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Home My WebLink About218-096DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180960 Well Name/No. HANSEN H -16A -L01 MD 17440 TVD 6797 REQUIRED INFORMATION Completion Date 12/14/2016 Mud Log _Nd" DATA INFORMATION List of Logs Obtained: GR/RES/DEN/NEU, Mudlogs Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C - 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data ED C 30246 Digital Data Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-60-00 Completion Status Q1 -0I1 Samples I La Log Log Run Interval Scale Media No Start Stop 14554 17406 14554 17440 Current Status 1-0I1- OH/ CH Received UIC No Directional Survey Yes v (from Master Well Data/Logs) 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- L01_EcoScopeImages _RM_LAS.Ias 1/15/2019 Electronic Data Set, Filename: BlueCrest_H16A- L01_EcoScope_RM_LAS.Ias 1/15/2019 Electronic File: BlueCrest_H16A-L01_EcoScope Images_RM_DLIS.dlis 1/15/2019 Electronic File: BlueCrest_H16A-LO1_EcoScope Images —RM _DLIS.html 1/15/2019 Electronic File: BlueCrest_H16A- L01 _EcoScope_RM_DLIS.dlis 1/15/2019 Electronic File: BlueCrest_H16A- L01 _EcoScope_RM_DLIS.html 1/15/2019 Electronic File: BlueCrest_H16A- L01_EcoScope_2in_RM_InvertTVD.PDF 1/15/2019 Electronic File: BlueCrest H16A- L01 _EcoSoope_2in_RM_MD,pdf 1/15/2019 Electronic File: BlueCrest H16A- L01 _EcoScope_5in_RM_InvertT V D. PDF 1/15/2019 Electronic File: BlueCrest H16A- L01 _EcoScope_5in_RM_MD. pdf 1/15/2019 Electronic File: BlueCrest_H16A- LO1_EcoScope_I mage_5in_RM_MD. PDF 1/15/2019 Electronic File: BlueCrest_1-116A-1-010D Surveys final.pdf 1/15/2019 Electronic File: BlueCres1_H16A-L01_DD Surveys final.xisx AOGCC Page 1 of 5 Friday, April 5, 2019 AOGCC Page 2 of 5 Friday, April 5, 20 t9 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180960 Well Name/No. HANSEN H -16A -L01 Operator BLUECREST ALASKA OPERATING L API No. 50-231-20051-60-00 MD 17440 TVD 6797 Completion Date 12/14/2018 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30246 Digital Data 1/15/2019 Electronic File: BlueCrest_H 16A-L01–Final Suweys.csv Log C 30246 Log Header Scans 0 0 2180960 HANSEN H -16A-1_01 LOG HEADERS ED C 30246 Digital Data 0 0 Electronic File: H16A-1_01 ASP Final Survey.pdf ED C 30246 Digital Data 0 0 Electronic File: H16A-1_01 ASP Final Survey.xlsx ED C 30544 Digital Data 14450 17550 4/3/2019 Electronic Data Set, Filename: H16A-L01.Ias ED C 30544 Digital Data 4/3/2019 r— Electronic File: Hansen H16A Nabors AM Report 10-10-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-11-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-12-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-13-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-14-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-15-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-16-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-17-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-18-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-19-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-20-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-21-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-22-18.pdf ED C 30544 Digital Data 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-23-18.pdf AOGCC Page 2 of 5 Friday, April 5, 20 t9 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180960 Well Name/No. HANSEN H -16A-1_01 MD 17440 TVD 6797 Completion Date 12/14/2018 ED C 30544 Digital Data ED C 30544 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data 30544 Digital Data Operator BLUECREST ALASKA OPERATING L API No. 50.231-20051-60-00 Completion Status 1 -OIL Current Status 1 -OIL UIC No 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-24-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-25-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-26-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-27-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-7-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-8-18.pdf 4/3/2019 Electronic File: Hansen H16A Nabors AM Report 10-9-18.pdf 4/3/2019 Electronic File: H16A-L01.dbf 4/3/2019 Electronic File: hl6a-101.hdr 4/3/2019 Electronic File: H16A-L01.mdx 4/3/2019 Electronic File: hl6a-L01r.dbf 4/3/2019 Electronic File: hl6a-LOtr.mdx 4/3/2019 Electronic File: H16A-L01SCL.DBF 4/3/2019 Electronic File: H16A-LOt_SCL.MDX 4/3/2019 Electronic File: BLUE CREST ENERGY H -16A FINAL REPORT.pdf 4/3/2019 Electronic File: H16A-L01 - Drilling Dynamics Log MD.pdf 4/3/2019 Electronic File: H16A-1_01 - Formation Log MD.pdf 4/3/2019 Electronic File: H16A-1-01 - Gas Ratio Log MD.pdf 4/3/2019 Electronic File: H16A-LO1 - LWD Combo Log MD.pdf 4/3/2019 Electronic File: H16A-LO1 - Drilling Dynamics MD.tif 4/3/2019 Electronic File: H16A-LO1 - Formation Log MD.tif AOGCC Page 3 of 5 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/5/2019 Permit to Drill 2180960 Well NamelNo. HANSEN H-16A-LOt MD 17440 TVD 6797 Completion Date 12/14/2018 ED C 30544 Digital Data ED C 30544 Digital Data ED C 30544 Digital Data ED C 30544 Digital Data ED C 30544 Digital Data ED C 30544 Digital Data Log C 30544 Log Header Scans Well Cores/Samples Information: Operator BLUECREST ALASKA OPERATING L API No. 50.231-20051-60-00 Completion Status 1.011. 0 0 Current Status 1 -OIL UIC No 4/3/2019 Electronic File: H16A-L01 - Gas Ratio MD.tif 4/3/2019 Electronic File: H16A-1-01 - LWD Combo MD.tif 4/3/2019 Electronic File: H16A-L01 Show Report 18 16925-17145 page 1.pdf 4/3/2019 Electronic File: H16A-L01 Show Report 18 16925-17145 page 2.pdf 4/3/2019 Electronic File: H16A-1.01 Show Report 19 17183-17360 page t.pdf 4/3/2019 Electronic File: H16A-1-01 Show Report 19 17183-17360 page 2.pdf 2180960 HANSEN H -16A -L01 LOG HEADERS COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 Description Date Comments Comments: Core Chips YA Core Photographs Y NA Laboratory Analyses Y N AOGCC Page 4 of 5 Friday, April 5, 2019 Sample Interval Set Name Start Stop Sent Received Number Comments Cuttings 16320 17440 11/26/2018 1681 INFORMATION RECEIVED Completion Report 0 Directional / Inclination Data Mud Logs, Image Files, Digital Data/S' ( NA Production Test Information Y ® Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files Geologic Markers/Tops (D Daily Operations Summary 0Y Cuttings Samples G/ NA COMPLIANCE HISTORY Completion Date: 12/14/2018 Release Date: 9/13/2018 Description Date Comments Comments: Core Chips YA Core Photographs Y NA Laboratory Analyses Y N AOGCC Page 4 of 5 Friday, April 5, 2019 DATA SUBMITTAL COMPLIANCE REPORT 415/2019 Permit to Drill 2180960 Well Name/No. HANSEN H -16A -L01 Operator BLUECREST ALASKA OPERATING L API No. 50-231.20051-60-00 MD 17440 TVD 6797 Completion Date 12/14/2018 Completion Status 1-0I1 Compliance Reviewed By: Current Status 1-0I1 UIC No Date: AOGCC Page 5 of 5 Friday, April 5, 2019 21 806 30544 due esti En rgy " B1ueCrestAlaska Operating LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Tel: (907) 754-9550 Fax: (907) 677-0204 Transmittal Date: 4/3/2019 Transmittal #: 2019-05 KToday's Ms. Meredith Guhl From: Andrew Buchanan any: AOGCC Company: BlueCrest Alaska Operating LLC Re: 1 Mud Logging Data -H16A Well: H36A- Included Information: 8 CD's with Mud Logging Data for Well H 16A. Regards Andrew Buchanan BlueCrest Energy RECEIVED APR 0 3 2019 AOOCC 21 8096 30 24 6 Schlumberger Transmittal #: 14JAN19-SP02 Drilling & Measurements Product Delivery Customer BlueCrest Energy, LLC Dispatched To: AOGCC: Abby Bell Well No H16A-101 Date Dispatched: 14 -Jan -19 Service Order # 18AKA0052 Dispatched By: Stephanie Pacillo Product Description Hardcopy Digital Copy Logging Date Color Log Prints: N/A Contents on CD 27 -Oct -18 EcoScope` 5 MD N/A x 2" MD N/A x 5" Invert TVD N/A x T Invert TVD N/A x 5" EcoScope Image N/A x Digital DataContents on CD Recorded Mode DLIS / LAS Data x JA 15 2019 A GCC Survey N/A Contents on CD Directional Survey Nad27 x EOW CD 1 Contents on CD Data: DLIS/ LAS x Graphics: PDF x Survey: XLS/PDF x Please sign and email a copy to: Please sign and email a copy to: abuchanan(o)bluecrestenerov.com Alas kaPTSPrintCenter(a)slb.com Attn: Andrew Buchanan Ir Attn: Stephanie Pacillo Received By: M Schlumberger -Private STATE OF ALASKA JAN 0 9 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil Q Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG[:] WDSPL ❑ No. of Completions: 1b. Well Class: Development 0 Exploratory ❑ Service ❑ Stmtigraphic Test ❑ 2. Operator Name: BlueCrest Alaska Operating LLC 6. Date Comp., Susp., or Comp: 12/14/2018 14. Permit to Drill Number/ Sundry: 218-096 ' 3. Address: 3301 "C" Street, Suite 202, Anchorage, AK 99503 7. Date Spudded: 10/25/2018 15. API Number: 50-231.20051-60.00 4a. Location of Well (Governmental Section): H1 6A - L01 Surface: 2408' FSL, 1509' FEL, Sec 2, T4S, R15W, SM Top of Productive Interval: 3737' FSL, 2820' FEL, Sec 33, T3S, R15W, SM Total Depth: 4291' FSL, 3676' FEL, Sec 33, T3S, R15W, SM 8. Date TD Reached: 10/28/2018 16. Well Name and Number: HI 6A - L01 9. Ref Elevations: KB: 180.25' GLA45.81 RKB:180.4 17. Field / Pool(s): Hansen,Undefined Cosmopolitan Oil 10. Plug Back Depth MD/TVD: 17440' MD / 6797' TVD 18. Property Designation: , Fee Hansen,AD1_18790,ADL 384403 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 168861.855 y- 2144856.07 Zone- 4 TPI: x- 157171.72 y- 2151790.8 Zone- 4 Total Depth: x- 156331.17 y- 2152368.86 Zone- 4 11. Total Depth MD/TVD: 17440' MD / 6797' 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 4 (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: 121. N/A (ft MSL) I Re-drill/Lateral Top Window MD/TVD: 16,375' MD 17,077' TVD (L01-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 SETTING DEPTH MO SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 0.500" wall A525 41 187 41 187 Driven N/A - Rotary Drilled/Driven N/A 13.375 72 L-80 40.5 4177 40.5 3175 17.5" 588 bbls Lead / 198 bbls Tail N/A 9.625 47 P-110 40.6 13161 40.6 6688 12.25" N/A N/A 9.625 53.5 P-110 13161 14767 6688 7083 12.25" 178 bbls 15.8 ppg G -Tail N/A 4.5 15.2 P-110 14381 21510 7070 7068 8.5" Slotted Liner - no cement N/A 3.5 9.3 L80 26.46 14435 26.46 7076 N/A Production Tubing String N/A 24. Open to production or injection? Yes Q No ❑ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): Laterals L01 through L07 completed barefoot and left uncased. - Cr 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 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Productinn- Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API(corr): Form 10-407 Revised 5/2017 (7 -(1 CONTINUES ON PAGE 2 RBDMS �,! " ? Ii 19 Submit ORIGINIAL on# ��1/i� � G U. ?))-(A 28. CORE DATA Conventional Co, -,$): Yes ❑ No Sidewall Cores: , as ❑ No Q If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. None All zones are Hemlock Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. TPI / KOP 16375 7077 Formation tops above are for the H 16A - L01 Lateral Formation at total depth: lHemlock 31. List of Attachments: Operations Summary, Actual Wellbore Diagram, List of Formation Tops, Mud Wt vs. Depth Data, Final Definitive Directional Surveys, Slotted Liner String Tally (4-1/2"), Tubing String Tally (3-1/2"), Wellhead & Tree Schematic, Pressure Test Results Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Larry Burgess Contact Name: Tom McKay Authorized Title: Alaska Manager Contact Email:tom.mckay aabluecrestenerov.cor Authorized�n D9 Contact Phone: 907-754-9566 Signature: 6„„l6w ( 20 Date: ( ( INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region 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 lust 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— L01 Lateral PTD No. 218-096 API No. 50-231-20051-60-00 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— L01 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, r� Larry Burgess Alaska Manager lue est Energy BlueCrest Energy Alaska Cosmopolitan Project H16A — L01 —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 H36A Hemlock 152764.05 2154807.92 -6887.87 21720 7068.3 H16A-LO3 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 H36A-11.04 Hemlock 154480.46 2153630.53 -6687.77 19660.15 6868.2 H16A-LOS 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-'/:" 9.2# EUE 8RD Production Tubing 4-%" x 9-5/8" Liner Hanger & Liner Top Packer H16A Lower Lateral ACTUAL Completion with Slotted Liner in Mainbore and Seven (7) Open Hole Fishbone Ribs NOTE: Well was sidetracked off a whipstock set at 14538' MD top of window in the 9-5/8" casing 9-5/8" 47.0/53.5# P130 H563 @ 14767' M D lIueCest Energy Fishbone ribs are 8-%" 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.O1 L02 L03 L04 LOS L06 L07 4-%" 15.2# H563 Slotted Liner @ 21,510' MD weliview Well Name: H16A BC - Daily Recap Well Name APIAM Surface Legal Ltcatim License# H16A 231-20051-01-00 2408'FSL, 1509' FEL,SEC.02T4S,R15W SM 218-095 Spud Date Rig Release Date Ground Elevation (fl)- -Ground Distance (fl) Well Subtype 10/16/2018 23:00 145.81 43 Fish bone Daily Operations Start Date Ertl Data SW Date dal Number of Reports Total neptn of Wellt," 0") 9/26/2018 79.0 22,310.00 Survey Data MD (N(aj Ind Aam (•) TVD (flKe) VS (fl) NS (fl) EW (fl) DLS (°/1nOflJ Date 21,587.58 89.79 302.69 7,068.24 18,791.4 9,44 .39 ,246.95 0.46 21,681.42 90.35 303.05 I 7,068.13 1 18,885.19 9,493.32 425.7ti 1 0.71 21,774.79 89.90 1 303.32 7,067.93 18,978.41 0.56 Rigs contractor Rig Number Dally Operations Rpt# Start Date Ertl Date Summary 1.0 9/26/2018 9/27/2018 Repair annular BOP 2.0 9/27/2018 9/28/2018 skid rig 3.0 9/28/2018 9/29/2018 center dg over hole 4.0 9/29/2018 9/302018 hook up lines from pits to sub base 5.0 9/302018 10112018 SET STAIRS ON SUB BASE AND PITS 6.0 10/12018 1022018 set berms for rig and pits/ mats for pits and set cuttings tanks 7.0 1012/2018 10/32018 CENTER TOP DRIVE RAIL Finish pit liners around rig 8.0 10/32018 10/42018 Start up boilers and function test lop drive 9.0; 10/42018 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. 