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218-098
DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permitto Drill 2180980 Well Name/No. HANSEN H -16A-1_03 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-62-00 MD 19268 TVD 6698 Completion Date 12/14/2018 REQUIRED INFORMATION C`,� Mud Log -N�' �0 Completion Status 1 -OIL Samples Dio Current Status 1 -OIL UIC No Directional Survey Yes V DATA r - INFORMATION List of Logs Obtained: GR/RES/DEN/NEU, Mudlogs (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30248 Digital Data 17093 19232 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- L03_EcoScopeImages _RM_LAS.Ias ED C 30248 Digital Data 17064 19268 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- L03_EcoScope_RM_LAS.Ias ED C 30248 Digital Data 1/15/2019 Electronic File: 81ueCrest_H16A-L03_EcoScope Images_RM_DLIS.dlis ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A-L03_EcoScope Images_RM_DLIS.html ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A- L03_EcoScope_RM_DLIS.dlis ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A- L03_EcoScope_RM_DL IS.htm I ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A- L03_ EcoScope_2in_RM_I nvertTVD. pdf ED C 30248 Digital Data 1/15/2019 Electronic File: 13lueCrest_H16A- L03_EcoScope_2in_RM_MD.PDF ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest H16A- L03_ EcoScope_5in_RM_InvertTVD. pdf ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest H16A- L03_EcoScope_5in_RM_MD.pdf ED C 30246 Digital Data 1/15/2019 Electronic File: BlueCrest H16A- L03_EcoScope_Image_5in_R M_MD. PDF ED C 30248 Digital Data 1/15/2019 Electronic File: 13lueCrest_H16A-L03_DD Surveys final.pdf ED C 30248 Digital Data 1/15/2019 Electronic File: 13lueCrest_H16A-L03_DD Surveys final.xlsx AOGCC Page I of 4 Friday, April 5, 2019 Permit to Drill MD 19268 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 2180980 Well Name/No. HANSEN H-16A-1-03 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-62.00 TVD 6698 Completion Date 12/14/2018 Completion Status 1-OIL Current Status 1-0I1. UIC No ED C 30248 Digital Data 1/15/2019 Electronic File: BlueCrest_H16A-1.03_Final Surveys.csv Log C 30248 Log Header Scans 0 0 2180980 HANSEN H-16A-1-03 LOG HEADERS ED C 30248 Digital Data 0 0 Electronic File: H16A-L03 ASP Final Survey.pdf ED C 30248 Digital Data 0 0 Electronic File: H16A-L03 ASP Final Survey.xlsx ED C 30546 Digital Data 14450 19350 4/3/2019 n Electronic Data Set, Filename: H16A-L03.1as y- w (,o L, ED C 30546 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report U 10-29-18.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-30-18.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-31-18.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03.dbf ED C 30546 Digital Data 4/3/2019 Electronic File: hl6a-103.hdr ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03.mdx ED C 30546 Digital Data 4/3/2019 Electronic File: h16a-L03r.dbf ED C 30546 Digital Data 4/3/2019 Electronic File: hl6a-L03r.mdx ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03SCL.DBF ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03_SCL.MDX ED C 30546 Digital Data - 4/3/2019 Electronic File: BLUE CREST ENERGY H-16A FINAL REPORT.pdf _ ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - Drilling Dynamics Log MD.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - Formation Log MD.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-1-03 - Gas Ratio Log MD.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - LWD Combo Log MD.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - Drilling Dynamics Log MD.tif ED C. 30546 Digital Data 4/3/2019 Electronic File: 1-116A-1-03 - Formation Log MD.tif ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - Gas Ratio Log MD.tif AOGCC Page 2 of 4 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill MD 19268 2180980 Well Name/No. HANSEN H -16A-1-03 TVD 6698 Completion Date 12/14/2018 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-62-00 Completion Status 1 -OIL Current Status 1-0I1- UIC No ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 - LWD Combo Log Name Start Stop Sent Received Number Comments MD.tif ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-1-03 Show Report 23 Completion Report O Directional / Inclination Data 18000-18310 page 1.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 Show Report 23 Geologic Markers/Tops (y) Daily Operations Summary 0 Cuttings Samples 5/ NA Laboratory Analyses YQfN;) 18000-18310 page 2.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 Show Report 24 18400-18550 page 1.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 Show Report 24 18400-18550 page 2.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 Show Report 25 18587-18830 page 1.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-L03 Show Report 25 18587-18830 page 2.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-1-03 Show Report 26 19183-19268 page 1.pdf ED C 30546 Digital Data 4/3/2019 Electronic File: H16A-1-03 Show Report 26 19183-19268 page 2.pdf Log C 30546 Log Header Scans 0 0 2180980 HANSEN H -16A -L03 LOG HEADERS Well Cores/Samples Information COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 AOGCC Page 3 of 4 Friday, April 5, 2019 Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 17940 19268 11/26/2018 1683 INFORMATION RECEIVED Completion Report O Directional / Inclination Data Mud Logs, Image Files, Digital Dat Y / NA Core Chips Y (i A Production Test Information Y / Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Core Photographs Y /® Geologic Markers/Tops (y) Daily Operations Summary 0 Cuttings Samples 5/ NA Laboratory Analyses YQfN;) COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 AOGCC Page 3 of 4 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180980 Well Name/No. HANSEN H -16A -L03 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-62.00 MD 19268 TVD 6698 Completion Date 12/14/2018 Completion Status 1-0I1 Current Status 1-0I1- UIC No Description Date Comments Comments: Compliance Reviewed By: Date: AOGCC Page 4 of Friday, April 5, 2019 ZuNest Energy BlueCrest Alaska Operating LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Tel: (907) 754-9550 Fax: (907) 677-0204 Transmittal 21 809a 35546 Today's Date: -------- 4/3/2019 ....------ - --- Transmittal #: --. 2019-05 To: Ms. Meredith Guhl --- - --- ----- From: --------_-------- -------- Andrew Buchanan Company: AOGCC_— Company: I BlueCrest Alaska Operating LLC Re: i Mud Logging Data - H16A Well: H 16 -�3 Included Information: 8 CD's with Mud Logging Data for Well H 16A. Regards /v C Andrew Buchanan RECEIVED BlueCrest Energy APR 0 3 2019 AOGCC 218093 30248 Schlumberger -Private RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 0 9 2019 WELL COMPLETION OR RECOMPLETION REPORT AN Ia. Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class: Development Q 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: 218-098 ' 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 7. Date Spudded: 10/30/2018 15. API Number: 50-231.20051-62.00 ' 4a. Location of Well (Governmental Section): H16A- L03 Surface: 2408' FSL, 1509' FEL, Sec 2, T4S, R1 5W, SM Top of Productive Interval: 4616' FSL, 4186' FEL, Sec 33, T3S, R1 5W, SM Total Depth: 5271' FSL, 5195' FEL, Sec 33, T3S, R15W, SM 8. Date TO Reached: 11/1/2018 16. Well Name and Number: Hill 6A - L03 r 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: 19268' MD / 6698' TVD 18. Properly Designation: , Fee Hansen,ADL18790,ADL 384403 41b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 166861.855 y- 2144856.07 Zone- 4 TPI: x- 155830.73 y- 2152708.02 Zone- 4 Total Depth: x- 154839.79 y- 2153390.79 Zone- 4 11. Total Depth MD/TVD: 19268' MD f 6698' TVD - 19. DNR Approval Number: LOCI 14-007 12. SSSV Depth MD/TVD: 543' MD / 542' TVD 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes L� (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 1 N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: 18,000' MD 17,064' TVD (L03-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 1198 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 WA 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. l 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 L No � Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: Date of Test: hours Tested: Production for Test Period -1110. Method of Operation (Flowing, gas lift, etc.): 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 (corr): Form 10407 Revised 5/2017 r� ' _ h, t S CONTINUEp ON PAGE 2BDS S ^I Submit ORIGINIAL onl f t �r �il�/9 n JAN 1 0 [119 3�:06.0'441u�i 28. CORE DATA Conventional C�.,qs): Yes ❑ No Sidewall Cores: res ❑ No Q If Yes, list formations and intervals cored (MD/TVD, Fromrro), 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 Q If yes, list intervals and formations tested, briefly summarizing test results. Hemlock 18851 , 6872 Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. TPI / KOP 18000 7064 Formation tops above are for the H16A - L03 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. 1 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. mckay(a)bluecrestenerov.com Authorized Contact Phone: 907-754-9566 Signature: , Date: 'V 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 Isr 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 — L03 Lateral PTD No. 218-098 API No. 50-231-20051-62-00 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 — L03 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, Larry Burgess Alaska Manager lue Energy BlueCrest Energy Alaska Cosmopolitan Project H1 6A — L03 — 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-LO3 Hemlock 155158.83 2153186.22 -6691.86 18851 6872.29 H16A-LO4 Hemlock 154480.46 2153630.53 -6687.77 19660.15 6868.2 H16A-11-05 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' MD 3-Y2" 9.2# ELIE 8RD Production Tubing 4-Y2" 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' MD Ilue tst Energy Fishbone ribs are 8-Y2" 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 1.01 L02 L03 L04 LOS LO6 L07 4-'/:" 15.2# H563 Slotted Liner @ 21,510' MD WeliViewe Well Name: H16A BC - Daily Recap Well Name APUMi Sunece Legal Location License# H1 BA 231-20051-01-00 24087SL, 1509' FEL,SEC.02T4S,R15W SM 218-095 Spud Date Rig Release Date Ground Elevation (f) BGrountl Disterca (a) Wail Subtype 10/16/2018 23:00 145.81 .43 Fish bone Dally Operations Slant Date End Date Spud Dela Total Number or Rep"Tdat Deptn or Wellbore (IKS) 9/26/2018 79.0 22,310.00 Survey Data MD(flk8) I Ind(") Aan (') TVD(fiKS) VS (11) NS (ft) EW (ft) DLS(VIWu Date 21,587.58 89.79 302.69 7,068.24 ,7 1.47 9,442.39 -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 -16,403.91 0.56 Rigs CCnvador Rig Number Daily Operations Rpt# Stan Date End Data Summary 1.0 9/26/2018 9/2712018 Repair annular BOP 2.0 9/27/2018 9/28/2018 skid dg 3.0 9/2812018 9/292018 center lig over hole 4,0 9/292018 91302018 hook up lines from pits to sub base 5.0r 9/302018 10/1/2018 SET STAIRS ON SUB BASE AND PITS 6.0 10/1/2018 10/22018 set berms for dg and pits/ mats for pits and set cuttings tanks 7.0 10/2/2018 10!32018 CENTER TOP DRIVE RAIL Finish pit liners around rig 8.0 10/3/2018 10/42018 Start up boilers and function test top drive 9.0 10/4/2018 10/52018 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 10/52018 10/6/2018 Install bell nipple, choke and kill lines. Install koomey lines and secure stack tie downs. 11.0 10/6/2018 10!7/2018 Drilling line was slipped on and top drive quit working 12.Q 1017/2018 10/82018 Install new 3W x 5W' VBR's in bottom ram, Install 31W' solid body style In top ram. Change out top drive IBOP valve, and -retest. Witnessed by AOGCC Jeff Jones. 13.0 10/8/2018 10/92018 PU 348 joints of 5 %d' 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. 14.0 10/92018 10/1012018 Pick up a total of 154 stands of 5'/V XT54 OF. Bull head 80 bbls 100° water down IA. Bull head 140 bbls 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 off IA. Pull hanger to floor. Well dead, no gas readings. Prepare to lay down tubing. 15.0 10/10/2018 10/112018 Kill well, 18 PSI on backside.Buiihead tubing volume plus 10 bills, bullhead 200bbis down IA, bleed residual gas off to production bleed tank. Lay down landing joint, hanger and pup. Open SSSV. Run chem line and (- Wire through sheaves, POOH laying down 3%a" EUE 9.3# L-80 tubing from joint #461 to joint #282. Retreive all cannon camps. Fill hole with 5Xs 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 10/12/2018 10/132018 Rig down GBR tubing running equipment, remove long bails, 75 ton elevators, cannon damps, GLM's, all completion equipment from rig floor and pipe shed. Rig down and release Carl spoolers, GBR. Strap 3 spiral DC's, 18 HWDP, TIH with Halliburton F2 drill SVB packer on XT 54 51/4' DP. 18.0 10/13/2018 10IM2018 Trip in hole with Halliburton EZ 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 p8 system. Displace well to 9.2 ppg OBM. Pump dry job. POOH strapping pipe. 20.0 10/15/2018 10/162018 TOOH from 4598'to surface. Lay down "Mechanical setting tool" after Halliburton CIBP run. Clean and dear 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 " Multi cycle by-pass tool". POOH to surface change out tools. Orient. TIH @ 45'/minute lowering speed. Trip to 1327'. crew change. 21.0 10/162018 10/17/2018 Shallow pulse test MWD tool @ 1325' MD. TIH W/ BHA#2 whipstock / Mill assembly to 3766'. Failed solenoid top drive elevators dosing 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 @ 14,563' bottom of tool. TOW=14,538', BOW= 14,552'. Begin milling @ 14,538'. 22.0 .