing Ea01D9 Le 4. LongRud. Commenb fl0 (.1 (.1 (ft) (10 go fl fl R '/1008 RUS M15 Tie-In Survey 17952.67 90.90 305.17 6884.77 7055.23 15164.50 15195.11 15165.04 7471.35 -13196.87 1.36 2152679.52 155968.64 59.87930983 -151.87323748 18044.62 92.92 305.67 6881.71 7062.17 15255.99 15287.0 15256.45 7524.61 -13271.76 2.26 2152734.00 155795.22 59.87945531 -151.87354536 18140.54 89.72 304.42 6079.50 7059.96 15351.49 15382.88 15351.89 7579.67 -13350.25 3.58 2152791.97 155716.25 59.87960569 -151.87407290 18234.53 90.17 303.92 6879.59 7060.05 15445.23 15476.67 15445.59 7632.46 -13428.02 0.72 2152846.06 155641.95 59.67974986 -151.87449643 18328.87 8987 304.09 6079.56 7050.D2 15539.34 15571.21 15539.65 7685.22 -13506.23 0.37 2152901.73 155565.20 59.87889390 -151.67492236 16422.51 09.75 301.99 6879.87 7080.33 15632.85 15664.85 15633.12 7136.27 43584.72 2.25 2152954.89 155488.13 59.68003340 -151.87534908 18516.45 09.73 300.62 6080.29 7060.75 15726.76 15758.79 15727.01 7705.22 -13664.89 1.25 2153006.01 155409.31 59.68D16707 -151.87578653 1861D.48 89.63 299.71 6880.82 7061.28 1582D.70 15052.82 15821.04 7832.61 -13746.11 1.19 2153055.59 155329.41 59.MD29646 -151.87622081 MsIn Survey 18703.08 09.98 299.32 6881.13 7061.59 15913.38 15945.42 15913.64 7878.23 -13826.69 0.57 2153103.38 155250.10 59.80042101 -151.87666766 18773.37 90.97 301.40 6850.55 7061.01 75963.66 16015.71 15903.91 7913.79 -13887.31 3.30 2153140.58 155190.47 59.88051812 -151.87699780 18866.23 89.59 301.87 680910 7060.56 16076.46 16108.58 16076.71 7962.55 -13966.33 1.54 2153191.47 155112.80 59.88065127 -151.87742820 18957.01 90.17 303.16 6880.29 7060.75 16167.17 16199.34 16167.38 8011.35 -14042.88 1.56 2153242.33 155037.60 59.88078451 -151.87704512 19050.46 89.30 299.16 6880.72 7061.18 16260.58 16292.79 16260.70 8059.69 -14122.83 4.30 2153292.83 154958.99 59.00091651 -151.87828056 _ 19145.05 90.11 303.40 081.21 7061.67 16355.12 16307.38 16355.31 81M.79 -14203.65 4.56 2153344.11 154879.54 59.88105056 -151.87872074 19243.26 89.4 306.57 6881.59 7062.05 16452.94 16485.59 16453.10 8165.09 -14284.10 3.30 2153402.50 154800.64 59.80120435 -151.87915897 19330.32 89.54 307.03 6082.44 7062.90 16547.33 16580.64 16547.44 8222.03 -14360.22 D.50 2153481.57 154726.10 59.88135908 -151.87957359 19431.81 89.77 307.48 6003.00 7063.46 16640.07 16674.13 16640.14 8278.63 -14434.63 D.54 2153520.17 154653.26 59.88151447 -151.07997895 19524.85 90.62 307.32 6882.69 7063.15 16732.33 16767.17 16732.37 0335.14 -14500.54 0.93 2153578.67 154580.91 59.08166802 -151.06038159 19617.49 95.61 305.05 6077.65 7058.11 16823.91 16859.64 16823.92 0392.05 -14581.42 5.58 2153637.55 154509.60 59.08102429 -151.88077883 19710.77 99.03 308.24 8865]7 7046.23 16915.41 16952.15 16915.41 8449.50 -14653.87 3.69 2153697.2 154430]4 59.08198142 -151.08117331 19802.85 98.83 304.50 6851.47 7031.93 17005]9 17043.11 17005]9 8503.51 -14727.10 402 2153752.93 154367.00 59.08212872 -151.68157224 19897.94 98.87 300.24 6036.64 7017.30 17099.65 17137.07 17099.65 0553.80 -14806.4 4.43 2153805.36 154289.06 59.88226604 -151.08200439 19%2.49 100.01 290.08 6821.33 7001.79 17192.90 17230.34 17192.90 0599.24 -14807.88 2.56 2153853.00 154200.80 59.08239009 -151.08244796 20088.61 103.64 299.19 6602.04 6902.50 17284.90 17322.4 17284.90 0643.30 -14960.72 4.03 2153899.32 154129.27 59.08251056 -151.08290027 20180.47 106.88 299.41 67..34 6957.80 17375.51 17412.98 17375.51 066289 -1504268 3.46 2153945.76 154051.54 59.88263150 -151.88331831 20273.78 109.43 299.98 6748.25 6928.71 17464.16 17501.63 17464.16 8731.60 -15124.68 2.03 2153991.75 153975.76 59.88275137 -151.88373776 2DW7.00 11078 301.08 6716.18 6096.64 17551.60 17589.16 17551.60 8776.06 -15200.08 1.00 2154038.24 153901.61) 59.88287275 -151.88414042 20461.49 112.45 301.21 6681.37 6861.03 17639.51 17677.00 17639.51 8821.49 -15275.26 1.77 2154085.70 153827.68 59.08299678 -151.88455794 2055675 113.19 301.56 6644.43 6824.09 17727.29 17764.81 17727.29 8867.22 -15350.22 0.85 2154133.45 153753.99 59.88312161 -151.88496623 20651.34 112.79 301.36 6607.48 6767.94 17814.33 17851.80 17814.34 8912.68 -15424.49 0.46 2154180.91 153600.98 59.80324572 -151.80537079 20659.04 112.90 301.36 6604.49 6784.95 17021.43 17850.90 17821.43 8916.37 -15430.55 1.45 215418477 153675.03 59.8032550D -151.88540379 20743.00 112.90 301.36 6571.82 6752.28 17898.75 17936.32 17898.75 8956.62 -15496.59 0.00 2154226.80 153610.10 59.80336569 -151.80576354 Survey Emor MOBd: ISCWSA Rev 0 "' 1D 95.000% ConfiOdwe 2.7955 sigma Survey Pro9nm: MD From AID MD Ta EDU Fraq H.I. Size casing Diameter Desctpebn Past IRI IRI Hal 0n1 S., Tool Typa BonOok /Survey 1 0.000 1200.030 Ad Stns 17.500 13.375 SLB CNSG+ ASING H16PB1/H16PB1 1 1209030 4126.100 Ad Stns 17.500 13.375 SLB MW WG 418PB1 I H16PB1 1 4126.100 14496.250 Ad Stns 12.250 9.625 SLB MWD�GMAG H16PB1 I H16PB1 1 14496.250 14762.300 Ad Stns 8.500 0.000 SLBIAWDINCONLY_FILLER H16A-L01/1416A-1.01 1 14762.300 16356.710 Act Sine 8.500 0.000 SLE_MWD+GWG H16A-101/H16A-LO1 1 16356.710 17108.930 Act San, 8.500 0.000 SLB_MWDtGMAG H16A-L02I Hi6A-102 1 17108.930 17952,670 Ad ants 8.500 0.000 SLB MWD GMAG H1fiAL03/H1fiA-L03 1 17952.670 18703.080 Ad Sins 0.500 0.000 SLB MWD+GMAG H1fiMLN I HIM-1-34 1 18703.80 20743.000 Act Sins 8.500 0.000 SLB MWDtGMAG Hl6 L05I 1116A-105 Cosmopolitan Unit\Cosmoplitan Pad"6\H16\Hi6 Drilling Office 2.10.302.0 . Schlumberger -Private 1/7/2019 3:30 PM Page 5 of 5 H16A Fishbone Well Naming & Numbering Index Planned KOP Actual TO Actual Lateral Footage Lateral Volume (bbls) H -16A Mainbore 14552 22310 Well Name PTD No. from AOGCC API No. from AOGCC Final TO (MD) Notes 17440 1065 75 L02 17180 H16A Mainbore 218-095 50-231-20051-01-00 22310 Final completed wellbore with 4-1/2" slotted liner in 8-1/2" hole H16A-LO1 218-096 50-231-20051-60-00 17440 8-1/2" Open Hole completion H16A-L02 218-097 50-231-20051-61-00 18390 8-1/2" Open Hole completion H16A-L03 218-098 50-231-20051-62-00 19268 8-1/2" Open Hole completion H16A-L04 218-099 50-231-20051-63-00 20020 8-1/2" Open Hole completion H16A-LOS 218-100 50-231-20051-64-00 20743 8-1/2" Open Hole completion H16A-L06 218-101 50-231-20051-65-00 21340 8-1/2" Open Hole completion H16A-LO7 218-102 50-231-20051-66-00 1 21860 8-1/2" Open Hole completion Planned KOP Actual TO Actual Lateral Footage Lateral Volume (bbls) H -16A Mainbore 14552 22310 7758 544 LO1 16382 16375 17440 1065 75 L02 17180 17130 18390 1260 88 L03 17980 18000 19268 1268 89 L04 18780 18770 20020 1 1250 88 LOS 1958019525 20743 1218 85 L06 20382 20270 21340 1070 75 L07 21180 21165 21860 695 49 Total 15584 1094 X (NAD27) Y (NAD27) TVDSS TVD MD Legal Description H16A Mainbore KOP (Top of Production) 158612.43 2150676.24 -6905.01 7085.44 14552 2663' FSL, 1350' FEL, Sec. 33, T3S, R15W SM TD 152294.39 2155159.54 -6850.78 7031.21 22310 1685' FSL, 2505' FEL, Sec. 29, T3S, R15W SM H16A-LO3 KOP (Top of Production) 157171.72 2151790.8 -6896.63 7077.06 16375 3737' FSL, 2820' FEL, Sec. 33, US, R15W SM TD 156331.17 2152368.86 -6616.64 6797.07 17440 4291' FSL, 3676' FEL, Sec. 33, T3S, R15W SM H16A-L02 KOP (Top of Production) 156545.57 2152212.42 -6893.22 7073.65 17130 4141' FSL, 3458' FEL, Sec. 33, T3S, R15W SM TD 155562.48 2152898 -6557.67 6738.1 18390 4798' FSL, 4459' FEL, Sec. 33, T35, R15W SM H16A-L03 KOP (Top of Production) 155830.73 2152708.02 -6883.44 7063.87 18000 4616' FSL, 4186' FEL, Sec. 33, T3S, R15W SM TD 154839.79 2153390.79 -6517.97 6698.4 19268 5271' FSL, 5195' FEL, Sec. 33, T3S, R15W SM H16A-L04 KOP (Top of Production) 155193.13 2153138.68 -6880.05 7060.48 18770 5029' FSL, 4835' FEL, Sec. 33, T35, R15W SM TD 154212.01 2153816.15 -6536.42 6716.85 20020 396' FSL, 552' FEL, Sec. 29, T3S, R15W SM H16A-LOS KOP (Top of Production) 154580.74 2153578.86 -6882.68 7063.11 19525 169' FSL, 177' FEL, Sec. 29, T3S, R15W SM TD 153610.04 2154226.91 -6571.82 6752.25 20743 790' FSL, 1165' FEL, Sec. 29, T3S, R15W SM H16A-L06 KOP (Top of Production) 153976.65 2154013.78 -6887.9 7068.33 20270 587' FSL, 793' FEL, Sec. 29, T3S, R15W SM TD 153105.84 2154577.4 -6649.98 6830.41 21340 1126' FSL, 1678' FEL, Sec. 29, T3S, R15W SM H16A-L07 KOP (Top of Production) 153224.5 2154498.02 -6887.64 7068.07 21165 1050' FSL, 1558' FEL, Sec. 29, T3S, R1SW SM TD 1 152675.82 2154902.24 -6759.78 6940.21 21860 1438' FSL, 2117' FEL, Sec. 29, T3S, R15W SM H16A Actual MW vs. Depth Data Table Days Depth MW From MD ppg Operational Notes Spud 0 8.3 Kill well with water for sidetracking; pull tubing 3 0 8.3 Kill well with water for sidetracking; pull tubing 4 0 8.3 Kill well with water for sidetracking; pull tubing 5 0 8.3 Kill well with water for sidetracking; pull tubing 6 0 8.3 Kill well with water for sidetracking; pull tubing 7 0 8.3 Set Bridge Plug / Pressure Test Casing 8 0 9.2 Swap to 9.2 ppg OBM 9 0 9.2 RIH w/ Whipstock & Mill BHA 10 14538 9.2 Set Whipstock 11 14544 9.2 Mill Window in 9-5/8" Casing 12 14569 9.2 RIH w/ new mill BHA / drill new hole 14569', FIT to 11.9 ppg 13 14582 9.2 Cure losses w/ LCM / drill w/ mill to 14582' MD / POOH 14 14582 9.2 POOH / fix top drive / service rig 15 14582 9.2 POOH w/ mill BHA / test BOP / make up motor BHA / RIH 16 14622 9.2 RIH w/ motor BHA / drill new hole to 14622' MD 17 14735 9.2 Drill new 8-1/2" hole to 14735' M D / pump put for RSS BHA 18 14735 9.2 POOH w/ motor BHA / test BOP / RIH w/ RSS BHA 19 14795 9.2 RIH thru window and to TD / drill new hole to 14795' MD 20 16336 9.2 Drill w/ RSS BHA / hi torque add lubes / drill to 16336' MD 21 17440 9.2 Drill L01 lateral to 17440' MD / backream & trench for L02 22 18214 9.3 Trench / sidetrack / drill L02 lateral to 18214' MD 23 18390 9.2 Stuck pipe / backream / drill L02 to 18390' MD / trench to L03 24 18592 9.3 Sidetrack & drill L03 to 18592' MD 25 19268 9.2 Drill L03 to TD of 19268' MD. Backream and trench for L04 26 18122 9.2 Drill L04 lateral to 18122' MD 27 20020 9.3 Finish drilling L04 lateral to TD of 20020' MD and backream same 28 20020 9.3 Backream to casing window / CBU / prep to TOH for new BHA 29 20020 9.3 Backream to inside casing / pump out of hole 30 20020 9.3 Pump out/ LDDP / DP management/ inspect BHA 31 20020 9.2 LD BHA 05 / Manage & LD DP for hard banding 32 20020 9.2 BOP Test / manage DP / hardband / PU BHA 06 33 20020 9.2 BOP Test / PU RSS BHA 06 / RIH on 5-1/2" DP 34 20020 9.2 RIH BHA 06 managing DP, 5-1/2" x 4-1/2" x 5-1/2" design 35 20020 9.3 RIH / circ well clean / RIH to window depth 36 18860 9.2 IRIH / search for L05 trench / drill ahead in L05 w/ RSS BHA 06 37 20743 9.3 Drill LOS lateral to TD of 20743' MD / C&C / BROOH for LO6 38 19881 9.2 BR & trench for L06 lateral / drill L06 to 19881' MD 39 20350 9.2 Drill & TD L06 / BROOH to trench for L07 40 20925 9.2 Trench for L07 / Drill ahead to L07 KOP at 20925' MD 41 21850 9.2 Drill L07 fishbone lateral to 21850' MD 42 21850 9.2 Drill L07 to TD at 21860' MD / BROOH / Trench & ST for L08 43 223101 9.2 Drill L08 to well TD at 22310' MD / BROOH for liner 44 223101 9.2 BROOH from well TD to 15003' MD 45 223101 9.2 1 BROOH to inside 9-5/8" / BROOH / Pump out for liner / LDDP 46 22310 9.2 BROOH to inside 9-5/8" / BROOH / Pump out for liner / LDDP 47 22310 9.2 Test BOPE / start picking up 4-1/2" liner 48 22310 9.2 Run 4-1/2" liner on drill pipe 49 22310 9.2 Run 4-1/2" liner on drill pipe / land in L02 - wrong lateral 50 22310 9.2 POOH w/ 4-1/2" liner after running into L02 wrong lateral 51 22310 9.2 MU Clean Out BHA & RIH 52 22310 9.2 1 DP management / RIH w/ clean out BHA / ream L02 area 53 22310 9.2 Clean out mainbore in preparation for re -running liner 54 22310 9.2 Check L02 area for liner entry - OK; BROOH for liner re -run 55 22310 9.2 BROOH; 7.2 earthquake hit; ream back to bottom to check hole 56 22310 9.2 Clean out to 21826'; BROOH; check L02 area for liner run 57 22310 9.2 BROOH to window; CBU / pump out for liner re -run 58 22310 9.2 Pump out / POOH on elevators for liner re -run / test BOPE 59 22310 9.2 Test BOPE / MU flex joint shoe track and run 4-1/2" slotted liner 60 22310 9.2 RU & run 4-1/2" slotted liner w/ flex joint shoe track 61 22310 9.2 Run liner on 5-1/2" DP / work liner past L02 junction / set same at TD 62 22310 9.2 Drop ball / set hanger & liner top packer / test to 3K / swap to 9.2 ppg brine 63 22310 9.25 POOH LDDP / hole static w/ 9.2 ppg brine / clean pits 64 22310 9.25 LDDP / RU to run 3-1/2" upper completion w/ control lines 65 223101 9.25 Run 3-1/2" / stop since handling pup ran in error/ POOH 66 22310 9.25 Take out incorrect pup / RIH w/ 3-1/2" upper completion 67 223101 9.25 1 Run & land upper completion/ connect control lines 68 fill NABORS / CANRIG Well: H16A: (Bundle 1- 6 boxes) Main, (Bundle 2- 7 Boxes) 1-01, L02, L03, 1-04, 1-05, L06, L07 9: 5023120051- 01-00 Set (10 & 11 trays / set) Type Frequency Interval (Feet / MD) H16A Main Boxes & 258 el Envelopes) Washed and Dried 30' Date: 11/20/2018 Operator: BSC Crest Alaska Operating 16320'— 17440' TD L02 (1 BOX & 43 Envelopes) Washed and Dried 30' Well Name: H16A Main, L01, L02, L03, prepared By: Alan Febus 17940'— 19268' TD 1-04, 1-05, 1-06, 1-07 Washed and Dried 30' 18660' — 20010' TD Kenai Borough, Alaska Washed and Dried 333 W 711 Ave, Suite 100 Location: Hansen Field Shipping: Anchorage, AK 99501 20280' — 21340' TD L07 (1 BOX & 24 Envelopes) Washed and Dried Attn: Meredith Guhl (907)739-1235 Well: H16A: (Bundle 1- 6 boxes) Main, (Bundle 2- 7 Boxes) 1-01, L02, L03, 1-04, 1-05, L06, L07 9: 5023120051- 01-00 Set (10 & 11 trays / set) Type Frequency Interval (Feet / MD) H16A Main Boxes & 258 el Envelopes) Washed and Dried 30' 14580'-22310' L01 (1 BOX & 38 Envelopes) Washed and Dried 30' 16320'— 17440' TD L02 (1 BOX & 43 Envelopes) Washed and Dried 30' 17100'— 18390' TD L03 (1 BOX & 45 Envelopes) Washed and Dried 30' 17940'— 19268' TD L04 (1 BOX & 45 Envelopes) Washed and Dried 30' 18660' — 20010' TD L05 (1 BOX & 42 Envelopes) Washed and Dried 30' 19500' — 20743' TD L06 (1 BOX & 36 Envelopes) Washed and Dried 30' 20280' — 21340' TD L07 (1 BOX & 24 Envelopes) Washed and Dried 30' 21150'— 21860' TD Number of Boxes: 13 & Number of Envelopes: 531 M I�'Al X1,82 iy0 3 �ob�l cgs Vo 13 (9 064 - Number of Boxes: 13 RECEIVED Packaged into 2 Shipping Bundles NOV 16 2018 Bundle 1: Main (6 Boxes) AOGCC Number of Envelopes: 258 Bundle 2: L01, L02, 1-03, 1-04, L05, L06, L07 (7 Boxes) Number of Envelopes: 531 BLUECREST RIG #1 / JOB #: A1712 / WELL: H16A: 1-01, L02, L03, L04, L05, L06, L07 THE STATE °fALASKA GOVERNOR BILL WALKER Larry Burgess Alaska Manager BlueCrest Alaska Operating, LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Hansen Field, Undefined Oil Pool, H16A-L05 BlueCrest Alaska Operating, LLC Permit to Drill Number: 218-100 Surface Location: 2408' FSL, 1509' FEL, SEC. 2, T4S, R15W, SM Bottomhole Location: 977' FSL, 1433' FEL, SEC. 29, T3S, R15W, SM 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Dear Mr. Burgess: Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 218-095, API No. 50-231-20051-01- 00. 0-231-20051-01- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 4yLP4ocrster Q� aUk Commissioner DATED this r/ day of September, 2018. STATE OF ALASKA r ALAL i OIL AND GAS CONSERVATION COMMISSr .A PERMIT TO DRILL 20 AAC 25.005 JUL 2 6 2098 1 a. Type - i b. Proposed Well Class: Exploratory -Gas Drill ❑✓ Late 1- tratigmphic Test Development - Oil Redrill Reentry plorelory - Oil Development - Gas ❑Service -WAG ❑ Service ❑ .❑Service - Winj ❑ Single Zone Q, Q Service -Supply ❑ Multiple Zone ❑ 1c. Specify' Coalbed s Geothermal []Shale Gas 2. Operator Name: BlueCrest Alaska Operating LLC 5. Bond: Blanket Q Single Well ❑ Bond No. 5511251547 • 11. Well Name and Number: H16A"L05 - 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 6. Proposed Depth: MD: 21 1 OS' TVD: 6,595' 12. Field/Pool(s): Hansen, Undefined Oil Pool . 4a. Location of Well (Governmental Section): Surface: 2408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM Top of Productive Horizon: 196' FSL, 228' FEL, Sec. 29, T3S, R15W SM Total Depth: 977' FSL, 1433' FEL, Sec. 29, T3S, R15W SM 7. Property Designation: , ADL 18790, ADL 384403, Fee -Hansen 8. DNR Approval Number: LOCI 14-007 13. Approximate Spud Date: 9/15/2018 9. Acres in Property: 14423 14. Distance to Nearest Property: 2372' (Y01665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 168863 • y- 2144856.073 , Zone- 4 10. KB Elevation above MSL (ff): 180.4 GL / BF Elevation above MSL (ft): 145.81 - 15. Distance to Nearest Well Open to Same Pool: 285'- Hansen 1A -Lt 16. Deviated wells: Kickoff depth:1 55 feet Maximum Hole Angle: 115 degrees 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Downhole: 3,549 psi Surface: 2,842 psi (using 7,070' TVD) 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling I Length MD TVD MD TVD (including stage data) 8.5 Open Hole Completion - L05 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 146 20" N/A - Driven 187 187 Surface 4136.5 13-3/8" 588 bbls Lead; 198 bbls Tail 4177 3175 Intermediate 14726 95/8" 178 bbls Tail 14767 7083 Production Liner Perforation Depth MD (ft): WA Perforation Depth TVD (ft): WA Hydraulic Fracture planned? Yes ❑ No E] 20. Attachments: Property Plat '❑ BOP Sketch Diverter Sketch s Drilling Program Seabed Report Time v. Depth Plot Drilling Fluid Program Shallow Hazard Analysis 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Thomas McKay Authorized Name: Larry Burgess Contact Email: fom.mckayC@bIuecreslenergy.co Authorized Title: Alask anger Contact Phone: 907-754-9566 Authorized Signature: Date: 26Jul-18 Commission Use Only Permit to Drill Number: p API Numill 50- .- + Permit Approval2 Date: q I ✓ 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 urethan , gas hydrates, or gas contained in shales: EV Other. SOD S` /J 6 n I / Samples req'd: Yes ❑ No Mud log req'd: Yes QJo Eu HzS measures: Yes ❑ No Directional svy mq'd:(9 240 Spacing exception req'd: Yes RNo ❑ Inclination -only svy req'd: Yes QJo Post initial injection MIT req'd: Yes QJo l n APPROVED BY I �1 Approved by: li COMMISSIONER THECOMMISSION Date: Qt) �— Submit Form and Form 10-401 Revised 512017 This permit is valid r ,},�►pF AAe��d o11 approval per 20 AAP 23 005(g) Attachments In Duplicate 04- s•24-fs � ilatM L 40#vxl�8 'tlt-o Ir/ri/ia nue est Energy 3301 C Street, Suite 202, Anchorage, AK 99503 Thomas W. McKay, P.E. Phone: (907) 754-9566 Email: tom.mckay@bluecrestenergy.com July 26, 2018 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Application for Permit to Drill: Horizontal Production Well H16A — L05 Form 10-401; Fishbone Multilateral Well Design Dear Commissioners, BlueCrest Alaska Operating LLC hereby applies for a Permit to Drill for the onshore horizontal production well H16A — L05. This well will be drilled and completed using BlueCrest Rig #1. The planned spud date could be as early as 15 Sept 2018. H16A will be a multilateral producer, employing seven (7) "fishbone" style ribs drilled off the mainbore up into the full section of reservoir present on this Lease. The H16A well will be sidetracked off a whipstock set in the 9-5/8" casing of the original H16 wellbore. The H16A Fishbone Sidetrack well will not be fracture stimulated but instead will rely on the seven (7) rib wellbores to drain the hydrocarbon fluids, etc. into the main bore which will be cased with a 4-1/2" slotted liner. The well will be completed with 3-1/2" tubing and lifted using gas lift. Please find attached for the review of the Commission form 10-401, and the information required by 20 ACC 25.005 for this well. Please note that the eight (8) Spacing Exceptions for this H16A well have already been submitted. Also note that seven (7) additional yet abbreviated APD packages will be submitted for each well "rib" numbered L01 through L07, which are proposed to be open hole sidetracks off the mainbore. As per AOGCC regulations, each rib requires its own unique name and APD. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office) or 907-350-9544 (cell). Sincerely, Larry Burgess Alaska Manager BlueCrest Alaska Operating LLC lust Energy Application for Permit to Drill Document Horizontal Producer H16 -A— L05 Multilateral "Rib" Table of Contents Cosmopolitan Project H1 6-A 10-401 L05 APD 1. Well Name...................................................................................................................3 Requirements of 20 AAC 25.005(f).............................................................................................................. 3 2. Location Summary........................................................................................................3 Requirements of 20 AAC 25.005(c)(2).......................................................................................................... 3 Requirements of 20 AAC 25.050(b).............................................................................................................. 3 3. Blowout Prevention Equipment Information..................................................................4 Requirements of 20 AAC 25.005(c)(3).......................................................................................................... 4 4. Drilling Hazards Information.........................................................................................4 Requirements of 20 AAC 25.005 (c)(4)......................................................................................................... 4 DrillingHazards Summary:..................................................................................................................... 6 S. Procedure for Conducting Formation Integrity Tests.......................................................7 Requirements of 20 AAC 25.005 (c)(5)......................................................................................................... 7 6. Casing and Cementing Program.....................................................................................7 Requirements of 20 AAC 25.005(c)(6).......................................................................................................... 7 7. Diverter System Information .........................................................................................7 Requirements of 20 AAC 25.005(c)(7).......................................................................................................... 7 8. Drilling Fluid Program...................................................................................................8 Requirements of 20 AAC 25.005(c)(8).......................................................................................................... 8 9. Abnormally Pressured Formation Information................................................................8 Requirements of 20 AAC 25.005 (c)(9)......................................................................................................... 