10/5/2018 10/6/2018 Install bell nipple, choke and kilt lines. Install koomey lines and secure stack tie downs. 11.0^ 10/62018 10/72018 Drilling line was slipped on and top drive quit working 12,0 10/7/2018 10/82018 Install new 3W x 5W VBR's in bottom ram, Install 3W' solid body style in top ram. Change out top drive IBOP valve, and -re-test. Witnessed by AOGCC Jeff Jones. 13.0 10/8/2018 10!92018 PU 348 joints of 5 %' XT 54 DP via mouse hole and stand back. This pipe will stay in the casing while drilling. Torque all connections to 49,000 fUlbs. 14.0 10/92018 10/102018 Pick up a total of 164 stands of 5W" XT54 DP. Bull head 80 bbls MY water down IA. Bull head 140 bbis down tubing. 100° water. Unseat hanger with 180k up weight. Free travel Q 160k. Turn 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 bbls 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.Bulihead tubing volume plus 10 bbls, bullhead 200bbls down IA, bleed residual gas off to production bleed tank. Lay down landing joint, hanger and pup. Open SSSV. Run chem line and I - Wire through sheaves, POOH laying down 3%" EUE 9.3# L-80 tubing from joint #461 to joint #282. Retreive all cannon clamps. Fill hole with 5x's displacement every 10 joints. 16.0 10/11/2018 10/12/2018 Complete tubing pull operations. 461 joints of 3%" EUE 9.3# L-80, 3 GLM's, SSSV, Chem injection sub, seal assembly. All joints and equipment to be inspected prior to re -running. Remove casing bails, and GBR 75 ton tubing elevators, install drilling bails and drilling elevators. 17.0 10/12/2018 10/132018 Rig down GBR tubing running equipment, remove long bails, 75 ton elevators, cannon clamps, GLM's, all completion equipment from rig floor and pipe shed. Rig down and release Camco spoolers, GBR. Strap 3 spiral DC's, 18 HWDP, TIH with Halliburton EZ drill SVB packer on XT 54 5h" DP. 18.0 10/13/2018 10114/2018 Trip in hole with Halliburton EZ Drill Packer. Set Q 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 10/152018 Circulate surface to surface 4BPM through open super choke & poor boy degasser. 920 Units max gas. Conduct casing test to 3500 psi, 30 mins, charted. Good. Dispose of excess fluids in pit system. Displace - well to 9.2 ppg OBM. Pump dry job. POOH strapping pipe. 20.0 10/15/2018 10/16/2018 TOOH from 4598'to surface. Lay down "Mechanical setting tool" after Halliburton CIBP run. Clean and clear rig floor. Pick up whipstock assembly with MWD tool. Orient. TIH to 1500'. Pulse test MWD tool. Mud pumps #2 & #3 were used. Both experienced pressure losses. Three cycles of pump pressure were recorded. Both pumps were isolated, and the cap gaskets were not property installed. Both pumps put back together as per specification. Tested flowing through the choke manifold with 1500 PSI back pressure. Good. Decide to trip out for back up " Mufti cycle by-pass tool". POOH to surface change out tools. Orient. TIH @ 457minute lowering speed. Trip to 1327'. crew change. 21.0 10116/2016 10/17/2018 Shallow pulse test MWD tool @ 1325' MD. TIH W/ BHA#2 whipstock / Mill assembly to 3766'. Failed solenoid top drive elevators closing function. Replace solenoid. TIH to 6282'. Failed solenoid top drive handier function. Replace. TIH to 14551', stand #147. Orient Whipstock 38 right. Failed solenoid top drive pipe handier rotational locking device. Replace. Set whipstock @ 14,563' bottom of tool. TOW=14,538', BOW= 14,552'. Begin milling @ 14,538'. 22.010/17!2018 10/182018 Milled window 14,535' to 14,543'. At 14,543'a pressure loss of 275psi was observed and milling torque fell as well. Varied parameters and made V in 7hrs. POOH to inspect the BHA and mills. L/D Drill collars, MWD, HWDP Flex, running tool, and Mill. www.poloton.com Page 115 ReportPrinted: 1212612018 WellView• Well Name: H16A BC - Daily Recap Daily Operations Rpt# Stan Date End Date summery 23.0 10/18/2018 10/19/2018 UD BHA#2(bottom tri -mill badly junk damaged and 1/4" under gauge). P/U BHA#3(new td -mill assy). RIH to 14,543" and Mfll/Drill window and new formation to 14,569'- Pump sweep and circulate hole clean with 9.2 ppg mud wt in and out. POOH above window - R/U to perform FIT - 24.0 10/19/2018 10/20/2018 Circulate for FIT, R/U and perform FIT, formation broke down @ 1470 psi - RID FIT assemably and monitored well on TT. High losses and began mixing LCM pill, pumped same, continued monitoring while mixing other LCM pill. Spotted 2nd pill and monitored losses. Began milling @ 15, 569' to 15,582'- Mill quit drilling - Observed well for losses - Pump out of hole 25.0 10/20/2018 10/21/2018 -C/O the grabber dies on the topdrive. -Pumped out of the hole 13,838'to 12,263'. -Pipe handler on the topdrive not functioning. Found a loose connection on a hydraulic line, tightened the connection and checked OK. -Pumped out of the hole 12,263' to 9,720'. -Serviced the rig. -Pumped out of the hole 9,720' to 3,171'. -Serviced the rig. -Average losses while pumping out 26PH. 10/21/2018 10/2212018 -Pumped out of the hole 3171' to 2983' -Pull out of the hole on elevators 2983' t0 576'. -L/D 18jnts of 5.5" HWDP. -UD mill easy, bottom 2 mills 1/4" under gauge. -Clean and clear the rig floor. -P/U the wash tool and wash the BOPE stack. Recovered 1 l of metal. _ -Pull the wear bushing and run the test plug and 5.5" test joint. -Test BOPE on 5.5" and 5" test joint 250/3500 psi 5 min. -Pull the test plug and install the wear ring. -C/O the solenoid for the top drive compensator valve. -C/O topdrive washpipe from Tesoo to mechanical. ' -P/U the motor BHA with crane assist. 27. 10/22/2018 10/23/2018 -P/U 6 joints of 5.5" HT -55 drill pipe while RIH to 328'. -Installed the mechanical washpipe. -Troubleshoot the topdrive grabber problem and installed a shorter saver sub and checked hydraulic pressure to the ram(OK). Verified that the saver sub could be broken out OK. -RIH to 2109' and filled the pipe and tested the MWD OK. -Continued to RIH to 7823' and serviced the dg - Trip in hole f/ 7823' to 14,485'- Slip and cut 1 10'Drilling line - Adjusted COM - Calibrated block height - Trip in to TOW @ 14,538 take SCR's orient tools and run through the window. Open under gauge hole to 14,582'- drill new hale to 14,622" 28.0 10/23/2018 10/24/2018 - Rotary Drill and Slide f/ 14,622' to 14,735' - WOB = 20/30K - 40 GPM = 1950 psi - 40 RPM - PIU WT = 305K - S1O WT = 150K - ROTNJT = 21 OK - Average losses = 13 BPH - Backream OOH FI 14, 735' to BOW @ 14, 552' - Oriented the motor and pumped out through window with 30 GPM with no excess drag - P/U WT 330K with 30 GPM - Begin clean up cycles and slowly bled in LCM pill 3. - 450 GPM C 1750 PSI - 80 RPM - Torque = 26K - P/U Wt = 220 K - Service TDS, drawworks, blocks, crown, clutches, upper bearing quill, choke, and IR - Monitoring well on TT with no losses - Pump out of hole as per K & M procedures FI 14,209' to 7,983'. @ 9962' Attempted to adjust the topddve grabber box lower limit. Found a washed out valve. Changed the safety chain on the topdrive grabber box. 29.0 10/24/2018 10/25/2018 - Pumping out of hole Fl 7983'T/3853" - Continue POOH on elevators F/ 3853' to 130' as per K & M Trip schedule - R/U and UD BHA with crane - Remove wear bushing - Install test plug and test BOPE to 250 PSI Low & 3500 PSI High - Remove test plug - Install Wear bushing - PIU New BHA - 30.0 10/25/2018 10/2612018 - RIH picking up HT 55 Drill pipe to 2063'- Shallow lest Directional tools with 460 GPM and 975 PSI - RIH picking up HT 55 DP to 3071'- Service Rig - Losses @ 1 BPH - P/U HT 55 DP to 5760' ( total its picked up = 174 ) Filled pipe every 20 Stds - Trip in hole from derrick a controlled speed as per K & M Tripping schedule TI 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 10/2712018 - Circulate and condition mud - Drill FI 14,795' to 14,838'- Torque erratic - Tool Face control on the RSS was lost - Circulate and add Lube to active mud system to 0.5% - Drilling F/ 14,838' to 16,336' 32.0 10/27/2018 10128/2018 - Drilling from 16,336' to 17,440' as per DD and K&M Schedule - Back Ream F/ 17,440' T/ 16,213' as per K&M Back Reaming Schedule - Service Rig - UD (3) As DP with excessive wear - RIH F/ 16,213' to 16,375' - Trenching and Time Drilling as per DD F/ 16,375' T/ 16,377 33.0 10/28/2018 10/2912018 - Time Drilling Fl 16,377' T/ 16,397'- Drilling ahead F/ 16,397' to 18,214' on Lateral # 2 34.0 10/29/2018 10/30/2018 Worked Stuck pipe Free with applying torque in string and worked down, observed string free with 30K Torque - Clean hole back reaming F18,213' T 18,122'- Drilling L02 FI 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 F/ 18,21T to 117.390'- 350 10130/2018 10/31/2018 - Time Dnlling F/17,138' T/ 17,143'- Drilling Main Bore FI 17,143'T/17,746'- Service TDS - Drilling F117,746' T/18,592'- (KOP F/ Lateral 03 17,933') Service Draw Works and ST 100 - Change Grabber dies wwvv.peloton.com Page 215 ReportPrinted: 1212612016 WellView Well Name: H16A BC - Daily Recap Daily Operations Rpt# start Date End Date summary 36.0 10/31/2018 11/1/2018 Directional Drill 8W hole from 18,592' to 19,268'. TO of 1-03. Change out grabber dies in top drive. Back ream out to 17,950'. Hole in good shape. Begin troughing from 17,975'to 18,000' MD for L04. 37.0 11/1/2018 11/2/2018 Directional work. Low side sidetrack. trench from 17,975'to 18,000' MD. Time drill to 18,045'. Began pushing on BHA @ 18,045', WOB increased to 10k, and Inclination dropped. Successful sidetrack. 38.0 11/2/2018 11/3/2018 Directional Drill 8%" hole with Exceed rotary steerable system from 18,122 to 19,249' MD. Drilling in L04. 39.0 11/3/2018 11/411018 Directional Drill 8%i' hole with Exceed rotary steerable system from 19,249' to TD of LD4 C 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 C 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 dry job. Trip out of the hole laying down singles. HT 55 drill pipe. From 5930' to Surface. Begin to lay down BHA#5. Constant hole fill using trip tank. 42.0 11/6/2018 11/7/2018 Lay down BHA#5. Lay down 180 joints of HT 55, and 360 joints of XT 54 from derrick and prepare for Premium Inspectors to machine on new hard banding. 43.0 11/7/2018 11/8/2018 Lay down 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 54 saver sub. Pull wear bushing, Install test plug. Begin testing BOPE with 5" TJ. 44.0 11/8/2018 11/9/2018 Conduct Bi -Weekly BOPE test W/ AOGCC Inspector. 5" and 5'R'test joints. Rig down test equipment. P/U and stand back 78 joints of 5%" XT 54. ODS. Discover out of spec XO provided for new 5" XT DP. (Wall thickness below minimum. 3.5 ID versus 2.813", junk XO). Rig up and test BOPE W14'h" TJ to enable Rig Team to use XT 46 string. Pick up BHA#6. Single in hole with 5 joints HT 55. Repair broken hydraulic hose on top drive, adjust clamps on bails to reach mouse hole. 45.0 11/9/2018 11/10/2018 Single in the hole with 246 joints of HT 55 DP. 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'N' in hole midnight. 46.0 11/10/2018 11111/2018 Continue to single in the hole with 41A" XT 46 from 10977'to 13,347'. Well Bore began to U-tube. Circulate bottoms up. Balance well. Single in remaining XT 46 pipe to 14,063'. 195 JTS total. Pick up and stand back 29 stands of XT 54 DP via mouse hole Slip and 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 11/12/2018 11/13/2018 Directional drill L05 W/ Exceed rotary steerable system, 8%" hole from 18,860' to 20,538' MD. 49.0 11113/2018 11/14/2018 Directional drill L05 W1 Exceed rotary steerable system, 8W' hole from 20,538' to 20,743' MD. BROOH slow, perform clean up cycle. Pick up and stand back 6 stands of newly hard banded XT54 DP. BROOH to 19,500. Trough from 19,500 to 19,525'. Time drill to 19545', Begin drilling L06 from 19,526 to 19,881' MD. 50.0 11/14/2018 11/15/2018 - Drilling 8 1/2" hole L06 with Exceed Rotary steerable assembly FI 19,881' T/ 21,340' - Circulate and clean hole, PIU 6 side of DP while circulating - BROOH T/ 20,350' 51.0 11/15/2018 11/16/2018 - Back Ream FI20,350' 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 DD F/ 20,270'T/ 20,295' - Drilling 8 112" hole as per DD & K&M parameters F110,295' T/ 20,925' 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 11/17/2018 11/18/2018 - Drilling F/21,850' T/ 21,860' TO for L07 - Begin Clean up cycle and Pick up 5 STDS of XT 54 DP and Rack in Derrick - Back Ream F121,745' T121,145' - Begin trenching F121,145' T/ 21,165'- Time Drilling F1 21,165' T/ 21,194' - Drilling L08 F121,194' T/ 21,850' 54.0 11/18/2018 11119/2018 - Drilled 8 112" 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 while back reaming @ 1 1/2 FT/MIN F12 22,310'T/ 21,753'- Back reamed FI 21,753'T/21,475'@ 15 1 FT/MIN - Serviced Rig 55. 