� 10/17/27 lulil 018 Milled window 14,535'to 14,543'. At 14,543'a pressure loss of 275psi was observed and milling torque fell 1 as well. Varied parameters and made Vin 7hrs. POOH to inspect the BHA and mills. UD Drill collars, MWD, HWDP Flex, running tool, and Mill. www.poloton.com Page 115 Report Printed: 12126/2018 WeliView BC - Daily Recap Well Name: H16A Daly Operations Rpt# start Date EM DaftSummary 23.0 10/18/2018 10!19/2018 UD BHA#2(boriom tri -mill badly junk damaged and 1/4" under gauge). P/U BHA#3(new tri -mill assy). RIH to 14,543" and Mill/Drill window and new formation to 14,569'- Pump sweep and circulate hole risen with 9.2 ppg mud wt in and out. POOH above window - R/U to perform FIT - 24.0 10/19/2018 10/2012018 Circulate for FIT, R/U and performFIT, 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 10120/2018 10/21/2018 •C1O 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 12,283'to 9,720'. -Serviced the dg. -Pumped out of the hole 9,720' to 3,171'. -Serviced the rig. -Average losses while pumping out 28PH. 26.0 1012112018 10/2212018 -Pumped out of the hole 3171' to 2983' -Pull out of the hole on elevators 2983' to 576'. -L/D 16jnts of 5.5" HWDP. -LID mill assy, bottom 2 mitis 114" under gauge. -Clean and Gear the rig floor. -PN the wash tool and wash the BOPE stack. Recovered 11b of metal. -Pull the wear bushing and run the test plug and 5.5" test joint. -Test BOPE on 5.5" and 5" test joint 250/3500 psi 5 min. -Pull the fest 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 10/2212018 10/2312018 -P/U 8 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 rem(OK). Verified that the saver sub mould 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 -Tdp in hole f/ 7823'to 14,485'- Slip and cut 110' Drilling line _ -Adjusted COM -Calibrated block height -Tdp 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 t/ 14,622' to 14,735' - WOB = 20130K - 40 GPM = 1950 psi - 40 RPM - P/U WT = 305K - S/O WT = 150K - ROT/WT = 210K -Average losses = 13 BPH - Badcream OOH F/ 14, 735' to BOW @ 14, 552' - Oriented the motor and pumped out through window with 30 GPM with no excess drag - PIU WT 330K with 30 GPM -Begin clean up cycles and slowly bled in LCM pill 3. - 450 GPM @ 1750 PSI - 80 RPM -Torque = 26K -PIU Wt = 220 K - Service TOS, 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' Ariempted to adjust the topddve grabber box lower limit. Found a washed out valve. Changed the safety chain on the topddve grabber box. 29.0 10/24/2018 10/2512018 -Pumping out of hole Fl 7983'T/3853"- Continue POOH on elevators F/ 3853' to 130' as per K 8 M Trip schedule - Rill 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 10/2512016 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 -PIU HT 55 DP to 5760' (total its picked up = 174) Filled pipe every 20 Side -Tdp in hole from denick (d 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 contlition 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 F114,838'to 16,336' 32.0 10/2712018 10/28/2018 -Drilling from 16,336' to 17,440' as per DD and K&M Schedule -Baric Ream F! 17,440' T/ 16,213' as per KBM Back Reaming Schedule -Service Rig - UD (3) Jls DP with excessive wear -RIH F/ 16,213' to 16,375' - Trenching and Time Drilling as per DD FI 16,375' T/ 16,377' 33.0 10/28/2018 10/2912018 Time Drilling F/ 16,377' T/ 16,397'- Drilling ahead FI 16,397' to 18,214' on Lateral # 2 34.0 10129/2018 10/3012018 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 Let 02 -Back ream F/ 18,390; to 18,213'- Trouble shoot HPU for Overheating -Service rig -Back Ream FI 18,213'to 17,390'- 35.0 10/30/2018 10/31/2018 -Time Drilling F/17,138' TI 17,143'- Drilling Main Bore F/ 17,143'T/17,746'- Service TDS -Drilling F/17,746' 7/18,592' - (KOP Fl Lateral 03 17,933') Service Draw Works and ST 100 -Change Grabber dies wvvw.peloton.com Page 215 ReportPrinted: 1212612018 WeliView Well Name: H16A BC - Daily Recap Daily Operations Rpt# Start Dale End Dale summary 36.0 10/31/2018 11/1/2018 Directional Drill 8W' hole from 18,592' to 19,268'. TO 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 11/212018 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 1-04. 39.0 11/3/2018 11/4/2018 Directional Drill 814" 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 casing. 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 11/612018 Pump out of the hole 100 GPM, 350 PP, from 12,148' to 5930'. CBU 2x's. Pump dryjob. 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 1117/2018 11/8/2018 Lay down 514" XT 54 drill pipe for hard banding. Repair HPU,install new fire rated hose coverings for Koomey room lines as per AOGCC. Install new XT 64 saver sub. Pull wear bushing, Install test plug. Begin testing BOPE with 5" TJ. 44.0 1118/2018 11/9/2018 Conduct Bi -Weekly BOPE test W/ AOGCC Inspector. 5" and 5%" test joints. Rig down test equipment. P/U and stand back 78 joints of 5W XT 64. 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 W/ 4h" 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 1119/2018 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 434' 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 OP via mouse hole Slip and cut 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 17,169. 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 11/1212018 11/1312018 Directional drill L05 W/ Exceed rotary steerable system, 814" hole from 18,860' to 20,538' MD. 49.0 11/1312018 1111412018 Directional drill L05 W/ Exceed rotary steerable system, SIA" hole from 20,53810 20,743' MD. BROOH slow, perform clean up cycle. Pick up and stand back 6 stands of newly hard banded XT54 OP. BROOH to 19,500. Trough from 19,500 to 19,525'. Time drill to 19545', Begin drilling LO6 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'T/ 21,340'- Circulate and clean hole, P/U 6 skis of OP while circulating - BROOH TI 20,350' 51.0 11/16/2018 11/16/2018 - Back Ream F/20,350' T/20,257' @ 15 FT/MIN - Service Rig - Troubleshoot and repair Reminder, Trenching as per DO F/20,250' T/20,270' - Time Drilling as per DO F/ 20,270'T/ 20,295'- Drilling 8 1/2" hole as per DO & K&M parameters F120,295' T/ 20,926 52.0 11/16/2018 11/17/2018 - Drilling 8 112" hole F/ 20,925' T/ 21,092'- Replaced Wash Pipe seals in TDS - Drilling F/ 21,092'T/ 21,850' - Service Rig 53.0 11/17/1018 11/18/2018 - Drilling F/21,850' T/ 21,860' 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/ 21,145'- Begin trenching F/ 21,145'T/ 21,165'- Time Drilling F/ 21,165'T/ 21,194'- Drilling LOB F/ 21,194'T/ 21,850' 54.0 11/18/2018 11/19/2018 - Drilled 8 1/2" hole LOB 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 30 while back reaming @ 1 1/2 FT/MIN F/2 22,310' TI 21,753'- Back reamed F121,753' T/21,475'@ 15 FT/MIN - Serviced Rig 55.0 11/1912018 11/2012018 - Back Reamed out of hjole F/ 21,475'T/ 19,787'- Worked through tight spot F/ 20,843' T7 20,833'- Back Reamed FI 19,787'T/ 18,660'- Service Rig Equipment - Back Reamed out of hole F/ 18,660'T/ 17110' - RIH ( Had to rotate) T/ 17211' and took survey to confirm still in Main Bore OK - Back Reamed F/ 17,211' T/ 15,003'- SLM 56.0 11120/2018 11/21/2018 - Replace ISOP Actuator due to bearing seizure(flow check, no gainAoss) - Back Reamed out of hole as per K&M Parameters F/15,003' T/ 14,672" - POOH with BHA through window with 100/GPM & No Rotation F/ 14,672'T/ 14,510'- Back Reamed while performing Clean up Cycle to 14,165'- Changed out Saver Sub to XT 46 for(flow check no gain/loss) pulling 4 1/2" Drill Pipe - Pumped out of hole F/ 14165'T/ 9,933'- SLM - Serviced Rig www.peloton.com Page 315 Report Printed: 12126/2018 WeIlV1eiW BC - Daily Recap Well Name: H16A Dairy Operations Rpt ft Start Dale End Oete Summery 57.0 17/21/2018 11122!2018 -PJSM -Pumped out of hole as per K8M Parameters F/ 9,933' T/ 8,047- SLM -Break out XOs and MIU Safety valve -Changed out Saver Sub From XT 48 7o HT 55 -Monitored Well an TT -Static -Pumped out of hole as per K8M Parameters Ff 8,047'T/ 6,600'- Serviced Rig and monitored well on TT -Static -Pumped out of hole as per K8M Parameters F/ 6,600'T/ 5,832'- Back Reamed out of hole while performing Clean up Cycle Q 1.5 FT/MIN F/ 5,832' TI 5,732'- POOH on elevators as per K8M Trip Schedule F15,732' T/ 3,525'- Monitor well displacement on TT -Back Reaming out of hole as per K8M Parameters while performing Clean Up Cycle F/ 3,525'T/ 3,430'- POCH on elevators as per K8M trip Schedule F! 3,430' T/ 163'- Lay down BHA 58.0 11/22/2018 11/23/2018 -Clean and organize Rig Floor - P/U 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 250/3500 Psi for 5 MIN -RID 3 !12" 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 assemblyand clear oft dg Floor 59.0 11/23/2018 11/24/2018 -PJSM -RIH Picking up 4 1/2" Liner Tl 7,917' -Steam out ice on collars -Inspect box/pin -Graph monitor make up torque -Monitored displacement on Trip tank -Static -Change elevators - PIU and Make up PER 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 4 112" Liner on HT 55 Drill Pipe from derrick F/ 8,085'T/ 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, 8 installed bell guide and safety wire -Broke out XO from TIW - Made up Stand and checked Parameters -Broke 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' (Entl of L02) POOH on elevators as per K8M Parameters F/ 18,390' TI 17,055' - Monitored well on Trip tank -RIH with 4 1/2" Liner as per K8M Parameters F/17,055' T/ 18.390'- (End of L02) -Rotated as necessary -Monitored well on Trip Tank -POOH on elevators FI 11,390'T/ 16,021'- Monitor well on Trip Tank -Service Rig 61.0 11/2512018 1112812018 -PJSM -POOH with 4 1/2" Liner as per K8M trip Schedule F/ 16,021'T/ 7,992'- Monitored well on Trip Tank -Changed out Bails and Elevators to Lay down Liner - Serviced Rig - 82.0 11/26!2018 11/2712018 -Clean Rig Floor of Base Oil and inspect tools -PJSM -POOH Laying down 4 112" Liner as per K8M trip schedule F/ 4,852' T/ 4,157'- Break connections with dg longs until 4,300'- Inspected each Box and Pin with Tenads Rep -Monitored well on Trip Tank - Had Safety Stand down Meeting with crews -POOH Laying down 4 1l2" Liner as per K&M trip Schedule FI 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 1l2" Liner as per K8M trip schedule FI 1,732'T/ Surface - Inspected each Joint with Tanana 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 3f4" 63.1. 11l27I2018 11128/2018 -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 1l2" HT 55 Drill Pipe from derrick FI 3,775' TI 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 FI 5,691' TI 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/ 6,036' T/ 14,145'- Monitor well on Trip Tank - F!II Pipe every 20 Stands -Changed elevator inserts to 5 1/2" -RIH withXT 54 Pipe T/ 14,424'- Break circulation with 100/GPM -PIU WT 295k -SIO WT 140k -Service Rig 84.0 11/2812018 11129f2018 Slip and cut 110' 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 exitpoint. 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'. Hale unloaded with unconsolidated sand on first BU. Ream from 17,285' l0 79,105' MD. MW=9.2 PPG in/out. 65.0 11!29!2018 11130/2018 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. 68.0 11/30/2018 12/1/2018 Continue to BROOH. Slight pack oft 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 B miles NW of ANC. Descion made to go back to bottom. Ream back in the hole from 17,100' l0 21,264' MD. 67.0 12/1/2018 121212018 Ream to 21,826'. CBU WI 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 atltl LVi to active. Monitor well, weight active back to 9.2 PPG. 68.0 12/2/2018 121312018 Bring active pit volume back to 9.2 PPG MW. Circulate. 500 GPM, 120 RPM, 2480 PP, 28K TO, BROH slow. Circ light fluid into annulus. Depth 15,457'. BROOH to window. 14,710' Circulate 10 mins. Pull first string reamer into casing with100 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 415 Report Printed: 12/26/2018 Wellview Well Name: H16A BC - Daily Recap Dally Operations Rpt# Sled Date End Data Summary 69.0 12/3/2018 12/4/2018 Pump Out of the hole to the top to the XT 46. 9144' to 8036'.C/0 saver sub to HT 55. Grease wash pipe. Change out inserts to 5%". 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 54 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 GER power tongs, load 30 joints of liner in shed. 71.0 12/5/2018 12/6/2018 Pre job safety meeting. Rig up and run 4%" 15.2# P-110 HYD 563 liner to 7071'. 184 joints. Ave TQ=7,000 fVlbs. 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 W/ 5X" DP to the Whipstock. 14,538'. record up/down weights. Rotate weight. TIH t0 15,090'. 72.0 12/6/2018 12/712018 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 ft/Ibs. Run liner to 21,51 O' MD. Drop ball to set hanger. Pressure up to 1500 PSI / 2200 PSI / 3000 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 12/812018 Pull dogs out of liner packer. Set packer. Rig up and test casing & liner top packer to 2600 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 1218/2018 121912018 Continue to lay down drill pipe from 5100 to surface, all of the HT 55. TIH with remaining HT 55 and XT 54 to 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 1211012018 Complete the task of lying down the XT 46 singles from 2480 to surface. Pull wear ring. Remove power tongs for liner job, bring GER 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 3W' YT elevators. Hang 3rd sheave in derrick. String all three control line spools through sheaves in derrick. Load pipe shed with completion jewelry and 3:5" 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 Wt 3'/:" tubing from 3333' to 9716' as per tally. Joint If 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 fr 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. 12/12/2018 12/13/2018 - RIH F/Derrick 3 1/2" Completion Tubing F/ 4,107' T19,716' 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 - M/U SSSV - SLB functioned x 3 and tested to 5000 PSI 15/MIN - RIH T/ 14,270' - Take P/U WT 138k - S/O WT115k - RIH and tag @ 14,434' with 10k - Space out and WU Hanger - Connect 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 top 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 - Spoil5bbls of LVT in casing X tubing annulus for freeze protection. Remove Landing Jt and Install BPV - Blow Down hoses and choke manifold - R/D Tubing tongs 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 - VD Mouse Holes - Remove SLB sheaves from derrick - Flush Mud Pumps - Continue Cleaning Pits - Fill Test Pump with 411 Water/Methanol - Nipple Down BOPE and set on stand - Secure same - Continue preparing for Rig Move www.peloton.com Page 515 Report Printed: 1 212 61201 8 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 IPOOH / 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' MD / 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' M D 20 16336 9.2 Drill w/ RSS BHA / hi torque add lubes / drill to 16336' MD 21 17440 9.2 Drill 1-01 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 1 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 RIH / search for L05 trench / drill ahead in LOS w/ RSS BHA 06 37 20743 9.3 Drill L05 lateral to TD of 20743' MD / C&C / BROOH for L06 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 22310 9.2 Drill L08 to well TD at 22310' MD / BROOH for liner 44 22310 9.2 BROOH from well TD to 15003' MD 45 22310 9.2 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 JDP management / RIH w/ clean out BHA / ream L02 area 53 223101 9.2 IClean out mainbore in preparation for re -running liner 54 223101 9.2 ICheck L02 area for liner entry - OK; BROOH for liner re -run 55 223101 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 223101 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 22310 9.25 Run 3-1/2" / stop since handling pup ran in error / POOH 66 22310 9.25 ITake out incorrect pup/ RIH w/ 3-1/2" upper completion 67 22310 9.25 1 Run & land upper completion / connect control lines 68 IuNest H16A-L03 Survey Geodetic Report Schlumberger Energy (Def Survey) ...... .....,...