8 30. Seismic Analysis...........................................................................................................8 Requirements of 20 AAC 25.005 (c)(10)....................................................................................................... 8 11. Seabed Condition Analysis............................................................................................8 Requirements of 20 AAC 25.005 (c)(11).......................................................................................................8 12. Evidence of Bonding.....................................................................................................9 Requirements of 20 AAC 25.005 (c)(12)....................................................................................................... 9 13. Proposed Drilling Program............................................................................................9 Requirements of 20 AAC 25.005 (c)(13).......................................................................................................9 11Page H16 -A 10-401 L05 APD lue est Energy Cosmopolitan Project H16 -A 10-401 Ho APD 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................................9 Requirements of 20 AAC 25.005 (c)(14)....................................................................................................... 9 15. Attachments................................................................................................................9 Attachment 1 Drilling Procedure.................................................................................................................9 Attachment 2 Directional Plan....................................................................................................................9 Attachment 3 Casing Design Calculations (see H16 APD package)................................................................. 9 Attachment 4 Formation Integrity And Leak Off Test Procedure(NIA) ............................................................ 9 Attachment 5 BOP & Choke Manifold Configuration.....................................................................................9 Attachment 6 Wellhead & Tree Configuration.............................................................................................. 9 Attachment 7 Diverter Schematics (N/A).....................................................................................................9 Attachment8 Lease Map....................................................................................................................................... 9 2 1 P a g e H16 -A10-401 L05 APD lue est Energy Cosmopolitan Project H16 -A10-401 L05 APD 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 10 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: H16 -A— L05 Multilateral "Rib" To include the L05 lateral drilling and completion only NOTE: This well will be proposed as a "fishbone" design with a mainbore named as H16 -A, and seven (7) open hole "barefoot" laterals drilled by open hole sidetrack from the mainbore to be named as: H16A-LO1, H16A-1-02, H16A-1-03, H16A-1-04, H16A-1-05, H16A-1-06, and H16A-1-07. The seven (7) laterals or "ribs" will be drilled upward into all the Hemlock and Starichkof reservoir layers at an inclination of 115 degrees, and each will have its own APD package to be submitted as per AOGCC Regulations. This particular package (H16A LOS) is for the H16A L05 drilling and completion operations. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plot identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; (D) other information required by 20 AAC25.050(b); Location at Top of Productive Interval ("Starichkof" Sand) Location at Surface - H16 Slot —same for H16A 2408' FSL, 1509' FEL, Sec. 02, T4S, R15W SM Measured Depth, RKB: 19,580' ASPZone4NAD27Coordinates Northing: 2,144,856.073' Easting: 168,861.855' RKB Elevation 180.4'AMSL Pad Elevation 145.81'AMSL Location at Top of Productive Interval ("Starichkof" Sand) 196' FSL, 228' FEL, Sec. 29, T3S, R15W SM ASPZone4 NAD27Coordinotes Northing: 2,153,607.47' Easting: 154530.21' Measured Depth, RKB: 19,580' Total Vertical Depth, RKB: 7,066' Total Vertical Depth, SS: 6,886' Location at Total Depth 977' FSL, 1433' FEL, Sec. 29, T3S, R15W SM ASP Zone 4NAD 27coordinates Northing: 2,154,422' Easting: 153,347' Measured Depth, RKB: 21,105' ' Total Vertical Depth, RKB: 6,595' Total Vertical Depth, SS: 6,414' Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 14401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well, Please see Attachment 2: Directional Plan Please see Attachment 8: Lease Map (1) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3lPage H16 -A10-401 L05 APD lue st Ene-rgy Cosmopolitan Project H16 -A10-401 L05 APD 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 10 AAC25.036, or 20 AAC 25.037, as applicable; Please see Attachment 5: 30P & Choke Manifold Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Starichkof / Hemlock Sands is 0.472 psi/ft, or 9.07 ppg EMW at 6,951' TVDss taken per MDT's on Cosmopolitan 1. The maximum known pressure in the upper Kenai sands is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. To be conservative, the highest pressure gradient of 9.66 ppg or 0.502 psi/ft will be used to determine MPSP at the production interval of 6,900' TVDss. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.10), and the planned vertical depth of the Starichkof / Hemlock formation is: MPSP=(6,900TVDss) (0.502 -0.1 psi/ft) =2,774 psi MPSP=(7,070TVD)(0.502-0.1psi/ft) =2,842 psi (using TVD instead of TVDss for this calculation) MAX BHP=(7,070TVD) (0.502 psi/ft) =3,549 psi (using TVD instead of TVDss for this calculation) (B) data on potential gas zones; The Sterling, Beluga and Tyonek sands within the Kenai group have been known to contain gas. The intermediate section will be drilled with a minimum mud weight of 10.5 ppg, the maximum known pressure through these sections is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see the Drilling Hazards Overview below. 4 1 P a g a H16 -A10-401 L05APD nue est Energy //E ./t 4000 N N r r Z p 5000 //i :111 Cosmopolitan Project H16 -A10-401 L05APD Pressure Model (EMW) !.44 i.01 8 9 10 11 12 13 14 15 16 17 18 19 20 EMW (PPG) —Lithostatic Stress • MDT Data—Frac Gradient—Moving Average—PlannedMudWeight 51Paga H16 -A 10-401L05APD lue est Energy Cosmopolitan Project H16 -A 10-401 L05APD Drilling Hazards Summary (only the 8-1/2" Hole Section applies to this APD): 17-Y2" Hole Section / 13-%" Casing Event Risk Level Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use Clay Balling Low weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Low Diverter drills, increased mud weight. Surface Formations Reduced trip speeds, mud properties, proper hole filling, real time Directional Control Low BHA design, on -sight geologic review, avoid "drilling the line". Directional Control Low Reduced pump rates, mud rheology, lost circulation material, use Lost Circulation Low of low density cement slurries, control running speeds. 12-Y4" Hole Section / 9-%" Casins Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost Circulation Low circulating density (ECD) monitoring, mud rheology, Pre -planned LCM pills, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Low Increased mud density and fluid composition according to plan, Sloughing Coals, Low controlled trip speeds, ECD monitoring, optimized hydraulics for Tight Hole hole cleaning. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure Low practices, mud scavengers. HzS drills, detection systems, alarms, standard well control Hydrogen Sulfide Gas Low practices, mud scavengers. 8-%" Hole Section / 4-%" Slotted Liner Event Risk Level Mitigation Strategy Fluid density according to plan, reduced pump rates, reduced trip Lost Circulation Low speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Low BHA design, on -sight geologic review. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure HzS drills, detection systems, alarms, standard well control Hydrogen Sulfide Gas Low practices, mud scavengers. 6 1 P a g e H16 -A10-401 L05 APD Fest Energy Cosmopolitan Project H16 -A10-401 L05 APD 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f),, Please see Attachment 4: Formation Integrity and Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed; Casing and Cementing Program — H16 Actual Depths & Cement Volumes for 20", 13-3/8" and 9-5/8" ib) Csg00 Hole weigh Length Top Btm Do in Size t Grade Conn IftMD/TVD ) MD/ND Cement Program (in) (lb/R) Ift) (ft) zo" .5001 N/A A525 Weld 146' 41'/41' 187'/ 187' N/A (in place) 13-3/8' 4,177'/ 786 TOTAL BBLS 17-1/2" 72 L-80 BTC 4,136.5' 40.5'/40.5' LEAD: 588 bbls 12.00 ppg Kenai Lead (In place) 3175 , TAIL: 198 bbls 15.8 ppg Class "G" 9-5/8" 13,161'/ 12-1/4" 47 P-110 Hydri1563 13,120' 40.6'/40.6' (in place) 6,688' 178 TOTAL BBLS TAIL: 178 bbls 15.8 ppg Class "G" 9-5/8" 13,161'/ 14,767'/ 12-1/4" 53.5 P-110 Hydri1563 1,606' (in place) 6,688' 7,083' 14,255'/ 22,829'/ No cement required 8-1/2" 15.2 P-110 Hydril 563 8,574' 6,870' 6,880' Slotted liner completion 10Yliner lap Please see Attachment 3 in original H16 APD package: Casing Design Calculations 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 15.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2),' Please see Attachment 5: BOP and Choke Manifold Configuration. A diverter system will not be necessary since the well will be sidetracked out of 9-5/8" casing using the Rig t;1 BOP stack and choke manifold. 71Pag0 H16 -A10-401 L05 APD 115 ue( iest Energy Cosmopolitan Project H16 -A10-401 L05APD 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including o diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Drilling will be done with a drilling fluid having the following properties over the listed Production interval in the following Table. It is planned to drill the H16A production section using a solids free oil based mud system with no barite and only a small amount of calcium carbonate used unless losses dictate the addition of bridging material, and coupled with an RCD and MPD v (Rotating Circulating Device or Rotating Head and Managed Pressure Drilling) to minimize near wellbore formation damage in the reservoir section. Since the well design does not allow for any type of well stimulation or acid clean up after completion, it is vital for well productivity to drill the reservoir using MPD with as light a mud weight as possible, and with as few solids as possible. Parameter Surface Intermediate Production Type N/A N/A OEM — Low Solids Name ACTIMUL Reservoir Drill -In Density (ppg) 8.8-9.0 Oil:Water Ratio 70:30 6/3 RPM 8-12 PV (Ibs/100ft) <28 API Fluid Loss (cc/30min) HTHP Fluid Loss (cc/30min) <5.0 Electric Stability (mlVolts) >300 pH Chlorides 75-80,000 ppm 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (9) for on exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 10 AAC 25.033); Not applicable: Application is not for an exploratory or stratigraphic test well. 30. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of thefollowing items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(x); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20AAC25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottomfoundedstructure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 8 1 P a g e H16 -A10-401 L05 APD lueC.iest Energy Cosmopolitan Project H16 -A-1 0-401 L05 APD 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding)have been met; Evidence of bonding for BlueCrest Alaska Operating LLC is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20 AAC 15.