11/19/2018 11/20/2018 - Back Reamed out of hjole F/ 21,476'T/ 19,787' - Worked through tight spot FI 20,843'T/ 20,833' - Back Reamed F/ 19,787'T/ 18,660'- Service Rig Equipment - Back Reamed out of hole FI 18,660' T/ 17,110' - RIH ( Had to rotate) T/ 17211' and took survey to confirm still in Main Bore OK - Back Reamed FI 17,211' T/ 15,003' - SLM 56.18 11121/2018 - Replace IBOP Actuator due to bearing sell check, no gain/loss) - Back Reamed out of hole as per K&M Parameters F115,003' T/ 14,672" - POOH with BHA through window with 100/GPM & No Rotation F1 1711 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 4 112" Drill Pipe - Pumped out of hole FI 14165' T/ 9,933'- SLM - Serviceded Rig www.peloton.com Page 315 Report Printed: 12126/2018 WellView Well Name: H16A BC - Daily Recap Daily Operations Rpt * Start Date End Date Summary 57.0 11/21/2018 11/22/2018 - PJSM - Pumped out of hole as per K&M Parameters F/ 9,933' T/ 8,047- SLM - Break out XOs and M/U Safety valve - Changed out Saver Sub From XT 46 To HT 55 - Monitored Well on TT - Static - Pumped out of hole as per K&M Parameters F/ 8,047'T/ 6,600' - Serviced Rig and monitored well on TT - Static - Pumped out of hole as per K&M Parameters F/ 6,600'T/ 5,832'- Back Reamed out of hole while performing Clean up Cycle @ 1.5 FT/MIN F/ 5,832'T/ 5,732' - POOH on elevators as per K&M Trip Schedule F/5,732' TI 3,525'- M44 onitor well displacement on TT - Back Reaming out of hole as per K&M Parameters while performing Clean Up Cycle FI 3,525' TI 3,430'- POOH on elevators as per K&M trip Schedule F/ 3,430' T/ 163'- Lay down BHA 58.0 11/22/2018 11/23/2018 - Clean and organize Rig Floor - 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 Ill" Test assembly and M/U 5 1/2" Test Assembly - Test BOPE To 250/3600 PSI for 5 MIN - Test Gas Alarms - Remove test plug - Install Wear Bushing - Rig down Test assembly and clear off rig Floor 59.0 11/23/2018 11/24/1018 - PJSM - RIH Picking up 4 1/2" Liner T/ 7,91T - 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 PBR assembly - Service Rig and monitor well on TT - Remove long bails and elevators - Install short baits and Hydraulic elevators - M/U Liner Hanger and RIH to 8,085'- Establish circulation - RIH with 4 1/2" Liner on HT 55 Drill Pipe from derrick F/ 8,085' 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, & 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' ( End of L02 ) POOH on elevators as per K&M Parameters F/ 18,390' TI 17,055' - Monitored well on Trip tank - RIH with 4 1/2" Liner as per K&M 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 11/25/2018 11/262018 - PJSM - POOH with 4 1/2" Liner as per K&M trip Schedule F/ 16,021' T/ 7,992'- Monitored well on Trip Tank - Changed out Bails and Elevators to Lay down Liner - Serviced Rig - 62.0 11/262018 1127/2018 - Clean Rig Floor of Base Oil and Inspect tools - PJSM - POOH Laying down 4 ill" Liner as per K&M trip schedule F/ 4,852'T/ 4,157'- Break connections with rig longs until 4,300'- Inspected each Box and Pin with Tenaris Rep - Monitored well on Trip Tank - Had Safety Stand down Meeting with crews - POOH Laying down 4 1/2" Liner as per K&M trip Schedule F/4,167'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 1/2" Liner as per K&M trip schedule F/ 1,732' T/ Surface - Inspected each Joint with Tenaris Rep - Monitored well on Trip Tank - Cleaned OBM from Rig Floor - Changed bails and elevators - Monitored Well on Trip Tank - Picked up BHA and RIH T/ 149'- RIH with HT 55 Drill Pipe checking each connection with Premium for wear - Ran in Hole with 20 Stands - POOH with 20 Stands culling out bad Joints under 4 314" 63.0 1127/2018 11/2812018 - PJSM - POOH laying down 5 12" 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 12" 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 1/2" HT 55 Drill Pipe from derrick F/ 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 F/ 5,691'T/ 8,038' - Drift each joint in V -Door - Fill Pipe every 20 Stands - Monitor well on Trip tank while RIH - Make up XO - change elevator Inserts to 4 12" - RIH with XT -46 Pipe F/ 8,038' T/ 14,145'- Monitor well on Trip Tank - Fill Pipe every 20 Stands - Changed elevator inserts to 5 112" - RIH with XT 54 Pipe T/ 14,424'- Break circulation with 100/GPM - P/U WT 295k - S/O WT 140k - Service Rig 64.0 11282018 11292018 Slip and cut 110' of drill line. Inside casing (di) 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' MO. Down weight 100k. Begin reaming. Ream to 16,389'. TO grabber - dies changed out. Ream to 16,948'. Service rig. Ream from 16, 948'to 17,205'. L02 exit point. Command rotary steerable tool to 100% lowside deflection, bring pumps up to 450 GPM, from 400 GPM, Increase RPM from 120 to 160 RPM. Work area from 17,208 to 17,286. Hole unloaded with unconsolidated sand on first BU. Ream from 17,285' to 19,105' MD. MW=9.2 PPG intout. 65.0 111292018 11/302018 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 fosses remain around 1 BPH while pumping. SIMOPS: Rebuild liner tally. 192 good joints ready to go. 98 _ slotted, 94 solid. 66.0. 11130/2018 1211/2018 Continue to BROOK Slight pack off 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 feel. Stayed in Mother Bore. Seismic Event: 7.2 Eath Quake centered 8 miles NW of ANC. Descion made to go back to bottom. Ream back in the hole from 17,100' to 21,264' MD. 67.0 12/1/2018 12/2/2018 Ream to 21,826'. CBU W/ 500 GPM, 120 RPM on first stand. Begin BROOH from 21,737' to 17,130'. Mimic liner run past L02 exit point. Wellbore smooth. Continue to BROOH to 15,441' MD. Inadvertently add LVT to active. Monitor well, weight active back to 9.2 PPG. 68.0 12212018 12/3/2018 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 15,45T. BROOH to window. 14,710' Circulate 10 mins. Pull first string reamer into casing with 100 GPM. Second reamer required 25 RPM, 400 GPM. Pulled last reamer and bit into window with 400 GPM no rotary. CBU Inside casing. 14,430'. Pump out of the hole from 14,430'to 9144' MD. 100 GPM, 350 PSI, 50 to 607min. www.peloton.com Page 415 Report Printed: 1212612018 wel(View° Well Name: H16A BC - Daily Recap Daily Operations Rpt # Start Date End Dere Summary 69.0 12/3/2018 12/4/2018 Pump Out of the hole to the top fo the XT 46. 9144' to 8036'.C/0 saver sub to HT 55. Grease wash pipe. Change out inserts to 5:4". 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 1215/2018 CIO 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 GBR 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 4W 15.2# P-110 HYD 563 liner to 7071'. 184 joints. Ave TQ=7,000 ftAbs. 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/ 5%" DP to the Whipstock. 14,538'. record up/down weights. Rotate weight. TIH to 15,090'. 72.0 12/6/2018 121712018 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/lbs. Run liner to 21,510' 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 12/8/2018 Pull dogs out of liner packer. Set packer. Rig up and test casing & liner top packer to 2500 PSI. Charted for 30 mins. Good test. Displace to 9.2 PPG brine. Capture MOBM in tank farm. Lay down singles from 14,264' to 5100' MD. 74.0 12/8/2018 12/9/2018 Continue to lay down drill pipe from 5100 to surface, all of the HT 55. TIH with remaining HT 55 and XT 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 - 12/912018 12/10/2018 Complete the task of lying doom the XT 46 singles from 2480 to surface. Pull wear ring. Remove power tongs for liner job, bring GBR power tongs for tubing run to floor. Inspect two pre-installed control line sheaves in - derrick from Work over. Lubricate same. Make up landing joint & hanger. Make 'dummy run' with hanger, mark LJ and lay down in pipe shed. Measure 35.45' ULDS distance. Change out drilling elevators and drilling bails to casing bails, and 3F" YT elevators. Hang 3rd sheave in derrick. String all three control line spools through sheaves in derrick. Load pipe shed with completion jewelry and 3W'9.3# L-80 Hyd 503 tubing. Make up seal assembly and run tubing tally as per Completion Eng tally from seal assembly to 3333'. 102 joints of 454 in the hole. 76.0 12/10/2018 12/1112018 RIH W/ 3F" tubing from 3333' to 9716' as per tally. Joint # 308. Stopped going in hole due to lost handling pup. It was discovered that a 1.69' pup had been left on the bottom of nipple #1. Begin to trip out of the hole. Nipple # 1 depth 764'. 77.0 12111/2018 12112/2018 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 3W tubing fir 1550'to 760'. remove 1.69' handling pup from bottom of X Nipple assembly #1. The box end of pup was handy. TIH from 760'to 1551'. Reconnect control line for chemical injection sub, continue to trip in with stands to 4107'. 78.0 12/12/2018 12/1312018 - RIH F/Derrick 3 1/2" Completion Tubing F/ 4,107'T/ 9,716' as per Tally Instructions - Install Cannon Clamp on each Connection - Install X -Nipple - Rig up and fill pipe with Trip Tank Pump - RIH with Completion Tubing F/ Pipe Shed F/ 9,716'T/13,903' filling pipe on the fly and topping off every 45 As - Continuous monitoring of the well - M/U SSSV - SLB functioned x 3 and tested to 5000 PSI 15/MIN - RIH TI 14,270' - Take P/U WT 138k - S/O WTI 16k - RIH and tag @ 14,434' with 10k - Space out and M/U 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 - Spotl5bbls of LVi in casing X tubing annulus for freeze protection. Remove Landing A 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 - LID Mouse Holes - Remove SLB sheaves from derrick - Flush Mud Pumps - Continue Cleaning Pits - Fill Test Pump with 4/1 Water/Methanol - Nipple Down BOPE and set on stand - Secure same - Continue preparing for Rig Move www.peloton.com Page 515 Report Printed: 1 2/2 612 01 8 P. F iC_ m a{ E� izmm y °' `SaSSe�aON.m,'.L�2a�. 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Qo< ^! e n m 1 N RR m "u'i $gg g $ YS �uwin T$ umi �u�vi u� n$�i $$$vi vi vii$ 14A iAlt FTI momTimis 55,11 8AwaA Tom&1 1wmRR &isms mos e 0606$ "nays R a swd. as ys "x 0. ga«w$ MA .m__2 evNdd WNNB 2N.Nd obs a swmsa M911H Vex xaa 11"17 .12 77777 77777 Hill H 12101 1111, ,"leo .1111 1111. a 1111 11111 mapq 21814 vuwi`ns 2Z22V 51211 28'-21 Qvnwa uwi,mmoa =.n 191 96111 10$x9 99011 milli �meem mill low a 1is 14 417"117 Rpm o,� mngnn .`9i, Rn� `wmRaa$� ^<^oa Eli21111 11111 1 1____ ?1717 214AS vAsuz AxAff mfm9v 92s*7 n1399 402Wrot go ggegq a R n$ l!aR y ""$ $ ` a -gi 17i_nn F__„_ 11111 _wa liasa-1"1- 711171 $_ 1.n wLsss s<1.a ^R;n s$aa; n;aaq^sml all naa^d nauung wry nmm0 a -2a 5 X11--oan N ramcHawe mama AAXXIV I 15 R eYNom aaa as ;wn VaaO$ amnno storm a$ sav e 777'1' L � LL 1111161 1 HUH L o 111111 w E 1111 =C 11111 r oa«s 11111 oq^e $v1s17 o$$ 22s22 22222 22222 2m $m ro$ 22222 mmmmm SIS A- AS g F°aoa $$Tam Wsmm sa« %82Vs war mm$no 1ss 8 LLS e �mm 11 11 Elm 18118 16181 MH 88111 888 x c 0 �1 - n$s�a aa�as n$;a saW$a $rasa wm 22222 mw�11 www11 w1111 pawls ss-Rp a U N_ lg-;s 11.1717 a $;r ss «1m grads yea". 117^=a $Rena om"'o$ 08 ow Sia w::S 11111 1o11V woe1V 11111 111 FR Z � E t W 6 g € c p O L C z U f »N �S�Rm1R$ >v8R$$ 9 H16A Actual MW vs. Depth Data Table Days Depth MW From MD ppg Operational Notes Spud 0 8.3 Kill well with water for sidetracking; pull tubing 3 0 8.3 Kill well with water for sidetracking; pull tubing 4 0 8.3 Kill well with water for sidetracking; pull tubing 5 0 8.3 Kill well with water for sidetracking; pull tubing 6 0 8.3 Kill well with water for sidetracking; pull tubing 7 0 8.3 Set Bridge Plug / Pressure Test Casing 8 0 9.2 Swap to 9.2 ppg OBM 9 0 9.2 RIH w/ Whipstock & Mill BHA 10 14538 9.2 Set Whipstock 11 14544 9.2 Mill Window in 9-5/8" Casing 12 14569 9.2 RIH w/ new mill BHA / drill new hole 14569', FIT to 11.9 ppg 13 14582 9.2 Cure losses w/ LCM / drill w/ mill to 14582' MD / POOH 14 14582 9.2 POOH / fix top drive / service rig 15 14582 9.2 POOH w/ mill BHA / test BOP / make up motor BHA / RIH 16 14622 9.2 RIH w/ motor BHA / drill new hole to 14622' MD 17 14735 9.2 Drill new 8-1/2" hole to 14735' 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 TO / drill new hole to 14795' MD 20 16336 9.2 Drill w/ RSS BHA / hi torque add lubes / drill to 16336' MD 21 17440 9.2 Drill L01 lateral to 17440' MD / backream & trench for L02 22 18214 9.3 Trench / sidetrack / drill L02 lateral to 18214' MD 23 18390 9.2 Stuck pipe / backream / drill L02 to 18390' MD / trench to L03 24 18592 9.3 Sidetrack & drill L03 to 18592' MD 25 19268 9.2 Drill L03 to TD of 19268' MD. Backream and trench for L04 26 18122 9.2 Drill L04 lateral to 18122' MD 27 20020 9.3 Finish drilling L04 lateral to TD of 20020' MD and backream same 28 20020 9.3 Backream to casing window / CBU / prep to TOH for new BHA 29 20020 9.3 Backream to inside casing / pump out of hole 30 20020 9.3 Pump out / LOOP / DP management / inspect BHA 31 20020 9.2 LD BHA 05 / Manage & LD DP for hard banding 32 20020 9.2 BOP Test / manage DP / hardband / PU BHA 06 33 20020 9.2 BOP Test / PU RSS BHA 06 / RIH on 5-1/2" DP 34 20020 9.2 RIH BHA 06 managing DP, 5-1/2" x 4-1/2" x 5-1/2" design 35 20020 9.3 RIH / circ well clean / RIH to window depth 36 18860 9.2 RIH / search for LOS trench / drill ahead in L05 w/ RSS BHA 06 37 20743 9.3 Drill L05 lateral to TO of 20743' MD / C&C / BROOH for L06 38 19881 9.2 JBR & 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 TO, to 15003' MD 45 223101 9.2 BROOH to inside 9-5/8" / BROOH / Pump out for liner / LOOP 1 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 223101 9.2 1 DP management / RIH w/ clean out BHA/ ream L02 area 53 223101 9.2 1 Clean out mainbore in preparation for re -running liner 54 223101 9.2 lCheck L02 area for liner entry - OK; BROOH for liner re -run 55 22310 9.2 BROOH; 7.2 earthquake hit; ream back to bottom to check hole 56 22310 9.2 Clean out to 21826'; BROOH; check L02 area for liner run 57 22310 9.2 BROOH to window; CBU / pump out for liner re -run 58 22310 9.2 Pump out / POOH on elevators for liner re -run / test BOPE 59 22310 9.2 Test BOPE / MU flex joint shoe track and run 4-1/2" slotted liner 60 22310 9.2 RU & run 4-1/2" slotted liner w/ flex joint shoe track 61 223101 9.2 Run liner on 5-1/2" DP / work liner past L02 junction / set same at TD 62 22310 9.2 Drop ball / set hanger & liner top packer / test to 3K / swap to 9.2 ppg brine 63 22310 9.25 POOH LDDP / hole static w/ 9.2 ppg brine / clean pits 64 22310 9.25 LDDP / RU to run 3-1/2" upper completion w/ control lines 65 22310 9.25 Run 3-1/2" / stop since handling pup ran in error / POOH 66 22310 9.25 Take out