-....,, .... Section .„...., ,.wman Clean GIM": Blet eld anntsth- Vertical Section Ar Vertical 300.000 ° (hue NOW (r.. NO Field: Commst (:aeTaPOMN Unit Ped/K18 \8 VeD Settlers Origin: gin: 0.000 fl Wall: H opoMen ,gyp jy v4°d1' � Wimence e.: TWDund Raday Title ����vve ;I31M: Sona ���� 0 Elevation:Elevation: MSL API6: 502312005182 Magnetic Declination: 14.623- 4.523°Survey S.,.,Name: H16A 03 Total Onvity Field Strength: 1001.2613., (9.80665 Saeed) Survey Dal: October 31. 2018 Gravity Model: DOX Tort I AND /DDI I ERD Rada: 236.963 ° / 16446.427 fl 17.02412.317 Total Magnetic Field Stiengtll: 55103.991 AT COOldidel Reference system: MAD27 Alaska Stale Plane, Zan 04. US Fast Magnetic Di, Anel: 72.876 ° Location Let l Lang: NBe- 51' 32.00254', W 151°41'5.0%92' Declination Dak: Odeber 31, 2018 Location Odd WM YM: N 2144851.950 flUS, E 168857190ItUS Magnetic Declination Model: HWM 2017 CRS Grid Convergence Angle: -1.5580 ° North Reference: True North Grid Seal Faator: 1.0000248 Grid Convergence Used: 0.0000 ° Version I Patch: 210.544.0 Toll Don Map North- True Mari 14.5230' MD Incl M. True TVDSS TVD VSEL AND cloeure has EW 26.8 NoMing Easung Letihide Longitude Corenents In) (ft) Or u fl( -/IBM) S S RTE 0.00 0.0 0.90 -180." 0.00 000 0.00 0.00 0.00 0.00 WA 2144851.95 168857]9 59.85888960 451.80141581 0.03 0.00 0.00 -180.43 0.03 0.00 Dw 0.00 0.00 0.00 0.00 214411151.95 168857.79 59.85888960 .151.80141581 34.65 0.00 000 -145.81 34.65 0.00 O.W 0.00 0.00 0.00 0.00 21441151.95 16885T79 59.85880960 -151.80141581 100.03 0.43 249.54 40.43 100.03 0.16 0.25 0.25 -0.09 -0.23 0.66 2144851.87 168857.56 59.85088936 -151.80141706 200.03 1.02 252.78 19.56 200.02 1.00 1.51 1.51 4." -1." 0.59 2144851.51 168866.35 59.85880828 -151.80142360 300.03 2.42 320.54 119.52 299.98 3.56 4.23 3.73 0.89 3.62 2.24 2144852.93 168854.19 59.85869202 -151.80143552 400.03 5." 333.89 219.28 399.74 9.47 11.02 9.75 6.74 -7.04 3.10 21"856.88 168850.94 59.85890804 -151.80145409 500.03 7.61 323.52 318.63 499.08 19.44 22.31 20.87 15.29 -13.05 2.49 2144060.59 168845.19 59.85893417 .151.80148677 800.03 9.91 303.00 417.48 597.94 34.11 37.39 35.75 26.31 -24.20 3.85 2144870.91 168834.31 59.858%157 -151.80154745 700.03 11.34 207.00 515.79 696.25 52.32 55.72 53.10 34.00 40.79 3.13 214,1687.05 168817.94 59.85098262 .151.80163764 800.03 10.96 272.57 613.92 794.38 70.37 74.95 70.42 37." 59.65 2.96 214,1890.99 168799.18 59.85899201 -151.80174023 900.03 9.37 273.40 712.35 892.81 86.09 92.60 %.26 38.34 -77.27 1.60 214"92.30 168781.59 59.85899449 -151.80153609 1000.03 10.13 294.04 810.93 991.39 102.12 109.35 102.81 42.41 -93." 3.515 2144896.B9 1687&5.54 59.85900562 -151.80192400 1100.03 13.66 301.29 "a." 1089.23 122." 129.94 123.14 52.13 .111.56 3.83 21"907.09 166747.68 59.85903221 -151.60202260 1200.03 16.58 303.80 1005.30 1185.76 148.73 156.01 149.3 66.20 -133.51 2.99 214,1921.76 168726.12 59.85907071 .151.80214200 _ 1245.20 17.W 305.85 1048.51 1228.97 161.84 169.17 182.05 73.72 -14,1.31 2.07 2144929.57 168715.53 59.85909128 -151.60220074 13".32 19.34 305.59 1142.60 1323.06 192.84 200.33 192.91 91.91 -169.61 2.06 2144948." 168690.74 59.65814103 -151.60233832 1435.98 21.29 301.72 1228.56 1409.02 224.58 232.14 224.61 109.49 .196.11 2.58 2144965.74 168664.72 59.85918913 -151.80248247 152&07 23.68 301.02 1314.57 1495.03 260.17 267.74 260.18 128.01 -226.51 2.56 2144988.00 168634.84 59.05923981 -151.80264762 1623.26 25.0 300.17 1400.06 1580.52 299.70 307.28 299.70 148A2 .260.54 2." 2145007.10 168601.37 59.85929481 -151.80283291 1717.56 26.63 300.05 1484.60 1665.06 341." 349.3 341.47 169.07 -296.67 0.72 2145029.03 168565.82 59.85935213 -151.803029" 1811." 27.53 300.20 1568.19 1748.65 384.20 391.71 364.20 190.52 333.64 0.96 2145051.46 168529.45 59.05941061 -151.80323049 1905.46 28.% 299.14 1651.13 1831.59 428.47 438.4 428." 212.43 -372.11 1.31 2145074.43 168491.50 59.85947075 -151.803"976 1999.50 30.32 298.11 1732.99 1913.45 474.75 482.33 474.76 234.60 452.75 1.85 2145097.69 188451.56 59.85953139 -151.00366079 2693.56 32.53 297.94 1813.24 1993.70 523.76 531.37 523.78 257.64 -455.04 2.35 2145121.90 168400.92 59.85959441 -151.803811625 2180.00 35.54 296]4 1691.56 2072.02 576.59 584.27 576.64 281.91 -503.03 3.26 2145147." 160362.60 59.85966062 .151.80415187 22%.00 37.49 296.42 1978.30 2166.76 640.69 646." 640.79 310.64 -560." 1.32 2145177.72 160305.97 59.85973940 .151.80446424 2376.60 39.21 297.75 2041.57 2222.03 6111 698.54 690.62 333." .605.02 2.36 2145201.72 168262.05 59.859801]/ .151.80470661 2473.39 42.17 299." 2114.89 2295.35 753.70 761.50 753.86 363.62 4660.37 3.26 2145233.39 188207.54 59.85988432 .151.80600767 2563.50 44.14 299.50 2180.62 2361.08 815.33 823.21 815.49 393.92 -714.03 2.19 2145265.15 166154.71 59.85996721 .151.80529958 2657.45 45.62 2%.71 2247.20 2427.66 881.57 88949 881.76 425.12 -772.51 2.62 21"297.93 168097.11 59.36005257 -151.80561763 2751." 47.92 295.03 2311.57 2492.03 949.87 957.97 950.15 454.98 434.13 2.77 21"329.45 168036.32 59.86013425 451.80595280 Cosmopolitan UniOCosmoplitan Pad\H16%H16\l 16 Drilling DmDe 2.10.302.0 . Schlumberger -Private 1/712019 3:29 PM Page 1 of 5 C9mmonb MO 1X1 1.01 1.1 Atlm T. VI TVO55 (a) TVD 1X1 VSEC (a) AHO IRI Closure (XI NS (a) EW m) DL9 (/10001 NoX61ng Mus) Eaatlng IXu31 "tHu6o ('I Longkud. VI 2045.15 50.92 294.28 2372.53 2552.99 1020.72 1029.13 1021.15 484.86 -890.81 3.26 2145360.88 167972.47 59.86021543 451.80630462 2938.96 53.66 20.61 2429.90 261036 1094.51 1103.34 1095.15 514.77 -06.63 2.97 21409282 167905.49 59.86029T79 -151.60661354 3033.00 56.06 295.10 2484.03 2654.49 1171.03 1160.23 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 -1108.04 3.49 2145462.64 167765.93 59.66047832 -151.60744273 3220.66 61.70 297.76 2580.53 276099 1331.55 1341.09 1332.70 617.83 -1100.83 3.03 2145501.67 167694.17 59.86057970 -151.80783868 3315.24 63.38 298.93 2624.14 2804.60 1415.43 1425.01 1416.61 657.68 -1254.68 2.09 2145543.52 167621.42 59.86060869 -151.80824042 3408.17 64.84 299.90 2664.72 2845.18 1499.02 1508.61 1500.17 698.74 -1327.50 1.83 2145586.54 167549.74 59.86080101 451.80863653 3502.99 84." 299.49 2705.63 2886.09 1504.56 1594.15 1505.66 741.12 -1401.81 0.93 2145630.93 167476.62 59.86091692 -151.80904073 3596.91 64.56 299.09 2746.36 2926.82 1669.19 1678.78 1670.27 782.52 -1475.52 0.67 2145874.32 167403.96 59.86103016 -151.80944223 3690.76 64.59 298.04 2706.65 2987.11 1753.92 1763.54 1755.02 023.05 -1550.06 1.01 2145716.86 167330.64 59.96114101 -151.80984717 3784.55 65.08 296.94 2026.53 3006.99 1836.72 1848.43 1839.90 862.23 -1625.36 1.18 2145758.07 167256.43 59.85124818 -151.81025680 3876.59 64.70 295.53 2866.44 3046.90 1923.69 103.58 1925.02 899.87 -1701.74 1.42 2145797.78 167181.11 $9.66135113 -151.81067228 3972.35 64.14 296.20 2906.93 3087.39 2008.4 2018.15 2009.54 936.]7 AM." 0.80 2145838.73 167108.04 59.86145203 -151.81108623 4066.28 64.20 296.38 2947.85 3128.31 2092.40 2102.70 2094.06 974.21 -1853.64 0.18 2145876.22 167031.28 59.88155444 -151.81149857 4126.10 64.99 295.88 2973.51 3153.97 2146.32 2156]3 2148.07 990.01 -1902.15 1.52 2145901.33 166983.43 59.08161952 -151.81176247 13.3161 417503 6551 296.63 2994.00 3174.46 2190.66 2201.17 2192.49 101767 -IW2,00 1.76 2145922.07 166944.13 59.86167329 -151.81197925 4215.22 65.94 297.25 3010.52 3190.98 2227.24 2237.80 2229.12 1034.27 -1974.65 1.76 2145939.55 166911.93 59.86171869 -151.81215692 4261.49 66.12 298.74 3029.32 3209.78 2269.46 2260.6 2271.40 1053.48 -2012.33 1.08 2145959.76 166874.80 59.86177117 -151.81236185 4355.37 66.26 297.61 306722 3247.68 2355.25 2365.97 2357.29 1092.68 -2088.74 0.66 2146001.05 166799.48 59.86187845 -151.81277751 4448.65 66.36 297.51 3104.7D 3205.16 2440.59 2451.39 2442.71 1132.21 -2164.47 0.15 2146042.61 166724.86 59.86198654 -151.81318946 4542.46 66.07 296.67 3142.53 3322.99 2526.32 2537.23 2528.54 1171.30 -2240.89 0.88 214083.77 10649.52 59.86209345 -151.81360521 4636.4 65.95 296.88 3180.74 3361.20 2612.04 2623.09 2614.40 1209.98 -2317.55 0.24 2146124.52 166573.94 59.06219923 -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 166498.58 59.06230592 -151.81443811 4824.27 65.97 297.98 3256.75 3437.21 2703.62 2794.86 2786.16 1288.78 -2470.16 0.85 2146207.45 166423.52 59.86241474 -151.81485246 4918.15 66.24 298.97 3294]8 3475.24 2669.42 2880.89 2871.98 1329.71 -2545.61 1.01 2148250.41 166349.21 59.66252665 -151.81526292 5012.24 66.06 20.87 3332.02 3513.28 2955.46 2966.75 2958.01 1371.32 -2620.94 0.21 2146294.06 166275.05 59.86264046 -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 -151.81608283 5200.19 65.82 299.27 3408A0 3588.06 3127.52 3138.83 3130.04 1455.09 -2771.25 0.80 2146381.88 166127.06 59.86286954 -151.81649047 5294.81 66.18 299.72 306.89 3627.35 3213.96 3225.27 3216.44 1497.65 -2846.49 0.58 2146426.47 16600.01 59.06298593 -151.01689979 5388.14 65.79 299.73 3484.87 3665.33 3299.21 3310.52 3301.64 1539.92 -2920.52 0.42 2146470.74 165980.15 59.86310152 -151.81730256 5481.25 65.86 299.88 3523.00 3703.46 3384.15 3395.47 3386.53 1582.14 -2994.23 0.17 2146514.95 165907.61 59.802160 -151.017703% 5575.30 66.01 299.57 3561.35 3741.81 3470.03 3481.34 3472.36 1624.72 -3068.01 0.34 2146559.55 165834.22 59.86333342 -151.01810929 5669.34 66.32 299.52 3599.35 3779.81 3556.04 3567.38 3550.35 1667.14 -3143.64 0.33 2146603.98 165760.57 59.86344941 -151.81851643 5763.67 66.91 299.25 3636.79 3817.25 3642.62 3653.94 3644.90 1709.62 -3219.08 0.68 2146648.50 165886.31 59.86356556 -151.81892667 5857.71 66.26 299.29 3674.16 3854.62 3728.91 3740.24 3731.17 1751.01 -3294.36 0.69 2146692.73 165612.20 59.86360095 -151.81933643 5951.71 66.29 299.63 3711.98 3892.44 3814.96 3826.29 3817.20 1794.14 -3369.29 0.33 2146737.07 165530.45 59.86379688 -151.81974409 60 534 66.35 299.18 3749.75 3930.21 3901.07 3912.41 3903.29 1836.42 -3"4.31 0." 2146781.38 1650 .61 59.86391229 -151.82015224 6139.71 66.95 299.30 3786.99 3967.45 3987.33 3990.60 3989.55 1878.56 -3519.59 0.65 2146025.55 165390.50 59.86402753 -151.82056102 6233.57 67.33 299.28 3823.46 4003.92 4073.81 4065.17 4076.02 1920.87 3595.02 0.41 2146869.90 165316.24 59.86414322 -151.82097222 6327.38 67.19 299.53 3859.72 4040.18 4160.33 4171.60 4162.51 1963.35 -3670.39 0.29 2146914.41 165242.05 59.86425937 -151.82138230 6421.39 67.60 299.49 3895.85 4076.31 4247.11 4250.47 4249.28 2006.10 3745.92 0." 2146959.20 165167.71 59.86437626 -151.82179324 6515.39 66.04 299.46 3931.34 4111.80 4334.15 4345.52 4336.30 2048.93 -3821.70 0.47 2147004.00 16093.13 59.86449337 -15La2220556 6609.28 0.21 290.39 3966.32 4148.78 4421.26 "32.65 4423.42 2091.07 -3097.96 1.07 2147040.27 16018.04 59.86460859 -151.82262045 6703.25 67.43 290.24 4001.80 4182.28 4508.24 4519.66 4510." 2132.34 -3974.56 084 2147091.62 164942.58 59.86472144 -151.82303725 6796.52 67.19 296.45 4037.78 4218.24 4594.26 4605.71 4596.49 2173.20 4050.30 0.33 2147134.52 164867.99 59.06483314 -151.82344931 6890.0 67.49 290.37 4074.17 4254.63 4681.40 4692.89 4683.65 2214.67 4126.98 0.33 2147178.06 164792.48 59.86494654 -151.82386652 6985.40 67.65 298.27 4110.19 4290.65 4768.63 4700.16 4]/0.93 2256.07 4203.80 0.20 2147221.54 164716.79 59.06505973 -151.02426451 7077.95 67.22 298.39 4145.71 4326.17 4854.06 4065.62 480A0 2296.63 -4279.03 0.48 2147264.13 164642.69 59.86517061 -151.82469383 7171.18 67." 290.54 4181.64 4362.10 494D.06 4951.65 4942.42 2337.63 4354.65 0.28 2147307.17 16408.21 59.86528271 -151.82510532 7265.10 67.94 298.21 4217.33 4397.79 026.98 5030.61 029.38 2378.96 -4431.17 0.62 214730.0 1WW.84 59.86539570 -151.02552165 7359.15 67.57 297.73 4252.90 4433.36 5113.91 5125.59 5116.36 2419.75 4507.98 0.62 2147393.43 16"17.16 58 66556722 -151.82593962 7452.94 67.45 297.57 4288.78 "69.24 5200.49 5212.25 5203.01 2459.97 4564.75 0.20 2147435.72 164341.52 59.86561716 -151.02635728 7548.93 67.26 297." 4324.96 4505.42 5207.15 5298.99 5289.75 250.03 4661.68 0.24 21474..85 16426590 59.86572668 -151.02677592 7640.96 67.49 297.84 4361.14 4541.0 5373.87 5385.78 5376.54 2540.29 4738.57 D.46 214752D.20 164189.93 59.86583675 -151.02719429 7735.00 67.36 20.41 4397.24 4577.70 5460.66 5472.62 5463.37 2581.23 4815.15 0.58 2147563.2D 184114.49 59.88594865 -151.82761099 7828.92 67.39 298.11 "33.37 4613.83 5547.31 5559.31 550.06 262227 4891.51 0.30 2147606.31 164039.27 59.8660086 -151.828D2648 Cosmopolitan Unit\Cosmoplitan Pad\H16\H76W16 Drilling office 2.10.302.0 Schlumberger -Private 1!7/2019 3:29 PM Page 2 of 6 MD M.1 A9m T. T ss TVD VSEC AHD Closgm N8 EW Me Northing E49eng tatKU& Longku& C9mm4nb fl R R R fl R fl R(Ilium) 1105 flus 7923.08 67.35 298.35 069.60 4650.06 5634.18 5646.22 5636.97 2663.38 4968.09 0.24 2147649.49 163963.84 59.86617324 -151.82844314 8016.85 67.60 20.16 4505.46 4685.92 5720.78 5732.86 5723.62 2704.4D -5044.40 0.40 2147692.56 163808.67 59.86628537 -151.82885842 811080 67.29 290.56 4541.0 4721.90 580153 $819.65 5810.40 2745.62 -5120.78 0.57 2147735.85 163813.44 59.86639806 -151.82927399 8204.75 67.33 290.81 4577.68 4758.14 5894.19 5906.33 5897.08 2787.23 -5196.82 0.25 2147779.51 163738.56 59.86651180 -151.62968777 0290.84 67.25 298.64 4614.00 4794.46 5900.97 5993.12 5963.87 2829.08 -5272.86 0.09 2147823.41 163663.68 59.86662619 A51.83D10155 8392.70 67.30 298.92 4650.29 4830.75 6067.60 6079.77 6070.51 2870.92 -5348.73 0.09 2147867.31 163580.97 59.86674059 -151.8305101 805.76 67.25 290.52 4666.21 4866.67 6153.34 6165.53 6156.27 2912.14 -5423.94 0.40 2147910.55 163514.91 59.86685324 -151.83092368 8579.76 67.37 298.