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting on Application for Sundry Approvals (Form 10, 403) with the information required under 20 AAC 25.280 and 20 AAC 25.283; (13) a copy of the proposed drilling program; Please refer to Attachment 1— Drilling Procedure. Note: The H16A Fishbone Sidetrack and all laterals 1.01 through L07 will NOT be hydraulically stimulated. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080for on annular disposal operation in the well.; Solid and liquid wastes generated during the drilling process will be disposed of at Hilcorp Alaska, LLC's Kenai Gas Field (KFG) Grind & Injection (G&I) Facility or AIMM Technologies' (hydrokinetics) facility in Kenai. No annular disposal is planned for this well. 15. Attachments for H16A Attachment 1 Drilling Procedure with Wellbore Schematics Attachment 2 Directional Plan Attochment 3 Casing Design and Cement Volume Calculations — no cement to be used, see H16 APD for casing design Attachment 4 Formation Integrity And Leak Off Test Procedure Attachment 5 BOP & Choke Manifold Configuration Attachment 6 Wellhead & Tree Configuration Attachment 7 Diverter Schematics — N/A; well will be sidetracked out of 9-518" casing using BOP stack Attachment 8 Lease Map 91Pag0 H16 -A10-401 LOS APD lNest Energy Attachment Cosmopolitan Project H16 -A-1 0-401 L05 AP D Attachments H16 -A10-401 L05 APD Attachments nue st Energy Cosmopolitan Project H16A_ APD Well Plan Drilling Main Bore and Laterals (8 total laterals planned — 8-1/2" Production Section) (NOTE: This one page of the Drilling Procedure is included in each of the APD Packages for Laterals L01 -L071 under Attachment 1, Drilling Procedure.) 55. Make up 8-1/2" PDC bit on RSS BHA and RIH. 56. Install RCD element for MPD after drilling BHA is below wellhead. 57. NOTE: The use of MPD on this operation is under evaluation internally at BlueCrest; but MPD is included in this APD Base Case Drilling Procedure. 58. RIH with drilling BHA on 5-1/2" drill pipe (combination of HT -55 and XT -54 drill pipe). 59. Enter window in 9-5/8" casing and correlate tally depths. 60. Exit window slowly with BHA and tag bottom. 61. Establish parameters and drill ahead using an 8.8-9.0 ppg low solids, barite free drilling fluid, as per directional plan to first sidetrack point for H16A-1-01. 62. Directionally drill well to LOl target and drill L01 lateral to L01 TD as called by Geologists. 63. Circulate and backream the L01 lateral back to the main bore. 64. Run back in to TD of the main bore. 65. Displace the L01 lateral with LVT. 66. Strip out using MPD without backreaming if possible to the main bore. 67. Initiate trenching and time drilling to execute an open hole sidetrack away from L01 and to the kickoff point for the L02 lateral. 68. Directionally drill the L02 lateral using the same procedure as L01. 69. Repeat these steps for drilling laterals 2 through 8 in H16A. 70. After drilling and displacing Lateral 8 with LVT, pull back to mainbore. 71. Backream and displace main bore to LVT is 1000' stages. 72. Continue backreaming and displacing to LVT until inside the 9-5/8" casing above the window. 73. Spot high viscosity pill and cap well to surface with a 9.7 ppg low solids mud without barite. 74. Backream / strip out to the BHA using MPD. 75. Remove the RCD element, and pull out with the BHA. 76. Lay down same and report wear patterns to office on all BHA components. 77. NOTE: BHA and drill pipe wear, along with the 14 -day AOGCC BOP test requirement, will determine how many laterals can be drilled on each bit run. 78. An RTTS packer for 9-5/8" casing is available on standby in the event a BOP test is conducted with the drill string hung off below the wellhead using the RTTS. 3(Page 1116A_APD Well Plan Last Updated: TWM, 11 July 2018 -187' MD/TVD Driven Bit: N/A RSS: N/A MWD: N/A LWD: N/A 17-1/2" Open Hole 4,177'MD/3,175'TVD Bit: N/A RSS: N/A 12-1/4" MWD: N/A Open Hole LWD: N/A Base of window depth in 9-5/8" casing 14,362' MD/ 7,068' TVD (Lower Lat) Bit: 8-1/2" PDC RSS: Xceed675 MWD: Telescope 8-1/2" LWD: GeoSphere Open Hole adnVISION 916-A Fishbone Production Well (Main Bore / Lower Lateral / Starichkof / Hemlock Primary Target) Well will be sidetracked through window in 9-5/8" easing Wall A252 ERW 729 L80 BTC 3-1/2" Production Tubing to Surface GLM's / SSSV / DH Gauges / CIM Liner Hgr & Liner Top Packer I 17a/a oa.oeruv n�oa law,roi, I I I I I 1 I I I I I I I I 1 4-1/2" 12.69 P110 H563 Slotted Liner JUn -Cemented Slotted Liner Completion in Mainbore Cement ACTUAL PUMPED 12.0 ppg Lead 588 bbls 15.8 ppg Class G Tail 198 bbls ACTUAL PUMPED 15.8 ppg Class G 178 bbls Un -cemented Slotted Liner No Frac's Ind 73 deg Ind 78 deg OBM 8.8-9.0 ppg VersaPro with MPD Max Incl 107 deg Azim 303 deg T. McKay, 12Ju1y2018 H16A Lower Lateral Completion with 20" Conductor Slotted Liner in Mainbore and Seven @ 187' BGL (7) Open Hole Fishbone Ribs NOTE: Well will be sidetracked off a whipstock /1ue est set at approx 14,350' MD in Energy 13-3/8" 72# 1.80 the 9-5/8" casing BTC @ 4177' MD 3-%" 9.3# IBT-MOD Production Tubing 4-%" x 9-5/8" Liner Hanger & Liner Top Packer 9-5/8" 47.0/53.5# P110 H563 @ 14767' MD Fishbone ribs are 8-%" open holes spaced approx every 800' with 4-%" slotted liner run in the mainbore after the seven ribs are drilled; ribs are drilled in order from L01 to L07 using open hole sidetracks to initiate each rib; ribs penetrate all layers of Starichkof and Hemlock pay sands L01 L02 L03 L04 L05 L06 L07 4-A" 17# H521 Slotted Liner @ 22829' MD H16A Fishbone Design SlueCiest Energy Attachmen Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16•A 10.401 L05 APD Attachments H16A - Table of Coordinates for Mainbore and Laterals L01 through L07 H16A Top Of Productive Horizon Distance to MD X Y Legal Main Wellbore 14632 158778.19 2150581.45 2572' FSL, 1182' FEL, Sec. 33, T3S, R15W SM LO7 16382 157163.69 2151793.49 1950' FSL. 2933' FEL, Sec. 29. T3S. R15W SM L02 17180 156506.56 2152245.94 4173' FSL, 3498' FEL, Sec. 33, T3S, R15W SM L03 17980 155847.77 2152699.77 4608' FSL, 4168' FEL, Sec. 33, T35, R15W SM L04 18780 155189.00 2153153.63 5044' FSL, 4839' FEL, Sec. 33, T3S, R15W SM L05 19580 154530.21 2153607 47 196' FSL, 228' FEL, Sec. 29, T3S, R15W SM L0620382 L05 153869.79 2154062.46 633' FSL, 901' FEL, Sec. 29, T3S, R15W SM L07 21107 153272.06 2154473 31 1026' FSL, 1509' FEL, Sec. 29, T3S, R15W SM H16A Total Depth Distance to MD X Y Y01665 Legal Main Wellbore 22829 151874.00 2155437.00 Y01665 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM L01 17722 156120.00 2152512.00 Y01665 4428' FSL. 3891' FEL, Sec. 33, T3S, R15W SM L02 18730 155305.00 2153074.00 Y01665 4967' FSL, 4721' FEL, Sec. 33, T3S, R15W SM L03 19590 154601.00 2153558.00 149' FSL, 156' FEL, Sec. 29, T3S, R15W SM L04 20374 153954.00 2154004.00 576' FSL, 815' FEL, Sec. 29, T3S, R15W SM L05 21105 153347.00 2154422.00 977' FSL, 1433' FEL, Sec. 29, T3S, R15W SM L06 21745152808.00 2154794.00 1334' FSL, 1982' FEL, Sec. 29, T35, R15W SM L07 22315 152320.00 2155129.00 1655' FSL, 2479' FEL, Sec. 29, T3S, R15W SM H16A Distance to Nearest Property Line Main Wellbore 694 Y01665 L01 5502 Y01665 L02 4595 Y01665 L03 3800 Y01665 L04 3066 Y01665 L05 2372 Y01665 L06 1751 Y01665 L07 1202 Y01665 I!i ueC,�ieSt HlMml-05 (P2) Proposal Geodetic Report Schlumberger Energy (091 Plan) COerd: Bl.e nart Verses] SacOon A i.0 : 300.000 ° (Tme North) Field: Cwmopolikle Uel Vertical Orlgln: 0.000 R. GMGft Stru CosPad /H-i6�Sibiliiy EzcluAlan Zone Dll olar, Table Walicture/SIM: H18��likn Study Elevation: Wl. Borehole : HifiML05 aML F� Gru ntl Elevoll 11145.010Reboya APO: 502312005164 Magreic DocllnMltn: 14.561- SurveyName: H16A-UO(P2) Total Greviry Field Strength: 10012613"n FaM665 Beset) Survey Dak: JUly10.2010 Gravity Model: DOX Tort I AND I DDI I ERD liaM. 208.715 ° 118259,312 it /].05512 575 Total Magnetic Field Strength: 55102.359 nT Coordinate Relentless System: NAD27 Alaska State Plmre. Zone 04, US Fast Mean"C Dip Angle: 72.880' Locaticn Lat I Long: N59. 51' 32.04311'. W 151-48'501216• Declination Dole: Se9temher 302018 Location Grid WE YM: N 2144855.960 RUS, E 108622M We Ma9rmec DeclkMkn Modal: HDGM 2018 CRS GrM Conwrganu Angk: -1.5500' No"Reference: True North Grid Seek Factor: 10000248 Grid Convergence Vead: 010000. Version I Patch: 2.10 544 0 Tafel Corr Mm NoM->True NMh: 14.5612 MD Incl AMm crus TVOSS T(M VSEL NS EW TIFM DLS00) EzcluAlan Zone Dll Exclusion Zona Gao8lapT) NOMing Earring CommaMs IRI (°) (% 111 IRI (fll IR) (fl) (% Index ('710011) 0118eully lnbx Alen Anila m OT) (NUS) MS) (flUSI RTE 0.00 000 -100.43 0.00 ON,am OM N/A 0 00am 17.12 2144855.90 168862.23 34.02 0.00 am 0.00 -145.01 34.62 am 0.00 am 000 0.00 25218M 000 17.12 I622IA6 16221.18 214485590 16006223 10000 0.43 24854 -90.43 100.00 0m -009 -0.23 252.54M 0.66 am 0.00 17.37 16451.11 214485590 168862.00 20000 102 19.50 199.99 1.00 -0.48 -143 0.59 0.14 1]68 15733.41 2144055.54 16888019 300.00 2.42 =54 320.54 119.52 299.95 3.57 -3.02 M3,89M 3M.21L 2.24 1.14 15.02 15019.20 2144858.96 1688063 40000 540 33399 219.29 399]1 9.47 6.09 616 13.06 63.21L 3.10 1.85 13.48 4043.10 2144062.91 168855.38 500.00 7.61 323.52 317.0 499.06 19.44 16.29 -13.05 70.091. 239 2.30 16.70 1299].50 2144872.62 1688M No00 9 91 303 00 41].40 59] .91 34.11 26.31 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(P5) 7/17/2018 3:08 PM Page 1 of 4 ND Incl M. 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388959 -7259.10 9089L 026 626 64.51 49811,46 21489258 161711.40 10834.41 67.42 297.28 5594.9 5774.W 8318.11 3929.96 4335.97 MAR 0.9 6.27 6415 49911.92 214899.03 1616359 1092639 9.02 297.W 5606.46 5810.89 90467 39699 -741289 21.31L OA9 628 9.30 49725.07 2149025W 161559.9 11022.43 6747 297.34 566683 597.26 99131 400980 -0489.86 145.6R 0.51 629 64.78 4992535 214909.03 161483.99 1111630 9.9 297.66 5703.13 0603.56 8577.80 4049.77 -0%6.65 32B6R 0% 629 64.28 49718.27 2149110.07 161408.31 1121029 9.57 298.03 5739.39 5919.82 8664A5 40W27 -09332 19.63 067 630 64.68 4988257 2149106.9 161332.77 11304.20 67.06 297.86 5775.65 5956.00 875102 4130.87 -7719.85 91 SR 063 631 64.19 49679.07 2149195.31 161257.37 11398.15 66.W 29.30 581237 5992.80 8837.45 417157 -77%.15 3.89R 0.43 632 9.05 49621.60 2149238.07 161182.21 11492.14 67.9 2%.35 %4860 602803 8924.14 4212.72 -792A9 159]51. 0.73 6.32 64.60 498990 2149281.28 161107.01 11585.95 67.32 20.21 %950 6064.93 W10.76 425318 -794881 14846L 0.40 6.33 64.39 49764.W 214932441 161031.03 119975 67.05 298.03 5920.88 6101.31 9097.18 42953 402507 152L 034 634 64.18 4968045 2149367.22 10690671 1177318 67.25 29797 5957.39 613782 9183.78 4335.21 410157 98.9E 0.22 6.31 64.39 49767.63 214909.96 16089.34 11867.06 6720 297.61 0693.73 6174.16 927021 437557 77178.15 71.17R 036 6.35 6445 49792.27 2149452.39 1O W5.80 1196153 9.82 29799 6030.02 6210.45 9356.78 415.95 42913 71.59R 0.39 835 64.45 49793.90 21494983 160730.43 120%.21 9.36 298.12 6066.11 6246.9 943.18 445681 4331.02 61.6R 0.13 6.36 64.45 49794.9 2149537.