incorrect pup / RIH w/ 3-1/2" upper completion 67 223101 9.25 Run & land upper completion / connect control lines 68 H16A Fishbone Well Naming & Numbering Index KOP Planned Actual TD Actual Lateral Footage Lateral Volume (bbls) H -16A Mainbore Well Name PTD No. from AOGCC API No. from AOGCC Final TO (MD) Notes LO1 16382 16375 17440 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 1-116A-1-03 218-098 50-231-20051-62-00 19268 8-1/2" Open Hole completion H16A-L04 218-099 50-231-20051-63-00 20020 8-1/2" Open Hole completion 1-116A-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 1-116A-1-07 218-102 50-231-20051-66-00 1 21860 8-1/2" Open Hole completion KOP Planned Actual TD Actual Lateral Footage Lateral Volume (bbls) H -16A Mainbore 14552 22310 7758 544 LO1 16382 16375 17440 1065 75 L02 17180 17130 18390 1260 88 L03 17980 18000 19268 1268 89 L04 18780 18770 20020 1 1250 88 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, T3S, R15W SM TD 156331.17 2152368.86 -6616.64 6797.07 17440 4291' FSL, 3676' FEL, Sec. 33,1 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, T3S, R15W SM TD 154839.79 2153390.79 -6517.97 6698.4 19268 5271' FSL, 5195' FEL, Sec. 33, T35, R15W SM H16A-L04 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, T3S, R15W SM H16A-LOS KOP (Top of Production) 154580.74 2153578.86 -6882.68 7063.11 19525 169' FSL, 177' FEL, Sec. 29, T35, R15W SM TD 153610.04 2154226.91 -6571.82 6752.25 20743 790' FSL, 1165' FEL, Sec. 29, T3S, R15W SM H16A-L06 KOP (Top of Production) 153976.65 2154013.78 -6887.9 7068.33 20270,587- FSL, 793' FEL, Sec. 29, T3S, R15W SM TD 153105.84 2154577.4 -6649.98 6830.41 21340 1126' FSL, 1678' FEL, Sec. 29, T3S, R15W SM H16A-L07 KOP (Top of Production) 153224.5 2154498.02 6887.64 7068.07 21165 1050' FSL, 1558' FEL, Sec. 29, US, R15W SM TD 152675.82 2154902.24 6759.78 6940.21 21860 1438' FSL, 2117' FEL, Sec. 29, T3S, R15W SM M I6- 01'� 00III I r►ABORS / CANRIG Operator: BSC Crest Alaska Operating Date: 11/20/2018 Well Name: H16A Main, L01, L02, L03, prepared By: Alan Febus L04, L05, L06, L07 Kenai Borough, Alaska 333 W 7'" Ave, Suite 100 Location: Hansen Field Shipping: Anchorage, AK 99501 Attn: Meredith Guhl (907)739-1235 Well: H16A: (Bundle 1- 6 boxes) Blain, (Bundle 2- 7 Boxes) L01, L02, 1-03, L04, LOv, L06, L07 API: 50231210051- 01-00 TD: 111181 _ . -,,,;. Set (10 & 11 trays / set) H16A Main el Boxes & 258 Envelopes) Type Washed and Dried Frequency 30' Interval (Feet/ MD) 14580'-22310' 1-01 (1 BOX & 36 Envelopes) Washed and Dried 30' 16320'— 17440' TD Lot (1 BOX & 43 Envelopes) Washed and Dried 30' —17100'— 18390' TD Loa (1 BOX & 45 Envelopes) Washed and Dried 30' 47940'— 19268' TD i L04 (1 BOX & 45 Envelopes) Washed and Dried 30' 18660'— 20010' TD I Los (1 BOX & 42 Envelopes) Washed and Dried 30' 1 19500' — 20743' TD I Lob (1 BOX & 36 Envelopes) Washed and Dried 30' 1 20280'— 21340' TD I L07 (1 BOX & 24 Envelopes) Washed and Dried 30' 1 21150'— 21860' TD I Number of Boxes: 13 & Number of Envelopes: 531 M431 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, L03, L04, L05, L06, L07 (7 Boxes) Number of Envelopes: 531 BLUECREST RIG #1 / JOB #: A1712/ WELL: H16A: 1-01, L02, L03, L04, L05, L06, L07 v or rH F M OF ALAS�P THE STATE °fALASKA GOVERNOR BILL WALKER Larry Burgess Alaska Manager BlueCrest Alaska Operating, LLC 3301 C Street, Suite 202 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: Hansen Field, Undefined Oil Pool, H16A-LO1 BlueCrest Alaska Operating, LLC Permit to Drill Number: 218-096 Surface Location: 2408' FSL, 1509' FEL, SEC. 2, T4S, RI 5W, SM Bottomhole Location: 4428' FSL, 3891' FEL, SEC. 33, T3S, R15W, SM Dear Mr. Burgess: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.aloska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. The permit is fora new wellbore segment of existing well Permit No. 218-095, API No. 50-231-20051-01- 00. Production should continue to be reported as a function of the original API number stated above. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, (�,,�Cathy P. Foerster ��JJ�� Commissioner DATED thisIb-l"day of September, 2018. I STATE OF ALASKA , Al OIL AND GAS CONSERVATION COMMISSL .. PERMIT TO DRILL 20 AAC 25.005 RECEIVE® JUL 9 6 2018 ta. Type of Work: Proposed Well Class: Exploratory -Gas ❑Service - WAG ❑ Service - Disp ❑ 1c. Specify i5 well0.Drill a ✓ Late tratigraphic Test ✓ Development - Oil ❑ Service - Winj ❑ Single Zone ❑✓ 4xploratory Coalbed Gas' dGas Ft7r11 Reentry -Oil Development - Gas Service -Supply ❑ Multiple Zone ❑ Geothermal ❑Shale Gas 2. Operator Name: 5. Bond: Blanket ❑✓ Single Well ❑ 11. Well Name and t' •m� - BlueCrest Alaska Operating LLC Bond No. 5511251547 • r,-16AL01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3301 "C" Street, Suite 202, Anchorage, AK 99503 MD: 17,722' TVD: 6,677' Hansen, Undefined Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM • ADL 18790, ADL 384403, Fee -Hansen Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM LOCI 14-007 9/15/2018 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4428' FSL, 3891' FEL, Sec. 33, T3S, R15W SM 14423 5502' (YO1665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (11): 180.4 15. Distance to Nearest Well Open Surface: x-168863 y- 2144856.073 • Zone- 4 GL / BF Elevation above MSL (ft): 145.81 to Same POOL 313' - Hansen 1A -L1 16. Deviated wells: Kickoff depth:(0395- 9 -feet" 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angl 115 de reas Downhole: 3,549 psi Surface: 2,842 psi (using 7,070' TVD) ' 18. Casing Program: Specification 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 - L01 19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll 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): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No ❑✓ - 20. Attachments: Property Plat ✓❑ BOP Sketch ✓ Drilling Program ✓ Time v. Depth Plot Shallow Hazard Analysis Divener Sketch Seabed Report Drilling Fluid Program ✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Thomas McKay Authorized Name: Larry Burgess Contact Email: tom.mckay(@bluecrestenerovcom Authorized Title: Alasklpanager Contact Phone: 907-754-9566 Authorized Signature: 40 Date: 26 -Jul -18 Commission Use Only Permit to Drill API Number, Permi_t' pproval/J� � i See cover letter for other Number: 2" 1$' —� ( 50- 0 0 Date: 1 1� 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: 19 Other: or A96y0� � Tv �s' Samples rl Yes ❑ No � Mud log req'd: Yes 1110iC( 19 HzS measures: Yes ❑ No Ey Directional svy nl Yes &to Spacing exception req'd: Yes [tq'No ❑ Inclination -only svy req'd: Yes ao Post initial injection MIT req'd: Yes ao Approved by: APPROVED BY 9 COMMISSIONER THE COMMISSION Date: I 01 1 /'�► 1 Submit Form and Form 10401 Revised 5/2017 This permit Is valid f r n�� (Fp�>+r+proval per 20AA 5.005(8) Attachments in Duplica(e McR17A v Kr`' iy ZNSt 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 71h Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Application for Permit to Drill: Horizontal Production Well H16A — L01 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 — L0T 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 1-01 through L07, which are proposed to be open hole sidetracks off the mainbore. As per AOGCC regulations, each rib requires its own unique name and . APD. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office) or 907-350-9544 (cell). Sincerely, Larry BuOr%gfe`s's' Alaska Manager BlueCrest Alaska Operating LLC uue sit Energy Application for Permit to Drill Document Horizontal Producer H16 -A — 11-01 Multilateral "Rib" Table of Contents Cosmopolitan Project H16 -A 10-401 L01 APD 1. Well Name...................................................................................................................3 Requirements of 20 AAC 25.005(f).............................................................................................................. 3 2. Location Summary........................................................................................................3 Requirements of 20 AAC 25.005(c)(2).......................................................................................................... 3 Requirements of 20 AAC 25.050(b).............................................................................................................. 3 3. Blowout Prevention Equipment Information..................................................................4 Requirements of 20 AAC 25.005(c)(3).......................................................................................................... 4 4. Drilling Hazards Information.........................................................................................4 Requirements of 20 AAC 25.005 (c)(4)......................................................................................................... 4 DrillingHazards Summary: ..................................................................................................................... 6 S. Procedure for Conducting Formation Integrity Tests.......................................................7 Requirements of 20 AAC 25.005 (c)(5)......................................................................................................... 7 6. Casing and Cementing Program.....................................................................................7 Requirements of 20 AAC 25.005(c)(6)..........................................................................................................7 7. Diverter System Information.........................................................................................7 Requirements of 20 AAC 25.005(c)(7).......................................................................................................... 7 8. Drilling Fluid Program...................................................................................................8 Requirements of 20 AAC 25.005(c)(8).......................................................................................................... 8 9. Abnormally Pressured Formation Information................................................................8 Requirements of 20 AAC 25.005 (c)(9)......................................................................................................... 8 30. Seismic Analysis...........................................................................................................8 Requirements of 20 AAC 25.005 (c)(10)....................................................................................................... 8 11. Seabed Condition Analysis............................................................................................8 Requirements of 20 AAC 25.005 (c)(11) ....... ..... ....... ............ ......... ............ --....... ........ ............................... 8 12. Evidence of Bonding.....................................................................................................9 Requirements of 20 AAC 25.005 (c)(12)....................................................................................................... 9 13. Proposed Drilling Program............................................................................................9 Requirements of 20 AAC 25.005 (c)(13)....................................................................................................... 9 I I P a g e H16 -A 10-401 L01 APD YlueNest Energy Cosmopolitan Project H16 -A10-401 101 APD 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................................9 Requirements of 20 AAC 25.005 (c)(14)....................................................................................................... 9 15. Attachments................................................................................................................9 Attachment1 Drilling Procedure................................................................................................................. 9 Attachment2 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 BOP & Choke Manifold Configuration.....................................................................................9 Attachment 6 Wellhead & Tree Configuration.............................................................................................. 9 Attachment 7 Diverter Schematics (N/A)..................................................................................................... 9 Attachment8 Lease Map....................................................................................................................................... 9 21Page H16 -A10-401 L01 APD lueNest Energy Cosmopolitan Project H16 -A10-401 L01 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 20AAC 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—L01 Multilateral "Rib" To include the L01 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'L01, H16A-1-02, H16A-L03, H16A-1-04, H16A-1-05, H16A-1-06, and H16A-LO7. 