$7 4722.47 4902.93 6240.04 6252.26 6242.99 2953.58 -5500.12 0.14 2147954.05 163439.80 59.86696652 -151.83133024 8673.60 67.17 296.21 4758.76 4939.22 6326.63 6330.88 6329.62 2994.77 -5576.33 0.41 2147997.29 163364.82 59.86707911 -151.83175293 8767.71 67.30 297.52 4795.15 4975.61 6413.27 6425.59 6416.32 3035.29 -5652.98 0.69 2148039.89 163289.3D 59.98718986 -151.83217004 8851.52 67.10 297.36 4831.50 6011.96 6499.66 6512.07 6502.79 3075.14 5729.73 0.26 2148081.81 163213.66 59.86729880 -151.83258769 8955.40 67.11 297.35 4860.03 5048.49 6586.06 6598.55 6589.27 3114.88 -5806.55 0.01 2148123.63 163137.95 59.86740742 -151.83300560 9049.36 67.35 297.49 4904.39 5084.85 6672.61 6685.19 6675.90 3154.78 -5083.45 0.29 2148165.60 163062.16 59.86751647 -151.83342418 _ 9143.37 67.56 297.47 4940.43 5120.89 6759.35 6772.02 6762.72 3194.54 -5960.46 0.22 2148207.75 162906.24 59.86762597 -151.83384335 9237.36 66.90 298.11 4976.81 5157.27 6845.95 6858.68 6049.38 3235.25 6037.15 D.94 2148250.22 162910.70 59.86773641 -151.83426057 9331.34 67.10 297.82 5013.53 5193.99 6932.40 6945.19 6935.89 3275.81 -8113.55 0.35 2140292.85 162835.42 59.86784728 -151.83467637 9425.31 67.59 297.74 5049.73 $230.19 7019.05 7031.91 7022.60 3316.23 6190.28 0.53 2148335.34 162759.82 59.86795775 -151.83509390 9519.14 67.55 297.78 5085.53 5265.99 7105.72 7118.64 7109.33 3356.63 6267.03 0.06 2140377.81 162684.20 59.06806016 -151.83551156 9613.00 67.12 297.95 $121.70 5302.16 7192.27 720.25 7195.94 3397.11 6343.60 0.49 2148420.36 162608.76 59.86817800 -151.03592825 9706.89 67.11 297.99 5158.21 5338.67 7278.72 7291.75 7282.0 3437.60 - 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59.87791887 -151.86894179 To-ln Survey 17108.93 91.86 301.29 6894.12 7074.58 14322.09 14351.43 14323.13 7011.75 -12489.49 1.43 21522%.84 156553.28 59.87805452 -151.86930513 17201.27 90.71 302.08 6892.05 7DM.51 1"14.36 14443.75 1"15.36 7060.24 -12568.04 1.51 2152251.45 156486.07 59.67818695 -151.86981291 17293." 90.47 303.08 6891.10 7071.56 14506.40 14535.91 14507.31 7110.40 -12645.35 1.97 2152303.70 156410.15 59.87832397 -151.87023392 17387.35 90.22 303.52 6890.54 7071.00 14600.11 14629.82 14600.% 7162.51 -12723.40 0.47 2152357.91 156333.46 59.87846629 -151.87%5940 17481.25 0.79 303.23 009.71 7070.17 11693.85 14723.72 14894.65 7214.16 -12801.89 0.68 2152411.68 156256." 59.87860738 -151.07108642 17575.21 0.74 302.65 6888.46 7068.92 14787.67 14817.67 14788.42 7265.25 -12%0.74 o62 2152464.90 156179.05 59.87874691 -151.87151582 17671.52 %.13 302.01 6887.73 7068.19 14883.% 14913.97 14884.60 7316.75 -12962.12 0.92 2152510.59 156099.10 59.07888758 -151.07195099 17764.94 90." 302.47 6886.81 7067.27 14977.24 15007.39 14977.91 7366.59 -13041.13 1.04 2152570.% 156021.48 59.87902368 -151.87238928 17857.58 90.30 304.02 6885.77 7066.23 15069.72 15100.02 15070.34 7417.37 -13118.60 1.03 2152623.43 155945.41 59.87916238 -151.87281119 Cosmopolitan Unit\Cosmoplitan Pao\H16\H76\H76 Drilling Office 2.10.302.0 Schlumberger -Private 1!7/2019 3:29 PM Page 4 of 5 Cosmopolitan Unit\Cosmoplitan Patl\Hi6\H16\H76 DdIling DreDB 2.10.302.0 Schlumberger -Private 1!7/2019 3:29 PM Page 6 of 6 MD Incl Azim True TVDSS TVD VSEC AND Closuro NS EW DLS NeMing Easting latitude Longitude C*mmema p h R k h R R -MINK RUS 3 17952.67 90.90 305.17 6884.77 7%5.23 16164.50 15195.11 15165.04 7471.35 -131%.87 1.36 2152679.52 155068.64 59.87930983 -151.67323748 10047.04 93.36 305.78 6881.27 7%1.73 15258.37 15289.41 15256.83 7526.0 -13273.66 2.69 2152736.32 155793.36 59.87945932 -151.87365574 18140.89 96.24 36.19 6873.41 7053.87 15351.37 15362.92 15351.76 7581.02 -13349.33 3.10 2152793.30 155719.21 59.87%094D -151.874%707 18234.47 98.87 304.78 6861.11 7041.57 15443]0 15475.68 1541.03 7630.87 -13424.% 3.18 2152849.18 155G15.18 59.67975649 -151.87447924 18328.65 103.13 305.27 6843.14 7023.80 15535.78 155N8.1D 15536.05 7687.92 -13500.55 4.55 2152904.27 155570.95 59.8799D137 -151.87489150 18424.44 104.52 304.09 6820.25 7000.71 15628.48 15561.12 15528.71 7740.84 -135]7.03 1.88 2152959.25 155495.93 59.88004593 -151.87530808 18515.81 1%.56 303.18 6796.54 6977.00 15716.54 15749.36 15716.74 7789.72 -13650.30 1.49 2153010.11 155423.82 59.88017942 -151.87570821 18608.51 105.30 302.80 6771.88 69s2.34 15805.P 15838.71 15805.95 7838.37 -13725.45 0.48 215360.79 155350.22 59.80031229 -151.87611642 18703.65 1%.46 301.41 6744.26 6924.72 150%.74 15929.74 158%.% 7886.76 -13802.55 36D 2153111.25 155274.46 59.88044442 -151.07653634 18794.88 11162 301.31 6713.15 6693.61 15982.48 16015.49 15982.61 7931.38 -13875.77 3.25 2153157.85 155202.40 59.88056628 -151.87693514 18891.05 114.13 301.65 6675.92 6856.38 16D71.10 16104.16 16071.24 7977.68 -13951.39 2.84 2153206.19 155128.15 59.88%9270 -151.87734697 18985.20 114.73 301.42 %36.% 6817.1 16156.79 16189.88 16158.92 B022.52 -14024.45 0.67 2153253.00 1550%.33 59.88081513 -151.8777188 19078.37 115.10 301.37 6597.73 6778.19 16241.26 16274.38 16241.38 8%.53 -14096.58 0.40 2153298.% 154985.42 59.88093532 -151.87813772 - 19172.64 114.80 300.54 6557.97 6738.43 16326.72 16359.85 16326.84 0110.50 -14169.08 0.86 2153344.90 154913.35 59.86105536 -151.07853693 19192.43 114.78 300.35 6549.67 6730.13 16344.69 16377.81 1631.80 8119.60 -14185.37 0.88 2153354.42 1548%.11 59.881%021 -151.87062129 19280.00 114.70 300.35 6518.00 6698.46 16413.30 16446.43 16413.41 8154.27 -14244.57 0.00 2153390.69 154839,86 $9,88117487 -151.87894376 Survey Emor MOdd: ISCWSA Rev 0 •" 3D 95.000%Confidence 2.7955 sigma Survey Program: Description Part MD From MDT* EOU Fdq H*bze Sising Ca Diarmfer Su rvey Tod Type Bonkob/Survey (RI (a) (ft) lin) (hl 1 0.000 1200.030 Ad Sins 17.500 13.375 SLBCNSG ASING H16PS1/H16PB1 1 1200.030 4126.100 Ad Stns 17.500 13.375 SLB MW GMAG H16PB1/H16PB1 1 4126.100 11%.250 Act Stns 12.250 9.625 SLB MW GMAG H16PB1/H16PB1 1 1196.250 14762.380 Ad Stns 8.500 0.0% SLB _MIN&NC_ONLY _RLLER HIM-LO1/H16 1.01 1 14762.380 163%.710 Ad Sins 8.500 0.000 SLS MW MAG HISA-LO1/H16A-L01 1 18356.710 17108.930 Ad Stns 8.500 0.000 SLB_MWD+GMAG Hi6A-t.021H16 1.02 1 17108.930 19182.430 Ad Sins 8.59 0.000 SLB MWD+GMAG H16A-L03/H16A-L03 1 19192.430 19268.000 ACF $tns 8.50 0.000 SLB BLIND�TREND H16A-LM/H16A-L03 Cosmopolitan Unit\Cosmoplitan Patl\Hi6\H16\H76 DdIling DreDB 2.10.302.0 Schlumberger -Private 1!7/2019 3:29 PM Page 6 of 6 H16A Fishbone Well Naming & Numbering Index KOP Planned 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-L01 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 1-116A-1-04 218-099 50-231-20051-63-00 20020 8-1/2" Open Hole completion 1-136A-1-05 218-100 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-L07 218-102 50-231-20051-66-00 1 21860 8-1/2" Open Hole completion KOP Planned Actual TO Actual Lateral Footage Lateral Volume (bbls) H -16A Mainbore 14552 22310 7758 544 L01 16382 16375 17440 1065 75 L02 17180 17130 18390 1260 88 L03 17980 18000 19268 1268 89 L04 18780 18770 20020 1250 88 L05 19580 19525 20743 1218 85 L06 20382 20270 21340 1070 75 L07 21180 21165 21860 695 49 Total 15584 1094 X (NAD27) Y (NAD27) TVDSS ND 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, T35, 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, T3S, R15W SM H16A-L03 KOP (Top of Production) 155830.73 2152708.02 -6883.44 7063.87 18000 4616' FSL, 4186' FEL, Sec. 33, T35, R15W SM TD 154839.79 2153390.79 -6517.97 6698.4 19268 5271' FSL, 5195' FEL, Sec. 33, T3S, R15W SM H36A-LO4 KOP (Top of Production) 155193.13 2153138.68 -6880.05 7060.48 18770 5029' FSL, 4835' FEL, Sec. 33, T3S, R15W SM TD 154212.01 2153816.15 -6536.42 6716.85 20020 396' FSL, 552' FEL, Sec. 29, T35, 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-LO6 KOP (Top of Production) 153976.65 2154013.78 -6887.9 7068.33 20270 587' FSL, 793' FEL, Sec. 29, US, R15W SM TD 153105.84 2154577.4 -6649.98 6830.41 21340 1126' FSL, 1678' FEL, Sec. 29, T35, R15W SM H16A-LO7 KOP (Top of Production) 153224.5 2154498.02 -6887.64 7068.07 21165 1050' FSL, 1558' FEL, Sec. 29, T3S, R15W SM TD 1 152675.82 2154902.24 -6759.78 6940.21 21860 1438' FSL, 2117' FEL, Sec. 29, T35, R15W SM e- 15 Ato d41 �4 le; 594 oo lot tot 011111 NABORS / CANRIG a t E-- Cq4 t&r- Operator: BlueCrest Alaska Operating O p LLC Date: H16A: (Bundle 11/20/2018 Well Name: L Main, L01, L02, L03, 1-04, 1_05, LO6, 1_07 prepared By: Alan Febus Location: Kenai Borough, Alaska 333 W 71h Ave, Suite 100 set(10 811 trays / set) Hansen Field Shipping: Anchorage, AK 99501 Envelopes) H16A Main Boxes & 258 Washed and Dried 30' Attn: Meredith Guhl (907)739-1235 Well: H16A: (Bundle 1- 6 boxes) Main, (Bundle 2- 7 Boxes) L01, L02, L031 L04, L05, L06, L07 1:5023120051-01- :5023120051-01-set set(10 811 trays / set) Type Frequency Interval (Feet / MD) Envelopes) H16A Main Boxes & 258 Washed and Dried 30' 14580'-22310' Lot (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 1 Los (1 BOX & 42 Envelopes) Washed and Dried 30' 19500'- 20743' TD Lob (1 BOX & 36 Envelopes) Washed and Dried 30' 20280'- 21340' TD L07 (1 BOX & 24 Envelopes) Washed and Dried 30' 21150'- 21860' TD I Number of Boxes: 13 8 Number of Envelopes: 531 Ind Number of Boxes: 13 RECEIVED Packaged into 2 Shipping Bundles NOV 2 6 2018 Bundle 1: Main (6 Boxes) AOGCC Number of Envelopes: 258 Bundle 2: L01, L02, 1-03, L04, L05, L06, L07 (7 Boxes) Number of Envelopes: 531 BLUECREST RIG #1 / JOB #: A1712 / WELL: H16A: L01, L02, L03, L04, L05, L06, L07 THE STATE Alaska Oil and Gas °fALAS-KA Conservation Commission GOVERNOR BILL WALKER Larry Burgess Alaska Manager BlueCrest Alaska Operating, LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Re: Hansen Field, Undefined Oil Pool, H16A-L03 BlueCrest Alaska Operating, LLC Permit to Drill Number: 218-098 Surface Location: 2408' FSL, 1509' FEL, SEC. 2, T4S, R15W, SM Bottomhole Location: 149' FSL, 156' FEL, SEC. 29, T3S, R15W, SM 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc,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. 50-231-2005 1-0 1- 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, (� ) Cathy P. Foerster �lJ� Commissioner DATED this a day of September, 2018. STATE OF ALASKA i ALA, -.,A OIL AND GAS CONSERVATION COMMISS.-A PERMIT TO DRILL 20 AAC 25.005 RECEIVE® JUL 26 2018 1a. Type of Work: 41bIrproposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ Drill v Lateral atigrephic Test v Development - Oil ❑ Service - Winj ❑ Single Zone Q Reentryxploretory-Oil Development -Ga Service - Supply ❑ Multiple Zone ❑ 1c. Specify (<�wgll' Coalbed Gd's-1 4�Reddll Geothermal ❑Shale Gas 2. Operator Name: BlueCrest Alaska Operating LLC a'+ - 5. Bond: Blanket O Single Well ❑ Bond No. 5511251547 - 11. Well Name and Number: H16A-L03 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 6. Proposed Depth: MD: 19,590' TVD: 6,559' 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: 4608' FSL, 4168' FEL, Sec. 33, T3S, R15W SM Total Depth: 149' FSL, 156' FEL, Sec. 29, T3S, R15W SM 7. Property Designation: ADL 18790, ADL 384403, Fee -Hansen S. DNR Approval Number: LOCI 14-007 13. Approximate Spud Date: 9/15/2018 9. Acres in Properly: 14423 14. Distance to Nearest Property: 3800' (YO1665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 168863 y- 2144856.073 Zone- 4 10. KB Elevation above MSL (ft): 180.4 GL / BF Elevation above MSL (ft): 145.81 15. Distance to Nearest Well Open to Same Pool: 251' - Hansen 1A -L1 16. Deviated wells: Kicko epthe{tF333 eet Maximum Holli Ae1f#"y 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 I Coupling Length MD TVD MD TVD (including stage data) 8.5 Open Hole Completion - L03 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 9-5/8" 178 bbls Tail 14767 7083 Production Liner Perforation Depth MD (ft): WA Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No ❑� 20. Attachments: Property Plat O BOP Sketch Diverter Sketch v Drilling Progrem Seabed Report Time v. Depth Plot Drilling Fluid Progrem 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: tom.mckayfi)bluecrestenemy.com Authorized Title: Ataskj Manager Contact Phone: 907-754-9566 AuthorizedSignature: Date: 26 -Jul -18 Commission Use Only Permit to Drill Number: 11 $ �- OQ $ API Nu er: 50- a3 - 00 51- sa.— QD Permit Approval Date: I � 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 methane, gas hydrates, or gas contained in shales: Other: t Hie �) P � -F-EVT 1 (5 Samples req'd: Yes ❑ No [9� Mud log req'd: Yes 1:140 'Jy f HzS measures: Yes ❑ No Y Directional svy req'd: Yest�o Spacing exception req'd: Yes [g'No ❑ Inclination -only svy req'd: Yes DO Post initial injection MIT mq'd: Yes [340 APPROVED BY 61 Approved by .� COMMISSIONER THE COMMISSION Date: "� I 1.11 PU75t�YJ-6 Form 10-401 Revised 5/2017 This permit is valid for 24 t o t e date of approval per 20 25005(g) D 161 NA i �'e! Submit Form and Attachs in DuiNl cate e B 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 7t' Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Application for Permit to Drill: Horizontal Production Well H16A — L03 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 — L03. 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, ��/ o/j4�`? — Larry Burgess Alaska Manager BlueCrest Alaska Operating LLC lue st Energy Application for Permit to Drill Document Horizontal Producer H16 -A — L03 Multilateral "Rib" Table of Contents Cosmopolitan Project H1 6-A- 10-401 L03 APD 1. Well Name...................................................................................................................3 Requirements of 20AAC25.005(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 Drilling Hazards Summary:.... ................................................................................................................. 6 5. 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 10. Seismic Analysis...........................................................................................................8 Requirements of 20 AA 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 AA 25.005 (c)(12)....................................................................................................... 9 13. Proposed Drilling Program............................................................................................9 Requirements of 20 AA 25.005 (c)(13)....................................................................................................... 