% 10665527 1214920 67.45 298.30 6102.2 6282.65 9529.91 497.63 4407,49 SOAR 0.20 6.37 64.49 49808.74 2149580.63 105n 94 12243.19 67.40 29867 6138.30 6316.73 961667 409.02 -98377 136.7E 037 837 933 4974463 214962409 16059.81 12W7.9 6706 29826 6174.67 6355.10 9703.16 4580.25 77559.83 9.35R 0% 638 64.07 49636.36 214969.38 16029W 12431.00 67.24 29880 621120 6391.0 9789.69 462160 4835.08 111.02R OW 6.38 64.14 49666.37 2149710.78 16355.00 Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan PacRH14\H14\H14 (P5) 7/17/2018 3:08 PM Page 2 of 4 Commantn MD Rzlm T. TVD35 TVD VSEL NS Ea) TF OLS Directlonal Eaoluelon Zone E.aunipn zplt. GaoMep Th Nahlng EasUng (R) (1) (7 (°) IX) (ft) IRI (ft) IRI (°) 1°I4DOfl) OHA1ully lndsa 111441 Rn9b (2371 (ROS) (Ru31 12524.87 67.12 299.14 6247.61 6428.04 987620 4663.51 -0711.50 1M.BR 0.36 6.39 63.93 4957].11 2149754.73 16MBO 47 12618.68 66.51 299.30 6284.52 648495 9962.44 470561 8786.85 168.5L 0.64 6.40 6328 4932241 2149790.86 160206.37 12]12.]2 66.27 29924 6322.16 6502.59 10018.61 474714 8862.02 25 ML 029 6.40 6309 49219.40 214984302 160IMN 1200645 66.00 298.93 635942 6539.85 10134.60 4789.55 893718 140.WL 0.72 641 6376 49500.25 2149886.66 1600W.37 12900.53 6695 298.45 6396]6 65]].19 1022093 4831.00 -%12.93 M.67L 0.73 6.42 63.40 49353.56 2149930.36 159983.]] 12994.02 66.82 29787 8434.23 6614.66 10307.41 487184 -9769.22 119.62L 0.75 6.42 64.02 49616.58 214997325 159908.63 1MB8.71 66.40 291.06 647151 6651.94 10393.50 491158 -9186.68 17.%L 091 6.43 63.86 49548.98 215001506 159833.27 1310220 66.93 296.60 6508.57 6689.00 10!/9.30 4950.55 -924225 67138 0.59 6.44 64.41 4978281 2159756.09 159757.79 13276.03 6707 29].25 8545.20 672563 105615.48 4989.81 -9319.10 59.598 0.39 644 64.44 49793.59 215009744 159602.03 13370.05 67.44 297.0 656155 6761,98 10fi59.11 5029.97 -9395.94 100.3E 017 6.45 64.59 4985721 215013967 159606.30 13464.09 67,29 297.02 6617.75 6790.10 10738.23 W70.01 -9172.95 9012L 0.91 6.45 64.71 4990887 21W18l.n 169530.41 135%.W 67.28 29588 6653.55 6033.90 10624.17 5107.97 -9519.97 47.94R 1.33 646 65.10 97%5.9 21M221.82 159454.84 13697.66 67.38 295.80 668972 6070.15 10910.53 5145.97 -9627.60 99.87L 0.16 6.47 65.16 59090.67 2150261.54 15937788 137".66 67.31 295.36 6725.93 6906.36 1099702 518304 -9]05.84 1044L 0.44 6A7 65.22 50116.56 2150301.11 159300.68 13838.74 67.04 295.25 6762.43 6942.86 11083.45 5220.10 -978423 0.14R 031 6.48 65.00 5026AI 21W34O.29 159223.32 139n.M 70.95 29526 679609 6976.52 1117083 5257.51 -9863.M 9.51R C16 649 M70 51431.67 215037985 15914506 1402848 75.05 295.97 6823.51 7003.94 11260.24 529629 -9944.40 24.85R 4.43 651 nAO 52617.49 21M420.81 159065.28 1412047 77.03 296.91 6846,19 7026.62 1135128 5336.90 -10026,06 1103R 2.32 &M 74.02 SM67.32 21SM63.63 158964.75 14214.46 7971 297.59 6865.13 704556 1144312 537905 -10107.90 40.9R 2.94 654 76.38 53649.09 21WW7.99 15990409 Tsln Su v 1430835 8138 299.05 6880.56 7060.99 11535.79 5422.99 -10189.42 20.35R 2.35 6.59 77.M 53904.71 21W5 A3 158823.79 Top Whipsmpk 1431997 82.40 299.43 600629 7 .n 11576.03 544265 -10234.54 20R 267 6.59 78.42 5407709 21M574.73 15878922 Basa WS 1438200 61.35 300.14 600]19 706822 11588.94 5"9.06 -10235.74 HS 16.00 6.97 80.08 54377.49 2150501.45 IM778A9 Cry WOO 1438297 8495 590.14 6897.76 7070.19 1197885 545997 -10252.95 OR 0.00 6.56 80.08 54377.54 2150591.91 IN76126 1"9700 84.62 300.61 6091.49 707192 11626.76 5468.12 -1026641 W.95R 300 6.56 80.21 54390.14 2150601.39 IM74605 14M0.00 86.13 59322 609.55 707998 11726.3] 5520.81 -1035300 59.74R 3.00 6.W 8092 54510.14 2150656.36 16866292 14600.00 87fi4 59581 691.99 708542 11825.90 557730 -00435.27 59AR 3.00 659 81.65 51617.10 210715.15 15958222 End Cry 14623.00 88.13 306.64 6906.17 7066.60 118570 5596.28 -1046107 HS 3.00 6.60 81.89 54650.07 2150734/4 lm5%m 14700.00 88.13 306.64 6908.39 708882 11925.20 %596 -1051560 HS 000 6.60 81.89 51650.17 2150776.77 168W3M Cry WOO 14]32.97 88.13 306.64 690943 708986 11956.97 W55W -10541.27 24.11L 000 6.60 81.89 51650.21 210796.54 15947840 14800.00 89.99 W5.81 01055 709098 12024.55 5696.10 -10.5%.11 241L 3.97 6.61 83.91 WNW 2150838.20 7042466 End Cry 14817.40 WA7 305.59 010.48 709091 12041.86 57%25 -1061024 HS 3.97 662 84.43 54941.42 21M04073 159410.81 1490000 MA7 M5.59 690.97 709023 12124.07 575432 -1067].41 HS OW 6.62 MM3 51941,47 219708.61 159344.90 15000.60 90.47 595.59 6908.% 708942 1nn.O 581252 -107M.73 HS 0.00 6.63 84.43 54911.54 2150959.00 15826527 15197.60 90.47 595.59 6908.17 7088.60 12323.11 5870.M -1081004 H$ O.W 664 04.43 54941.60 2151019.39 1WIM57 15200.97 90.47 WS.O 6597.35 ]08].78 124n.M M2892 -1091.M HS 000 6.64 M43 5494166 2151079.78 150105.06 15300.00 9.47 595.59 6906.54 ]0869] 12592.15 5967.12 -11002.67 HS 0.09 6.65 04.43 54941.n 2151140.17 10026.16 15400.00 W47 W5.09 6%6.n 7086.15 12621.67 6045.32 -11083.99 HS 000 6.65 04.43 54941.78 2151200.M 157946.45 15500.97 9.47 595.59 6904.90 7085.33 12M120 6103.M -1110M HS 0.00 6M MA3 5194184 2151260.95 157066.75 15600.00 90.47 W5.O 6904.09 7084.52 12UOn 6161.59 -1124662 HS 09 667 84.43 54941.9 2151321.M 157787.04 15700.00 90.47 W5.50 693.27 708370 12920.24 6219.92 -1132)9 HS 000 6.67 MM3 54941.% 2151381.73 157707.34 15000.00 W.47 W5.59 6902.45 7002.80 IW19.76 678.12 -114025 HS 0.0 6.68 MM3 5194201 215144212 157627.63 15997.60 W.47 W5.59 691." 7002.07 13119.28 0W.M -1149.59 HS 0.00 6.69 MM3 54%2.07 2151592.51 157547.93 16097.60 W.47 W5.59 690.82 708125 1n18.W 6394.52 -1157188 HS 0.9 668 04A3 54942.12 2151972.90 157460.23 16160.00 9047 W5.O 69000 708043 1331832 8459.72 -11MA9 HS 0.9 6.70 04.43 54942.18 215162329 157388.52 16297.97 9047 305.59 689.19 ]0]962 13117.84 6510.92 -11731.51 HS 000 6.70 04.43 54942.23 2151M3.68 157300.02 16397.97 WAT 305.59 689837 7078.80 1M17.M 6569.12 -1181582 HS 0.97 611 84.43 5194228 2151744.9 157239.11 Cry WOO 163W.M 9.47 397.59 6898.12 7078.55 13518.08 68778 -11840.92 10.8L 0.97 6.71 84.43 %942M 2151762.71 157204.51 KOP Cry 21100 16382.00 91.97 MS.M 659703 7077.46 13598.9] 6616.73 -11882.57 LS 3.00 6.72 85% M065.O 2151]9.49 157163.69 lum.00 91.61 W5.M 689647 7076.9 IW16.88 6627.13 -1189725 lS 297 6.72 8561 55041.10 215180428 157149.29 Cry 21100 1648200 89.97 W5.W 6895.23 7075.76 1%98.52 6674.51 419M.16 8309L 2.00 6.73 84.04 54904.16 2151853.47 157063.69 1650.00 W.02 M4.95 689&M 7075.76 13716A5 66M.87 -1197888 83OL 200 673 MAS 54918.06 2151864.22 157089.26 1669.00 9.26 W296 6895.09 7075.52 13816.21 674072 42061.83 8309L 297 6.74 84.% 54989.57 2151922.31 1669786 End Cm 16591.% W.n 592.30 6094.92 7075.59 1384712 675].74 -12088.30 HS 200 6.75 85.21 5010.08 215194004 156%1.7 1679.97 9.M W234 6894.59 7074.96 12816M 6794.59 -1214622 HS 0.00 6.75 85.21 SW10.11 215197821 1%904.95 1689.00 W.9 592.34 609394 7074.37 14016.03 604284 -122M12 HS 000 675 6521 SM10.16 2152033.98 15fi821.94 18997.97 90.M W2M 6893.36 7073.79 14115.94 6901.23 .1231521 HS 0.00 6.76 85.21 5501021 2159089.74 197736.93 -- 17000.00 90.38 W2.M 689217 7073.20 14215.86 8954.81 -12399.70 HS 0,00 6.77 8521 5W10.26 215214551 1M0593 17100.00 W.M WIM 6092.19 70]2.62 14315.77 7008.30 -124M 19 HS 0.00 877 8521 5W10.M 215220128 155972.92 Cry WOO 17126.11 9.n 97234 6092.04 7072A7 14341.06 702326 -1206.25 5.63R 0.00 6,77 8521 55010.23 2152215.83 15655125 KOP Cry 2/100 17180.00 9194 39.49 6890.96 7071.39 14285.69 7051.14 -12551.73 LS 3.00 618 8671 5511208 2159245.94 1565%56 17200.00 91.54 30249 68M.38 707079 14415.66 7061.80 -125M.59 LS 2.00 678 MM 55009.63 2152357.14 156490.00 Cry 21197 17280.00 89.94 592.49 680.32 786975 1"95.50 7104.86 -12836.% 63.93R 297 6.79 M19 54975.13 2152591.93 15642372 17M0.00 MM2 302.85 6689.31 706974 14515.56 7115.65 -12652.9 63.938 2.0 6.79 8486 54981.05 2152313.18 156407.19 End Cry 17313.31 9024 M309 6M9.27 7069.70 1452085 71n.9 -12664.07 HS 2.9 679 84.91 54901.97 21523M.73 1M39622 17400.00 90.24 30309 68M.91 7069.34 14615.41 717023 -12736.69 HS 0.00 6.80 84.91 54985.01 2152370.02 1%23491 17WO.00 9024 30309 6086.60 7068.93 14715.27 7224.83 4202047 HS 000 6.80 04.91 5495.05 2159426.07 1M24264 1760097 90.24 30309 6666.08 706851 14815.12 7279.43 -12901.25 HS 09 881 84.91 54%5.10 2152483.73 lMl60M 17700.00 9024 59309 659767 706BAO 14914.97 7334.03 -12959.02 HS OW 882 8491 5490514 2152540.59 1%078.11 1700000 9024 303.09 688726 706769 1591683 7300.63 -15971.80 HS O.W 6.82 84.91 5 %5.18 2152M7A5 155995.85 1790000 9024 W3O 6886.84 706723 15114.68 7"3.23 -13155.50 HS 0.00 6.03 8491 5490523 2152651.31 lW913.59 Cry WOO 1]923.3] 9024 W3.09 688615 706718 151M.01 70.55.9 -13175.15 107L 000 6.9 84.91 5985.24 2152667.59 156894.36 KOP Cry W100 1790000 91.94 59306 65567 7006.70 15194.55 7486.89 -12322.60 LS 3.97 683 86.59 5510290 2152699]] 155847.77 1800000 91.54 W306 6M5.07 7065W 15214.51 749719 -tn39.35 LS 2.00 684 MA7 5Wn.39 21571113 155831.23 cn 2vlw 1800000 09.94 W3.06 604.04 ]064.4] 15291.39 7511.13 -1330639 1W.73L 2.0 6.84 84.63 51997.65 2152756.59 15976549 EMOm 18089.72 8915 W397 6884.07 7064.50 15591.10 7516.73 -MUM HS 297 6.85 MA7 5046.17 2123762.10 1075749 18100.00 89.75 W300 6884.11 706454 15314.M 7552.33 -13233.17 HS 0.60 885 MA7 51916.18 2152767.93 159749.02 18200.00 09.75 97300 68"55 7064.90 15414.22 76%.78 -13197.9 HS O.W 6.85 MA7 51946.23 2152824.65 1066687 18WO.97 8975 W300 688496 706541 15514.0 766124 -1319.9 HS 0.9 6W 04.47 51946.29 2152881.37 15558/31 18400.00 89.75 W3.00 6MS41 ]06584 15613.95 771570 -1M7477 HS OW 6.59 04.47 5194634 2159930.09 15559195 1850.00 89.75 MOM 08585 706620 15713.81 7770.16 -13658.64 HS OW 6.87 0447 51946.39 2152994.81 15541959 1800.00 09.75 WIN 6059.28 ]066.]1 1M13.67 782462 -1374251 HS 0.9 6.67 MA7 5 "6" 2153051.53 1552].23 18797.9 8975 303.00 0M.71 7067.14 15913.54 7879.0 -13826.38 HS 0.00 6.59 84.47 5494648 215310825 15525487 Drilling Office 2.10.302.0 Cosmopolitan UnidCosmoplitan Pad\H14\H14\H74 (P5) 7/17/2018 3:08 PM Page 3 of 4 Commenb MD (ft) Incl 1°) Frim Tma (°) MOSS lftl ND Ifl) VSEL IR) NS (ft) EW (ft) TF (% DLS Olmclionel Excluelan Zane (•/100X) DIMwNy Index Z.e Eatlucion Zoe Angle 1• GseMap TM1 (nT) NorlM1ing IRDS) Eeatlnp ("a) Cry &100 18707,48 89.75 303.00 688615 706718 15921 01 7883.15 Amn 65 0.33R am 6.88 84 47 54946 ,49 2153112.49 155248.71 KOP Cry 21100 18780.00 91.93 303-01 6005.60 7%6.11 15993.41 7922.65 -13893.46 LS 300 689 86.56 5510354 215315363 155189.00 SLB M 18%.00 91.53 303.01 600500 7065.51 16013.38 7933.54 -13910.22 LS 3.00 689 86.18 5508010 2153164.97 155172.53 Crv2/100 1888000 89% 303.01 6884.06 70&.49 1609326 7977.12 -1397730 178.621- 200 690 84.64 54961A1 2153210.35 155106.66 End Cry 1888866 89.75 303D1 6884.09 7064.52 16101.90 7981.83 -13984.57 HS 200 6.90 84.47 54946,53 215321527 155099.53 18900.00 89.75 303.01 6804.14 7064.57 16113.M 798801 -1398400 HS 0.00 6% 84.47 51946.53 2153221.70 155090.19 19000.00 8975 30301 6084.57 7065.00 1621309 804248 -14077.94 HS 0.00 690 84.48 5494650 2153278.43 15500784 19100.00 8975 303.01 6885,00 7065.43 16312.95 8096.95 -14161A0 HS 0.00 691 MA8 5494&63 2153335.17 154925.49 1920000 8975 303.01 6885.42 7065.85 181261 8151.42 -14245.66 HS 0.00 6.91 84.48 54946a7 2153391.90 15483.14 1930000 89.75 303.01 6005.05 7066.28 16512.68 8205.89 -14329.52 HS 000 692 UAB 5486.71 215344863 18760.79 180000 8975 30301 688628 7066.71 16612.54 8260.37 -1441330 HS 0.00 692 M48 548675 215350538 15467644 19500.00 89.75 306.01 6886.71 706714 16712,40 8314.8 -1449724 HS 0.00 693 8448 8946.80 2153562.10 18596.09 Ory 3/100 1950783 8975 30301 6806.75 7067.18 16720,22 8319.10 -14503.01 0.041 000 6.93 8.48 5486.00 2153566.54 154%9.8 19589.69 92.00 30300 688560 706CO3 1678.96 8359.87 -14566.58 HS 3.00 6.94 86M 55107.82 215350900 15452800 1960000 9252 303.00 6884.92 7065.35 1681223 036829 -1458100 IS 300 694 87.13 55133.93 216361861 154513.76 19700.00 95U 303.01 6877.91 7058.31 16911.84 842362 -14664.73 HS 3.00 6.95 8999 55202.93 215367540 154431.62 19800.00 9852 303.01 6065.69 7046.12 17010.94 8477.60 -14747.95 HS 300 6,96 87.10 55132.30 215373170 154349.89 19900.00 10152 303.01 6848.29 7028.72 17109.27 8531.32 -14830.52 HS 3.00 6.97 84,22 54922.29 215378757 154268.81 End Cry 1992380 10223 30301 654340 702383 17132.53 0544.01 -14850.06 HS 3.00 698 83.54 54651.83 215300038 15424963 20000.00 10223 303.01 6027.25 7W7M 1720890 8554.50 -14912.50 HS O.00 6,98 83.54 8851.60 215383.03 154188.30 Cry MOO 20050.93 102.23 303.01 6816.46 899869 17256.61 0611.70 -14954.25 0.141. 