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 LOl) is for the H16A L01 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 on item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; (D) other information required by 20 AAC 25.050(6); Location at Top of Productive Interval ("Starichkot" Sand) Location at Surface - H26 Slot —same for H16A 2408' FSL, 1509' FEL, Sec. 02, T4S, R15W SM Measured Depth, RKB: 16,382' 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 ("Starichkot" Sand) 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM ASP Zone4 NAD 27 Coordinates Northing: 2,151,793.49' Easting: 157,163.69' Measured Depth, RKB: 16,382' Total Vertical Depth, RKB: 7,007' Total Vertical Depth, 55: 6,897' Location at Total Depth 4428' FSL, 3891' FEL, Sec. 33, T3S, R15W SM : ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB17,722' Northing: 2,152,512' Easting: 156,120' Total Vertical Depth, RKB: 6,677' Total Vertical Depth, 55: 6,497' Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill /Form 10 401) must (1) include a plot, 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 all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 31Page H16 -A10-401 L01 APD DIOe est Energy Cosmopolitan Project H16 -A10-401 101 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, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 5: BOP & Choke Manifold Configuration 4. Drilling Hazards Information Requirements of 20AAC25.005 (c)(4) An applicationfor 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=(7,070TV1D) (0.502-0.1 psi/ft) =2,842 psi (using TVD instead of TVDss for this calculation) MAX BHP=(7,070TVD) (0.502 psi/ft) p =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. 41Pag0 H16 -A10-401 L01 APD lue st Energy 4000 N N V p 5000 Pressure Model (EMW) 9 10 11 12 13 14 15 16 17 18 19 20 EMW (PPG) Lithostatic Stress • MDT Data —Frac Gradient —Moving Average —Planned Mud Weight Cosmopolitan Project H16 -A10-401 L01 APD VpperTyonek,3292.44 Lower Tyonek, 6059.01 Sterichkof, 6874.84 Hemlock, 6902.77 SlPage H16 -A 10-401 LOl APD lue st Energy Cosmopolitan Project H16 -A10-401 L01 APD Drilling Hazards Summary (only the 8-1/2" Hole Section applies to this APD): 17-Yz" Hole Section / 13-%" Casing Event Risk Level Mitigation Strategy Clay Balling Maintain planned mud parameters, Increase mud weight, use Lost Circulation Low weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in LCM pills, lost circulation material. Surface Formations Low Diverter drills, increased mud weight. Directional Control LOW BHA design, on -sight geologic review, avoid "drilling the line". Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use Tight Hole 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 LOW Reduced trip speeds, mud properties, proper hole filling, real time trips LOW equivalent circulating density (ECD) monitoring, weighted sweeps. Sloughing Coals, Low Increased mud density and fluid composition according to plan, Tight Hole controlled trip speeds, ECD monitoring, optimized hydraulics for Pressure Low hole cleaning. Abnormal Reservoir Low H2S drills, detection systems, alarms, standard well control Pressure Low t Well control drills, increased mud weight. Hydrogen Sulfide Gas ° Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers. 8-34" Hole Section / 4-%" Slotted Liner Event Risk Level Mitigation Strategy Fluid density according to plan, reduced pump rates, reduced trip Lost Circulation Low - speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips LOW equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Low BHA design, on -sight geologic review. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers. 61Page H16 -A10-401 L01 APD lue' est Energy Cosmopolitan Project H16 -A10-401 L01 APD 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formotion integrity tests, as required under 20 AAC 15.030(a, 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 10 AAC 25.030, undo description of ony 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" Cs9/Tbg Hole Weigh Length Tap atm OD (in) Size t Grade Conn (ft) MD/TVD MD/TVD Cement Program (in) (Ib/ft) lfU (R) 20" .5001 N/A A525 Weld 146' 41'/41' 187'/ 187' N/A (in place) 13-3/8' 4,177'/ 786 TOTAL BBLS 17-1/2" 72 L-80 BTC 4,136.5' 40.5'/40.5' LEAD: 588 bbls 12.00 ppg Kenai Lead (in place) 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' (in place) 6,688' 7,083' 14, 22, 829'/ No cement required 4-1/2" 8-1/2" 15.2 P-110 Hydrit563 8,574' Slotted liner completion 6,870' 6,880' 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 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 5: BOP and Choke Manifold Configuration. A diverter system will not be necessary since the well will be sidetracked out of 9-5/8" casing using the Rig # 1 BOP stack and choke manifold. 71Pa9e H16 -A10-401 L01 APD lue,7clkst Energy Cosmopolitan Project H16 -A10-401 L01 APD 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: f8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Drilling will be done with a drilling fluid having the following properties over the listed Production interval in the following Table. It is planned to drill the H16A production section using a solids free oil based mud system with no barite and only a small amount of calcium carbonate used unless losses dictate the addition of bridging material, and coupled with an RCD and MPD ✓ (Rotating Circulating Device or Rotating Head and Managed Pressure Drilling) to minimize near wellbore formation damage in the reservoir section. Since the well design does not allow for any type of well stimulation or acid clean up after completion, it is vital for well productivity to drill the reservoir using MPD with as light a mud weight as possible, and with as few solids as possible. Parameter Surface Intermediate Production Type N/A N/A OEM — Low Solids Name ACTIMUL Reservoir Drill -In Density (ppg) 8.8-9.0 Oil: Water Ratio 70:30 6/3 RPM 8-12 PV (lbs/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 an item already on file with the commission and identified in the application: (9) for on exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 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 for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from on 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(6); Not applicable: Application is not for an offshore well. 81Page H16 -A10-401 L01 APD nue est Energy Cosmopolitan Project H16 -A10-401 L01 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 (Sonding)have been met; Evidence of bonding for BlueCrest Alaska Operating LLC is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 15.005 (c)(13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 20AAC 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) with the information required under 20 AAC 25.180 and 20 AAC 15.283, f13) 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 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; 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 9 1 P a g a H16 -A10-401 1-01 APD llueNest Energy Attach Cosmopolitan Project H16 -A10-401 L01 APD Attachments H16 -A10-401 L01 APD Attachments lue 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 11.01-11.071 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-L01. 62. Directionally drill well to 1-01 target and drill L01 lateral to 1-01 TD as called by Geologists. 63. Circulate and backream the L01 lateral back to the main bore. 64. Run back in to TD of the main bore. 65. Displace the L01 lateral with LVT. 66. Strip out using MPD without backreaming if possible to the main bore. 67. Initiate trenching and time drilling to execute an open hole sidetrack away from L01 and to the kickoff point for the L02 lateral. 68. Directionally drill the L02 lateral using the same procedure as LOl. 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 H16A_APD Well Plan Last Updated: TWM, 11 July 2018 ^187' MD/TVD Driven BR: N/A RSS: N/A MWD: N/A LWD: N/A 17-1/2" Open Hole 4,177' MD/3,175' TVD H16 -A Fishbone Production Well (Main Bore / Lower Lateral / Stanchkof / Hemlock Primary Target) Well will be sidetracked through window in 9-5/8" casing ACTUAL PUMPED 12.0 ppg Lead ---------------- 588 bb1s 15.8 ppg Class G Tail a 198 bbls Incl 73 deg Azim 304 de 3-1/2" Production Tubing to Surface GLM's / SSSV / DH Gauges / CIM Bit: N/A RSS: N/A 12-1/4" MWD: N/A Open Hole 9-5/8" 47# P110 H563 (13,161') LWD: N/A 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 Inc[ 78 deg 1 I I 9-5/8" 53.5# P310 H563 (14,767') I Azim 303 deg Bit: 8-1/2" PDC I RSS: %ceed675 OBM MWD: Telescope 8-1/2" I I Un -cemented 8.8-9.O ppg VersaPro LWD: GeoSphere Open Hole I I Slotted Uner with MPD adnVISION i No Frac's 4-1/2" 12.6# P110 H563 Slotted Liner J6,, Un -Cemented Slotted Liner Completion Max Incl 107 deg 22,829' MD/ 6,880' TVD Total Depth in Mainbore Azim 303 deR T. McKay, 12Ju1y2018 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-h" 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 9-5/8" 47.0/53.5# P110 H563 @ 14767' MD lye est 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-X" 17# H521 Slotted Liner @ 22829' MD H16A Fishbone Design IueC.fest Energy Attachmen Cosmopolitan Project H16 -A10-401 LOt APD Attachments Nf6-A 10-401 L01 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 2150581.45 2572' FSL, 1182' FEL, Sec. 33, T3S, R15W SM L01 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, T3S, R15W SM L03 17980 155847.77 4967' FSL, 4721' FEL, Sec. 33, T3S, R15W SM 2152699.77 4608' FSL, 4168' FEL, Sec. 33, T35, R15W SM L04 18780 155189.00 2153153.63 5044' FSL, 4839' FEL, Sec. 33, T35, R15W SM LOS 19580 154530.21 2154004.00 2153607.47 196' FSL, 228' FEL, Sec. 29, T3S, R15W SM L06 20382153869.79 153347.00 2154062 46 633' FSL, 901' EEL, Sec. 29, T3S, R15W SM L07 21107 153272.06 152808.00 2154473.31 1026' FSL, 1509' FEL, Sec. 29, T35, R15W SM H16A Total Depth Nearest Property Line MD X Y01665 Y 5502 Legal Main Wellbore 22829 151874.00 L03 2155437.00 Y01665 1950' FSL, 2933' FEL, Sec. 29, T3S, R15W SM LO7 17722 156120.00 2372 2152512.00 L06 4428' FSL. 3891' FEL. Sec. 33. T3S. R15W SM L02 18730 155305.00 Y01665 2153074.00 4967' FSL, 4721' FEL, Sec. 33, T3S, R15W SM L03 19590 154601.00 2153558.00 149' FSL, 156' FEL, Sec. 29, T3S, R15W SM L04 20374 153954.00 2154004.00 576' FSL, 815' FEL, Sec. 29, T3S, R15W SM L05 21105 153347.00 2154422.00 977' FSL, 1433' FEL, Sec. 29, T35, R15W SM L06 21745 152808.00 2154794.00 1334' FSL, 1982' FEL, Sec. 29, T3S, R15W SM L07 22315 152320.00 2155129.00 1655'2479' FEL, Sec. 29, T3S, R15W SM H16A Distance to Nearest Property Line Main Wellbore 694 Y01665 L01 5502 Y01665 L02 4595 Y01665 L03 3800 Y01665 L04 3066 Y01665 L05 2372 Y01665 L06 1751 Y01665 L07 1202 Y01665 lueC est Energy SIO. Name: Dela: I AHD I DDI / ERD Ratio: dine Reference System: non Lat/ Lone: Von Grid ME YA: Grid Convargenea Adak: Scale Factor: on I patch: H16A-L01 (P2) Proposal Geodetic Report (Def Plan) BlueCont Vertical $action Azimuth: Coamo'lien link Vertical Section Origin: dik1emopn Pad/K18 w Reference Darted, StudyTVO H16 Y NS Fessib"i Ground Ekvaeon: 50231200051-60 MaalGe 111".1.01 Total Mfay FieldStr SVen9m: 10710.2010 ly10218 , Model: Totalgneti 189,185°/1402272ftn16,848,n2,U Total Magnetic Feld 54enIlIM1: 64,21 Fact NA5T Dip Magnetic Dip Angle: N 1'M W'Plane,Zane OedlnaIc mi 14,185328434S.E1688U 23001216' N 218855.980 813.E 180062.230 /IUs Magnetic Declination Model: Declination -105)(0" Relerencc 1.0000218 Grid ce Wei Corr 2.10.540.0 Tonal Map Total Corr Mao NortM1-aTrue Nr Schim"erger 300.000' (Tme Nom) 0.000 It, 0,000 ft Rotary Table 180 030 ft above MSL 1450100above MSL 14.561' 1012613m9n (9.80865 8e0etl ) DOX 55102.359 nT Serpen 10, 2018 HDGM2DGM North Tme Nom 0.0000' 10.5612 ° c.,mmant. MO Ind Adm True TVOSS WD VSEC NS EW TF OLS Directional Exclialon Zone Excluclon Zone Gang, Th NeHM1in9 Eaanng Ifll 1°I (9 Ifl1 Ifll IRI (al (ftl 1°I 1°neeftl wmally index Alert Angle et (nT) (MS) (fats) RiE am 090 080 -18003 0.00 080 000 080 OM NIA 0.00 17.12 16221.09 218055.98 168862.23 34.62 0.00 0.00 -145.81 34.62 0.00 0.00 000 249.54M 0.00 0.00 1712 16221.16 218055.98 16886223 10080 043 24954 -60,13 100.00 0.16 409 -0.23 252,78M 0.66 000 17.37 16451.11 218855.90 168862.00 20.00 1.02 252.78 is" 199.99 1.00 41.48 -143 320.54M 0.59 0.19 17.68 18]33.41 218855.54 16006019 3000 2A2 320.54 119.52 299.95 358 009 -3.62 333.09M 224 1.14 1582 1019.20 2144856.% 168850.63 400.00 540 331.89 219.28 399.71 9.47 674 -104 33.21L 3.10 1.85 1340 12843.18 2144862.91 16885538 0080 Tat 323.52 318.63 499.06 19.8 1629 -13.05 64.094. 2.49 2.30 13.64 12997.58 218872.62 168049.63 60.00 9.91 30390 417.48 59191 34.11 26.31 -2420 70.581. 3.85 2.0 1677 15902,54 2144882.64 160830.75 700.00 11.34 287.80 515.79 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16863928 1623.23 2595 30.17 14086 150.49 299.70 148.12 -20.54 452L 2.44 4.11 26.62 246960 214011.13 1600581 171Z0 26.63 300.05 1484.0 1665.03 341.46 169.07 296.67 4.41R OR 4.17 27.18 25179.-63 214033.0 168570.26 1811.41 2].53 30020 1560.19 1748,62 384.20 190.52 .731.64 2431, 096 4.24 27.85 257054 2145055.51 180533.89 190543 20.66 299.14 1651.13 1831.56 420.47 212,13 -372.11 17434. 1.31 030 29.05 26769.95 2145INSA6 168496.02 1999.47 3032 290.11 1732.99 191342 474.75 234.60 412,75 2.37L 1.85 4.36 30.70 20147.42 214510112 168456.0 2093.53 32.53 297.94 1813.24 1993.67 52316 257.64 -056.64 1306L 2.35 442 32.0 29704.21 2145125.93 16811336 218805 35.54 296.74 1891.56 2071.99 576.59 20191 -03.03 &71L 326 4.49 3553 32038.34 2145151A7 16836104 229597 37.49 298.42 1978.30 2158.73 640.69 310.64 560.46 26.15R 1.02 4.66 3233 33430.65 214510115 168310.41 237665 3921 29]15 2041.5] 2=0(s 6088 333.8 {05.02 2DW 2.36 4.61 38A6 34292.42 2145205.75 1,-6826-6.49 -" 24]3.35 42.17 29940 2114.89 2295.32 ]53.]0 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MO 131 Incl 1°I Anm True 1°I NDSB (ft) NG (rt) VSEL Ifll HS Iftl EW Ift1 TF 1% OLS Duty Ind.l EaeluA Zom 1°nooRl Difficulty lnaas awn EFdueim7Zons An01e GeoMp TN (nr) NaHHin9 (ftus) EesOng (flus) SLB MWD6GMAG 1252487 6212 299.14 6247.61 6428.04 9076.20 466351 ,3711.58 165.OR 0.36 639 63.93 4SM241 2149756.73 100280,37 SLB MWD+SAG 12618.68 66.54 299.30 620482 6404.95 9%2,34 4]05.61 -078685 168.5L 0,29 640 63.33 49322.41 2149790.06 160206.3] 12]1212 66.2] 299.24 632216 6502,59 10048.61 4789.% -8862.02 25061- 029 640 6309 4921948 2149843.02 160132.36 12806.45 66.08 298.93 653985 10134.60 4]89.55 -9932.18 140.361. 