9 1lPage H16 -A10-401 L03 APD lue st %Energy Cosmopolitan Project H16 -A10-401 L03 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 Drilling Procedure.................................................................................................................9 Attachment 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 21Paga H16 -A10-401 L03 APD tflue est Energy Cosmopolitan Project H16 -A-1 0-401 L03 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—L03 Multilateral "Rib" To include the L03 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-1-01, H16A-1.02, H16A-1.03, H16A-LO4, H16A-LOS, 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 1-03) is for the H16A L03 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 plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) 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 AAC 25.050(6); Location at Top of Productive Interval ("Starichkor Sand) 4608' FSL, 4168' FEL, Sec. 33, US, R15W SM ASP Zone NAD 17 Coordinates Measured Depth, RKB: 17,980' Northing: 2,152,699.77' Easting: 155,847.77' Total Vertical Depth, RKB: 7,066' Total Vertical Depth, SS: 6,886' Location at Total Depth Location at Surface - H16 Slot —same for hl 2408' FSL, 1509' FEL, Sec. 02, T4S, R15W SM ' Measured Depth, RKB: 19,590' ASP Zone 4 NAD 27 Coordinates 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 ("Starichkor Sand) 4608' FSL, 4168' FEL, Sec. 33, US, R15W SM ASP Zone NAD 17 Coordinates Measured Depth, RKB: 17,980' Northing: 2,152,699.77' Easting: 155,847.77' Total Vertical Depth, RKB: 7,066' Total Vertical Depth, SS: 6,886' Location at Total Depth 149' FSL, 156' FEL, Sec. 29, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,153,558' Easting: 154,601' Measured Depth, RKB: 19,590' Total Vertical Depth, RKB: 6,559' Total Vertical Depth, SS: 6,379' 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 (2) for oil wells within 200 feel of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail, or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 31Page H16•A 10.401 L03APD nue st Energy Cosmopolitan Project H16 -A 10-401 L03 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 (ROPE) as required by 20AAC 25.035, 10 AAC 25.036, or 20AAC 25.037, as applicable; Please see Attachment 5: BOP & 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 an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient, The 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 — 0.1 psi/ft) =2,842 psi (using ND 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. 4lPage H16 -A10-401 L03 APD r nue est Energy Pressure Model (EMW) 1000 2000 3000 4000 N N p 5000 Cosmopolitan Project H16 -A10-401 L03APD UpperTyonek,3292.44 Lower Tyonek, 6059.01 Starichkof, 6874.84 Hemlock, 6902.77 8000 1"' 8 9 10 li 12 13 14 15 16 17 18 19 20 EMW (PPG) —Lithostatic Stress • MDT Data —Frac Gradient —Moving Average —Planned Mud Weight 51 Page H16 -A10-401 L03 APD I, *1ye rgesk Cosmopolitan Project H16 -A10-401 L03 APD 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-%" Hole Section / 9-%" Casing 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 -Ya" 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 0 H16 -A10-401 L03 APD lue est Energy Cosmopolitan Project H16 -A-1 0-401 L03 APD S. 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 20AAC 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" Csg/Tbg Hole Size Weigh t Grade Conn Length TOP MD/TVD Btm MD/TVD Cement Program oD in I ) tin) Ob/R) IR) (R) (ft) 20" N/A .5001 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) 3,175 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' 6,688' 7,083' (in place) 14,255'/ 22,829'/ No cement required 4-1/2" 8-1/2" 15.2 P-110 Hydri1563 8,574' 6,870' 6,880' Slotted liner completion 100' liner 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 20AAC 25.035, unless this requirement is waived by the commission under 20 AAC25.035(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 # 1 BOP stack and choke manifold. 71Pag9 H16 -A10-401 L03 APD Dl ueN St Energy Cosmopolitan Project H16 -A10-401 L03APD 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 on item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 15.033; 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 ✓ (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 OBM — Low Solids Name ACTIMUL Reservoir Drill -In Density (PPB) 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 an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application fora 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: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20AAC 25.061(a), 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, exceptfor on item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom -founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 8lPage H16 -A10-401 L03 APD tSlueNest Energy Cosmopolitan Project H16 -A10-401 L03 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)hove 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 far hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10- 403) a403) with the information required under 10AAC 25.280 and 20 AAC 75.283; (13) a copy of the proposed drilling program, Please refer to Attachment 1— Drilling Procedure. Note: The H16A Fishbone Sidetrack and all laterals L01 through L07 will NOT be hydraulically stimulated. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20AAC25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 15.080 for an 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 Attachment 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 91Page H16 -A10-401 L03 APD lue, est Energy Attachment Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A 10-401 L03 APD Attachments lug est 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 -L07, 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 L01 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 TO 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 1-01 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 H1.6A_ APD Well Plan Last Updated: TWM, 31 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 MWD: N/A LWD: N/A 12-1/4" Open Hole H16 -A Fishbone Production Well (Main Bore / Lower Lateral / Starichkof / Hemlock Primary Target( Well will be sidetracked through window in 9-5/8" casing ACTUAL PUMPED 12.0 ppg Lead ---------------- 588 bbis 15.8 ppg Class G Tail s 198 bbis 3-1/2" Production Tubing to Surface GLM's / SSSV / DH Gauges / CIM P310 H563 ACTUAL PUMPED 15.8 ppg Class G 178 bbls Base of window depth in 9-5/8" casing: 14,362' MD/ 7,068' TVD (Lower Lat( liner Hgr &Liner Top Packer 9-5/8" 53.5# P110 H563 (14,767') 1 I Bit: 8-1/2" PDC I RSS: %ceed675 1 1 I MWD: Telescope 8-1/2" I I Un -cemented LWD: GeoSphere Open Hole I I Slotted Liner adnVISION i i No Frac's 4-1/2" 12.6# P310 H563 Slotted Liner JUn -Cemented Slotted Liner Completion 22.829' MD/ 6.880' TVD Total Depth in Mainbore Mud Incl 73 deg Inc] 78 deg Azim 303 de OBM 8.89.0 ppg VersaPro with MPD Max Ind 107 deg Azim 303 deg T. McKay, 121uly2018 H16A Lower Lateral Completion with 20" Conductor Slotted Liner in Mainbore and Seven @ 187' BGL (7) Open Hole Fishbone Ribs 13-3/8" 72# L80 BTC @ 4177' MD 3-%" 9.3# IBT-MOD Production Tubing 4-%" x 9-5/8" Liner Hanger & Liner Top Packer NOTE: Well will he sidetracked off a whipstock set at approx 14,350' MD in the 9-5/8" casing I 9-5/8" 47.0/53.5# P110 H563 @ 14767' MD Iue est Energy Fishbone ribs are 8-36" 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 L01 to L07 using open hole sidetracks to initiate each rib; ribs penetrate all layers of Starichkof and Hemlock pay sands 1.01 L02 L03 L04 L05 L06 L07 4-%N 17# H521 Slotted Liner @ 22829' MD H16A Fishbone Design lue est Energy Attachment 2 Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A10-401 L03 APD Attachments H16A - Table of Coordinates for Mainbore and Laterals L01 through L07 H16A Top of Productive Horizon Nearest Property Line MD X Y01665 Y Legal Main Wellbore 14632 158778.19 151874.00 2150581.45 2572' FSL, 1182' FEL, Sec. 33, T3S, R15W SM LOl 16382 157163.69 17722 2151793 49 1950' FSL. 2933' FEL. Sec. 29, T3S, R15W SM L02 17180 156506.56 L02 2152245.94 4173' FSL, 3498' FEL, Sec. 33, T35, R15W SM L03 17980 155847.77 4967FSL, 4721' FEL, Sec. 33, T3S, R15W SM 2152699.77 4608' FSL, 4168' FEL, Sec. 33, T3S, R15W SM L04 18780 155189.00 2153153.63 5044' FSL, 4839' FEL, Sec. 33, T35, R15W SM L05 19580 154530.21 2153607 47 196' FSL, 228' FEL, Sec. 29, T3S, R15W SM L06 20382 153869.79 153347.00 2154062.46 633' F%L9015 L, 901' FEL, Sec. 29, T3S, R15W SM L07 21107 153272.06 21745 2154473.31 1026' FSL1509' FEL, Sec. 29, T35, R15W SM H16A Total Depth Nearest Property Line MD X Y01665 V 5502 Legal Main Wellbore 22829 151874.00 L03 2155437.00 Y01665 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM LOl 17722 156120.00 2372 2152512.00 L061751 4428' FSL, 3891' FEL. Sec. 33, T3S, R15W SM L02 18730 155305.00 Y01665 2153074.00 4967FSL, 4721' FEL, Sec. 33, T3S, R15W SM L03 19590 154601.00 2153558.00 149' FSL, 156' FEL, Sec. 29, T35, R15W SM Loa 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 21745 152808.00 2154794.00 1334' FSL, 1982' FEL, Sec. 29, T3S, 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 LOl 5502 Y01665 L02 4595 Y01665 L03 3800 Y01665 L04 3066 Y01665 L05 2372 Y01665 L061751 Y01665 L07 1202 Y01665 IueCaiest Energy I ODI I ERD Ratio: GHd Conv4fgence Angle: H16A-L03 (P2) Proposal Geodetic Report (Def Plan) BlueCreat Cosmopolitan Unit Ccemopolilan Ped l H-16 H16 F����909 u41 HIM103 S21200516gy C4�J 5 0 2 July 10 2010 199 NAD275' 116]36.517la I6 966 12 360 * 59' Alaska SMM Plane, lane N. US Feet N 59.51'32.0MS..W151°465.01S N 2144855,90011U3. E 168062.230 f1U3 -1.5580 ° 1.0000240 210. Seen IdIInM ler VeNical Section Aalmutir 300.000°(Tme NOM) Vortical Section Origin: 0.000 ft, 0,000 B ND Reference Dila: Rotary Table TVD Reference Elevation: 180.430 ft above MSL Ground Elevation: 145.010 ft above MSL Magnetic Declination: 14 561 ° Total Gravity Fleld Strenglh: 1001.2613mgn (9.8060 Based) GravRy Model: DOX Total Magrwtic Field Strength: 55102 359 nT Magcetic Dip Angie: M.80° Declination Dale: September 302018 Magnetic Destination Mani; HDGM2010 NOM Reference: True NoM Oris C -Mone Uad: 00000 • Toel Corr Mag NOM�True NoM: 14.5612 AIDEa`uouuntaw Incl Azlm T. 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298.14 5521.5 5702.18 0134.35 3410.52 -7102.69 HS 0.30 26 64,28 49916.13 2148898.65 161886.9 9 11038 67.43 298.14 5554.97 9 3840 82 31.36 3009.59 -9259.10 90.89E 026 6 2 64.51 4901146 2148901.58 16161140 1%34.1 942 297.28 5594.06 5814.56 8310.11 3829.98 -]335.9 173.18 0.41 66277 6435 4991192 214894193 161635.% 1092839 6531 29553 563086 5810.89 4104.61 3969.41 -7412.89 21.31E 01 28 64.30 4925.9 2149025.99 16155964 11022.43 67.1 29533 3 1 58.26 811.31 4009.00 -0409.06 58 56R 0.51 6 629 6428 49925.35 2149060.03 1614.99 11116.30 65.57 298.66 57011 570313 5983.56 8518.80 409917 -0588.8532668 0.% 629 64.28 4988.27 2149152.1 1613080.31 11210.29 67.50 298.03 5739.39 59109 8664.05 4090.27 -781.32 164,65L 0.63 6.30 49882.57 214919.64 161332.37 11.20 396 9.90 73% 2.15.65 9 5956.% 957.31 41.87 33 -771985 91.5R 0.63 6.31 6419 64 19 49S21,31 214910.31 16129.31 11396.15 66.99 2%.30 5812.30 5992.00 8937.45 4111.52 -7896]5 043 6.32 73.65 49621.60 214923803 161102.21 192.. 5895 99 2.35 % 5848.60 6029.03 8924.14 42.72 -784249 975 1508&. 083 632 64.68 49864.90 211281.28 161101.01 11575.95 67.32 296.23 5964.50 6000.% %10.6 4253028 -094861 58846L 040 633 73.39 0986490 214932641 161031.03 1199.5 9.05 298.03 592088 6101.31 097.18 433511 602507 1511. 031 634 73.11 69780.65 214936522 1673%.1 9.25 297.9 599.39 613512 9183.18 4335.21 6101.55 9666E 6.34 6439 4979.83 2149409.% 160001.30 1189.% 11W.66 9.20 297.W 5993.73 6080.16 93%.28 4315.9 -98815 71.10R am 0.36 6.35 64.45 49792.28 214949.39 18%0588 11%1.53 67.32 2%.% 6030.02 621045 9356.18 4415.95 6254.83 ]61AR 0.39 635 64.45 4979398 2149473.93 160759.43 1205521 6236 2%.32 6246.54 9403.18 44%61 633102 0.13 6.36 60.45 49794.84 214953555 16%55.25 1214920 6545 20.30 610222 61M22 6212.65 489.03 640549 9648 RBAR 0.20 833 60.09 4980873 2149580.63 1609991 1221.19 67,00 2%.66 6138.30 6318.13 %W67 91666 4539.02 A 9.TT 1361E 035 6.37 73.33 4966663 214%24.09 180508.80 12331.73 6].% 2%. 81463 6355.10 9103.16 4580.25 6559.83 R 0.59 6.38 64.33 4963536 2149667.38160429.%12431M 121100 926 20.0 BO 3111.20 838183 989.89 6821.% 6635.98 1110211M8 0.59 6.38 73.14 49676.37 21/71018 173355.00 Drilling Once 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H14\H1AHI 4 (P5) 7/17/2018 2:44 PM Page 2 of 4 MD Incl A21m True TVDSS WD VSEC H6 EW TF DLS Dlmctlonal EaclValon Zom Eacleelon gene GeoMa9TH Nofting Eaeen9 Ca4n.� lRl 19 1°I fftl IRI IRI IRI Ifll (°) ('110011) olMculty Inez Alen Awe (nT) (AMS) (nus) 12524.87 67.12 29914 6247.61 6428.64 987620 4663.51 4711.58 1658. 0.36 6.39 63.93 49577.11 2149754.73 160280.47 12618.68 66.54 299.30 628452 6464.95 99s!.44 4705.61 4786.85 168.5L 0.64 640 63.33 49322.41 2149798.86 160206.37 1271272 66.27 299.24 6322.16 6502.59 10048.61 4747.74 4862.02 2506E 029 6.40 6309 49219.48 2149843.02 160132.36 12806.45 66.88 298.93 6359.42 6539.85 10134.60 4789.55 4937.18 140.36L 0.72 6.41 6376 49508.25 2149806.86 1611058.37 12900.53 66.35 298.45 6396]6 6577.19 10220.93 483100 4012.93 48.67L 0.73 642 63.40 49353.56 2149930.36 159983.77 12994.82 66.82 297.87 643423 6614.66 10307.41 4071.04 -908922 119.62L 075 6.42 64.02 49616.58 214997325 159908.63 13088.71 6640 297.06 6471.51 665194 10393.50 4911.58 -9165.68 1TWL 0.91 s43 63.86 49548.98 215001506 12983327 1318228 66.93 296.80 6500.57 668900 10479.30 4950.55 -9242.25 67.73R 0.59 644 6401 49702.04 2150058.09 159757.79 13276.03 67.07 297.25 6545.20 6725.63 10565.40 4989.81 4319.10 59.5911 039 644 64.44 49793.59 2150097A4 159682 03 13370.05 67.44 297.93 6581,55 6!6198 10652.11 5029.97 .4395.94 1003L 077 6,45 6459 49857.21 2150139 67 159 0 .30 13464.09 6/.29 29702 661715 6!98.18 10730.02 5070.01 -9472.95 9012L 0.91 6.45 64.71 49908.87 2150181.79 159530.41 13556.80 67.28 295.68 6653.55 6BI3.9B 10024.17 5107.97 -9549.58 47.94R 1.33 SAS 65,10 50065.93 2150221.02 159454.84 13650.66 67.38 295.80 6609.72 070.15 1091D.53 514550 .9627,60 99.87L 0.16 647 65.16 5009067 2150261.54 159377.88 13744.66 67.31 295.36 6725.93 6906.35 10997.02 5103.04 -970584 159.0L 044 647 65.22 50116.56 2150301.11 15930068 13838]4 67.04 29515 6762.43 6942.86 1100345 5120.10 -9784.23 0.14R 0.31 648 6500 500,26.41 2150340.29 15922332 13932.68 70.95 29516 6796.09 6976.52 11170.83 526/.51 -9863.53 951R 4.16 649 68.70 5143167 2150379.85 15914506 14026A8 7505 29597 6823.51 1003.94 11260.24 5296.29 -990.40 24.858 443 6.51 72.40 52617.49 2150420.81 15906528 14120.47 77.03 296.91 6646.19 7026.62 11351.28 5336.90 -15026.06 14.038 232 6.52 74.02 53087.32 215046363 1589M75 14214.46 79.71 297.59 6065.13 704556 1103.22 5379.05 -10107.90 4098 2.94 6.54 76.30 53&909 2150507.99 158904.09 Tisln Survey 14308.35 81.38 299.05 6880.56 706099 11535.79 542299 -1018942 20.358 2.35 6.55 77.55 53904.71 2150554.13 15882379 Top WSipetpck 14349.00 82.40 29943 6886.29 706632 11576.03 50265 -10224.54 20R 267 6.55 7842 54077.89 2150574.73 15878922 B.. WS 1436200 84.35 300.14 6887.79 7068.22 11586.94 50906 -10235.74 HS 16.00 6.56 80.08 5437149 2150581.45 158778.19 Cry 31100 14302.00 84.35 300.14 880976 7070.19 11606.85 5459.06 -10252.95 6oR 0.00 6.56 8008 54377.54 2150591.91 15876126 1000.00 84.62 30061 091.49 7071.92 11626.76 5468.12 -10268.41 5995R 300 6.56 00.21 54398.14 2150601.39 _ 150746.05 14500.00 86.13 303.22 6899.55 707998 11726.37 5520.81 -1035300 0,74R 3.00 6.50 80.92 54510.14 2150656.36 10662.92 14600.00 87,64 305.81 6904.99 708542 11825.90 5577.38 -1043527 596R 300 6.59 81.65 54617.10 2150715.15 150582.22 End Cry 14632.00 88.13 306.64 6906.17 708660 118570 55%38 -10161.07 HS 300 660 0189 54653.07 21WM74 10556.95 14700.00 88.13 306.64 6908.39 7088.82 1192520 5636.84 -1051560 HS 0.00 650 81.69 54650.17 2150776.77 158503.53 Cry 31100 14732.00 WAS 306.64 699A3 7089.86 11956.97 5655.92 -1054127 24.11L 000 6.60 8189 54650.21 2150796.54 150478.40 14800.00 0999 305.81 691055 7090.98 1202455 5696.10 -10596.11 24AL 3.00 6.61 83.91 51890.81 2150838.20 160424.66 EndCry 14017.40 9047 30559 6910.48 7090.91 12041.86 51216.25 -10610.24 HS 300 6.62 64A3 54941.42 2150808.73 156410.81 1490000 9047 305.59 6950.80 709023 12124.07 5754.32 -10677.41 HS 000 662 84.43 54941,47 2150390.61 15830.90 1500000 90.47 305.59 690099 7089.42 12223.59 5812.52 -10758.73 HS 000 6.0 84.43 54941.54 215095900 158265.27 15100.00 90.47 305.59 6908.17 7008.60 12323.11 5370,72 -1084004 HS 000 6.64 84.43 6494160 2151019.39 158185.57 15200.00 90.47 305.59 6907,35 7087.78 1242263 592892 -1092136 HS 000 664 84.43 5494166 215107918 158105.86 15300.00 90.47 305.59 6906.64 7086.97 12522.15 5987.12 -11002s7 HS am 665 64,43 54941]2 2151140.17 158026.16 15400.00 90.47 30559 690572 7086.15 1262167 604532 -1108399 HS 0.00 US 84.43 64941.78 215120056 157946,45 15500,.00 90.47 305.59 6904.90 7085.33 1272t20 6103.52 -1116530 HS 0.00 6.66 84.43 54941.84 2151260.95 157866.75 15600.00 90.47 30559 690409 7084.52 12820.72 616172 -11246.62 HS 0.00 667 64.43 54941,90 215132134 157187.01 15700.00 90.47 30.5.59 6903.27 7083.70 1292024 621992 -11327.93 HS 0.00. 