0.00 698 83.54 54051.44 2153871.20 154147.31 2010000 103.71 303.01 660545 6985.88 17354.35 8637.74 -1498.34 0.141 3.00 6.99 82.12 M68129 2153898.40 15410794 2020000 106.71 303.00 6779.22 695965 1740011 0690.29 -15075.26 0.151, 3.00 7.00 79.24 54231.75 2153953.14 154028.48 2030000 109.71 302.99 674790 692841 17495.56 0742.02 .15154.93 0.15L 3.00 7.01 76.37 53645.66 2154007.01 153%0.24 20400.00 112.71 302.98 6711M 689225 1758885 8792.77 -15233.12 0.151- 3.00 7.02 73.49 52925.02 2154059.87 153ST3A6 20409.82 113.00 302.98 6708.00 6888.43 17597.69 8797]0 4524072 DAL 3.00 7.02 73.21 52847.06 2154065.00 15386600 End Cry 20480.22 115.11 302.96 6679.31 8859]4 17661.09 8SUM -1529464 HS 3.00 7.03 71.18 52250.52 215410144 1538138 2050000 115.11 30296 8670.91 6851.34 17679.77 6842.42 -1530967 HS 0.00 7.03 71.18 52250.40 215411159 153798.29 20600.00 115.11 302.96 6628.47 6808.90 17770.20 809169 -15385.64 HS 0100 7.03 71.10 52249.78 215416290 15372368 207M 00 115.11 302.96 6586.03 6766.46 17860.63 8940.96 -15461,61 HS 0.00 7.04 71.18 U249.17 2154214.22 153649.08 20800.00 115.11 302.96 6543.60 672403 17951.05 8990.23 -15537.50 HS 000 7.54 71.10 52248.55 2154265.54 163574.47 20900.00 11511 302.96 6501.16 668159 18141.48 9039.49 -15613.55 HS 0.00 7.05 71.18 52247.93 2154316.05 153499.87 21000.00 115.11 302.96 60.50.72 6639.15 1813191 %00.76 -15809.52 HS 0.00 7.05 71.16 5224732 2154358.17 16342526 21100.00 115.11 302.% 6416,28 859671 18222.33 9130.03 -1576549 HS 000 7.05 71.10 52246.70 2154419A9 153350.86 TD 21104.90 • 115.11 302.96 641620 • 6594.63 102'16)7 9140.44 -15769,22 0.00 7.05 7118 52246.67 2154422.00 15334700 Survey Error Model: ISCVISA Rev 0 "' 3-095.0005 Confidence 2.7955 sn ne, Survey Program: MD From MD To EOU Fred Hale Sire Casing Dlaaleter ExpectedtMaxet 0¢ecription PM IncllnaH.tl.n Survey Tool Tye B W.l Survey IRI (ft) IRI (i.) On t 1 1200.000 4126070 ACI Sin. 17.500 13375 SLB MWD.GMAG IHIE, H16PB1 I H16PB1 1 4126.070 143%.350 Aal SM. 12253 9625 SLB M HUMIN 1 14308.350 14319000 1/100000 12250 9.025 O-GMAG 31-8 MWDONLY M1 01 H1 MUM IH16A101(P2) 1 14349000 14800.000 11100000 8.500 0000 31-8_8060-INC_DNLV_FlLLER H16A101 IMM-LO1(P2) 1 14800.000 16390.000 1/100000 8.500 0.000 61-8 MWD+SAG H16b 01 2 14800000 1/100000 8.500 0060 SLB_MWD+GMAG IMM-L01(P2) H16A101 IMBA101(P2) 2 163820% 17180000 17180000 1/100.000 8.500 0.000 SLB M H16A103/H1SA102(P2) 2 P1%000 17980000 1/100.000 8.500 0060 SLB M O+GMAG H16A106IMBA103(P2) 2 17980000 18780.000 1/100000 8.500 0000 O+GMAG SLB MWD•GMAG H16AlUIH16AlU(P2) 2 18780.000 21104.900 1/100.000 8.500 0.000 SLB MWDaGMAG H16ALOSl Hi6A105 (P2) Drilling Office 2.10.302.0 Cosmopolitan Unit\CDsmoplitan Pad\111 4\111 4\H14 (P5) 7/17/2018 3:08 PM Page 4 of 4 fenwxnarvw.i,. o.00rt x, o.aoft q woa.oa• Q£ F v.max Q£ F vwC s jft) R CI O MO.W VMicel9e tm(fl) WEST (ft) EAST WEST (fl) EAST H16A-L05 (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10, 2018 -12:06 Analysis Method: 3D Least Distance Client: BlueCrest Reference Trajectory. H16A-LO5(P2)(Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (it) Structure: Cosmopolitan Pad Rule Set: D&M AndCollision Standard S002 v5.115.2 Slot: H-16 Min Pts: All local minima indicated. Well: H16 Version I Patch: 2.10.544.0 Borehole: H16A-L05 Database l Project: localhos8dnlling-Cook Inlet Scan MD Range: 18780.00ft-21104.900 ISCWSA03-D 95.000% Confidence 2.7955 sigma, for subject well. For Traiectory Error Model: offset wells, error model version is specified With each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection filters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Non -Def Surveys when no Def -Survey is set in a borehole -All Non -Def Plans when no Det -Plan is set in a borehole Offset TrajectorySe ration Allow Sep. Controlling Reference Tra ecto Risk Level Alert Status Ct-Ct ft MAS tt EOU ft Dev. ftFact. Rule Mn 110 TVD ft Alan Minor Ma'or Me'or Major H16A.L04 (P2) (Def Plan) Fall Major 3585 0,001 335,85=== -224.23 -335.85 0.00 OSF1.50 187W 00 7066.11 OSF15.00 OSF�150 OSF<100 Enter Major 0.04 123.84 -82.85 -123.80 -0.01 OSFi.W 18]90.00 ]065.]9 MinPt-0-SF 76.16 116.78 -2.02 40.62 0.97 OSF1.50 19280.00 7066.20 OSF>100 Exit Major 112.02 113.28 36.17 -1.27 1.48 OSF1.50 19420.00 7066.80 OSF>1.W Exit Minor 339.15 110.86 264.91 228.296. OSFI.W 20450.00 6872.34 M1nR.O.SF 340.73 103.92 271.12 236.81 4.95 OSF1.50 20680.22 6859.74 OSF>5.00 Exit Alert 73757 70.23 690.43 667.34 15.96 OSF1.W 21104.90 65Nd63 TD H16PBI (Def Survey) Fall Major 7917 295.11 -117. -215.9 0. OSF1.W 18780.80 ]066.11 OSF<5.00 OSF<1.W OSF,1.00 Enter Major 81.11 354.93 -145.84 -263.83 0.38 OSF1.W 19420.00 7066.80 MInPt-C(Ct 91.27 391.12 .169.81 -299.861 0. 7.11 OSF1.50 19460.00 7066.97 MInft 180.69 246.44 -10.93 -92.75 0.93 OSF1.W 19582.69 7066.03 OSF>1.00 all Major 193.56 202.87 57.98 .9.31 1.43 OSF1.50 19630.00 7D63.79 OSF>1.50 Exi(Minor 399.43 123.89 316.80 27EW 4.86 OSF1.50 198W.W 7038.07 OSF>500 Exit Alen 1623.64 101.72 155549 152191 24.16 OSF1.50 21104.80 6594.63 TO H16 (Def Survey) Fail Major 92.98 22578 -528F___132_8111 0.61 OSF1.50 18780.00 7066.11 OSF<500 OSF,1.W 0SF-100 Enter Malo, _ 91.62 246.33 -72.92 -154.71 055 OSF1.50 18990.00 7064.95 MInPI-ctct 9224 280.09 44.81 -15T8=____ OSF1.W 19030.00 7065.13 MinPt-O-SF 9256 250.75E-_-]49 -180, 19 0.55 OSF1.50 19040.W 7065.17 MINPT-O-EOU 92.94 251.29 -74.92 158.3 0.55 OSF1.W lww.00 7065.21 MinPt-O-ADP 97d 280.61 .89.97 483.18 0.52 OSF1.W 19430.00 7066.84 MinPl-CtCt 98.28 287.91 -93.9) AS9.63 0.51 OSF1.W 19516.02 7067.19 MinPt-O-SF 98.93 289.24 -94.22 190.30 0.51 OSF1.50 19560.00 7067.04 MINPT-O-EOU 9931 289.68 .94 14 -190.37 0.51 OSF1.W 19580.00 7066.89 MinPt-O-ADP 16195 245.65 -2.14 -83.70 0.99 OSF1.50 201W.00 6970.75 OSF>1.W &it Major 213.75 213.82 70.87 -0.07 1.80 OSF1.50 20380.00 M99.87 OSF>1.50 Exit Minor 49821 16249 389.55 335.71 4.62 OSF1.50 21104.90 6594.63 TO Hanaen#IAL1(Def Survey) - Fall Major 482.23 422.03 200.55 6020 1.71 OSF1.50 1878000 ]066.11 OSF�5.00 Enter Alen 964.4 443.66 16836 20.80 1.57 OSF1.50 19210.00 7065.90 MInPt-CUOt 464.52 443.8 16832 20.]2 Igl OSF1.50 19230.00 7065.98 MinPts 46tIA8 669.18 180.06 -1.80 1.80 OSF1.50 20210.00 69M.75 OSF-1.50 Enter Minor 376.29 638.48 -3.02 -192.19 0.99 OSF1.W 20530.80 6838.61 OSF<I.W Enter Major 284.63 770.97 -229.68 486.34 0.63 OSF1.50 21050.00 6617.93 MinPt-cct 285.04 ]T3.]6 -231.1 -0 B,M 0. OSF1.50 21080.00 6605.20 MlnPls 265.35 ]]4.22 -231.13 488.8 0.55 OSFi.W 21090.00 66W.95 Mir PEO -ADP 285.98 ]]4.51 -230.70 48B.M 0.55 OSF1.50 21104.90 6594.63 TD H16A-L03(P2)(Def Plan) Waming Alen 162.65 103.37 93A11 59281 2.31 OSF1.50 18780.00 7066.11 OSF<5.00 Enter Alert 330.34 iM.23 263.19 230.11 4.98 OSF1.50 1919000 7065.81 OSFPEOO Exit Alert 1523.21 ]0.8] 147564 1452.34 32.67 OSF1.50 21104.90 6594.63 TD Hansen #1 (Def Survey) Warning Alen ]6248 683.401 306 541 19077 OSFt S0 18780.00 7066.11 OSF<5.00 Enter glen 1417.40 428A9 1131.42 988,92 4.97 OSF1.50 19750.00 7052.88 OSF>5.00 Exit Alen 2691.67 292.11 2496.60 2399.56 13.86 OSF1.50 21104.90 6594.63 TO H12-103 (Non -Def Survey) WamiN Alert 815.19 310.21 608.06 904.98 3.95 OSF1.50 18780.00 7066.11 OSF<5.00 Enter Alert 811.96 310.661 604.511 W1.2131 3.9 OSF1.50 18910.00 7064.61 MlnPis 949.44 285.8 758.63 663.71 5.W OSF1.W 20190.00 6973.39 OSFx5.00 Exit Alen 951.60 286.89 76001 664.70 4.99 OSF7.50 20170.00 6968.05 OSF<5.00 Enter Alen 959.14 319.W 1 OSF1.W 20250.00 6964.65 MlnPis 1001.84 302.23 800.02 699.61 4.98 OSF1.W 204W00 6855.90 OSF15.00 Exit Alen 1307.30 232.12 1152.23 1075.19 8.48 OSF1.50 2110490 6594.63 TD 1112-1-05 (Non -Def Survey) Waming Alan 821.55 309.53 614.87 512.02 3.99 OSF1.50 18780.00 ]066.11 OSF<5.M Emer Alert 818.3 310.81 610.84 W].M 3.96 OSF1.50 19040.00 ]065.1] Minm-CiCt 81842 310.9 610.]8 M7.46 3.96 OSF1.W 1901000 7065.30 MINPT-O-EOU 818.45 311.01 610.]9 90].4 3.96 OSF1.50 19080.00 1065.34 MinPt-0-ADP AM% 311.29 611.11 90].6 3.9 OSF1.W 19140.00 7065.60 MinR-0SF 820.34 311.80 612.14 M8. 3.9 OSF1.W 19230.00 1065.98 MInPt-O-SF 813.18 315.10 602.78 498.90 3.88 OSF1.W 19]20.00 MW.31 MlnPt-M 813.20 315.1]562.18 498.03 3.88 OSF1.W 19740.00 1054.08 MINK-O-EOU 813.22 315.20 902.]6 488.02 3.88 OSF1.50 19750.00 ]052.88 MsPt-0-ADP 813.36 315.28 W2.85 498.08 3.8; OSF1.W 19780.W ](908.98 MinPt-O-SF 841.81 317.2 629. 524.52 OSF1.50 21104.W 6594.63 MIOPts 1 -412 -LOB (Non -Def Survey) Waming Alert 821.55 309.52 614.87 512.03 3.99 OSF1.50 18780.90 7066.11 OSF<5.90 Enter Alen 018. 310.81 610.84 W1.57 3.96 OSF1.W 19040.90 7W5.17 mism1 ICt 818.42 310.98610.18 907.46 3.96 OSF1.W 19070.90 7065.30 MINPT-O-EOU 618.45 311.01 610.19 901.4 396 OSF1.W 19080.90 7905.34 MinPE0-ADP 818.% 311.29 811.11 90].6 39 OSF1.W 19140.90 ]905.60 MInPt-0-SF 820.34 311.90 612.15 590. 3.9 OSF1.W 19230.90 7065.98 MinPt-0-SF 813.1 315.10 602.18 498.08 3.88 OSF1.50 19720.90 7056.31 MInPt-CICt 813.20 315.1602.]6 498.03 3.88 OSF1.M 19140.90 70.54.08 MINPT-O-EOU 813.22 315.20 602.78 498.03 3.88 OSF1.W 19790.00 7052.88 MinR-0-ADP 813.36 315.28 602.65 4M.091 3,881 OSF1.50 19]80.0) 7048.9B MinPt-0-SF 940.54 285.55 149.85 654.99 4.95 OSF1.W 21104.% 6594.63 TD H12 (Non -Def Survey) Waming Alert 821.55 309.52 614.88 51203 3.99 OSF1.W 18180.M ]906.11 OSF<5.00 Enter Alen 818.38 310.90 610.85 501.57 3.96 OSF1.M 19040.90 1M5.17 Mint -=t 818.42 310.9 610. W7.46 3.96 OSF1.W 1%]0.90 7M5.30 MINPT-0-EOU 81845 311.90 610.]9 901. 3.96 OSF1.W 19080.90 ]905.34 MinPt-0-ADP 818.96 311.28 611.11 W].68 3.9 OSF1.W 19140.90 1065.60 MlnPt-0-SF 820.34 311.80 612.15 508.5 3.9 OSF1.M 19230.00 7065.98 MInPt-0SF 813.18 315.90 602.9 4%.OB 3.88 OSFI.50 1980.00 1056.31 MinPECiCt 813.20 315A61 602.761 498.04 3.88 OSF1.W 19740.90 ]054.08 MINPT-0-EOU B13.22 315.19 602.17 4%.0 3.88 OSF1.W 197W.W 7052.88 MsPt-0-ADP 813.36 315.27 602.85 4%.09 3.88 OSF1.W 19780.90 7048.98 MsPt-0-SF 941.34 283.99 751.68 657.35 4.98 OSF1.50 21070.90 61M9.44 0SF>5.00 Exit Alen 949.16 282.48 70.51 656.68 5.05 05171.90 21104.W 6594.63 TD H12 -L04 (Nor,0Dd Survey) Wonting AMrt U1.55 309.53 614.87 512.02 3.99 OSF1.W 18780.00 7066.11 OSF<5.00 Enter Alert 818.38 310.82 610.84 507.56 3.96 OSF1.W 19040.0 7065.17 WR-CtCt 818.42 310.9 61018 507.45 3.96 OSF1.W 19070.0 7065.30 MINPT-O-EOU 818.45 311.01 810.78 500. 3.96 OSF1.W 19080.0 7065.34 MmPtA-ADP 818.913 311.29 611.10 507.67 3.9 OSF1.19]1 19140.00 7065.60 MmPt-OSF 820.22 31115 612.06 508.4 3. OSF1.50 19220.00 7065.94 MinPt-O-SF 842.24 315.98 631.26 WE. 2 4.01 OSF1.W 19830.00 71741.44 MlnPt-OSF 9332 318.8620.3 514.40 3.93 OSF1.W 20640.00 6791.93 Min% 833.28 318.89 620. 