022 641 63.76 49978.25 21498a&M 160058.3] 12997.53 66.35 290,35 6359.42 6396]6 65]].19 10220.93 4831.00 -9012.93 4987L 013 642 63,30 4935356 2149930.36 159983.]] 12984.82 66.02 29].0] 661666 1030741 49]1,84 -908912 11736L 075 642 64.02 49618.56 210015,05 159908.63 13000.71 66.40 297.06 6471.51 6471.51 665904 10393.50 4911.58 -9242,25 081 643 63.86 49540.98 215001500 15983327 13182.28 68.93 296.88 6508,5] 6609.00 104]930 4950.55 -9242.25 7,361- 0.59 844 49]92.54 215005609 159757.79 132]603 67.44 297.25 654520 6725.63 1056548 4909.01 -9319.10 W.WR 0.39 644 Mad 64.44 49793.59 215009]44 159882.03 133]0.05 6]44 297.93 6581.55 616198 10652.11 5029.9] 1M.31. 100.3L 0.77 645 64,59 490 215013987 159606.30 13484.09 6.29 297.02 669.]5 6790.10 1073882 5070.07 .9395.94 -94]2.95 90.721- 0.91 6.45 97.]1 8.87 49900.81 21 1.]9 159530.41 13556.80 6738 29 6653.55 803398 1221-17 510].9] -9549.50 47.941. 1.33 646 65.10 50065.93 2150 W22221.82 15945684 136W.fi6 67.30 29580SA(I 6689.]2 6010.15 1091053 5105.50 -9627.97 99.871. 0.16 647 65.16 50090.61 2150261.51 1593]].88 1374408 67.31 29536 6725.93 6906.36 1099102 5103.04 -970584 159441- Odd 6.41 6522 0116.50 2150301.14 159300.60 1363874 70.04 29525 676243 694286 1108345 5220,50 -9784.23 0.14R 0.31 6.48 65.00 5002867 21 W378 15922332 13932.68 70.95 295.26 6]98.09 6916.52 111]0.83 525].51 -9063.53 9511. 4,16 6 69 69 40 51431.67 21 W379.855 15914506 14026.48 295.97 6823.59 7003.94 11260.24 5296.29 -9944.40 26. 443 6.51 ]240 5261109 215042081 159065.28 1412047 n 710 .03 29691 6846.19 7026.62 11351.28 5336.05 -100260614.M 2.92 6.52 74.02 53061.32 219063.63 15898015 1421846 8911 29105 6885.13 T045.% 53]905 -10107.90 290 6.50 ]638 53649.09 215050].99 15890409 Top Survev 1430935 81.30 299.05 6886.56 9060.99 lliM539 11535.]9 5422.99 40109.42 20358 o3W 285 6.55 ]197 53904.71 2150554.13 158023.19 Top WHips4«k /1431900 • 82.40 6886.29 7066.22 11576.03 544265 -10224.54 201. 2.67 70.42 54977.09 21505]4.]3 150]6922 Buse WS X1436280 84.35 300.14 WOA4 688].79 7060.22 1160894 5449.06 -1023510 HS 16.00 ESE 6.97 8008 5437749 215059145 158768.19 Cry 1100 1438200 8435 39714 6891,49 7070.19 11608.85 545906 -10252.95 0.00 6.56 8008 5431154 2197591.91 158]61.26 1440000 86.62 6091.49 7071.92 11626.]6 5160.12 -102%.41 95R 59.958 3.00 6.56 80.21 54390.10 2150601.39 160646.05 14500.00 86.13 WWOE13,22 30322 6099.55 7449.90 11726.37 5520.81 -10353.2 59.761. 6,97 80.92 54510.14 2150656.36 15866292 1462.2 8164 30581 706542 1182590 5597.30 -1043527 59.6E 3,W 32 659 8185 54617.10 2150715.15 160602.22 End Cry 14632.00 30664 6906,17 6906.4] 8086.82 1185].69 5596.28 -1048101 HE 3.00 6.60 8189 54650.07 2150]36.]4 1472.00 MM3 88.13 30664 7088.82 1192520 5636.84 -10545.60 416 000 660 8189 54650.11 2150]]6.]] IMMO.95 1%97340 Cry 1100 14]3200 88.13 W5A1 6909.43 690943 729.88 1192.9] 5655.92 -10511.27 2110L OM 660 8189 54690.21 210OW24 1604]0.40 1482.2 89.99 30581 6910.55 9090.98 12024.86 5696.10 -10596.21 241E 3.2 6162 8391 5402.82 21083810 158424.66 End Cr, 14817,40 WAT 6910.46 7090.91 12124.07 $106.25 40610.24 HE 300 6.62 8443 5494142 21WB48.63 158410.81 1492.2 90.47 WISM W5W 6909.80 1090.23 12124.0] 5154.32 -10617.41 HE 000 6.62 8443 5494141 2150090.61 158364,98 1512.2 90.41 305.59 1089.42 12223.97 5812.52 -10750.73 HS OW 6.63 8443 5494150 2150959.00 102652] 1512.2 90.47 305.59 6908,17 7088.78 12323.11 97]0.22 -10010.01 HS 02 6.64 8443 54941.66 2150019.39 1018557 15200.00 90 47MAT 30559 6907.35 6907.35 72178 12422.63 5920.92 -1221.36 HE 02 6.61 83A3 54941.66 2151019.18 15810586 15300.00 WAIT 30559 6905.54 4086.97 12522.15 5986.12 -1122.61 HE 0.2 865 04.43 54941.%2 2151140.9 150026.18 15400.00 2.46 305.59 6905,]2 626.15 12721.20 6045.52 -1123.30 HE O.W 6.65 04.43 5494110 2151260.56 15796645 1552.00 2.47 6904.90 6085.33 12721.20 6163.52 -11165.30 HE 0.2 697 84.43 5494104 215126095 151086,75 15600.00 90,47 W&W 305.59 6904.09 7 12820.72 6161.12 -11266.62 IS 02 667 64.43 54941.96 2151321.34 15]]8].04 1570000 904] 305.97 6903.27 723]008310 12820,24 6219.92 -11327.93 HS OW 6.70 84.43 54941.98 2151381.13 157]0].34 15900.00 90.47 32.9 6902.45 722.68 1301976 6270.12 -1142.25 HS 0.2 6.60 84.43 54942.01 215152.9 15762163 1592.00 90.47 305.59 690164 408206 13119.20 6336,32 -11690.88 HS 0.2 669 84.43 5494201 2151562.51 15]56].93 1610000 97.47 3050 721.25 13220.00 6394.52 -11511.80 HS 02 6.69 84.43 5494212 2151582,90 15736823 16100.00 96 305 59 6900.0 0.47 7090.63 13318.32 6452.22 -11653.19 HS 02 6.70 86.43 54942.18 215162329 15]38952 1622.00 90.47 305.59 6899,19 6099.19 609.62 13417.04 6510.92 -11636.51 HS 0.2 6.70 64.43 5494213 2151683.60 15730882 16300.00 9047 30597 898 7078.60 13517,36 6569.12 -11815.82 HB 000 6.71 3 54942.28 215944.00 157229.11 C 1100 ry 1633086 247 305.59 6 6090.12,12 9448.55 13546.06 6617.06 -11860.92 10.81,MM 0.2 6.71 84.43 51942.30 2151762]1 157264.51 16382.86 922 305.30 6897.00 7077.43 13619.02 669.22 -11883.27 11.14L 3.2 6.72 85.99 552133 215991.2 157163.00 1640000 92.97 305.20 6896.33 13616.08 6621.11 -11891.25 11.18L 3.2 6.72 N150Was 59799.69 2151974.26 15714929 16500.2 9535 304.62 6889.39 7M.82 1059.82 13716.26 6680.19 -11919.2 11.18E 3.00 673 97.59 5522.52 2151083.55 15706964 16600.00 9939 303.03 607135 M57 78 1301524 7040.17 -1221.2 1134 3.2 675 84.52 54151.02 2151921.13 156908 ,64 16700.00 101.33 32.43 6860.22 7040.65 13913.54 70948 ] -12142.95 118 % 32 616 84.53 51951.33 2151910.65 1%9003414 16000.2 104.2 30203 6830.2 6918.49 14010.2 6888.9 -12224.75 11.46L 3.00 6.T7 88.54 51602.01 2152034.06 15682806 06900.00 10].211 302.20 6010.91 6991.37 1410104 6830.2 -1230575 11 3.2 6.79 78.55 5410404 2152068.2 156748.34 EndC, 16969.53 109,25 30115 6109.10 6969.61 1417504 693681 -123611 HS6 HS 3.2 6.79 7648 5356031 2152124.54 156693.30 9000.00 109.25 301.75 6779.13 6926.59 1420119 6950.01 -1238623 H3 0.2 76.48 53670.33 2152140.% 15666926 1]100.2 109.25 30115 6]66.26 6926.97 14296.15 6999.69 -1246650 HE 0.2 son 697 7848 5367033 215219209 1156590.36 Cry 112 17156.26 109.25 30115 672826 6 14347.35 ]026.65 -125102 104R 0.2 697 76.00 537002 2152220.32 1%547.55 17200.2 110.80 30202 6112.61 6893.1089110 14390.33 704936 -1251651 10.49R 3.2 6.81 15.26 53382.83 2152286.02 15651167 17201.25 113.00 302.62 6602.97 1"U.91 ]2962 -12610.36 11.11R 3.2 682 73.2 52813.28 215226600 156449.00 1]300.00 113.55 302,62 66152 MOM 6855.52 14002.93 702.89 -1262480 11.118 3.2 682 122 52613.13 215229566 156634.77 EM Cry 17354.07 115.17 30297 6652.46 6832.89 14532.63 ]1252 42M,17 HE 3.2 683 71.15 52238.14 2152323.86 t%3938] 1]400.00 115.9 302.97 6633.21 6113.10 14573.63 7148.19 -127771.11 HE 0.2 683 7115 52231.86 215234102 1%359.82 9500.00 115.9 302.97 652.71 14664.01 119164 -127n.10 HE 02 6.84 71.15 5223636 2152398.32 1562115.25 17600.00 115.1] 302.97 6546.22 6728.65 672965 14754.40 7246.69 -12653.2 H 0.2 6.84 71.15 52236.0 50 21529.61 156210.68 1]]2.2 115.1] 302.9] 645.59 6686.12 14044.78 7295.94 -1292997 HE 0.2 685 1114 52236.2 2152510.90 156136.12 ID 61772161 115.17 39797 662.97 667603 14066.32 7306.59 -12945.38 02 685 7114 52235.92 21525122 1%12000 Surv.y Error Modi ISCWSA Rev 0"'3095.20% Conftlancs 2T955 sigma survey Program: De ... 1ps. pan MD From MO To (A) (a) 4126.070 14300.350 1432.397 14349.02 14349 WO 1402.02 14000.000 163202 14600.000 9121.612 DRlling Office 2.10.302.0 EOU Frey H.I. Sin Casing DiemalsrEape and Mas (ft) (in) (in) Indlnallen Survey Tod Type sad Ad Sma 17.00 13.375 SLB CNSG•CASINI Ast Sins 17.00 13.375 SLB MWD6GMAG Act Sols 12250 9825 SLB MWDeGMAG 1/100000 12,250 9.625 SLB MWD6GMAG IIIW.02 0.500 0000 SLB_MWD4NC ONLY F 1/100.000 0.500 0.000 SLB MWD+SAG 1/12.02 0.500 0000 SLB MWD•GMAG Cosmopolitan Unit\Cosmoplftan Pad\H74\H14\H14 (P5) Sdaw.Isum, H16PB1/H16PS1 H16PS1/H16PB1 H16A-L01 IMM-LO1(P2) H16A4L01 IMSA101(P2) 411691-01 I H16A101(P2) H16A-LO1 IMM-LO1(P2) 7/17/2018 2:04 PM Page 3 of 3 [omas.me.xw .00 rt x, a.00 rt o s mo.00• (OAihx, F VMI"Is. (fl) NaM 11 E10 ]04.W VMictl Sacllan lh) WEST (h) EAST WEST (h) E T .r]%O .tAb .t]GT. .tKq .ttLLp .�RCp .fpif0 .96W H16A-L01 (P2) Anti -Collision Summary Report Analysis Date-Ydhr Time: July 10. 2018-10:53 Analysis Method: 3D Least Distance Client: BlueCrest Reference Trajectory: H16A-LOt(P2)(Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (ft) Structure: Cosmopolitan Pad Rule Set: D&M AntiCallision 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-L01 Database l Project: Iocalhostldnlling-Cook Inlet Scan MD Range: 14308.35ft-17721.61ft ISCWSA03-D 95.000% Confidence 2.7955 sigma, for subject well. For Traiectory Error Model: offset wells, error model version is speciried with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not pwfomledl Selection filters- Definitive Surveys - Definitive Plans - Derinfive surveys eulude definitive plans -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 Trajectory Se aralw Allow Sep. Controlling Reference Trahwh Risk Level Alert Status Ct-Ct ft MAS R E0U ft Oev. ft Fact. Rule MD ft TVD ft Alert Minor mor Major Maim H16P81(Def Survey) 0.00 231.89 -154.92 -2310 -0.01 OSF1.50 14308.35 7060.99 OSF15.00 OSF<1.50 OSF<1.00 Enter Major 0.06 183.75 -122.83 -1837 -0.011 OSF1,50 14310.00 706123 MinPt-0-SF 0.00 196.50 -131. -196.5 -0.01 OSF1.50 14349.00 7066.72 Mins 000 141.46 -9463 -141.46 -0.01 OSF1.50 14350.00 7066.85 MhP(-OSF 0.14 144.7 -96.71 -144. -0.01 0SF1.50 14360.00 7068.02 Min% 10.16 236.8 -148.09 -226.71 0.06 0SF1.50 14580.00 7084.51 MINK-O-EOU 14.20 241.55 -147.16 -227.3 0.08 OSF1.W 14620.00 7086.19 MInPI-0-ADP 22.96 251.46 -145.01 -228.50 0.13 OSF1.50 14690.0 7088.49 MinR-0-ADP 37.98 277. -147. -239.82 0.20 OSF1.5014800.00 7090.98 MINPT-O-EOU 40.51 281.08 -147.20 -240.57 0.21 OSF1.5) 14817.40 7090.91 MInPt-O-ADP 288.18 -10992 -MS.65 043 OSF1.50 15710.00 7083.62 MinPt.CtCt 82.61 288.81 -110.26 -206.2 0.4 OSF1.M 15740.00 7083.37 MinPt-O-SF 82.98 289.61 -11042 -208.63 0.43 OSF1.50 15783.06 7083.05 MINPT-O-EOU 84.55 291.43 -110.06 206.88 0.43 0SF1.50 15890.00 7082.15 MInPI-O-ADP 85.64 292.55 -109.72 206.91 0." 0SF1.50 15960.00 7081.58 MhNP O -ADP B7.W 29525 0SF1.50 16130.00 7080.19 MINPT-O-EOU 88.14 296.37 -109.771L_208 J2 0.44 0SF1.50 16180.00 7079.78 MinPt-O-ADP 142.95 217.30 -2.25 -74.35 0.98 0SF1.M 16960.W 6972.73 OSF>1.06 &it Major 179.55 183.17 57.11 -3.62 1.47 OSF1.5] 17110.W 6923.29 OSF>1.M Exit Minor 408.47 133.42 319.19 275.04 4.62 OSFi.M 17721.61 6676.93 TD H16 (Def Survey) Fail Major O.W 231.89 -154.9 -231.8 -0.01 OSF1.50 14308.35 ]060.99 OSF<500 0SF<1.50 OSF<100 Enter Major 0.00 183.75 -122.83 -183.] -0.01 OSF1.50 14310.00 7061.23 MinP,-O-SF -1965 O.06 196.101-228ZO -0.01 OSF1.50 14349.06 7066]2 Mire O.06 141.3 -14146 -0.01 OSHZI) 1439.06 7066.85 MInPI-O-SF 0.14 144.1 -144.6 -0.01 OSF1.50 14360.00 706B.2 Mh%s 10.16 236. -226.71 0.06 OSF1.50 14560.06 7084.54 MINPT-O-EOU 14.20 241 -22].3 0.06 OSFI.M 14620.W 7086.19 MInPt-0-ADP 22.96 251.1 -228.50 0.13 OSF1.50 14690.00 7083.49 Min% -0 -ADP 3].98 2T7.-239.82 0.20 OSFI.M 14600.00 7090.98 MINPT-0-EOU 40.51 281.0 -240.5 0.21 0SP1.60 14B17.40 7090.91 MaPt-0-ADP 82. 288.18 -109.92 -205.65 0.43 OSFI.M 15710.00 7083.62 MinPt-C1Ct 82.61 288.81 -110.26 -206.2 0.4 OSFi.M 15740.06 7083.37 MinPt-0-SF 8298 289.61 -110.42 -206.63 0.43 OSFI.M 15780.00 7083.05 MINPT-O-EOU tW65 291.43 -110. -206.8 0.43 OSF1.M 15890.06 ]062.15 MinPt-O-ADP 85.64 292.55 -109.]2 -206.91 0.44 OSF1.50 15960.W 7081.58 MInPt-O-ADP 87.30 295.2 -1098 -207.95 0.44 OSFI.M 16130.00 7080.19 MINPT-O-EOU 88.14 298.37 -1WJ I 0.44 OSF1.50 16180.00 7079.78 MinN.0-ADP OSF>1.00 all Major OSF>1. W all Mirror TD OSF<5.00 0SF15.0 142.95 217.30 -2.25 -74.35 0.98 OSF1.W 16960.00 6972.73 179.55 183.17 57.11 -3.62 147 0SF1.W 17110.00 6923.29 408.47 133.42 319.19 275.04 4.62 0SF1.50 17721.61 6676.93 Hansen #1 AL1 (Def Survey) Enter Alen MinPls MinR.0-SF 103051 310.96 822.88 719.55 498 OSFi.W 1491000 7090.15 OSF>5.00 806.77 532.75 451.2 274.01 2.2 OSF1.W 16300.00 7078.80 587.63 592.66 192.20 -5.02 149 OSF1.W 18850.50 7005.55 431.27 651.41 -3.34 -220.15 0.99 0SF1.50 1724060 6878.64 316.38 646.76 -115.15 -330.38 0.73 OSF1.50 17I .W 6886.12 313.47 643.62 -115.98 .3WA51 0.73 OSF1.W 17721.61 6676.93 Hansen#1 (Def Survey) MinP1-O-SF MInP1-0-ADP MINPT-O-EOU 1030.51 311.13 822.77 719.38 4.98 OSF1.W 14910.00 7090.15 821.09 560.3 44].21 260Jfi 220 0SF1.5() 16300.00 7(1]8.80 697.% 701.66 229.72 -3.90 1.49 OSF1.50 16950.00 6975.96 656.72 751.31 155.52 -94.59 1.31 0SF1.W 17300.00 6655.52 656.98 752,311 155.11 -95331 1.311 OSF1.W 17330.00 6843.32 711.86 714.47 235.21 -2.62 1.49 OSF1.W 17680.00 6694.63 72389 70564 253.13 18.25 1.54 OSF1.50 172161 667693 Hansen #1 A (Def Survey) 1030.51 311.11 822.78 719.40 4.98 OSF1.W 14910.00 TOW.15 821.09 560.244].2 250.8 2.20 OSF1.50 16300.00 7078.80 702.12 702.47 233.48 -0.35 1.50 OSF1.50 16950.50 6975.96 6]3.3 750.73 172.53 -77.39 1.35 OSF1.W 1727080 6867.30 674.26 754.18 1]1.16 -79.90 1.34 OSF1.50 17 .W 6847.43 675.03 755.17 171.25 -80,141 I.M1 OSF1.50 1T340.00 6839.16 729.34 738.10 236.94 -8.77 1.48 OSF1.50 1772161 6676.93 H12-LO5(Non-Def Survey) 956.33 287.82 764.12 668.51 5.00 OSF1.W 15370.00 708640 865.93 313,83H 656.3811 5U.101 4.15 OSFl.W 16300.00 707880 650.08 301.16 652.98 552.92 02 OSF1.W 16650.00 ]049.65 853.98 301.11 652.91 5528 426 OSF1.50 16670.00 7046.32 853.96 301.08 6U.911 552.88 426 OSF1.50 16680.0 704446 853.9 301.05 652.92 652.90 4.26 OSF1.W 1669D.00 ]002.59 922.71 277.51 73].37 645.19 5.W OSF1.W 17670.00 6698.68 931.00 275.26 ]4].16 655.74 5.09 OSF1.W 1]72161 6676.93 H12 (Non -Def Survay) 9%33 287.82 754.12 668.51 5.00 OSF1.W 15370.00 ]086.40 885.93 313.83 15 OSF1.50 16W0.0D ]0]8.80 654.08 301.16 652.98 552.9 4.2 OSF1.W 16850.0 7049.85 853.98 301.10 652.11211 M2.8811 4.26 OSF1.W 16670.00 7006.32 853.96 301.0 652.92 55289 4.26 OSF1.50 16680.00 7044.48 853.9 301.04 652.93 552.91 4.26 OSF1.50 16690.00 7042.59 922.71 277.51 737.37 645.20 5.00 0SF1.50 17670.00 6698.88 931.0 275.25 747.17 8 .75 5.09 OSF1.W In21.61 667693 H12-1.03 (Non -Def Survey) 956.33 287.83 764.12 668.50 5.00 0SF1.W 15370.00 708640 865.93 313. 