667 84.43 54941.96 2151381]3 1MMN 1585000 9047 305.59 6902,45 7082.80 1301976 6278.12 -11409.25 HS 0.00 668 84.43 54942.01 2151442.12 157627.63 15900.0 90.47 30559 6901.64 7082.07 1311928 6336.32 -11490.56 HS 0.00 6.69 84.43 54942.07 2151502.51 157547.93 1000000 90.47 30559 6900,82 7081.25 13218.80 6394.52 -11571.08 HS 0.00 6.69 84.43 64942.12 215156290 157468.23 1610000 90,47 305.59 6900.00 7080.43 13318.32 645232 -11653.19 HS 0.00 8.70 84.43 54942.18 2151623.29 157388.52 1625000 90.47 30559 6899.19 7079.62 13417.84 6510.92 -11734.51 HS 0.00 670 64A3 54942.23 2151683.68 157308.82 1635000 90.47 30559 6898.37 7078.80 13517.36 6569.12 -11815.82 HS 0.00 611 84.43 5494228 2151744.08 157229.11 Cry 31100 16330.86 80.47 30559 6898.12 1078.55 13548.08 6507.00 -1184092 10.BL 0.00 671 84.43 54942.30 2151762.71 15720451 KOP Cry 21100 1638200 91.97 305.30 689703 7077.46 13598.97 661673 -11802.9 LS 3.00 6.72 85.96 55065.59 2151793.49 15710,69 16400.00 9161 305.30 689647 7076.90 13616.08 6627.13 -1189725 LS 2.00 6.72 8561 55041.10 2151004.28 157149.29 cNW100 1648200 8997 305.30 689533 7075.76 13698.52 6674.51 -11964.16 83,09L 2.00 6.73 84.04 54904.16 2151053.47 15708369 1650000 9002 304.95 6895.33 707576 1371645 6684.87 .11978.80 8309L 2.00 6.73 84.18 54918.06 2151864.22 157069.26 16600.00 90.26 302.96 609509 7075.52 1301821 674072 -12061.83 83.09L 2.00 0.74 84.96 54909.9 2151922.31 156987,86 End Cry 16631.55 9033 302.34 609492 7075.35 13047.72 675774 -12000.39 Hs 2.00 6.75 8521 55010.00 2151940.04 15696177 16700.00 9033 302.34 6894.53 7074% 13916.11 6794.35 -12146.22 HS 000 6.75 0521 55010.11 2151978.21 15690495 16800.00 90.33 302.34 6693.94 707437 1401803 6647,84 -12230.72 HS 0.00 6.75 85.21 55010.16 2152033.9015682184 16900.00 9033 302.34 6893.36 707379 14115.94 8901.32 -12315.21 HS 0.00 6.76 8521 5501021 2152089.74 _ 156738.93 1700000 90.33 302.34 689277 7073.20 14215.86 6954.81 -12399.70 HS 0.00 6.77 0521 550,1026 2152145.51 156655.93 17100.00 9033 30234 6892.19 707262 1431577 7008.30 -12484.19 HS 0.00 6.77 05.21 55010.30 215220128 156572.92 Ory 3100 17126.11 9033 302.34 689204 7072A7 1434186 7022.26 -12506.25 5.6311 0.00 6.77 05.21 55010.32 2152215.83 15655115 KOP Cm 21100 17100.00 9194 30249 689096 707139 1439569 7051.14 -12551.73 LS 3.00 878 06.71 5511200 2152245.94 15650656 1720000 91.64 302.49 6890.36 707079 1015,66 71161.08 -12588.59 LS 2.00 678 06.33 55089.63 215229.14 156490.00 Crv21150 17200.00 09.94 30249 6889.32 706975 1095.50 7101.86 -1263606 639311 2.00 6.79 64.79 5495.13 2152301.93 15642372 1730000 90.12 302.85 6889.31 7069.74 1451556 7115.65 -1265290 63.938 200 6.79 84.86 54981.05 215231318 156407.19 End Cry 17313.31 9024 303.09 8809.27 7069.70 14528.85 712290 -12664.9 HS 250 6.79 64.91 54984.9 2152320.73 156396.22 17400.00 9024 30309 6888.91 7069.34 14615.41 7170.23 -12736.69 HS 0.00 6.00 04.91 64985.01 2152370.02 156324.91 1750000 9024 303.09 6898.50 7060.93 14715.27 7224.83 -1282047 HS 000 6,50 04.91 64985.05 215242687 156242.64 17600.00 90.24 303.09 6888.08 7068.51 14815.12 7279.43 -1290125 HS 000 6.81 04.91 5198.5.10 2152483.73 156160.38 17700.00 90.24 303.09 6887.67 706010 14914.97 7331.03 -12960.02 HS 000 662 04.91 54985.14 2152510.59 156078.11 1780000 90.24 303.09 688726 7067,69 15014.83 7388.63 -13071.80 HS 000 6.82 04.91 20985.18 215259145 155995.85 17900.00 90.24 303.09 6886.84 706727 15114.68 7443.23 -13155.58 HS 0.00 6.83 64.91 54985.23 2152654.31 15591359 Cry 31100 17923.37 9024 303.09 668675 7067.18 15138.01 7455.98 -13175.15 1.07L 0.00 6.83 84.91 56985.24 2152667.59 155894.36 17982.16 92.00 303.06 6865.50 7066.03 15196.70 748806 -13224.41 0.24L 300 6.83 B661 55106.49 2152701.00 155846.00 18000.00 92.54 30306 6884.89 706532 15214.51 749.79 -13239.35 0.24L 300 6.81 87.13 55133.57 2152711.13 15503133 1010000 95.54 30305 6871.86 7050.29 15314.11 7552.19 -13322.95 024E 300 6.85 89.99 55202.9 2152767.78 155749.24 18200.00 98.54 30303 686561 7046.04 1541320 7606.29 -13406.14 0.24L 300 6.86 07.10 55132.18 2152824.13 155667.55 10300.00 101.54 3039 6848.19 702862 15511.52 7659.95 -13188.69 0.24L 3.00 89 64.22 6492172 2152880.02 155586.48 EndC, 18336.20 102.62 303.02 6840.61 702104 1554687 767924 -13518.37 HS 3.00 688 03.17 5481122 2152900.10 155557.34 18400.00 102.82 30302 682667 709.10 1560805 7713.16 -13570.58 HS 000 6.88 83.17 6401102 2152935.43 155506.9 Cry&100 18468.63 19.62 303.02 681168 699211 15675.93 7749.65 -1362674 023E 0.00 688 83.17 5481081 2152973.44 155450.93 18500.00 103.% 303.01 6804.57 6985.00 15700.44 776630 -13652.35 0.23E 300 6.89 82.27 6470031 215299078 155425.77 18600.00 106.% 30300 6778.59 0959.02 1580266 7818.89 -13733.33 024L 300 6.90 79.39 64257.54 2153645.65 155346.25 Drilling Office 2.10.302.0 Cosmopolitan Unit\Cosmoplitan Pad\H14\H14\H74 (P5) 7/17/2018 2:44 PM Page 3 of 4 Drilling Office 2.10.302.0 Cosmopolitan UnitXCosmoPlitan Pad\H74\H14\H14(P5) 7/17/20182:44 PM Page 4 of MD Ind Auden True NDSS 1VD VSEC NS EW TF DLS Eacluemn Zone Eadusion Zox GeDMapin Ne(Mrs) Extlnp Cammem. (el 1% 1°I IRI IR) IRI IR) IR) 1°I 1'/100%1 dDinsufflonaletyInex Dlnroulry Index Alen Anpla MT) (Ru5 RUG 18700.00 109 56 302.99 6]4].59 6926.02 1599199 782066 -1381306 O24L 300 691 ]651 53663.96 2153099.47 155267.96 18800.60 112.56 3029) 6711.65 688208 15990.99 792145 -1309133 0.251- 3.00 692 7321 52848.16 2153152.37 155181.09 16614.60 11300 302.97 6706.60 6886.13 16004.41 7920.]7 0.621-HS 3.00 6.93 7311 52649.16 2153160.00 155180.00 End Civ 18804.12 115.09 302.95 66)160 6856.11 16062.62 7963.31 .13902.83 -1395590 HS 300 6.93 7121 52258.09 2153195.59 155127.69 18900.00 115.09 302.95 6620.95 6851.98 16082.18 9991.13 -13969.96 HG 0.00 693 7121 52258.79 215320442 155115.64 19000.00 115.09 302.95 6620.55 6.98 16172.63 8020.39 -1404397 HG 000 6.94 71.21 52258.18 215325542 155041.20 19100.00 115.09 302.95 6596.15 6]66766.56 1628307 8069.84 -1411997 HS 000 6.94 71.21 52252.57 2153306.93 15486856 19200.00 115.09 302.95 6543.75 6724.18 1635352 0110.90 -14195.50 HG DAO 6.95 7121 52256.96 2153358.03 154891.92 0 115.091 30295 650136 6691.79 16443.87 0180.15 -14271.96 HS 0.00 6.95 7121 52256.35 2153409.33 151842.29 19400.00 INOD 11509 302.95 6456.86 6639.39 16534 0217,40 -14349.98 HS 0.00 6.96 7121 52255]4 2153460.94 154742.05 19500.00 115.09 302 95 641656 6596.99 077 1662487 8268 88 -14423.96 HS 0.00 696 7121 52255.13 2153511.90 154668631 TD 19589.78 • 115.09 302.95 6378.50 • 6550.93 16706.07 0310.00 -14492.22 0.00 8.97 7121 52254.50 215355000 154601630 Survey Error M.Cul: ISCWSA Rev 0--' 3D 95000% Confidence 2.7955 sigma Survey Program: MD Frain MDT. EOU Fre, Hou Size Casillg0lamamr E.pacletlNn De.ariptl.n Pert IRI (R) (ft) Ilnl Ilnl Indlxtl.n Ida.t Survey Tool Type Borehole I Surxy 1 0000 12WAOD Act Sure 11500 13.375 SLB_CNSG•CASING H1WB11 H16PB1 1 1200.000 412&070 ACI She 11500 13375 SLB_MWDWM4G H16RB11 H16PB1 1 4126.070 14308.350 Act Sins 12250 9.625 SLB MWD+GMAG H16PB1 I H16PS1 1 14308.350 14319000 11100.000 12.250 9625 GLB_MWD+GMAG 1416A{01 I H16A.L01(P2) 1 143496300 14800.000 11100.000 8.500 0,000 SLB-MWD-INC-ONLY-FILLER H16A101 I H16A101(P2) 1 14800.000 16300.000 1/100000 8.500 0.000 SLB_MWD+SAG 1116A-L01 I H16Al01(P2) 2 14800.000 16382.000 11100.000 8.500 0.000 SLB_MWD+GMAG H16A101 I H16A101(P2) 2 16382.000 171806300 1/100000 8.500 0000 SLB_MWD+GMAG H16A 021W1-L02(P2) 2 17180.000 191 1/100000 8.500 0.000 SLB MWD+GMAG H16AiWIH16A103(P2) Drilling Office 2.10.302.0 Cosmopolitan UnitXCosmoPlitan Pad\H74\H14\H14(P5) 7/17/20182:44 PM Page 4 of (.mavmanncro a.cortx, o.00rto nao.00• Venrtei Senim(R) wEsr ml Ensr G VMIUI5MI0nAme N.W Rx, 0.Y0Rq OfUO.W° Vmld 9edcn lh) WEST (hi FAST H16A-L03 (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10, 2018 -11:26 Analysis Method: 3D Least Distance Client: BlueCrest Reference Trajectory: H16A-L03(P2)(Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (ft) Structure: Cosmopolitan Pad Rule Set: D&M AntiColliston 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-1.03 Database l Project: IocalhosiWnlling-Cook Inlet Scan MD Range: 17180.00%- 19589.78ft ISCWSA03-D 95.000%Confidence 2.7955 sigma, for subject well. For Tralecrory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not Pelfonnedl Selection filters: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Nen-Def Surveys when r1U Def -Survey is set in a borehole - All Nan -Def Plans when no Det -Plan is set in a borehole Offset TrajectorySe Allow Sep. Controlling Reference Tra acro Risk Level Alert Status CtCt 11MAS Raration EOU(fillDev. R Fact. Rule MD @ TVD ft Alert Minor Me Or Major major H16A-L02(P2)(Def Plan) Fail Major 0.00 32].56 -218]0 -32756 0.00 OSF1.50 17180.00 7071.39 0SF15.00 0SF11.50 OSF<1.00 Enter Major 0.04 11].68 -78]4 -11].60 -0.01 OSF1.50 1719000 7071.07 MinPt-O-SF 70.89 10633 -0.59 -35.84 0.99 OSF1.50 17670.00 7068.22 OSF>1.00 all Major 102.33 103.44 33.04 -1.11 1.48 OSF1.50 17800.00 7067.69 OSF>1.50 Exit Minor 321.35 97.14 256.26 224.21 5.00 OSF1.50 18660.00 6941.01 OSF15.00 &it Alen 854.85 73.86 805.29 780.99 17.58 OSF1.W 19589.78 6558.93 TD H16POI (Def Survey) Fail Major 82.49 288.50 -110.17 -206.01 043 OSF1.50 17160.00 7071.39 OSFa5.00 OSF<1.50 CSFC00 Enter Major 5876 28].79 -1334 -229.03 0.30 OSF1.50 1796000 ]066.67 MinPa 58.50 28].13 -133.25 -228.63 0,WI OSF1.50 17990.00 7M.74 Min% -0 -SF 58.48 286.44 -132.83 -227.98 0.30 OSF1.W 18010.00 7064.86 MInPt-CtCt 12910 198.00 -2.63 -68.30 0.98 OSFi.50 18570.00 6967.34 0SF>1.00 Exit Major 1]].93 179.13 58.18 -1.20 1.49 OSF1.W 18720.00 6921.22 OSF>1.50 Exit Minor 494]0 156.11 390.27 MB.59 4.78 OSF1.50 19589.78 6558.93 TO H16 (Def Survey) Fail Major 82.49 2M,W 410.17 -206.01 0.43 OSF1SO 17180.00 ]0]1.39 OSF<5.00 OSF�1.50 OSF<I,W Enter Major 64.62 287.89 -127.64 223.27 0.33 OSF1.W 17780.00 7067.77 MinPt-0-ADP 64.39 287.59 -127.68 -223.20 0.33 OSF1.50 17]90.00 7067.73 MINPTA-EOU 6408 286.74 -127.41 -222.66 0.33 OSF1.50 17810.00 7067.65 MinPt-OSF 63.9 285.49 -126.69 -221.52 0.33 OSF1.50 17830.00 7067.56 M1nPt.CtCt 124.10 188.92 -2.17 -64.81 0.98 OSF1.W 18320.00 7024.52 OSF>1.W Exit Major 163.34 165.15 52.91 -1.81 1.48 OSF1.50 18510.00 6982.63 OSF>1.50 all Mirror 462.81 140.52 368.80 322.29 4.96 OSF1.50 19340.00 6664.83 OSF>5.00 Exit Alert 556.11 139.89 462.52 416.22 5.99 OSF1.50 19589.78 6558.93 TD Hansen Nl AL1 (Oaf Survey) Fail Major 511.08 572.11 129.34 4t1.03 1.30 OSF1.50 17180.00 7071.39 OSF<5.00 OSF11.50 Enter Minor 427.30 546.87 62,39= 1.17 OSF1.60 17570.00 7068.64 MinPtA ADP 42516 544.42 61.69 -119.2 1.1 O5F1.50 17580.00 7068.55 MinPt-OSF 42420 543.1 61] -118.92 1.17 OSF1.50 17600.00 7068.51 MINPTA-EOU 41].80 518.55 71.18 -100.74 1.21 OSF1.50 17740.00 7067.93 MInR-CtCt 436.66 437.95 144.37 -1.29 1.50 OSF1.50 18090.00 705913 OSF>1.M Exit Minor 429.93 430.20 142.80 -0.27 1.50 OSF1.50 18300.00 7028.62 OSF<1.50 Enter Minor 353.33 529.83 -0.22 -176.50 1.00 OSF1.W 187]000 6903.38 OSF<1.00 Enter Major 250.68 735.1 -239.79 -484.07 0.5-11 OSF1.M 19330.00 6669.07 Min% 265.49 692.04 -196.28 426.54 0.57 OSF1.50 19589.78 6558.93 TD Hansen #1 (Def Survey) 700.37 ]00.0] 233.33 0.30 1.50 OSF150 17111 ]0]1.39 699.06 701.43 231.11 -237 1.49 OSF1.50 17190.00 7071.07 659.53 753.05 15].1] -93.52 1.31 O1 1]860.00 7067.44 OSF>5.00 659.59 753.21 157.12 .93.621 O1 1]880,00 7067.36 OSF<5.00 70600 ]08.9] 233.03 -2.96 1.49 O1 18370.00 7013.66 1435.91 440.34 1141.91 995.57 4.90 OSF1.50 19589.78 6558.93 H16A.1 01 (P2) (Def Plan) Enter Alert Mill Mii 169.54 96861 104,641 n.681 2.64 OSF1.50 1718000 70]1.39 295.52 89.89 23526 205.62 4.97 OSFt50 17510.00 7068.88 184804 75.59 1]9].31 1]]244 37.13 OSF1.50 1958978 6558.93 Hansen #1A (Def Survey) MinPtClC:t MInPt-=t MINPT-O-EOU 724.97 696.46 260.33 28.50 1.56 0SF1.50 17180.00 7071.39 Y10.80 712.58 245.42 8.22 1.52 0SF1.W 17350.00 7069.54 n2.33 718.15[::] 43.2 6.18 1.51 0SF1.W 1]430.00 ]089.21 724.68 720.96 243.70 3,711 1,511 0SF1.150 17480.00 ]069.01 1372.17 686.69 914.05 685.48 3.00 OSF1.50 19589.78 6558.93 1412103 (Nor-Od Survey) Waming Alert O81F<5.00 Enter Alert MinPts 85684 302.77 654.67 554.07 425 OSF1.50 17180.00 7071.39 i 304. 641.22 540.10 4.17 OSF1.W 17690.00 ]068.14 OSF>5.00 844.45 304.35 641.22 540.10 4.1 OSF1.W 17700.00 7068.10 836.51 305.97 632.20 530.53 4.11 OSF1.W 18120.00 7056.25 830.40 305.83 626.19 524.5 4.0 OSF1.W 18410.00 ]004.92 830.28 305.76 626.11 524.52 4.08 0SF1.W 18430.00 7000.55 830.26 305.7,'L__62.6=1 1 A 524.53 4.08 0SF1.1% 18440.00 8998.36 830.2 305.70 626.13 524.56 4.08 OSF1.50 18450.00 6996.18 630.27 305.25 626.45 525.02 iiiiiiii4. OSF1.W 18620.00 6953.22 824.50 303.83 621.62 520.6 4.08 OSFI.50 18790.00 6895.90 824.01 303.57 621.W 520.44 4.08 OSF1.50 18830.00 6880.36 823.95 303.50L_621.29 520,45 4.08 O1 18840.00 6876.35 823.91 303.38 621.33 520.54 4.08 OSF1.W 18860.00 8868.20 827.] 