5-14.39 3.93 OSF1.W 20650.0 6787.68 MInPt-O-ADP 833.32 318.91 620.39 514.42 3.9 OSF1.W 20660.00 6783.44 MinPt-OSF 836.91 357.501 598.251 4nAll 3.121 OSF1.50 20850.00 6702.81 MinPts 881.29 337.76 65519 543.54 3.92 OSF1.50 21104.90 6594.63 TO 1-112-L02(14on-(Dsf Survey) Warning Alert 69665 296,041 698.97 600.6114.5 OSF1.W 18780.00 7066.11 OSFPoSW Enter Alert 940.14 283.04 751.12 657.10 4.99 OSF1.50 19100.00 7065.43 OSi Exit Alert 1013.29 295.27 816.12 ]18.02 5.1 OSF1.W 19450.00 706.93 MMP1s 1978.22 152.99 1875.90 1825.23 19.51 OSF1.W 21104.90 6594.63 TO Hansen #1A (Def Survey) Warning Alert 1021.32 729.48 534.67 291.84 210 OSF1.W 18]80.0 ]066.11 OSF<5.00 Enter Alert 1534.]1 88.31 1048.64 806.40 3.16 OSF1.W 2W30.0 701.32 MmPt-O-SF 1670.40 746.60 1172.34 923.80 3.36 OSF1.W 2D350.00 6910.94 Mi m -O -SF 1986.46 741.06 1492.09 1245.39 4.02 OSF1.50 21104.0 6594.63 TO 1118A4.2(P2)(Oef Plan) Pass 4,91.28 97.Mi 425921 393.74 7.62 OSF1.W 18780.W 7066.11 MM%s 2377.11 71.86 2328.87 2305.24 50.28 OSF1.50 21104.90 6594.63 TO 1112-L01(Non-Def Survey) Pass 1099.18 259,161 926081 NO 021 38 OSF1.50 1878000 ]066.11 Minpts 2944.30 110.74 2970.14 2833.56 40.23 OSF1.50 2110490 6594.63 TO H16A-L01(P2)(Def Plan) Pass 1195.7] W.32 1161.89 114SA5 36.3 OSFi.W 18780.00 7066.11 MinPts 3368.07 73.31 3318.87 3294.76 69.83 OSF1.W 21104.90 6594.63 TO H14PB2(Def Survey) Pass 1366.10 402291 1097.Mi 963.81 5.10 OSF1,W 18780.00 7066.11 MinPls 2716.51 216.70 2571.72 2499.82 18.88 OSF1.50 21104.90 659463 TO Cosmopolitan Stare 1 (Def Survey) Pass 1370.51 250.68 1202.86 1119.84 824 OSFLW 21020.W 6630.66 mh.P 1372.60 2W.35 1205.36 112244 627 OSF1.50 21104.90 6594.63 TO H14POl (Def Survey) Pau 145116 304.0 1248.71 114)67 7.18 0SF1.W 1975000 7052.88 WnPt-Ct t 1451.79 304.19124B68 114]61 7.18 OSF1.W 19]70.0 7050.33 MINPT-O-EOU 1451.87 304.28 1248.69 114760 7.18 OSF1.50 19790.00 7047.% MlrlR-0-ADP 1452.30 304.% 124865 1147.32 7.16 OSF1.W 19920.00 7024.63 MINPT-O-EOU 1452.42 305.13 1248.68 1147.30 7.16 OSF1.50 199W.0 701827 MinPt-O-ADP 1453.W 305.66 1249.50 1147.94 7.15 OSF1.W 2070.00 6992.75 MinPo-O-SF 1551,27 296.87 1353.02 1254.39 7.86 OSF1.W 21104.0 6594.63 TO H14PB3(Def Survey) Pass, 1582.06 297.60 1383.33 1284.46 8.00 OSF1.W 18780.W 7036.11 MxPt-CtCt 1548. 303.13 1348.11 1245.40 7.68 OSF1.W 194W.W ]067.06 MMPI-CtCt 15467 306.55 1342.08 1240.22 7.59 0SF1.50 19920.0 7024.63 MlnPPCtCt 1546.81 30.66 1342.04 1240.15 7.59 OSF1.50 19940.00 7020.39 MINPT-O-EOU 1546.65 30.71 1342.05 1240.13 7.58 OSF1.50 199W.00 7018.27 MIOPI -O -ADP 1518.92 307.84 1343.W 1241.28 7.5 OSF1.W 20110.00 6983.48 MinPt-0SF 1%1.83 30.09 1355.44 1252.] 7. OSF1.W 20440.00 8876.42 MinPt-O-SF 1617.W 30.02 141434 1314.06 8.03 OSF1.0 21104.0 6594.83 TO H14 (Def Survey) Pass 298.9 1468.0 1368.]6 8.39 OSF1.50 18]8000 7066.11 MinPis 16]0.]3 300.32 14]0.18 13]0.41 8.3 OSF1.50 19020.00 7065.08 MinPt-O-BF 1661.72 309.71 1454.92 1352.01 8.07 0SF1.50 20260.00 6941.50 MinPt-OtOt 1861.]3 309.74M451.91 1351.99 8.07 0SF1.50 202]0.00 6938.31 Mh% 1661.98 309.83 1455.10 1352.15 8.07 0SF1.50 20310.00 6925.02 MinPt-0-SF 1720.88 304.74 1517.39 1416.14 a." OSF1.50 21104.90 6594.63 TD StafiOkof State 1 (Def Survey) Pass 305978 105.851 2988.891 2953.93 43]5 OSF1.50 18780.00 7066.11 MlnPts 5206.06 86.29 5148.21 5119.]] 91.52 OSF1.50 21104.90 6594.63 TD H16A-1-05 (P2) Anti -Collision Summary Report Analysis Dale-24hr Time: July 10, 2018-12:09 Analysis Method: Normal Plane Client: BlueCrest Reference Trajectory: H16A-LOS(P2)(Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (R) Structure: Cosmopolitan Pad Rule Set: D&M AntiCollision Standard 5002 v5.1/5.2 Slot: H-16 Min Pts: All local minima indicated. Well: H16 Version/Patch: 2.10.544.0 Borehole: H16A-L05 Database \Project: IOcalhoslWnlling-Cook Inlet Scan MO Range: 18780.000 - 21104.90R ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject well For Trajectory Error Model: offset wells, error model version is spaded with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection fitters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans -All Non -Def Surveys when no DefSurvey is set in a borehole - All Non -Def Plans when no Def -Plan is set in a borehole Offset Trajectory Se aralion Allow Sep. Controlling Reeren Risk Level Alert Status CttR MD DTDR Alert Minor Ma'or Ma or Ma'ore De. Fat Rule H16A-L04 (P2) (Def Plan) -F aMajor 0.00 335.85 -224.23 -33585 0.00 OSF1.50 18]80.00 ]066.11 OSF<500 OSF�1.50 OSFG 00 Enter Major 0.00 124.15 -83.09 -024.15 -0.01 OSF1.50 1878242 7066.03 MinPts 0.17 124.41L_-83.1 -124.3 -0.01 0SF1.50 18800.00 7065.51 Mine 86.06 129.32 -0.48 43.26 0.99 OSF1.50 19311.68 7066.33 OSF>1.00 Exit Major 129.03 130.37 41.78 -1.35 1.48 0SF1.50 19455.35 7068.95 OSF-1.W alt Minor 339.10 112.32 263.89 226.78 4.56 0SF1.50 20443.53 6874.98 TD H16PB1 (De Sumey) Fall Major 7927 294.3 -117.31 -215.10 0.401 0SF1.50 18780.00 7066.11 OSF1500 OSF11.50 OSFO.00 Enter Major 9111 352.02 -143.90 -260.91 0.39 0SF1.50 19416.76 ]066.]9 MinPt-CtCt 91.26 391.04 -169.76 -299.78 0.35 OSF1.50 19458.75 706697 Min% H16 (Def Survay) _'-_----- Fall Major 93.02 224.82 -5].19 -1310 0.62 OSF1.50 18780.00 7066.11 OSW5.00 OSFPo1.50 0SF<100 Enter Major 91.62 245.95 -72.67 -154.33 055 0SF1.50 18986.62 7064.94 Mlr Pt-CtCt 91.94 248.62 -7413 -156.6 0.5 OSF1.50 19016.77 7065.07 MinPt-0-SF 92.50 249. 44.35 -15733 0.55 OSF1.50 19036.75 7065.15 MINPT-O-EOU 92.88 250.27 -74.29 -15]. 0.55 OSF1.50 19046.74 7065.20 MinPE0-ADP 97. 281.22 -90.38 -183.80 0.52 0SF1.50 19436.00 7066.87 MinPI-CtCt 98.29 287.55 -93.74 189.26 0.51 OSF1.W 19515.62 7067.19 MinPE0-SF 98.53 288.06[::: 93.84 189.53 0.51 OSF1.50 19525.40 7067.17 MINPT-O-EOU NAB 288.88 -93.731 -189.70 0.51 OSF1.5D 19544.97 7066.97 MinPt-O-ADP 159.75 241.62 -1.66 -81.87 0.99 OSF1.W 20134.10 6977.50 OSP1.00 Exit Major 205.23 205.40 67.97 -0.17 1.50 OSF1.50 20322.42 6920.73 OSF-1.50 Exit Minor 461.52 139.76 368.02 321.76 498 OSF1.50 20916.08 6674.76 OSF>5.00 Fait Alen 598.06 131.83 459.85 416.23 6.27 0SF1.50 2110490 6594.63 TD Hansen N1AL1 Def Survey) Fail Major 48359 420.46 202.95 63.12 1.73 0SF1.50 18780.00 ]066.11 OSF�500 Enter Alert 464.4 443.65 168.37 2081. 1.57 OSF1.50 19208.64 7065.89 M1OPI-CICt 464.48 443.69 168.36 20.7 1.5 OSF1.W 19218.64 7065.93 MinPts 468.21 489.17 155.10 -0.96 1.50 OSF1.50 20259.96 6941.52 OSF-1.50 Enter Minor 377.71 569.58 -2.34 -191.87 0.99 OSFL50 20586.24 6814.74 OSF<1.00 Enter Major 284.64 770.57 -229.40 -485.93 0.55 OSF1.W 21046.60 6619.37 Minpt-Ctct 284.76 7]2.30 -230.44 487.55 0.55 OSF1.50 21064.47 6611.79 MinPt-0-SF 284.94 7M.671 2W.50 487.73 0.55 0SF1.50 21072.58 6608.35 MinPts 286.44 772.34 -228.80 485.91 0.56 0SF1.50 21104.90 6594.63 TD H16Ai03 (P2) (Def Plan) Waming Alen' -'-- 1]4.02 124.24 W.841 49.75 2.11 OSF1.W 18783.22 7066.01 OSFn5.00 Enter Alert 426.98 129.41 340.38 29].5] 4.98 OSF1.W 19319.92 ]066.3] OSF15.00 all Alert 506.18 130.67 420.74 3T).51 5.87 OSF1.50 19491.45 ]06].11 TD H12-1-03 (Nun-Def Survey) Warning Alen 816.56 309.98 609.58 506.58 3.96 OSF1.50 18780.00 706611 OSFPo5.00 Enter Alert 811.94 310.87 604.50 501.27 3.93 OSF1.W 18910.18 7064.61 Min% 811.98 310.71 604.51 501.27 3.93 OSF1.50 18919.70 7064.65 MInR-0-ADP 812.07 310.74 604.56 501.33 3.931 0SF1.50 18929.17 7064.69 MmR-0-SF 954.11 323.1 ]38.36 630.98 44 OSF1.W 2013672 6976.83 WPM H12-L05(Non-Def Survey) -- - - --_- - --- - Warning Alert 821.57 30943 61495 512.14 3.99 OSF1.50 18786.11 7065.91 OSF15.00 Enter Alert 818.38 310.85 61082 507,53 3.96 OSF1,50 19046.25 7065.20 MinPt-CtCt 818.45 311.0610.] 50].41 3.95 OSF1.W 19076.25 ]065.32 MINPT-0-EOU 818.87 311.09 610.]] 50]40 3.95 OSF1.W 19086.25 ]065.3] MInPt-0-ADP 820.39 311.97 61208 508.42 3.91 0SF1.W 19226.24 ]065.9] MinPt-0-SF 813.18 315.08 602.80 498.10 3.88 OSF1.50 19715.00 ]056.84 MinPt-CiCt 813.21 315.21602.]5 498.00 3.88 OSF1.50 19]44.5] ]053.53 MINPT-0-EOU 813.24 315.24 60275 496 W1 3.88 OSF1.W 19754.41 7052.34 MinPt-0-ADP 81348 315.38 602.90 498.101 3.881 OSF1.W 19793.60 ]04].06 MlnPt-0-SF 842.8 317.11___631 10J525.71 3,A1O5F1.W 21104.90 6594.63 Min% 1412-LOB (Non-Def Survey) Warning Alert 821.57 309.43 614.95 512.14 3.99 OSF1.W 18786.11 ]065.91 OSF<500 Enter Alert 818. 310.85 610.82 507.53 3.96 OSF1.W 19046.25 706520 MinPt-0tCt 818.45 311.03LL_§I0.AL 507.41 3.95 OSF1.50 19076.25 7065.32 MINPT-O-EOU 818.50 311.03 610.]] 507.4 3.95 OSF1.50 19086.25 ]065.3] MinP1-0-ADP 820.39 311.97 612.08 50842 3.9 OSF1.50 19126.24 ]085.9] MinPt-0-SF 813.18 315.08 602.80 498.10 3.88 OSF1.50 19715.0 7056.84 MinPt-CtCt 813.21 315.20 802]5 498.01 3.88 OSF1.50 19]44.5] 7053.53 MINPT-O-EOU 813.24 315.24 1302.75 498.001 3.88 OSF1.50 19754.41 7052.34 Min%-0ADP 813.48 315.38 602.90 498.111 3.84 0SF1.50 19]93.60 ]04].06 MinPt-0SF 964.19 284.45 754.83 660.34 4.99 OSF1.51) 21071.28 6608.90 OSF>5.60 Ext Alert 948]6 283.67 759.32 665.09 5.03 0SF1.50 21104.90 6594.63 TO H12 (Non-Def Survey) Warning Alert 82157 309.42 614.96 512.14 3.99 OSF1.50 18786.11 7065.91 0SF<5.00 Enter Alert 818. 310.84 610.82 50254 3.% OSF1.W 1904625 7065.20 Min%-CiCt 818.45 311.0 810.] 507.42 3.95 OSF1.W 19076.25 1065.32 MINPT-0-E0U 818.50 311.09 610.]8 50].41 3.95 OSF1.W 19086.25 ]065.3] WnPt-0-ADP 820.39 311.96 612.08 W842 394 OSFi.50 19226.24 ]065.9] MIePt-0-SF 813.18 315.07 W2.W 498.11 3.88 OSF1.W 19715.00 7087.84 MinPt-01Ct 813.21 315.20 602.7 498.01 3.88 0SF1.W 19]44.5] 1053.53 MINPT-O-EOU 813.24 315.24 602.76 498.011 3.88 OSF1.50 19751.41 ]052.34 MirR-0-ADP 813.46 315.37 602.91 4N.111 3.88 OSF1.W 19793.60 ]04].06 MinPt-O-SF 942.14 283.51 752.81 6W.63 5.00 OSF1.W 20964.47 6654.23 OSF-5.00 all Alen 9]].43 275.30 ]93.5] 702.13 534 OSFLW 21104.90 6594.63 TD 1112- Nt (NorvDef Survey) Warning Alert 821.57 309.43 61495 51213 3.99 OSF1.W 18786.11 7065.91 0SF<500 Enter Alen 818.38 310.85 610.81 507.53 3.96 OSF1.50 1904625 7065.20 MInPI-CICt 818.45 311.61056 50].41 3.95 OSF1-50 190]6.25 7065.32 MINPT-0-ECU 818.50 311.10 610.] 50].4 3.95 OSF1.W 19086.25 ]065.3] MinPt-O-ADP 82102 312.25 612.53 50818 3.9 OSF1.W 19256.1] 7066.10 MhPt-0SF 833.26 318.88 620.34 514.38 3.93 OSF1.50 20639.91 6]91.91 Mirpi-CtCt 833.28 318.9 62032 514.33 3.93 OSF1.50 20649.91 6]8].]2 MINPT-O-EOU 833.34 319.03 620.32 514.31 3.93 OSF1.W 20659.91 6783.48 MinPt-O-ADP 834.35 319.55 620.99 514.87 3. OSF1.W 20]29.90 6753.18 MinPt-0SF 836.62 357.94 59].6] 4]8.68 3.51 OSF1.50 2082].8] 6712.20 MinPte 1412-1-02 (Nan-Def Survey) Warning Alen 901.55 295801 704.02 605.75 4.58 OSF1.50 1878116 ]066.0] OSFn5.00 Enter Alert W.24 285.02 754.0 660.23 4.99 OSF1.W 19039.11 T065.16 OSF>5.W Exit Alert 98.14 295.53 78079 682.61 4.98 OSF1.W 19183.64 7065.78 OSF<S.00 Enter Alert 985.11 307. 7]9]6 677.5 4.82 OSF1.50 19212.71 7065.91 MNPI.s Hansen #1A (Def Survey) Warning Alert 1100.86 761.98 592.55 33889 2.17 OSF1.50 18]8326 7066.01 OSF<5.00 Enter Alert 1921.27 782.01 1399.60 113926 3.69 OSF1.50 20486.14 6857.22 TO Cosmopolitan State i (Def Survey) Pass 1370.52 250.69 1202.85 1119,83 8.24 OSF1.5O 2102005 6630.64 MinPts 137069 208.16 1202.98 1119.93 8.24 OSF1.50 21028.27 6627.15 MInPt-0-SF 138542 249.52 1218.54 1135.90 8.37 OSF1.50 21104.90 6594.63 TO H14PBi(Def Survey) Pass 1451.]6 304.08 124871 1147.68 7.18 OSF1.W 194709 7053.23 MinPt-CtCt 1451.82 304.2 1248.6 1147.59 7.18 OSF1.50 19m.54 7049.59 MINPT-O-EOU 1451.86 304.28 1248.68 1147. 