656.mll 552091 4.151 OSF1.W 16300.00 707880 854.08 301.17 652.97 5529111 4.2 OSF1.W 16650.00 7049.85 853.98 301.11 652.91 552.8 4.26 OSF1.W 16670.01) 7046.32 853.96 301.8 652.91 5528] 4.26 OSF1.W 16680.00 7044.48 850. 301.05 652.92 552.90 4.26 OSF1.50 16690.00 7002.59 922.71 277.52 737.37 645.19 5.00 OSF1.W 17670.00 6698.68 93100 27526 747.16 655.73 5.09 OSF1.50 17721.61 6676.93 H12-101 (Non-OMSurvey) 956.33 287.81 764.13 666.52 5.00 OSF1.W 15370.00 7086.40 885.93 313.Ul 656.3911 552.111 OSF1.W 16300.00 70]6.80 OSF>1.00 all Major OSF>1. W all Mirror TD OSF<5.00 0SF15.0 OSF<1.W OSF<1.00 OSFQ.W OSF>1. W Fail Major Enter Alert MinPls Enter Minor Enter Major MiaPI-O-ADP Min% Enter Alen Min% Enter Minor MInPt-=t Mlnft all Minor TO OSF<5.00 Enter Alert Minft 0SF11.W Enter Minor MinR-=t MINPT-O-EOU MinPts TD Warning Alan OSF<5.00 Enter Alen MinPls MinR.0-SF MinPt-O-ADP MINPT-O-EOU MinPt-CtCI OSF>5.00 Fxlt Alen TD Warning Alen OSF<5.00 Enter Alen MinP% Minta -O -SF MmR-O-ADP MINPT-O-EOU MinPt-CtCt CSF>5.00 Exit Alen TD Waming Alert OSF<5.00 Enter Alen Min% MinP1-O-SF MInP1-0-ADP MINPT-O-EOU MinPtCtCt 0SF500 EaOAlan TD Wamin9Alen 05F<5.00 Enter Alert MInft H12 -L04 (Non -Def Survey) 85408 301.15 65299 552.9 4.26 853.98 301.09 652.92 552.89 4.26 853.96 301.06 652.92 552.90 4.26 853.85 301.03 652.94 552.92 426 888.72 297.26 690.22 59146 4.49 888.56 296.38 6]0.6 5]2.18 4.41 956.33 287,83 764.12 668.50 5.00 B65.93 3138 6%.A 552.09 4.15 854.08 301.17 652.97 552.91 4.26 853.98 301.11 652.91 552.8 4.26 853.% X1.081 652.91 552.68 426 853.95 301.05 652.92 552.90 4.26 922.71 277.52 ]3].37 645.19 5.00 931.00 275.26 747.16 65574 509 111ZI-06 (Non -Def Survey) 956.33 287.82 764.12 668.51 5.00 865.93 313.8311 6563811 5U.101 4.15 85408 301.16 652.98 552.92 426 853.98 301.11 652.91 552.8 426 853.96 301.08 652.91 552.88 6.26 853.95 301.05 652.92 552.90 4.26 922.71 277.51 ]3].37 645.19 5.00 93100 275.26 747.16 655.74 509 1112-1-02(Non-Def Survey) OSFi.50 16690.00 7042.59 OSF1.53 956.33 287.81 764.13 668.52 5.00 865.93 313.8 1 6563 552111 4,151 854.08 301.15 652.98 552.9 4.26 853.98W1.09 7049,85 652.92 552.8 4,26 853.96 301.06 652.92 552.89 4.26 853.95 301.03 652.93 552.92 4.26 921.21 277.91 735.61 64330 4.98 930.26 275.28 746.41 654.98 H14PB2(Def Survey('' -"--"`------- 15]]] 1609.2 1609.42 1609.51 1609.15 1079.1 1609.94 195.94 1387.18 1382.15 1382.11 382.10 1377.54 13]].09 137207 1421.95 275.07 1238.24 1146.88 5.08 ].78 H14PBi(Def Survey) 226.681426.3 1351.09 10.48 1609.2 272.56 1427.21 1336.68 888 1609.42 282. 14207] 1326.93 8.57 1W6.72 298.6 1307.28 120805 7.59 1500]6 285.6 13098 121091 ].90 1568.47 27)81 1382.93 1290.66 8.49 H14PB3(Def Survey) OSF1.50 16650.00 7049.85 OSF1.50 16670.00 7046.32 OSF1.W 16880.00 7004.48 OSF1.50 18690.00 7042.59 OSF1.50 17510.00 6766.92 OSF 1.50 1 ]721.61 6676.93 OSF1.50 15370.00 7086.40 OSF1.W 1630000 ]0]8.80 OSF1.50 16650.00 7049.85 OSF1.50 16670.00 7046.32 OSF1.W 16680.00 7004.48 OSFi.50 16690.00 7042.59 OSF1.53 17670.00 6698.88 OSF1.W 17721.61 6676.93 OSF1.50 15370.00 7086.40 OSF1.W 16300.00 7078.8(1 OSF1.50 16650.00 7049,85 OSF1.W 16670.00 7046.32 OSF1.50 16680.00 7044,48 OSF1.50 16690.00 7042.59 OSF1.W 1]6]0.00 6698.88 OSFt W 17]21.61 6676.93 OSF1.50 1537000 7086.40 OSF1.W 16300.00 7078.80 OSF1.W 16653.00 7N9.85 OSF1.W 16670.00 7046.32 OSFi.50 16070.00 7044.48 OSF1.W 16690.00 ID 259 OSF1.50 17660.00 6703.13 OSF1.W 1781.61 6676.93 OSF1.50 14308.35 7060.99 OSF1.W 14780.00 7090.88 OSFi.W 14817.40 7090.91 OSF1.50 14853.00 7007.64 OSF1.W 14890.00 7007.31 OSF1.W 14900.00 7090.23 OSF1.W 15180.00 7087.95 OSF1.W 15210.00 7(187.70 OSF1.W 1630000 7078.80 OSF1,W 16440.00 7074.W OSF1.50 18407.00 703.93 OSF1.W 16407.00 7073.21 OSF1.W 16820.00 7013.46 OSF1.50 16880.00 6997.19 OSF1.5D 16900.00 6991.37 OSF1.50 17721.61 6676.93 OSF1.W 14308.35 7063.99 OSF1.50 14]80.00 7090.88 OSF1.50 14817.40 7090.91 OSF1.W 16300.00 7078.6 OSF1.W 16700.00 7040.65 OSF1.50 17721.61 6676.93 OSF1500 OSF�5.01) OSF<5.00 OSF-5.00 OSF<5.00 OSF>8.00 MInPt-O-SF MlrR,O-ADP MINPT-O-EOU MinP(-CICt MInPt-O-SF Min% Warning Alert Enter Alen MinPts MinPt-O-SF Min% -0 -ADP MINPTC-EOU MinPt-CtCt bit Alert TD Warning Alert Enter Alen MinPts MirP.O-SF MinPt-O-ADP MINPTC-EOU MinPICICt Exit Alert TO Warning Alen Enter Alert MInP15 MinP1-O.SF MinRt ADP MINPTC-EOU MinPt-C1Ct Exit Alert TO Pass Mine s MlnPt-CICt MINPT-D-EDU Mint-OSF Min% MinPt-C1Ct MlnPt-O-SF Min% Mm% MinR.O-SF MinPls MinR-CtCt MlnPI-OSF MinPts MinPt-CtCt TO Pass MInPos MInPt-=t MINPT-O-EOU Mints Minma TO Pass Cosmopolitan State i (Def Survey) 577] 1609.2 1609.42 1609.51 1609.15 E609.1 1611. 1612.06 1582.61 1561.49 1561.49 191.67 1563.9 1622.86 4634.6 103.38 4]09 ]9 4]3122 81,51 3558.]2 121.66 34]2.]9 343].6 4959 0SF1.W 14308.35 7060.99 Min% 0SF1.W 14780.00 7090.88 MInPtCtCt OSF1.50 14817.40 7090.91 MINPT-O-EOU OSF1.50 14850.00 7090.64 MmR-O-SF OSF1.50 148W.W 7090.31 Mnift OSF1.W 149W.N 7090.23 MInR-CtCI OSF1.50 151N.W 708].8] MInft OSF1.50 IuW.00 ]08].38 Ming -O -SF OSF1.50 16300.00 7078.6 MinPts 0SF1.W 16400.00 7076.76 Ming-CtCt 0SF1.W 18410.6 ]076.29 Min% OSFi.W 164W.W ]0]3.93 MinR-O-SF OSF1.W 16690.6 7042.59 MlnPls OSF150 17]21.61 66]8.93 TD OSFi.W 163W 00 ]0]8.80 0SF1.W 1]]21.61 6676.93 Ming -O -SF Mints Pass H16A-L01 (P2) Anti -Collision Summary Report Analysis Date-24hr Time: July 10, 2018-10:54 Analysis Method: Normal Plane Client: BlueCrest Reference Trajectory: H16A-LO I(P2)Def Plan) Field: Cosmopolitan Unit Depth Interval: Every 10.00 Measured Depth (ft) Structure: Cosmopolitan Pad Rule Set: DBM AnfiCollision Standard 5002 v5.1/5.2 Slot: H-16 Min Pts: All local minima Indicated. Well: H16 Version f Patch: 2.10.544.0 Borehole: H16A-LO1 Database l Project: localhostkldlling-Cook Inlet Scan MD Range: 14308.35ft-17721.61ft ISCWSA03-D 95.000% Confidence 2.7955 sigma, for subject well. For Trajectory Error Model: offset wells, error model version is specified with each well respectively. Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Not performed! Selection fibers: Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans - All Non -Det Surveys when no Def -Survey is set in a borehole -Al Non -Def Plans when no Def -Plan is set in a borehole Offset Trajectory Se arauon Allow Sep. Controlling Reference Traecto Risk Level Alert Status CRCt R MAS ft EOU ft Dev. ft Fact. Rule MDR TVD ft Alert Minor Major MaimMa or Maim H16PB1(Def Survey) =77-. _.. _ .._._.. FOR K*iv_. 0.00 231.89 -154.92 -231.8 -0.01 OSF1.50 14308.35 7060.99 CSF<5.00 0SF11.50 OSF<1.00 Enter Major 0.00 183.74 -12282 -183.] -0.01 OSF1.50 14310.00 7061.23 MinPt-O-SF 0.00 198.41 -131.2 -196AI -0.01 OSF1.50 14340.0 7065.51 Mir is 0.00 141.39 -94.59 -141.39 -0.011 OSF1.50 14350.00 7050.85 Min Ws 0.14 143.9-96.1 -143. -0.01 OSF1.50 14360.00 7068.02 MinPts 9.26 233.1 -146.4 -223.87 0.05 OSF1.W 14569.35 ]084.03 MINPT-0-EOU 11.05 235.36 -146.19 -224.31 0.06 OSF1.W 14589.16 7084.96 MInPt-O-ADP 13.05 237.31 -145A 1 -224.2 0.08 OSF1.50 14608.93 7085.7] MinPI-O-ADP 39.50 277. 446.11 -238.43 0.21 OSF1.W 14807.55 7090.96 M1NPT-0-EOU 40.98 2]9.92 -14596 .238.94 0.22 OSF1.W 14817.56 7090.91 MMPI -O -ADP 82. 288.28 -109.98 -205.75 0.43 OSF1.50 15715.78 7083.9 MlnR.CtCI 82.59 288.59 .110.13 -2060 0.4 OSF1.W 15735.77 7083.41 MinPt-OSF 82.82 2119.0=1 0.43 -206.23 OSF1.50 15765.T7 7083.16 MINPT-O-EOU 87.13 294.8 -109. -20].53 0.46 OSF1.W 16115.73 7080.31 MINPT-0-EOU 0.67 295.35 -109. -207.68 0A4 OSF1.W 16155.73 7079.98 MInPt-0-ADP 139.54 213.18 -2.90 -73.63 0.98 OSF1.5) 16929.62 6982.39 OSF>1.00 aft Major 173.36 174.67 56.59 -1.31 1.49 OSF1.60 17063.24 61 OSF-1.W Exit Minor 358.85 108.56 286.15 250.30 4.99 OSF1.W 17523.66 6761.11 OSF�5.50 Exit Alen 450.49 101.71 38235 348]8 6.69 OSF1.W 17721.61 667693 TO H16 (Def Survey) .. "' -Fal Major 0.00 231.89 -154.92 -2318 -001 OSFL50 14308.35 7060.99 OSF15.00 OSF,l.50 OSF11.00 Enter Major O.0 183.74 -12282 -18374 -0.01 OSF1S0 14310.00 ]061 23 Mire -O -SF 0.00 196.41 -1312 -19641 -0.01 OSF1.W 14340.0 7065.51 MinPls 0.00 141.39 -9459 -141.39 -0.01 OSF1.W 14350.00 7066.85 Minft 0.14 W. -961 -143.80 -0.01 OSF1.50 14350.00 7068.02 MinPts 9.26 233.1 -146.4 -22387 0.05 OSF1.W 14569.35 7084.03 MINPT-O-EDU 11.05 235.36 -146.1 -224.31 0.06 OSF1.W 14589.16 7084.98 MinP1-0-ADP 13.05 237.31 -145.48 -224.2 0.08 OSF1.W 14608.93 7085.P MinP1-O-ADP 39.W 277.9 -146.11 -238.43 0.21 OSF1.50 14807.55 ]090.96 MINPT.-EOU 40.98 279.92 -145.96 -238.94 0.22 OSF1.5) 14817.56 7000.91 WrPt-0-ADP 82. 288.28 -109.98 -205.75 0.43 OSF1.W 15715.76 ]083.9 MinPt-C1Ct 82.59 288.59 -110.13 -20. 0.4 OSF1.W 15735.77 7083AI MInPI-0-SF 82.82 289.6):[-11021 -208.23 0.43 OSF1.W 15]65.7] 7083.16 MINPT-O-EOU 87.13 294. -10.6 -207.0 0.44 0SF1.W 16115.73 ]080.31 MINPT-O-EOU 87.67 295.35 -109.56 -207.8 0.44 OSF1.50 16155.73 709.98 Mlr Pt -O -ADP 139.54 213.18 -2.90 -73.63 0.98 OSF1.W 16928.62 6982.39 OSF-1.00 all Major 173.38 174.67 56.59 -1.31 1A9 OSF1.W 17063.24 6938.71 OSF>i.W air Minor 358.85 108.56 286.15 2W.30 4.99 OSF1.W 1793.66 6761.11 OSF1500 as Alen 457.48 101.45 389.52 356.03 6.82 OSF1.W 1]]21.61 66]6.93 TD Hansen #1AL1 Def Survey) 1145.32 248.0 9]9.62 89].26 6.9 OSF1.W Fail Major 14348.30 ]066.63 MinRs 102254 308.99 821.22 718.55 5.110 OSF1.W 15030.10 7089.17 OSF<5.00 Enter Alert 826.01 545.311 462.71 280.7011 2.2 OSF1.W 16292.17 M78.87 MinPb 639.33 640.53 211.98 -1.20 1.5 OSFi.50 16920.89 6995.08 OSF<1.50 Enter Minor 460.70 7W.73 4.12 238.03 0.99 OSF1.W 1]24323 6877.44 OSF<1.00 Enter Major 332.56 688.72 -126.96 356.171 Olt OSF1.W 17632.70 6714.74 MrPt-O-ADP 317.39 669.99-129.65 -352.61 0.71 OSF1.W 17716.41 6679.14 MINPT-O-EOU 316.0 88814 -129.62 -352.16 0.71 OSF1.50 17721.61 6676.93 MinPts Hansen #1 (Def Survey) 1146.5 24].8 980.95 8911.66 6.9 OSF1.50 14n3,17 Fail Minor ]0645] MinP1s 1027.27 309.35 820.71 71193 499 OSF1.W 15031.36 7089.16 OSF<5.00 Enter Alerl 827.18 552. 458.79 2]5.0I OSF1.W 16293.02 708.86 Minft 703.78 704.22 23397 -0.44 1.W OSF1.50 17013.14 695523 OSF<1.W Enter Minor 65615 751.59 155.37 -94.83 1.31 OSF1.50 17298.18 6856.25 Minlots 656.]1 751.53 155.37 -94.81 1.31 OSF1.W 1730480 053.W Minpb 70022 70292 231.27 -271 1.49 OSFtM 1]532.66 6757.28 OSP1.50 all Minor 794.04 620.28 35.19 17376 1.92 OSFiM 17721.61 6676.93 TD Hansen #1A(DO Survey) ---""----- 1146.6 247.8 981.10 89882 69 OSF1.50 14331.60 Fag Minor 706435 MlnPls 1027.45 30921 820.99 718.25 5.00 OSF1.50 1503051 7089.17 08F<5.00 Enter Alert 827,28 551.8 4590 2]5.42 2.2 OSFLM 16292.17 708.0 Min% ]02.49 706.0 231.44 -3.59 1.49 OSF1.50 1702016 695212 OSF<1.50 Enter Minor 03.35 75.99 1]2.36 -77.64 1.34 OSF1.50 17273.15 6866.08 MInPt-C1Ct 673.82 ]52.55 1]1.]9 -78.73 1.34 OSF1.W 1]296.07 689.09 MINPT-O-EOU 04.39 ]53.28 171.87 -78.89 I.M1 OSF1.W 17311.14 6851.04 MlnPts 73102 731.81 242.81 -0.80 1.50 OSF1.W 176W0 6715.8 OSF�1.50 all Minor 763.49 720.93 282.54 42.56 1.59 OSF1.M 1]]21.61 6676.93 TD H12-L05(Non-Def Survey) _-" - "-'�- - - -- - - --- - - Warning Alen 1098.86 218.64 952]] 88021 7.9 OSF1 S0 14344.38 7066.11 MInPt-CtCt 1098.87 218.641 952,711 8802111 7.5 OSF1.50 1435.98 7066.98 MinPts 952.24 286.54 760.88 66570 5.00 OSF1.W 15462.57 7085.64 OSF<5.00 Enter Alert 867.10 313.Od 658.0 554.Rj 4.16 OSF1.W 16299.47 708.81 Minpls 853.9]W1.0 652.93 552.90 4.2 OSF1.W 18875.05 7045.40 MinPt-O-SF 80.95 301.06 652.92 552,891 4.26 OSF1.50 16692.83 7043.95 Min% 80.9 301.(N4 60.93 552.91 4.26 OSF1.W 16692.78 7042.06 MmPt-CtCt 921.97 277.39 73612 64458 5.00 OSF1.50 1708.10 6733.71 OSF>500 Exit Alert 948.38 270.40 76779 677.98 5.27 OSF1, 50 tA21.61 576.93 TD H121Non-Def Survey) -"" -' ----' -- -- - Warning Alen 10988 218.64 952.77 B80.22 7.57 OSF1.5 1435.38 7066.11 MinPt-CtCt 1098.87 218.650 952.7 8W.2111 OSFI W 14350.98 706698 Minpts 95224 286.53 760.89 665.70 5.00 OSF1.M 15462.57 7066.64 OSF<5.W Enter Alert 80.10 313.051 658.0 554.0 4.16 OSF1.W 16299.47 ]08.81 Mirp" 653.9] 30106 60.93 552 90. 4.2 OSF1.M 1605.0.5 7045.40 MinR-O-SF 853.95 W1.051 652,921 512,901 4.26 OSF1.50 Imu.0 7043.95 Mln%s 853.95 301.04 652.93 59.92 4.26 OSF1.W 16692.78 7042.06 MInP4CtCt 92197 277.38 736 72 644.59 5.00 OSF1.50 17568.10 6733.71 OSF>5.00 Exit Alert 948.38 27039 767.79 677.99 5.27 OSF1.50 1772161 6676.93 TD H12-103 (Non -Def Survey) Warning Alen 1098.86 218.65 95276 860.21 ].9 OSF1.W 14344.38 7066.11 MinPt-CtCI 1098.87 218.66 952.]6 880.20 7.5 OSF1.W 1435).98 7066.98 Min% 952.24 286.54 760.88 66569 5.00 OSF1.W 15462.57 70115.64 OSF<5.00 Enter MM 667.10 313.06 658.06 5540 1A OSF1.50 16299.47 7078.81 Minft 853.97 301.08 652.92 552Z41 42 OSF1.W 16675.05 7045.40 MinPI-O-SF 853.95 301.07 6U.921 5M.891 4.26 OSF1.W 1666283 7043.95 Min% 853.95 301.05 60.92 59.90 4.26 OSF1.W 16692)8 704208 MinPFCtCt 921.97 277.39 738.71 644.58 5.00 OSF1.6() 17588.10 6733.71 OSF15.00 Exit Alert 948.38 270.40 76778 677.98 5.27 OSF1.W 17721.61 667693 TO H12 -L01 (Non-Oef Survey) Waming Alert 1098. 218.63 95278 880.23 757 OSF1.W 14344.38 )066.11 MinPt-CtCt 1098.87 218.6 952.7 880,220 7.5 OSF1.50 14350.98 7066.98 MinPts 952.24 286.53 76089 66571 5.00 OSF1.50 1546257 7085.64 OSF<5.00 Enter Alen 867.10 313.011 N8,0811 554.Wjj 4.16 OSF1.50 16299.47 7078.81 853.97 301.05 652.94 552.9111 4.26 OSF1.W 16675.05 7045.40 MinPei MInPt-O-SF 85395 WI.Nj 652,931 552,911 426 OSF1.50 16682.83 7043.95 Mki% 853.95 301.03 652.94 55292 4.26 OSF1.50 16692.78 7042.06 873.90 297.2 675. 