304.62 624.37 523.15 4.08 OSF1.50 19310.00 66A.55 827.80 304.8 624. 523.11 408 OSF1,W 1933000 6669.07 827.83 304.72 624.3 523.11j 4.08 O1 19340.00 6664.83 828.35 305.01 624.68 523.34 408 OSF1.W 19420.00 6630.91 830.70 305]6 626.53 524.94 4.08 OSF1.W 19589,78 6558.93 H12.1.02 (Non -Def Survey) 856.84 302.75 654.68 55409 4.25 OSF1.W 17180.00 ]071.39 8432 304.83 639.70 538.42 4.16 OSF1.150 17]80.00 7007.77 84326 304.86 639.69 53840 4.16 OSF1.50 17790.00 706733 842.5 305.68 638.47 53691 4.14 OSFLW 17930.00 ]06].14 842.00 305.7 63846 5360 4.14 OSF1,W 17940.00 ]06].04 842.86 305]5 638.5) 536.92 4.14 0i 179130.00 7066.67 844.50 306.30 639.88 536.21 4.1 OSF1.W 18090.00 7059.23 856.53 307.03 651.52 549.50 4.1 OSF1.W 18468.63 6992.11 829.31 M7.061 59].60 48225 3.59 OSF1.50 19350.00 6660.59 8292 346.88 597.69 482.39 3.59 OSF1.W 19360.00 6656.35 861.09 331.18 639.97 52991 391 O1 19569]8 6558.93 H12-1-04 (Nor,Del Survey) 856.84 302.]] 654.67 5540] 425 0SF1.50 17180.00 ]0]1.39 84444 304, 641.2 540.10 417 OSF1.W 17690.00 7068.14 844.45 304.35 641.22 540.1 41 OSF1.50 17]00.00 7008.10 836.51 305.97 632.20 530.53 4.11 O1 18120.00 7058.25 830.37 305.81 626.1] 524.58 4.08 OSF1.W 18410.00 7004.92 830.14 305.67 626.031 ] 4.08 OSF1.W 18440.00 6998.36 830.11 305.62 626.03 524.49 4.08 01 18450,00 6996.18 r-FO.A 305.52 626.08 524.57 4.08 Oi 18468.63 6992.11 924.11 278.41 738.18 645]0 4.99 OSF1.W 1939000 6843.63 Fail Minor OSFa5.00 Enter Alert OSF<1.50 Enter Minor WrPt-CtOt MinFts OSF>1.50 Exit Minor TD Warning Alert OSF<5.00 Enter Alert OSF>5.00 Exit Alert TD Warning Alert OSF<5.00 Enter Alert Min%-01Ct MINPT43-EDU Mirl TD Warning Alm OSF<5.00 Enter Alert Mill Mii MinPtClCt WnPt-0-SF MInPt-0-ADP MINPT-O-EOU Min%CICt Mine[ -O -SF Ming O -SF MinPt-O-ADP MINPT-O-EOU MinPtClC:t MInPt-=t MINPT-O-EOU MinR-O-ADP MinPt-O-SF TD Warning Alart OSF<5.00 Enter Alert MInPt-C1Ct MINPT-O-ECU MInPFOtCt Knots MinPt-O-SF MinPt-O-SF MinPt-O-Sf Knots MinPtClCt TD Waming Alert O81F<5.00 Enter Alert MinPts Mal MinPtCtCt MinPt-O-SF MInPt-O-ADP MINPT-O-EOU Mine CICt OSF>5.00 Exit Alert 95B.88 273.18 ]]6.43 685.70 5.28 OSF1.50 19589]8 6558.93 TO 1112-1-06 (Non-Def Survey) Warning Alert 856.84 302.76 65467 554.08 4.25 OSF1.50 17180.00 7071.39 OSF<5.00 Enter Alert 844. 304A= 540.11 4.17 OSF1.50 17690.00 7068.14 MlnPts 844.45 304.34 41 211 540.11 4. IJI OSF1.50 1]]0000 7068.10 Mine 836.51 305.97 63220 530.54 4.11 OSF1.50 18120.00 7056.25 Min%-CtCt 8311.37 305.80 626.17 524.56 4.08 OSF1.W 18410.00 7004.92 MlePEO-SF 830.14 305.67 626.04 524.48 4.08 OSF1.9 18440.00 6998.36 MInPE0-ADP 830.11 305.Uj U6,031 524.49 4.08 OSFi.W 18450.00 6998.18 MINPT43-EOU 830.09 305.51 626.08 524.58 6.08 OSF1.9 18468.63 6992.11 MinPt-CtCt 922.66 278.20 736.86 646.45 6.99 OSF1.9 19370.00 6652.11 OSF>5.00 Exit Alert 965.57 267.68 786.78 697.88 5.43 OSFi.M 19589.]8 6558.93 TD 1112-1-05 (NornDef Survey) Waming Alert 85684 302.76 654.6] 554.08 425 OSFi.W 17180.00 7071.39 OSF<5.00 Enter Alen 844. 304. 641.22 540.11 4.17 OSF1.9 17690.00 7068.14 Mtn% 844.45 304.35 641,23U 54G.1 111 4.1 OSF1.W 177M 00 7068.10 MinPls 836.51 305.97 632.20 580.54 4.11 OSF1.W 18120.00 7058.25 MinM.CtCt 830.37 305.81 626.17 524.56 6.08 OSF1.5O 18410.00 7004.92 MinPt43-SF 830.14 305.67 62604 524.48 4.06 OSF1.W 18440.00 6998.36 MInPt-O-ADP 830.11 305.62 626.03 524.49 4.08 OSF1.W 1849.00 6996.18 MINPT-O-EOU 830.09 305.51 626.08 524.9 4.08 OSF1.W 18468.63 6992.11 MinPt-CtCt 922.66 278.21 736.86 644.45 4.99 OSF1.9 19370.00 6652.11 OSF>5.00 Fait Alen 965.57 MT69 ]86.]8 697.88 5.43 OSF1.50 19589.78 6558.93 TO H12 (Non-Def Survey) Warning Alen 856.84 302.76 65,167 554.08 4.25 OSF1.50 1718000 ]0]1.39 OSF<5.00 Enter Alen 844 304. 64L2 540.12 4.17 OSF1.50 1769000 7068.14 Mine 844.45 304.34 w.211 mo 1 lu 4.1 OSF1.50 17700.00 M68.10 MinPts 836.51 305.96 632.21 530.55 4.11 OSF1.W 18120.00 7056.25 MinN.CtCt 830.37 305.80 1326.17 524.57 4.08 OSF1.W 18410.00 mm.92 MinPEO-SF 630.14 305.66 U6.13,11 524.40 4.08 OSF1.W 18440.00 6998.36 MhPE-0ADP 830.11 305.61 96.04 524.9 4.08 OSF1.9 18450.00 6996.18 MINPTO-EOU 830.09 305.50 626.09 524.58 4.08 OSF1.W 18/58.63 6992.11 Minl4ctCt 922.66 278.20 736.87 644.46 4.99 OSF1.50 19370.00 6652.11 OSF15.00 Exit Alen 965.57 267.68 768.79 697.89 5.43 OSHZI) 19589.78 6558.93 TO 1112-101 (Non-Def Survey) Warning Alen 86461 302.72 662,261MI.691 429 OSFL50 17180.00 7071.39 OSF<5.00 Enter Alen 88799 3M.25 10 7068.59 MinP6 887.68 301.31 68648 586.37 443 OSF1.W 1]69.00 7058.31 Ming-CtCt 915.47 314.81 7052 600.6 4.3 OSF1.60 18336.20 7021.04 Min% 969.01 292.25 ]]386 6]6.]7 4.99 OSF1.W 18610.00 6956.14 OSF15.00 Exd Alen 1539.45 185.30 1415.59 1354.15 12.52 OSF1.W 19589.78 6558.93 TO H14PB2 (Def Survey) Pass 13560] 290.38 1161.15 1064.68 7.02 OSF1S0 17740.00 ]06].93 MinPt-OtCt 1355.13 290.5 1161.12 1064.61 7.02 OSF1.W M70.00 7067.81 MINPT-O-EOU 1355.26 290.68 1161.1 1064.58 7.01 OSF1.50 17800.00 ]06].69 MinPl-O-ADP 1355.16 292.73 1159.67 1062.43 6.96 OSF1.W 181W.00 7051.58 MinPt-C1Ct 1355.1] 292.]6 1159.6 1062,41 6.96 OSF1.9 1817000 70W.H MlnPIs 1355.54 292.90 1159.95 1062. 6.9 OSF1.50 16220.00 ]042.9] MinFrt-0-SF 1364.42 293.98 1158.11 1070. 6.9 OSF1.W 18520.N 6980.21 MMR.O-SF 1369.26 4W.221 11M.111 969.031 SA41 OSF1.W 18730.00 6917.75 MinPts 1645.31 33809 1419.59 1307.22 TM OSF1.50 19589.78 6558.93 TO H14P61(Def Survey) Pass 15104 287.5 1318. 1222.91 ).9 OSF1.W 17180.00 7071.39 MInPN 1467.98 293.7 1271. 1174.24 7.52 OSF1.W 1M70.N ]013.66 Mir is 146].99 293.75 12]1. 11]4.24 7.52 OSF1.W 18380.00 7011.47 MinR-0-ADP 1468.W 293.89 1272.24 1174.61 7.52 OSF1.W 18490.N 6987.32 MInPE0-SF 1558.13 281.12 1370.39 1277.01 8.34 OSF4.W 19589.78 6558.93 TO H14PB3(Def Survey) H14 (Def Survey) Stanshkof State 1(Def Survey) 15]14 1676.19 288.1 13]9.0 1283.3 8.20 OSF1b0 17180.00 7071.39 1564.25 291.58 1369.54 1272.68 8.07 OSF1.50 17850.00 7067.48 1564.27 291.62 13119.5 1272.65 607 OSF1.50 17860.00 ]06].44 1564.31 291.67 1369 12]2. 8.07 OSF1.W 17870.00 7067.0 1564. 293.85 136835 12]0.]3 8.01 OSF1.W 1824D.00 ]038.69 1584.59 9 A 136834 MAC= 12]0.]1 6.01 OSF1.0 18250.00 ]03].97 1564.62 293.92 1368.35 12]0.]0 8.01 OSF1.W 18260.00 7036.21 1565.02 294.06 1368.65 1270.96 8 ml OSF1.50 18310.00 7026.59 1585.58 295.94 1387.96 1289.6 8.06 OSF1.50 18820.00 6884.31 1582.83 294.85 13M.9411 1289 8.07 OSF1.W 1908000 677508 1562]4 2941 1385.9 128800 8.08 OSF1.W 1910000 6766.58 1582]1 294.57 1386.00 1288.14 8.08 OSF1.W 19130.00 6753.86 1603.79 290.15 1410.03 1313.64 8.31 OSF1.W 19589.]8 6558.93 16]9.]6 289.6 1486. 1390.1 8.72 OSF1.W 1]180.00 ]0]1.39 1680.34 2N.75 1486.65 1390.59 872 OSF1.W fl20D.00 ]070.]9 1682.10 290.09 1488.38 1392,011 8,721O5F1.W 17277.18 ]069.]5 168340 290.34 1489.51 139306 8]2 OSF1.W 1738000 7069.W 1684.67 291.qL_jA90.32JL 393.63 8.71 OSF1.50 17480.00 7069.01 1684.]0 291.07 149032 13936 8.71 OSF1.W 17490.00 7068.97 1683.49 292.]8 148].9] 1390.70 8.65 OSF1.W 17810.0 ]06].65 1668.76 297.0 1470.39 137169 8.45 OSF1.W 18870.0 693].84 1666.81 29209 14]0.42 13]1 ]2 8.45 OSF1.W 18690.00 6931.34 1727.63 292.98 1531.99 143466 8.87 OSF1.50 19589.78 6556.93 16151 1568 181 151467 1565 3733.20 96.25 3668.70 3636.95 58.76 OSF1.50 1]180.00 ]0]1.39 OSF1.50 19589.78 655893 Cosmopolitan SURe 1 (Def Survey) 1986.33 187.59 1857.161 1798.731 16.891 OSF1.W 19589.78 655893 Pass Wets MInPt-CtCt MINPT-O-EOU MinR,O-ADP mhPt-CtCt MINPT-O-EOU Min% -O -ADP MinP(.O-SF MinPt-O-SF MInPI-O-ADP MINPT-O-EOU MMPI-CtCt TD Pass MimPos MInPt-O-SF MinPt-O-SF MInM.O-SF MINPT-O-EOU MmPt-O-ADP MinPt-CtCt Mln MinPt-O-SF TD Pass _ MinPts TD Pass MlnPts Offset Trajeclory I Separation I Allow I Sep. I Controlling I Reference Trajectory I Risk Level H16A-L02(P2)(Def Plan) H16A-1_03 (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10. 2018 -11:29 Analysis Method: Normal Plane Client: BlueCrest Reference Trajectory: H16A.L03 (P2) (Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (0) Structure: Cosmopolitan Pad Rule Set: D&M AnfiColljsion Standard 5002 v5.115.2 Slot: H-16 Min Pts: All local minima indicated, Well: H16 Version I Patch: 2.10.544.0 Borehole: H16A-1_03 Database l Project: IocalhostW011ing-Cook Inlet Scan MD Range: 17180.000-19589.780 102.10 264.01 230.31 ISCWSA03-D 95.000%Confidence 2.7955 sigma, for subject well. For H16PBI (DefSurvey) TraJectory Error Model: offset wells, error model version is specified with each well respectively. 82.51 Offset Trajectories Summary -110.55 Offset Selection Criteria 042 58.92 Wellhead distance scan: Not performed! 22941 0.30 Selection fillers: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans 288.14 -133.64 229.36 - All Non -Def Surveys when no Def -Survey is set in a borehole - All Non -Def Plans when no Def -Plan is set in a borehole Offset Trajeclory I Separation I Allow I Sep. I Controlling I Reference Trajectory I Risk Level H16A-L02(P2)(Def Plan) 0.00 2].56 K7.56=2= -218]0 -32]56 000 0.00 118.9] -]9.64 -118.97 -0.01 77.89 119.41 -2.05 41.52 0.97 118.17 120.24 37.69 -2.06 1.47 332A0 102.10 264.01 230.31 4.92 H16PBI (DefSurvey) 82.51 289.10 -110.55 -206.56 042 58.92 288.33 -133.63 22941 0.30 58.78 288.14 -133.64 229.36 0.30 58.57 287.62 -133.W -229.05 0.3D 58.d6 286.47 -132.85 -228.01 0.30 126.24 169.78 -0.60 -63.53 1.00 165.24 168.56 52.54 -3.32 1.47 434.07 133.05 34504 301.02 4.92 H16 (Def Survey) 82.51 289.10 -110.55 -206.58 0.42 64.93 288.94 .128 Wr 224.01 0.33 64.65 288.60-128.08 223.95 0.33 84.09 287.09 -127.63 -223.00©0. 63,97 285.56 -126.73 -221.59 0.33 121.00 18222 -0.80 -61.21 0.% 1%.20 156.83 51.32 -0.62 1.49 385.15 116.76 306.98 268.38 4.98 610.00 114.% 533.03 495.04 8.02 Hansen #1AL1(Def Survey) 536.55 616.79 125.03 -80.24 1.30 440.55 578.76 54.3 -13820 1.14 433.45 570.56 52.75 -137.1 1.1 430.33 566. 5261 -135.75 1.14 41].8 518.95 71.51 -101.15 1.21 436.67 43TW 144.77 468 1.58 430.33 430.84 142.78 -0. W 1.50 353.08 533.14 -2.68 .180.06 0.99 25036 735.58 -239.% 484. 0.51 258.73 735.56 -239.98 484.82 0.51 OSF1.50 17180.00 OSFL50 17181.89 OSF1.W 17692.94 OSF1.W 17837.38 OSFi.W 18785.96 OSF1.W 17180.37 OSF1.W 17949.19 OSF1.50 17959.12 0SF1.50 17978.96 OSF1.50 18008.69 OSF1.W 18540.67 OSF1.W 18858.22 0SF150 19352.48 OSFI.W 17180.37 OSF1.W 17769.47 OSF1.W 17779.45 OSF1.W 17809.35 OSFi.W. 17829.25 OSF1.50 18293.13 OSF1.W 18481.57 OSF1.W 19062.77 OSF1.W 19589.78 7071.39 OSF<500 70]1.33 7068.13 7067.58 689T42 707138 OSF-500 7066.90 7066]0 7066.14 7064.92 6975.04 6942.20 6659.54 OSF<1.W 0SF11.00 OSF>1.W OSF>1.50 OSF<1.50 OSF1100 OSF>1.00 OSF>1.50 7071.38 OSF<5.W OSF<LW 7067.81 7o6Tn 7067.65 7067.57 7029.98 6993.65 OSF>1.50 6782.37 OSF>5.00 6558.93 OSF1.W 17180.00 7071.39 OSF1.50 17518.21 7068.85 OSF1.50 17556.41 7068.69 OSF1.50 17575.51 7068.61 OSF1.50 1773781 7067.94 OSF1.50 18086.32 7059.38 OSF1.W 18310.80 7026.43 OSF1.W 18828.30 6881.03 0SF1.50 19311.34 6676.98 OSF1.W 19313.64 6676.00 OSF<1.00 OSF>1.00 OSF<5.00 OSF<LW OSF>1.W OSF<1.50 OSF<1.00 Alert Fail Major Enter Map, Minpts Exit Major Exit Minor TD Fail Major Enter Major MnPbO-ADP MINPT-O-EOU Minlet-O-SF MInPt-CtCt Exk Major Eck Minor TD Fall Me* Enter Major MmPtA-ADP MINPT-O-EOU MhPt-0-SF MinPt-CICt Exit Major all Minor Exit Alen TD Fail Major Enter Minor MinPt-O-ADP MIoPf0-SF MINPT-O-EOU MinPt-0tDt all Minor Enter Minor Enter Major MMRADP MINPT-0-EOU 250.69 735.42 -239.94 -484.73 0.51 OSF1.50 19320,44 6673.12 Minot-OSF 250.68 735.07 -239.72 -48439 0.51 OSF1.50 19329.57 6669.25 Minot-CtCt 266.94 68069 -187.25 -41375 0.59 OSF1.50 19589.78 6558.93 TO Hansen #1(Def Survey) - Fal Mirror 707.03 700.12 239.96 6.91 1.51 OSF1.W 17180.00 7071.39 OSF<5.00 Enter Alert 702.61 704.47 232.63 -1.66 1.50 OSF1.W 17209.12 7070.56 OSF<1.50 Enter Minor 659.54 753.02 157.20 -93.48 1.31 OSF1.50 17843.85 7067.51 MinPts 859.a 753.001 157,19 -93.48 1.31 OSF1.W 17852.99 7067.47 Minlets 696.70 699.04 23034 -2.34 169 OSF1.W 18256.15 7036.89 OSl E It Minor 76395 651.61 329.22 112.M 1.76 OSF150 1844313 6997.55 TO H16A-101 (P2) (Def Plan) - Warning Alen 178-3] 116191 100591 62.181 2.31 051`1.50 17180.70 707137 OSF<5.00 Enter Alen 39138 119.49 311.38 271 BB 4.94 OSF1.W 17650.90 7068.30 TO Hansen #IA (Def Survey) Warning Alert 72586 695.81 261.66 30.05 156 051`1.50 1]180.00 7071.39 OSF<5.00 Enter Alert 720.80 712,50 245.47 8.30 1.52 OSF1.50 17349.02 7069.55 Minot-CICt 722.01 716.60 243.95 5.41 1.51 OSF1.W 1740]66M69.31 MINPT-0-EOU 723.94 718.93 244.33 5,011 1,511 OSF1.M 17448.93 7069.14 Minors 16M 41 720.60 1173.68 933.81 345 OSF1.W 19589.78 6558.93 TO H12 -L03 (Nan-Oef Survey) - - - - - Warning Alert 85735 302.70 655.19 554.60 4.26 051`1.50 17180.00 7071.39 OSF1500 Enter Alert 844A 304.33 64123 540.12 4.17 051`1.50 17687.85 7068.15 MinPt-COt 844.45 304. 641.21 540.0 4.17 OSFI.W 17697.85 7068.11 MinPoe 1336,51 305.97 63220 530.% 4.11 OSF1.W 18116.13 7056.66 Minot-CICt 836.51 305.9 632,19 530.53 4.11 OSF1.W 18123.85 7080.84 MINPTC-EOU 830.37 305.78 626.19 524.5911 OSF1.W 18417.35 7003.31 MinPPO-SF 83026 305.74__626.12 24.gl 4.08 OSF1.W 18437.02 6999.01 MInPrs 830.2 305.71 626.12 524.55 408 OSF1.W 1856.88 6996.86 MInPt-Ctrl 824.64 WIN 621.8 520.76 4.08 OSF1.50 1B791.81 6895.21 MinPI-O-SF 824.00 303.5 621.31 520.45 4.08 OSF1.50 18833.22 6879.07 MinPt-O-ADP 823.97 303.52 621.30 5045 4.08 OSF1.50 1883)39 6877.40 MINPT-O-EOU 823.91 W140 621.32 520.51 408 OSF1.W 18855.63 6869.99 Min%-CtCt 827] 304.60 624.38 523.18 4.08 OSF1.50 19302.58 6680.69 MInm.ctCt 827.81 304.72 62434 523.09 408 OSF1.W 19332.58 6667.98 MINP -O-EOU 827.88 304.80 624.35 523.08 408 OSF1.W 19352.57 66W.W MInPt-O-ADP 828.66 305.21 624.85 5234 4.0 OSF1.W 19442.56 6621.35 MmPt.O-SF 830.78 305.89 626.52 524.88 408 OSF1.5D 19589,78 6558.93 TD 1112.102 (Non -Def Survey) Warning Alert 65735 302.72 65520 554.62 4.26 OSFL50 17180.00 707139 OSF<500 Enter Alert 843.2 304.82 63971 538.43 4.16 OSF1.50 17777.59 7067.78 MInPt-Ctct 843.29 304.9 6396 538.35 4.16 OSF1.W 17197.50 7067.70 MINPTC-EOU 305.70 638.46 536.88 4.14 OSF1.W 17936.79 7087.07 Minot -Cort 842.61 W5.761 638. 538.0 4.14 051`1.80 17948.]4 7080.94 MinPts 84287 305.92 638.80 536.95 4.1 OSF4.W 1]9]6.61 7066.22 MinPI-O-SF 829.2] M.921 M7.661 482.Mi 3.59 OSF1.50 19357.85 6657.26 MinPts Hit -L04 (NornOaf Survey) Waming Alen (35]35 30214 655.19 55461 426 051`1.50 17180.00 707139 OSF<5.00 Enter Alert 8444 304.33 W,23 540.12 4.17 OSF1.W 17687.85 7068.15 MInR-CtCt 844.45 304. 