7.18 OSF1.W 19785.01 7048.28 MirR-O-ADP 1452.2 304.83 1248.70 1147.42 7.16 OSF1.W 1988B.W 7030.93 MirRt CI 1452.30 304.99 1248.84 1147.31 7.16 OSF1.W 19917.01 7025.25 MINPT-O-EOU 1452.42 305.14 1248.67 114].28 7.16 OSF1.50 19946.34 7019.05 MinPt-O-ADP 1453.82 305.77 1249.64 1148.051 7.15 OSF1.50 20869.17 6992.94 MlnPI-O-SF 1566.14 294.04 1369]9 1272.11 8.01 OSF1.W 21104.90 6594.63 TO H14PB3 (Def Surrey) Pass 1582.18 29].88 13832 128430 7.99 OSF1.W 18780.00 7066.11 MinPis 1548.5 303.13 1346.11 1245.40 7.68 OSF1.W 19480.00 7067.06 MiaR.CtCt 154677 3W.W 1342.11 1240.27 7.59 OSF1.W 19912.26 7026.24 MiaPt-C1Ct 1546.83 306.72 1342.02 1240.11 7.58 OSF1.0 19941.88 ]02000 MINPTO-EOU 1546.89 306.]9 1342.03 1240.10 7.58 OSF1.W 19951.68 7017.92 MinRt ADP 1549.92 308.03 1344.24 1241.89 7.5 OSF1.50 20127.93 699.06 MhPP- F 1636.21 29998 1435.89 1336.23 B.20 OSFi.W 211I14.90 6594.63 TO H14 (Def Survey) Paas F166].] 288.0 1468.09 1368.7 8.39 OSF1.50 18780.00 7066.11 MInPts 1661.]3 309.]0 1454.93 1352.03 8.07 OSF1.W 20256.32 6942.67 M"Pt-CtCt 1661.73 309.73 1454.91 1351.99 8.07 OSF1.W 20265.48 6939.76 MINPT-O-EOU 1661.76 309.]] 1454.91 1351.99 8.07 0SF1.W 20274.57 6936.83 MinPI-0-ADP 1662.12 309.90 1455.19 1352.22 8.07 OSF1.W 20310.67 6924.79 WR -O -SF 1738.78 302.59 1536.72 1436.19 864 OSF1.W 21104.W 6594.63 TO H12-L01(Non-Def Survey) Pass Stanchl of Slate 1 (Def Survey) Pass H14PB2(Daf Survey) Pass H16A-LO2 (P2) (Def Plan) Pass Hansen#1(Def Surrey) Pass H16A1-01(P2)(Def Plan) Pass O �^ x u $ a s' u i +o N �4EVA g _ •� T r �1 L w IN gE�B• gm bq i c 0 N Q cu x N d O Cl CO �4EVA VMS R IN gm bq i c 0 N Q cu x N d O Cl CO lue est Energy Attach r' Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16 -A10-401 L05 APD Attachments NOTE: The Rib Laterals in H16A are left as open hole completions after drilling, and as such, there are no casing design nor cement volume calculations to present in this section of the respective L01 through L07 Lateral APD -s. tilueest Energy Attachmer Cosmopolitan Project H16 -A 10-401 L05 APD Attachments H16 -A10-401 L05 APD Attachments NOTE: The Rib Laterals in H16A are left as open hole completions after drilling, and as such, there are no FIT and/or LOT Procedures to present in this section of the respective L01 through L07 Lateral APD's. The only FIT to be conducted in H16A is at the 9-5/8" casing window, and that Procedure is included in the H16A Mainbore APD Package. glue( feat Energy Attachmen Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16 -A10-401 L05 APD Attachments �Sr Energy Cosmopolitan Project BOP & Choke Manifold Configuration 5K# WI H 10K# 49 3/32- 070 FLANGE `le N C) 66 5/8" o ® �in a o_ D U") 27 3/4" 0 4111/16" ° 13 5/8"X 10K# CAMERON BOP STACK BLUECREST ENERGY 13 5/8-MOK CAIMN BOP STACK -2 J2 16 11 u —@ W 1 6 6 U67FD 6 Nu - wc� isvcn BSBC7002 2 10-401 APD Attachments BOP & Choke Manifold Configuration nue st Energy Cosmopolitan Project BOP & Choke Manifold Configuration 10-401 APD Attachments BOP & Choke Manifold Configuration W � � In Mill J 3 Y� mw O OCCSS d0 pC � t o c g \ I � w m z Y O I Z M � Z 7 � W N U a/1 a r O W -nn 10-401 APD Attachments BOP & Choke Manifold Configuration Zue)est Energy Diverter PORT I 8 N �. 1 � r G H K L t --- --. / E O AS 1 W II 10. 0. J cc� LL 51% P Q AS CAST til Hub 16Huh ' CLOSING PORT G FLANGED Cosmopolitan Project BOP & Choke Manifold Configuration -- M AS CAST -- I 8 N �. D — —O I G H J K L M --- --. / E O AS 5214 CAST II 10. 0. 7h 10,9 27% 45% 51% P m AS CAST til K — L AS CAST F CLAMP HUB Nominal Dimensions—Inches—with 2000 psi Bottom Connections A I 8 C D E F G H J K L M N O P 5214 Hub 1Bj .. 12y: 23% ""61 7h 10,9 27% 45% 51% 50% 5522% 60 til Hub 16Huh 111 soy: SM Nominal Dimension"nches—with 3000 psi Bottom Connections A �yppB C D E F G H H50t47 H5 S J K L M N O P 5414 .. 121A 23111 9114 ou 27% 45% 5141 W% 52% 50 1% 10-401 APD Attachments BOP & Choke Manifold Configuration nue est Energy Attachm Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16 -A10-401 L05 APD Attachments IueC,iest Energy Cosmopolitan Project Wellhead/Tree I—zall- L Ul9 S= FS .l. I I I I Wb6 I I I SCS . um sono os, •- Ll ni w L .ZSMFWI L�M 63r 13.519' SAO9 DL t Vl!' SPIXI f51 Mw }uil' S.M all MSV bf I L_ 65.9!' I Y9'LY. MG9 i1.. I 11�Ltl'SPb Ki i I I �-13�S1D"IWIlD J MLNpL[L My$L9 IAA' I i i I I i I — ® L-mT K I m le.t]9[LL9ELi Sl 13-V -11 '. sn•oo cw---' ---i �-.�1. •uraolecr-�'� I _ nlMUL•lw 10-401 APD Attachments Wellhead/Tree lueC fest Energy Attachment 7 Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16 -A10-401 L05 APD Attachments NOTE: The Rib laterals in H16A are to be drilled from a window cut in the 9-5/8" casing using the BlueCrest Rig 1 BOP stack and choke manifold for well control (no Diverter system applicable), and as such, there are no Diverter Schematics to present in this section of the respective L01 through L07 Lateral APD's. toueC,fest Energy Attachment 8: Cosmopolitan Project H16 -A10-401 L05 APD Attachments H16 -A- 10-401 LOS APD Attachments H16A & H16A-L05 With 1000' Radius Around Production Section 500'From Lease Boundary JADL384403 T,.1 w H12 H16A-L05 Surface Location (NAD 27) Northing: 2,145,914.43', Easting 166,970.57' 2,408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM Surface Casing Point Northing: 2145773.805' Easting: 167211.107' 3,414' FSL, 3,429' FEL, Sec. 2, T4S, R15W SM Kick Off Point Northing: 2,153,566.54', Easting: 154,589.64' 157' FSL, 168' FEL, Sec. 29, T3S, R15W SM Total Depth Northing: 2,154,244.00', Easting: 153,347.00' 977' FSL, 1,433' FEL, Sec. 29, T3S, R15W SM SFC 3, Cosmopolitan Unit Development Date 11/07/2018 Company 1 BlueCrest Energy , 0 1000 2000 3000 4000 5000%1S 1:30000 111 T•' PETREL New Well Rig Elevation Form FIELD WELL RIG Cellar Box Elevation (CBE) (from 'As Built' Survey Plat dated 12-30-1980) Actual Rig Height (RT -GL) (from rig measure) Actual Rig Elevation (Actual RTE) (CBE+RT-GL=Actual RTE) Rotary Table - Base Flange Height (RT -BF) (from rig measur) Base Flange - Mean Sea Level (BF -MSL) (actual RTE - RT -BF = BF -MSL) DATE Cosmopolitan Unit H16 BlueCrest#1 145.81 ft 34.62 ft 180.43 ft 40.56 ft 139.87 ft November 23, 2016 DIRECTIONAL DRILLER (please print) Marty Rinke TRANSMITTAL LETTER /CHECKLIST WELL NAME: H 16 A — h D5 PTD: :�Z13— I o 0 V Development —Service —Exploratory _ Stratigraphic Test —Non -Conventional FIELD: H Q h SP h POOL: (-i a Ns -e , ul,d B r' huC 0t l 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.a.{$-095 API No. 50a�1 - nncil -__ A (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 hi accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50-_- _-� from records, data and logs acquired for well name on ermit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program, Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: J 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 Name: HANSEN H -16A -L05 Program DEV _ — _ Well bore seg ❑d PTD#:2181000 Administration 1( Nonconven. gas conforms to AS31.05.0300.1.A),(j,2.A-D) _ .. _ NA OH sidetrack of. exiting wellbore. _ _ ........... . 1 Permit. fee attached. - - - - - - - - - - - - - - NA NA 2 Lease number appropriate. _ _ _ _ _ _ _ _ _ _ Yes CMT vol adequate to circulate on conductor & surf csg _ 3 Unique well name and number... _ _ Yes 21 4 Well located in a. definedpool _ _ _ _ _ Yes 5 Well located proper distance from drilling unit. boundary..... _ _ Yes Spacing exception required. Hearing vacated; spacing exception order in progress. SFD 9/12/2018... 6 Well Jocated Proper distance from, other wells _ _ _ _ _ _ _ _ _ _ _ _ _ No.. NA 7 Sufficient acreage available in.drilling unit... _ .. Yes Adequate tankage or reserve pit _ _ _ _ 8 If deviated, is wellbore plat_included _ _ _ _ _ Yes _ _ _ _ . . ... . ........ 25 9 Operator only affected party.. _ _ _ Yes 10 Operator hasappropriate bond in force _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order _ _ _ _ _ _ _ _ No.. SFD 9/12/2018 12 Permit can be issued without administrative approval . ....... ...... Yes ........... Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ 13 Can permit be approved before 15 -day wait _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ .... _ ...... _ _ _ _ _ _ _ _ _ _ ............. .. 29 14 Well located within area and strata authorized by Injection Order # (put. 10# in. comments). (For. NA ............................ _ _ _ ........ 15 All wells _within 1/4_mile area of reyiew identified (For service well only). _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____________ 16 Pre -produced injector; duration of pre production less than 3 months (For service well only) _ NA_ .. As planned, this well does NOT conform with statewide spacing requirements__ Geologic Engineering Public OH sidetrack ... lateral will be left as barefoot completion. GIs Commissioner: Date: Commissioner: Date Commissioner Date ksxc QV- D75 9/a/d LA�sc 9 �p�/3�r 18 Conductor string_ provided _ _ _ .. NA OH sidetrack of. exiting wellbore. _ _ ........... . Engineering 19 Surface casing. protects all. known USDWs _ ........... NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ..... .... . 20 CMT vol adequate to circulate on conductor & surf csg _ _ _ .. _ _ NA. ..................... . . . . . . . . . . .. . . ......... . . . . . . . 21 CMT. vol adequate to tie-in long string to surf csg_ _ _ _ _ . NA. _ _ . . . . . . . . . . . . . . . ..................... . . . . . . . . 22 CMT_will coverall known productive horizons_ .... _ _ _ _ _ _ NA... 23 Casing designs adequate for C, T, B &_ permafrost. _ _ _ .. _ ........ NA _ _ ....... .. . .. . . . . . . . . . . . . . ....... 24 Adequate tankage or reserve pit _ _ _ _ ... Yes 25 Ifa_re-drill, has_a 10x403 for abandonment been approved _ .... ... NA H-16 to. be_P & A d.... 26 Adequate wellbore separation proposed _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ______ 27 If diverter required, does it meet regulations_ _ _ .. NA _ _ _ _ _ _ _ _ ___ _ __ _ ___ _ Appr Date 28 Drilling fluid. program schematic & equip list adequate_ _ _ _ _ _ _ _ _ . Yes _ _ ............ . ....... _ _ _ _ ........ . GLS 8/29/2018 29 BOPEs, do they meet regulation . . . . . . ....... . . . . . .............. Yes 30 BOPE press rating appropriate; test to (put psig in comments). _ .... _ _ _ _ Yes _ _ ........ _ _ . . .. . . ............ 31 Choke. manifold complies w/API RP -53 (May 84) .... . . ...... . . . . . . . Yes 32 .Work will occur without operation shutdown. _ _ _ .... _ _ _ _ _ _ _ Yes 33 Is presence of 1-12S gas probable _ _ _ _ _ ______ _ _ _ _ _ _ _ _ _ _ _ No 34 Mechanical condition of wells within AOR verified (For service well only) .. _ NA 35 Permit can be issued w/ok hydrogen sulfide measures . . . . . . . . ............ Yes H2S not observed in nearby Hansen wells.. Rig has sensors and alarms. Geology 36 Data.presented on potential overpressurezones _ _ _ .... _ .. _ Yes "J-shaped" well branch targets. Sterichkof sand and Hemlock, Planned mud weights in conjunctign.with. Appr Date 37 Seismic analysis of shallow gas zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ Managed Pressure. Drilling technique appear adequate to control maximum anticipated downhole...... DLB 8/14/2018 38 Seabed condition survey.(if off -shore) .. . . . . . . ..................... NA ... _ ... pressure of 9.65 PK. whichis based on MDT measurements of reservoir pressure in nearby well. 39 Contact name/phone for weekly.progress reports_ [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ Geologic Engineering Public OH sidetrack ... lateral will be left as barefoot completion. GIs Commissioner: Date: Commissioner: Date Commissioner Date ksxc QV- D75 9/a/d LA�sc 9 �p�/3�r