5767 4.42 OSF1.50 17721.61 6676.93 MinN.CtCt Min%s 1112-1O4 (Non -Def Survey) Waming Alert 1098.8 218.65 952.76 880.21 757 OSF1.50 1434438 ]066.11 MInPt-CtCt 1098.87 218.66 952.]6 880.20 ].5 OSF1.W 14350.98 7066.98 Mirl 952.24 286.54 760.88 665.69 5.00 OSF1.50 15462.57 7085.64 OSF<5.0 Enter Alen 86].10 313.06 658.06 554. 4.16 OSF1.W 16299A7 7078.81 MlnPls 853.97 301.08 652.92 552.89 4,2gi OSF1.W 16875.05 7045.40 MinPt-O-SF 853.95 301.06 652.92 552.89 426 OSF1.50 16682.83 7043.95 MlePls 853.9 301.05 652.92 552.90 4.26 OSF1.50 16692.78 7042.06 MinR-CtCt 921.97 277.39 738.71 644.W 5.00 OSF1.W 17588.10 6]33.71 OSF>5.00 aft Alert 948.38 270.40 76738 677.98 5.27 OSF150 17721.61 6676.93 TO H12 -LOB (Nort-Def Survey) Waming Alert 10988 21664 952.]] 880.21 757 OSF1.50 14344.38 7066.11 MinPt-CtCt 1098.87 218.Mp 952.7AI OSF1.W 14350.98 7066.98 Min% 952.24 286.54 760.88 685.70 5.00 OSF1.W 15482.57 7085.64 OSFI5.0 Enter Alert 867.10 313. 658.0 554.0 4.16 OSF1.W 16299.4] 7078.81 Min% 853.97 301.0] 652.93 552.90 42 OSF1.W 16875.05 7045.40 MlnPt-O-SF 853.95 mi.mi 652.Ul 5U.901 4.26 OSF1.W 16682.83 7043.95 Min% BW.95 301.04 652.93 552.91 4.26 OSF1.50 1669218 7042.06 Mini 921.97 277.39 736.72 844.58 5.00 OSF1.W 17588.10 6733.71 OSF>5.0 Exit Alert 948.38 2]0.40 '76719 677.98 5.27 OSFi.W 17)21.61 6676.93 TO H12102 (Non -Def Survey) WarningAlen --'-"- 1098.86 218.63 952.]] 88022 ].5] OSF1.W 14344.38 ]066.11 MinPt-CtCt 1098.87 218.6 952.] 880.22j 7.5 OSF1.50 14350.98 7066.98 Mtn% 952.24 286.53 760.89 665.71 5.00 OSF1.W 15462.57 7085.64 OSF<SAO Enter Alert 867.10 313.0511 N8,0711 55TO5H 4,161 OSF1.W 16299.47 7078.81 Mirl 853.97 301.06 652.93 552.91 4.26 OSF1.W 16675.05 7045.40 Mill 853.95 W1.051 652.9 552.91 426 OSF1.W 16682.83 7043.95 Mill% 853.95 301.03 652.94 552.92 4.26 OSF1.W 16692.78 ]042.06 MinPt-CtCt 920.77 277.56 735.40 643.21 4.99 OSFi.50 17588.90 6733.37 OSF>5.00 Exit Alert 941.18 27220 759.38 66898 520 OSF1.W 1721.61 66]6.93 TO H14PB2(Def Survey) 159]3 2300 14436 136]32 10.45 OSF1.50 Pass 14308.35 ]060.99 MInPtS 1601.36 230.92 1447.0 1370.4 10.4 OSF1.50 14362.25 7068.25 Min% 16092 272.18 1427.46 1337.06 8.90 OSF1.50 14779.20 7090.87 MirR-CtCt 1 W946 282.5 1420.78 1326.93 8.57 OSFi.W 14819.47 7090.89 1609.1 282.71L_IL20A OSF1.W 14899.46 7090.24 MINPT-O-EOU MioPls 109.18 282.n4203 1326 d6 8. OSF1.W OSF1.W 14909.46 7090.16 MmRP SF 1391.04 297.52 1192.3 1 Aq35211 7.031 OSF1.W 16292.96 7078.88 Mift t 1382.11 284.64 1192.02 109747 7.0 OSF1.W 16451.14 70]3.85 MinPt-CtCt 1382.11 284.6 1192. 1097.4 7.30 OSF1.50 18459.61 7073.24 MinPS 1382.45 284.76 109].68 7.3 OSF1.50 16484.98 ]0]1.19 MInPt-O-SF 1377.69 285.0 38 1092.69 I OSF1.W 16816.78 7014.29 MinPt-O-SF 1377.13 ��I28 284.80 93 1092.32 7.27 OSF1.50 16872.98 6999.19 MinPt-O-ADP 137].09 284.7] 92 1092.33 7.27 OSF1.50 16880.94 6996.92 MINPT-O-EOU 137.0 284.69 1186.95 1092.38 7.28 OSF1.W 16696.83 6992.30 MlnPt-CtCt 1434.32 273.11 1251.92 1161.21 7.W OSF1.W 17721.61 6676.93 TO H14PB1 (DefSurvey) 159].3 1601 36 1609 2 1609.46 1509.52 1500.]8 1500.76 15009] 15]2.35 OSF1.50 14308.35 7060.98 MhRs OSF1.50 14362.25 7068.25 MmRs OSF1.50 147/9.20 ]090.8] Min%-C1Ct OSF1.50 14819.47 ]090.89 MINPT-O-EOU OSF1.50 16295.44 ]0]8.84 MInPIs OSF1.50 16694.96 7041.64 MmRP tCI OSF1.50 16703.14 7040.03 Mint OSF1.50 16711.30 7038.40 MinPt-O-SF OSF1.50 1]]21.61 6676.93 TO Pass H14P63(Def Surrey) Paea 159]3 230.0 1443.6 136]31 10.45 OSF1.50 14308.35 7060.99 1601.36 230.92 144].09 13]0. 1004 OSF1 W 14362.25 7068.25 Mi Ms Mmft 1609.2 272.19 1427.46 1337.06 8.90 OSF1.50 147/9.20 ]090.8] 1609.46 282. 1420]8 132693 8.57 OSF1.50 14819.47 7090.89 MinPt-CtCt 1609.1 282.71 1620. 1326.4 8.56 OSF1.50 14899.46 MINPT-O-EOU 1090.24 MinPts 160918 282]3 1420.37 1326.46 656 OSF1.50 14909.46 1090.16 MinPt."F 1611.6 283.51 142235 1328.18 8.55 OSF7.50 15188.99 ]007.81 MinPt-C1Ct 1611,70 283.5 1422.3 1328.16 8.55 OSF7.50 15198.95 ]OBTn MINPT-O-EOU 1611.75 283.60 1422.36 1320.1 8.55 OSF1.50 15208.92 7087.71 MMPI -O -ADP 1563.26 298.00 1364.2] 126526 1.89 OSF1.50 16291.14 ]0]8.82 Mlnft 1561.69 285.00 1371.16 1276.49 8.24 OSF1.50 16403.87 ]0]6.58 M[nPFCtCt 1561.52 285.0 1311.1 12]6.4 8.24 OSF1.50 16420.13 7075.14 Minlsts 1563. 285.81 13]3.0] 1278.13 8.23 OSF1.50 16681.05 1043.15 MinPt-C1Ct 1563.94 285.82 13]3.0 1218.12 8.23 OSF7.50 16695.22 ]001.59 Wnpts 1564.00 285.84 1313.12 12]8.1 8.24 OSF1.50 16711.52 ]0311.35 1630.47 2P.67 144503 1352.80 8.83 OSF1.50 1]]21.61 6676.93 MinR.O.SF TO Cosmopolitan State i (Def Surrey) Pass Traveling Cylinder Plot •pa Rwwn Eou'. enw a. p..m,e EOV p•m.•..en wiro� Rnv TRAVELING CYLINDER PLOT ..c.w.wn.w....a. psu.•xn..w nssm.s.InE nm. em.cw.. EwM Ce,mvpe u,n Unn mepaiNn Rq Mfp North 3. o fU Dm So-m-zau Before exemption Traveling Cylinder Plot NeOO RpI,n EOVt e„p en: O•vnwC EpU Oim,mimuinv A.� Tf Lm.CWiunrW u.,C. p6N I.n,CeiW ,N YSSH�'S2 /` /��%\ . In \Y�AELI Jr�/ F'w Slnw 310 North sso ^ sp After exemption 330 40 In 310 no no 70 70 so 270 100 r, v12.130 After exemption 40 70 70 so 100 r, v12.130 ue sr Energy Attachmen Cosmopolitan Project H16 -A10-401 L01 APD Attachments H16 -A10-401 L01 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. llueNes[ Energy Attachme Cosmopolitan Project H16 -A 10-401 L01 APD Attachments H16 -A 10-401 LO7 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 1.01 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. tflueNest Energy Attachme Cosmopolitan Project H16 -A10-401 L01 APD Attachments H16 -A 10-401 L01 APD Attachments lue est Eneigy Cosmopolitan Project BOP & Choke Manifold Configuration 5K# WI H 10K# 49 3/32" BOTTO FLANGE (M 66 5/8u o ® �Ln n. in 904 27 3/4" 0 4111/16" o. )a 13 5/8"X10K# CAMERON BOP STACK BLUECREST ENERGY 13 5/8-MOK CWWN BOP HACK 3 1 MF t 1 16 INMhD AP%JIGQw rw1 .... BSBC7002 2 10-401 APD Attachments BOP & Choke Manifold Configuration m 0 90 T 0 UST OFWTM3MR«NO T CIWEAON ] 116 10K 8C VANE II_ _% CNlENd1 Z I N % 10f RC 00 WE I FROM BORE IDA69&E c J I 1 % lQK I WH JMICO NYD dKKE J 116 % Ip!MI FREMW 03WE ICK p M= S ULS, EIC % 10K i0'-8, 5/B�--' I 1 fvmm 3 0/IC % 10 VNAE 11 flK W061W hNOR KID Rw om , f/1m 21/16. % Im CM 00AD01 WLVE Kim N i 1 I T-0 1/r A ( VIEW A SHAKER UNE SHAKER LINE PANIC LINE Si POOR POOR O PANIC LINE ER CAMERON 3 1/16 X 10K C & K MANIFOLD KOIE BLUECREST ENERGY 2 3116%Id(Ck KIPN6'Ol0 J. 6 I/M1 1' 6 lNe5t Energy Diverter ' OPEI PORT t0 L CLOStNG PORT G FLANGED Cosmopolitan Project BOP & Choke Manifold Configuration M AS CAST N —0- — K — L AS CAST--- - E AS CAST P AS CAST F CLAMP HUB Nominal Dimensions—Inches—with 2000 psi Bottom Connections A 8 Hub 18 C D E F Hub 1 G H J K L M N 0 P 5244 51 .. 12Y= 23% 6 71i SV,e 27% 46% 51% 58% 5274 So 1% Hub18 Hub1 &WI SV6 Nominal Dimensions—Inches—with 3000 psi Bottom Connections A uybb8C D E I F G H J nwH5 1 9V'4 &I 2776 K <5% L 51% MLN;A 5ft 0P12Va 50 Ni 10-401 APD Attachments BOP & Choke Manifold Configuration IN Energy Attad r Cosmopolitan Project H16 -A-1 0-401 L01 APD Attachments H16 -A10-401 L01 APD Attachments �� r t lue( lest Energy P-VSu SA VS e V1 S." Y I VS!S.OW OSI MSV 2 vii. S. m % MSF ;lend 952'wO - - PSI Cosmopolitan Project Wellhead/Tree LMat , t[ �y.�, cLaccs IELLM35 3LSfD r: I 13-V! L 9gr3 3 I -III y 44,14 SP ME l�IE WENTI µ "Urt- 10-401 APD Attachments Wellhead/Tree tSl ue C.fesr Energy Attachmen Cosmopolitan Project H16 -A10-401 L01 APD Attachments H16 -A10-401 L01 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. !flue( iesr Energy Attachment 8: Cosmopolitan Project H16 -A10-401 LOt APD Attachments H16 -A 10-401 L01 APD Attachments H 16A & H 16A -L01 With 1000' , ._ 500' From Lease Boundary H12 ADL3844031 H-1 Hansen to SEC32. T3S.R15W. SM S[C 33. T3 R15 M llllllll{'I—� '� 1116A-1-01 Surface Location (NAD 27) Northing: 2,145,914.43', Easting 166,970.57' 2,408' FSL, 1509' FEL, Sec. 2, T4S, R15W SM Surface Casing Point Northing: 2145773.805' Easting: 167211.107' 3,414' FSL, 3,429' FEL, Sec. 2, T4S, R15W SN Kick Off Point Northing: 2,151,762.71', Easting: 157,204.51' 3,709' FSL, 2,787' FEL, Sec. 33, T3S, R15W S Total Depth Northing: 2,156,120', Easting: 152,512.00' 4,428' FSL, 3,891' FEL, Sec. 33, T3S, R15W SI nd Production Section .M SEC 27. T3S, R15W. SM 0 ,0 Ti. 1 , '. Cosmopolitan Unit Development Date 10/0712018 cw Marry BlueCrest Energy 0 1000 2000 3000 4000 5000flUS 1:30000 ADL39190 SEC 26. T35, R15W. SM SEC 35. T3S, R15W. SEC 36, T3 SEC 1, T4s. n New Well Rig Elevation Form FIELD Cosmopolitan unit WELL H16 RIG BlueCrest#1 Cellar Box Elevation (CBE) 145.81 ft (from 'As Built' Survey Plat dated 12-30-1980) Actual Rig Height (RT -GL) 34.62 ft (from rig measure) Actual Rig Elevation (Actual RTE) 180.43 ft (CBE+RT-GL=Actual RTE) Rotary Table - Base Flange Height (RT -BF) 40.56 ft (from rig measur) Base Flange - Mean Sea Level (BF -MSL) 139.87 ft (actual RTE - RT -BF = BF -MSL) DATE November 23, 2016 DIRECTIONAL DRILLER (please print) Marty Rinke n rc Degrees Minutes Secon X + v — m X F U Gl a dvmr fcc.gov- Proceedings and Actions Items on Circulation Ructions Overview Ex -Parte Paper Filings Electronic Comment Filing System (ECPS) Daily D;ge=_t Commission Documents (EDOCS) Mergers & Transactions Most Active Proceedings COLORIT HTML Color Generaeor Decimal Degrees to Degrees Minutes Seconds seconds. For convenience, a link is included to the National Geodetic Survey's NADCON program, which allows AM Query conversions between the NA083 / WGS84 coordinate system and the older NAD27 coordinate system. NAD27 Antenna Height Above Average coordinates are presently used for broadcast authorizations and applications. Terrain(HAATI Calculator This tool requires thatjavascript be enabled to perform the calculations. Antenna Structure Regi ,ration (ASRN) Records Wcthin A Radius Degrees Minutes Seconds to Decimal Degrees Broadrast Station mailing Address Search Enter Degrees Minutes Seconds latitude: 59 32.043 Ca11 Sign Reservation and Authorization System {CSRS) Enter Degrees Minutes Seconds longitude: _l51 c� 5.012 CDBS Database Public P es Convert to Decimal Clear Values Children's Educational Teievision Reporting - Form 398 Results: Latitude: 59.858901 Longitucle: -151.801392 Children's Programming Query COLORIT HTML Color Generaeor Decimal Degrees to Degrees Minutes Seconds TRANSMITTAL LETTER CHECKLIST WELL NAME: H ICA -lot / PTD: 'a-{$ — OQ i vDevelopment _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: r` all 5e�j, \ POOL: 1 I Q, p\ 5 2 h, t, w h e2d Q 1 Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER J MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. 7_18-095 API No. 50-2;1-1o0Sl �• v// (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements/ J �/ 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 PTD#:2180960 Company BLUECREST ALASKA OPERATING LLC Initial Class/Type Well Name: HANSEN H -16A-1_01 Program DEV Well bore seg DEV/PEND GeoArea 820 Unit 10370 On/Off Shore Off Annular Disposal ❑ Administration 17 Nonconven. gas conforrnsto AS31.05.030(j,1.A),(j.2.A-D) .. _ _ NA 1 Permit fee attached .. NA _ - 2 Lease number appropriate......... _ _ - - - - - - - - - - Yes - 3 Unique well. name and number .............................. . .. .... . Yes_... _.. _. _..... _.. ... __..... _.. _... 4 Well located in a. defined pool..... ___ __..._.. ___.. _..... Yes ___... _.... ....... ......... _... ..._ ... _. 5 .Well located proper distance. from drilling unit.boundary _ Yes 6 Well located proper distance from other wells _ _ _ _ _ _ _ _ _ _ _ _ _ No.. _ _ _ Spacing exception required. Hearing vacated: spacing exception order in progress. SFD 9/12/2018- 7 Sufficient acreage available in drilling unit _ _ _ _ _ _ _ _ Yes 8 Jf deviated, is wellbore plat.included _ _ _ _ ... ..... Yes 9 Operator only affected party.. _ _ _ Yes _ 10 Operator has. appropriate bond in force .... _ _ _ _ _ _ _ _ Yes Appr Date 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - - - No 12 Permit can be issued without administrativeapprovalYes SFD 9/12/2018 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 114_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 stdng.provided _ ... _ _ _ _ .......... NA.. ..... Open hole Jateral in producflon hole Engineering 19 Surface casing_ protects all known USDWsNA .. _ ...Open hole lateral Jn production hole 20 CMT. vol. adequate to circulate on conductor & surf csg ...... ......... NA. .... Open hole lateral in production hole 21 CMT -vol adequate to tie-in long string to surf csg..... _ _ _ NA... _ _ _ _ _ Open hole lateral in production hole_ 22 CMT. will cover all known productive horizons.. - NA. _ _ Cemented above reservoir, open hole completion 23 Casing designs adequate for C, T, B &. permafrost.. Yes 24 Adequate tankage. or reserve pit Yes 25 If a. re-rlrill, has.a 10 403 for abandonment been approved Yes 26 Adequate wellbore separation proposed. _ _ Yes _ _ _ _ Close_ approaches in the reservoir 27 If.diverter 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)- .... - . Yos 31 Chokemanifold complies w/API. RP -53 (May 84)... .. .... - - - Yes 32 Work will occur without operation shutdown- - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ - - - - _ _ - _ _ _ _ _ .. - - - - - - ........... 33 is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ 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 wails. Rig has sensors and alarms. Geology 36 Datapresented on potential overpressure zones ...................... Yes ...... ",-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 PressureDrillingtechnique appear adequate to controlmaximum. anticipated. downhole DLB 8/9/2018 38 Seabed condition survey.(if off -shore) . ............................... NA....... pressure of 9.66 ppg, which. is based on MDT measurements of reservoir. pressure innearbywell.. 39 Contact name/phone for weekly.pfogress reports [exploratory only] - - _ _ - - _ _ _ ..... NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date '/��