641.21 I 540.0 4.17 OSF1.50 17697.85 7068.11 Miners 836.51 305.97 63220 530.54 4.11 OSF1.W 18116.13 7056.66 MInPt-CICt 836.51 305.98 632.1 530.53 4.11 OSF1.W 18123.85 7055.84 Mllil - -EOU 830.34 30536 626.17 524.58 4.08 OSF1.W 18417.28 ]003.33 MInPt-O-SF BWA3 805.64 626.04 52449 408 OSF1.W 18414.16 (INT45 MinPl-O-ADP 830.12 305. 626.04 524.. 4.08 OSFi.W 18446.57 6996.93 MINPT-O-EOU 305.5 626.07 524.55 4.08 OSF1.W 11PIN.07 6992.67 MlnR.CICt 924.62 278.73 738.47 645.89 4.99 OSF1.W 19308.05 6678.38 OSP5.00 Exit Alert 91 272.60 782.84 6W14 5.32 OSF1.W 191 6558.93 TO 1112-106 (NorFDef Survey) Wamirg Alert 85735 302.]4 65520 554.61 4.26 OSF1.50 17180.W ]0]1.39 OSF<5.00 Enter Alert 844.4 304.32 641.24 540.13 4.17 OSF1.W 17687.85 7068.15 MInN.CtCt WAS 304. 64122 Sd0.0 4.17 OSF1.W 1]69].85 7068.11 MinPls 836.51 305.96 63221 530.55 4.11 OSF1.W 18116.13 7056.66 MInR.CtCt 836.51 W5.91= 530.53 4.11 OSF1.W 18123.85 7055.84 MINPT-O-EOU AM 34 305.76 626.17 524.58 4.08 OSF1.W 18417,28 7003.33 MhPt-O-SF 830.13 305.64 626.05 524.49 4.08 OSFI.W 18444.16 6987.45 MmR-0-ADP 83012 305. 626. 524.50 4.08 OSF1.W 18"6.57 6996.93 MINK-O-EOU 830.09 305.53 626.07 524.56 4.08 OSF1.50 18466.07 6992.67 MinRl ct 922.19 277.84 736.63 6".34 4.99 OSF1.50 19274.20 6692]2 OSF>5.00 Exit Alert 990.85 259.76 817,35 731.09 5.74 OSF1.W 19589.8 6558.93 TD 1112-1-05 (Non -Def Survey) Waming Alert 85].35 W2 74 655.19 554.61 426 OSF1.50 1]180.00 7071 39 OSF<5.00 Enter Alert 844,4 304.32 641.24 540.13 4.17 OSF1.W 17687.85 7068.15 MinPt-CICt 8".45 304.36 641.21 540.0 4.17 OSF1.50 1]69].85 7068.11 min N 836.51 305.96 632.21 530.55 4.11 OSF1.W 16116.13 7056.66 MinPPCtCt 836.51 305. 632.2 530.53 4.11 OSF1.50 18123.85 7055.84 MINPT-O-EOU 830.34 305.6 626.17 524.58 4.08 OSF1.W 18417.28 7003.33 MhRP -SF 830.13 305.64 626.05 I! .4911 4.08 OSF1.W 184".16 6997.45 MInPFO-ADP 830.12 305.631 U6,1MI 524.49 448 OSF1.W 18446.57 6996.93 MINPT-0-EOU 830.09 305.53 626.07 524.56 4.W OSF1.50 18466.07 6992.67 MinM-CICt 922.19 2]].84 736.56 6".34 4.99 OSF1.W 192741.20 6692.]2 OSF>5.W Exit Alert 990.85 259.76 817.35 731.09 5.74 OSF1.W 19589.78 6558.93 TD H 12(Non-Def Surrey) _-- Weming Alert 8935 302.73 655.20 554.62 4.26 OSF1S0 17180.00 70]1.39 OSF<5.00 Enter Alert 30431 641.24 540.13 4.17 ESP 50 1]68]85 7068.15 MinPt-CtCt WAS 304. 641.22 540.1 4.17 OSF1.50 1]69].85 7088.11 836.51 305.95 63221 "0.56 4.11 OSF1.W 18116.13 7056.66 MinPts MinPt-C1Ct 836.51 305.9 632.20 530.54 4.11 OSF1.50 18123.85 7055.84 MINPT-0-EOU 830.34 305.75 626.18 524.1WI 4.08 O$FI.50 18417.28 7563.33 MInR-O-SF 830.13 305.63 626.051 14.56 4.08 OSF1.W 184".16 697.45 MinPt-O-ADP 830.12 305.62 826.05 94.W 4.08 OSF1.50 18446.57 6996.93 MINPT-O-EOU 83009 305.52 626.08 524.57 4.08 OSF1.W 18466.7 6992.9 MInPt-CICt 922.19 2]].84 73663 6".35 4.99 OSF1.50 19274.20 M92.2 OSF>5.00 Exd Alert 990.85 2W76 81136 731.10 5.74 OSFI W 19589.8 6558.93 TD H12-101 (Non -Def $urvey) Watnfegme[: 86525 30323 662.77 562.92 4.29 OSFI,50 1]18].92 ]0]1.14 OSF<5.00 Enter Alert 88]92 302.11 486 13 565.82 442 OSF1.50 17592.80 7068.54 MINPT.O-EOU 887.68 301.34 686.46 586.34 4.43 OSF1.W 17648.07 706831 913.31 317.2 7014 596. 4. OSF1.50 18265.02 7035.30 MinPt EtCt MlnPts H 14PB2(Der Survey) -- 1355.0 290.40 1161.14 1064.67 7.02 OSF1.50 17741 42 Pass 7067.93 MinPt-CICt 1355.15 290. 1161.11 1064.59 7.01 OSF150 17]]1.40 7067.W MINPT-O.EOU 135529 290.73 1161.1 1084. 7.01 OSF1.W 17801.38 7067.68 MInPt-O-ADP 13551 292.72 1159.68 1062.44 6.% OSF1.W 18156.13 7052.05 MinPt-CtCt 1355.17 292.7 11W.M 1062.40 6.96 OSF1.W 18165.91 TOW.W MINPT-0-EOU 1355.20 292.61 1159.6 106240 6.96 OSF1.M 18175.7 7049.50 MinR-0-ADP 1355.94 293.07 1160.23 1062.86 6.9 OSF1.W 18234.11 7040.68 MinPt-O-SF 1368.55 400421 1101.281 968.131 5.14 OSF1.W 18687.30 6932.23 MinPM H14PB1 (DefSurvey) 288.2 13204 1224.]2 ].9 OSF1.W I71W.00 Peas a1512.96 ]71.39 Min% 146].98 293.74 1271.83 1174.24 ZM OSF1.50 18369.21 7013.83 Minm.ctCt 146199 293.] 1271.83 11]4.24 7.52 OSFI.W 18378.97 7011.70 Min% 1468.49 293.89 12]2.23 11]4.56 7.M OSF1.M 18485.15 6968.43 MinR,0-SF 15W.99 24.29 1395.56 1303.70 8.1 OSF1.W 1999.76 65M.93 TD H14P83(Oef Survey) _- ._.--_._--...___... 15]1.5 288.19 13]90 1283. 8.20 OSF1.50 1718143 >071.35 Pus MinPls 1564.25 291.56 1369.54 1272.68 807 OSF1.W 17068.65 ]66].49 Cosmopolitan State 1 (Def Survey) MinPtCtCt MINPT-O-EOU MmPtA-ADP Min%-CtCt MINPT-0-EOU AMR -0 -ADP MMPI -O -SF MinP1-0-ADP MINPT-O-EOU MinR.Ctct TD - "'P 49-6- _... _ MInPO MmPFO-SF Mi RP ct MINPT-O-EOU MinPt-O-ADP MinPI-CtCt MinR.CICt Min% MinPt-0-SF TD Pass MMPL MinPt-CtCt TD Pass 1564.27 291. 1369. 12]2.60 807 OSF1.50 17858.63 ]06].44 1564.32 291.70 1369. 12]2.82 8.07 OSF1.50 1]888.60 7067.0 1564. 293.82 1368.37 12]0.]6 8.01 OSF1.50 18233.29 7040.81 1564.61 293.92 1368.34 12]0.69 8.01 OSF1.50 18252.88 ]03].47 1564.65 293.97 1368.35 12]0.68 8.01 OSF1.W 18262.64 T03513 1565.]1 294.29 1369.18 1271.41 0.00 OSFi.50 18330.82 7022.21 1W2.82 294.86 1385.9111 128].9 1.07 OSF1.W 19086.96 6]72.11 1582.77 94 2.80 1385.91 128].9] 8.08 OSF1.50 19096.21 6768.19 1 W2J1 294.61 1385.97 1288.10 8.08 OSF1.W 1912388 6756.66 1616.32 288.55 142362 1327,77 8.43 OSF1.50 19589]8 6558.93 H14 (Def Survey) 1680.5 289.9 1486.9 1390.6 8.72 OSFL50 1]185.69 ]0]1 21 168201 290.14 1488.26 1391.88 8.72 OSF1.W 17256.33 7069.82 1684.62 290.93 -1490 34 1393.69 8,71 OSF1.W 1]453.9] 7069.12 1684.66 291.02 1490.31 139363 8.71 OSF1.50 17473.97 7069.03 1684.]3 291.12 1490. 1393.62 8.]i OSF1.50 17493.9] ]068.95 BE1683.4 292.81 1487.95 1390.68 8.65 OSF1.50 17813.6] 7067.63 16W.76 297.06 1470.40 13]1.]0 8.45 OSF1.W 18665.80 6939.18 1660.. 297.08 14]0.38 13]1.69 8.45 OSF1.50 186]5.01 6936.23 1688.88 29].12 14T0.47 13]1.]6 8,451 OSFi.W 18693.37 6930.23 1732.46 29138 1537.62 1440.69 8.93 OSF1.W 19W9.78 65W83 SWnchkof State 1 (Def Survey) 698599 81.77 6931.141 69W.221 129.69 OSF1.W 18882.51 6858.79 6985.99 81.76 6931.15 6904.23 129.71 OSF1.W 18888.33 WW.32 7424.46 81.40 ]389.87 7343.06 138.48 OSF1.W 19095.45 6768.51 Cosmopolitan State 1 (Def Survey) MinPtCtCt MINPT-O-EOU MmPtA-ADP Min%-CtCt MINPT-0-EOU AMR -0 -ADP MMPI -O -SF MinP1-0-ADP MINPT-O-EOU MinR.Ctct TD - "'P 49-6- _... _ MInPO MmPFO-SF Mi RP ct MINPT-O-EOU MinPt-O-ADP MinPI-CtCt MinR.CICt Min% MinPt-0-SF TD Pass MMPL MinPt-CtCt TD Pass Traveling Cylinder Plot 11 .a EOwim..u.m M-1PM TRAVELING CYLINDER PLOT smxarn.x cam Ra.cm� FnM p " .n UVIN CeunepN.n Vm. elncm. Caem.p�tin v.a Wai NI! North e..na. X+eFLm eso ro o.a v �`- �Lri MW lINja'�Slac\7�\ NIi1, I , • iii.. %l�� !��% iweytA whir I. ..� .._.-;��1��� 04 ME' I � Traveling Cylinder Plot naoa R.ei.n eau'. e«.ann on.a.e eau o• n.mn- na, u.� TRAVELING CYLINDER PLOT Inntrtai.nn.ua u..a:o nwtem.answa.resmx.ar2) ..T erwCna CeunepN.n Vm. elncm. Caem.p�tin v.a Wai NI! North e..na. X+eFLm eso ro o.a rwm.z°+e Traveling Cylinder Plot naoa R.ei.n eau'. e«.ann on.a.e eau o• n.mn- na, u.� TRAVELING CYLINDER PLOT Inntrtai.nn.ua u..a:o nwtem.answa.resmx.ar2) ..T erwCna CeunepN.n Vm. tion North A.ona. e+uLm Tso ° w zeu Before exemption After exemption �st Energy Attach Cosmopolitan Project H16 -A-1 0-401 L03 APD Attachments H16 -A 10-401 L03 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. I t1 eNest Energy Attachm Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A10-401 L03 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. toueNesr Energy Attachment 5: _ Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A 10-401 L03 APD Attachments $I Energy Cosmopolitan Project BOP & Choke Manifold Configuration 5K# WI H 1OK# 49 3/32" 8070 FLANGE ° x (U Cl 66 5/8"3% o ® Lr) U) a. d� a� U) 27 3/4" 0 41 11/16" )e 13 5/8"X10K# CAMERON BOP STACK BLUECREST ENERGY 13 5/8 MOK CAMERON BOP STACK 1 3J1]f IE�YRIiGiRI THE-iiT Ref 1 1 6 I6 UPBIiED /RILYlGE)IFHT 6/22/t5 « nu BSBC7002 z 10-401 APD Attachments BOP & Choke Manifold Configuration lNeSt Energy R h Cosmopolitan Project BOP & Choke Manifold Configuration I Z a O= MW 10-401 APD Attachments BOP & Choke Manifold Configuration lNesr Energy Diverter Cosmopolitan Project BOP & Choke Manifold Configuration Nominal Dimensions—Inches—with 2000 psi Bottom Connections A 8 I C H 18 M AS CAST �- G H N K L M – O 0 P 52% 5118 .. 12t2 2311 D ffis 'OPENING, 4614 51% 511% PORT ____— � 50 + Hub 16 -- E AS CAST G LU soya m 5n J 00 LL 1 rASCAST aHymn P m L ' CLOSING PORT G FLANGED F K -- CLAMP — L ASCAST- - --.{ HUB Nominal Dimensions—Inches—with 2000 psi Bottom Connections A 8 I C H 18 D E F X61 G H J K L M N 0 P 52% 5118 .. 12t2 2311 Its ffis 27% 4614 51% 511% 6214 � 50 SA Hub 16 Hub t soya 5n Nominal Dimensions—Inches—with 3000 psi Bottom Connections A B HtA 17 50�h C DTE I F G I Hub 1 .. 1211 2314 j 5�+ 9�'� H J Baa 27% K 45W L 5114 M 58i: N 52% 0 50 P 1i4 5414 10-401 APD Attachments BOP & Choke Manifold Configuration toueC.iesr Energy Attachme Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A10-401 L03 APD Attachments t3lueNesr Energy Cosmopolitan Project Wellhead/Tree 1 �,iI Ar,�k I I i �I!I I I� I I I P ll16 S,'JW PSS s 65 ni wrw.r sfu P,us ll -SII 5,00 P1 I L/1!' SPOV Pu M5P I Ll!' S,{q0 P Mw rr i L35T 5,001 PM �-r-4 I i ..-"--SS/e'PKAoq 65.91' I-SA'CSG MGR MDS' 4iI I � t I ' MRNOXFl MAVG[A I � 195a ii i i i +�f m � !-1]l_9W 9[LLXGJ 615I[9 [0.00 CSG"' I C•:r•�^W.,.— l:I �.i �Ifllf SR i[[[o-ll} U 11l mcx._--- ' I �� em re[ .unto ,Mwnae ♦IIY m left- � OI Mt}I•IM 10-401 APD Attachments Wellhead/Tree IueC.Tesr Energy Attachment 7 Cosmopolitan Project H16 -A10-401 L03 APD Attachments H16 -A10-401 L03 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. Ju s[ Energy Attachment 8: r" Lease Map, Cosmopolitan Project H16 -A 10-401 L03 APD Attachments H16 -A 10-401 L03 APDAttachments H16A & H16A-L03 With 1000' Radius Around t—�500' From Lease Boundary I A_D_L_384403� SI[; 2B 7,1 ,R1'W SM Hansen 1A SEC 32. 735, R15W. SM SEC 33 \-L03 Surface Location (NAD 27) ting: 2,145,914.43', Easting 166,970.57' T FSL, 1509' FEL, Sec. 2, T4S, R15W SM ice Casing Point ling: 2145773.805' Easting: 167211.107' V' FSL, 3,429' FEL, Sec. 2, T4S, R15W SM Off Point ting: 2,152,667.59'. Easting: 155,894.36' " FSL, 4,121' FEL, Sec. 33, US, R15W SI Depth ling: 2,153,558.00', Easting: 154,601.00' FSL, 156' FEL, Sec. 29, T3S, R15W SM SFC 27. T35. R15W. SM Section SEC 26.735. R15W. SM D S1 1 t 5EC 36. T3: Cosmopolitan Unit Development 0 1000 2000 3000 4000 5000ttus 1:30000 PCTM Date 11/072018 company BlueCrest Energy New Well Rig Elevation Form 91497 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 DIRECTIONAL DRILLER (please print) Cosmopolitan Unit H16 BlueCrest#1 145.81 ft 34.62 ft 180.43 ft 40.56 ft 139.87 ft November 23, 2016 Marty Rinke TRANSMITTAL LETTER CHECKLIST WELL NAME: H I6 A - L 03 PTD: a.1$ --o98 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: H a h Se In POOL: H A IA S, h. U\ a e T t h d 01 - Check 1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. !J R — 09,5 , API No. 50- 2.31 -�--�- 00 . (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by j (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool HANSEN, HANSEN UNDEF OIL - 290100 Well Name: HANSEN H -16A -L43 Program DEV Well bore seg d❑ - _ - PTD#:2180980 Company B3L3 ECREST ALASKA OPERAtBNG.L1_Q Initial Class/Type _DEV_./ PEND _ GeoArea 620 _ -- Unit 10370 On/Off Shore Off Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(1.1.A),lj,2.A-D) NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date QTS 9/3/�d� 1 Permit fee attached. - NA - - - - - - - - - - - - 2 Lease number appropriate - - - Yes - - - - - 3 Unique well name and number Yes A Well located in. a. defined pool- - - - Yes 15 Well located proper distance from drilling unitboundaryYes 16 Well located proper distance from other wells - No. 7 Sufficient acreage available in drilling unit. Yes 8 If deviated, is wellbore plat included - - - - Yes 9 Operator only affected party- - - Yes 10 Operator has. appropriate bond in force - - - Yes Appr Date i11 Permit can be issued without conservation order - - - No . SPACING EXCEPTION REQUIRED: Will lie within same govt quarter section as intervals that are, open to SFD 9/12/2018 12 Permit can be issued without administrativeapproval_ Yes same pool. Hearing vacated; spacing exception order in progress. SFD 9/12/201.8 - 13 Can permit be approved before 15 -day wait - - - No 14 Well located within area and. strata authorized by Injection Order # (put 10# in. comments) (For- NA. 15 All wells. within 1/4. mile area of review identified (For service well only).. - - _ _ NA - - - - - ----- - - - - - - - 16 Pre -produced injector; duration of pre production less than.3 months (For service well only) NA 18 Conductor string provided - - - .. _ - _ - _ - - - - - - _ _ NA - - Sidetrack from whipstock placed in existing intermediatecasingstring. Engineering 19 Surface rasing protects all known USDWs - NA... - Sidetrack from whipstock placed in existing intermediate. casing string- - 20 CMT vol adequate. to circulate on conductor & surf csg - .... - - NA - Sidetrack from whipstock placed in existing intermediate casing string.. - 21 CMT. vol adequate to tie-in long string to surf osg- - ........ - - - - - NA - Sidetrack from whipstock placed in existing intermediate casing string 22 CMT. will cover all known productive horizons - NA Cemented above the reservoir,. slotted liner completion 23 Casing designs adequate for C. T, B &-permafrost. Yes 24 Adequate tankage or reserve pit - - - Yes !25 If a. re -drill, has a 10-403 for abandonment been approved Yes _ 26 Adequate wellbore separation proposed - - Yes Close approaches in the reservoir - 27 Ifdiverter required, does it meet regulations- - - NA Appr Date 28 Drilling fluid. program schematic & equip list adequate. Yes MGR 8/21/2018 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 H2$ gasprobable- - - - - - - - - No 34 Mechanical condition of wells within AOR verified (For service well only) - NA. 35 Permit can be issued w/o hydrogen. sulfide measures - Yes H2S not observed in nearby Hansen wells.. Rig has sensors and alarms. Geology 36 Data presented on potential overpressure zones - _ Yes - - "J-shaped' well branch targets. Starichkof sand and Hemlock. Planned mud weights in conjunction. with. - Appr Date 37 Seismic analysis of shallow gas zones. NA.... - Managed Pressure Drilling technique appear adequate to control maximum anticipated. downhole DLB 8/13/2018 38 Seabed condition survey (if off -shore) NA- - - pressure of 9.66 ppg, which is based on MDT measurements of reservoir pressure innearby well.. 39 Contact name/phone for weekly. progress reports [exploratory only] - NA... - - Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date QTS 9/3/�d�
