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Home My WebLink About219-030'7—/`�- (_)3e Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Wednesday, July 24, 2019 10:29 AM To: Guhl, Meredith D (CED); Colombie, Jody J (CED); 'tom.mckay@bluecrest.com' Cc: Roby, David S (CED); Schwartz, Guy L (CED); Rixse, Melvin G (CED) Subject: RE: REQUEST TO CANCEL PTD_Hansen H13_PTD 219-023_23July2019 Done: Well H-13 and all associated well branches cancelled in RBDMS database (PTDs 219-023 thru 219-030) and removed from Geographix database. Conservation Orders 768 thru 775 marked as cancelled in RBDMS and on the website. Copies of this email thread have been printed and they will be scanned and placed in all affected well history files and order files. Thanks, Steve D CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Wednesday, July 24, 2019 9:58 AM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov>; Colombie, Jody J (CED) <jody.colombie@alaska.gov>; tom.mckay@bluecrest.com Cc: Roby, David S (CED) <dave.roby@alaska.gov>; Schwartz, Guy L (CED) <guy.schwa rtz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: REQUEST TO CANCEL PTD_Hansen H13_PTD 219-023_23July2019 The eight associated spacing exception Conservation Orders must be cancelled too. Thanks, Steve D CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Sent: Wednesday, July 24, 2019 9:09 AM To: Colombie, Jody J (CED) <iody.colombie@alaska.gov>; tom.mckay@bluecrest.com Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Roby, David S (CED) <dave.robv@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: REQUEST TO CANCEL PTD_Hansen H13_PTD 219-023_23July2019 I have updated Hansen H-13 (PTD 219-023) and seven associated laterals H-13 L01 through H-13 L07 (PTDs 219-024 through 219-030) as Canceled. Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-rnail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Colombie, Jody J (CED) <lody.colombie@alaska.gov> Sent: Wednesday, July 24, 2019 9:03 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; tom.mckay@bluecrest.com Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Roby, David S (CED) <dave.robv@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Subject: RE: REQUEST TO CANCEL PTD—Hansen H13—PTD 219-023_23July2019 Tom, Once the AOGCC cancels PTD 219-023, BlueCrest Alaska will not need a bond for this well. Jody From: Tom McKay <tom.mckay@bluecrestenergy.com> Sent: Tuesday, July 23, 2019 2:23 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: 'Tom McKay' <tom.mckay@bluecrestenergy.com>;'Andrew Buchanan' <abuchanan@bluecrestenergy.com> Subject: REQUEST TO CANCEL PTD—Hansen H13—PTD 219-023_23July2019 Guy and Mel, Please be advised that BlueCrest Alaska requests the cancellation of the H13 approved PTD (PTD No. 219-023) since we have no current plans to drill this well at this time. The well API Number is 50-231-20065-00-00, FYI. BlueCrest understands that since this PTD will be cancelled, that no further bonding expenses by the AOGCC would be incurred on H13. Please advise if this is not the case, and if there are any issues with cancelling and voiding this PTD. Thanks and best regards, Tom McKay Principal Drilling Engineer BlueCrest 907-350-9544 cell 907-754-9566 office tom.mckav@bluecrestenergV.com THE STATE 'ALASKA GOVERNOR MIKE DUNLEAVY 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, H13-L07 BlueCrest Alaska Operating, LLC Permit to Drill Number: 219-030 Surface Location: 2344' FSL, 1524' FEL, SEC. 2, T4S, R15W, SM Bottomhole Location: 437' FSL, 5179' FEL, SEC. 21, T3S, R15W, SM Dear Mr. Burgess: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 219-023, API No. 50-231-20065-00- 00. Production should continue to be reported as a function of the original API number stated above. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce is contingent upon issuance of a conservation order approving a spacing exception. BlueCrest Alaska Operating, LLC assumes the liability of any protest to the spacing exception that may occur. 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, Daniel T. Sea unt, Jr. Commissioner DATED this 5" day of March, 2019. STATE OF ALASKA ALA. A OIL AND GAS CONSERVATION COMMIS, N FEB ? 2o1 9 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: 11b. Proposed Well Class: Exeloratory- Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 C. Specify if well is proposed for: Drill (If Lateral tratigraphic Test ✓ Development O ❑ Service - Winj ❑ Single Zone 0 Coalbed Gas [:]Gas Hydrates E Redrill FIReentry Rxploratory - Oil Development - Gas Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas [ 2. Operator Name: 5. Bond: Blanket • ❑ Single Well ❑ 11. Well Name and Number: BlueCrest Alaska Operating LLC Bond No. 5511251547 H13 - L07 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 3301 "C" Street, ' 102, Anchorage, AK 99503 MD: 23,264' TVD: 6,860' 7. Property Designation: f j�L --s-_�436. e- Hansen, Undefined Oil Pool . 4a. Location of Well (Governmental Section): Surface: 2344' FSL, 1524' FEL, Sec. 2, T4S, R15W SM ADL 18790, ADL 384403, Fee -Hansen Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 5228' FSL, 4404' FEL, Sec. 28, T3S, R15W SM LOCI 14-007 3/10/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 437' FSL, 5179' FEL, Sec. 21, T3S, R15W SM 14423 2549' (YO1665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 180.65 115. Distance to Nearest Well Open Surface: x-168845 y- 2144793.15 Zone- 4 GL / BF Elevation above MSL (ft): 146.2 Ito Same Pool: 3200' - H14 16. Deviated wells: Kickoff depth: 22300 feet , 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 115 degrees Downhole: 3,549 psi Surface: 2,842 psi (using 7,070' TVD) 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20 0.5" wall A252 Welded 152 41 41 193 193 N/A - Rotary Drilled / Driven 17.5 13.375 72 L-80 BTC 4759 40 40 4799 3528 Lead: 564 bbls, 13.0 ppg Class A Tail: 154 bbls 15.8 ppg Class G 12.25 9.625 47 Pilo Hyd 563 17389 38 38 17427 7125 Tail: 132 bbls, 15.8 ppg Class G TOC: 15,927' MD / 6,800' TVD 8.5 4.5 1 15.2 1 P110 I Hyd 563 6500 1 17227 1 7118 1 23727 1 6998 1 Slotted Liner -No Cement; 200' lap 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): N/A Perforation Depth TVD (ft): N/A Hydraulic Fracture planned? Yes ❑ No ❑✓ 20. Attachments: Property Plat ❑✓ BOP Sketch r7✓ Drilling Program ✓ Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch ✓ Seabed Report Drilling Fluid Program ✓ 20 AAC 25.050 requirements E 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.mckavd)bluecrestenergv.com Authorized Title: Alaska#1anager Contact Phone: 907-754-9566 Authorized Signature: Date: Commission Use Use Only Permit to Drill%� �yy j� 150- API Number: _1r Permit Approval, 3 5 See cover letter for other Number: C/ ' Date: 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: Other: Cad /�/ Samples req'd: Yes ❑ No a" Mud log req'd: Yes 0, J H2S measures: Yes Directional svy req'd es o Spacing exception req'd: Yes Inclination -only svy req'd: Yes o 4 y VNOoEr] i Post initial injection MIT req'd: Yes ]lo APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: t v - t + 7 Submit Form and t l� rm 10-401 Revised 5/2017 This permit is Valid or 2 o t h prova'I per 2�0 C�iC 25.005(g) Attachments in Duplicate ZuNest Energy 3301 C Street, Suite 202, Anchorage, AK 99503 Thomas W. McKay, P.E. Phone: (907) 754-9566 Email: tom.mckay@bluecrestenergy.com February 11, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Cosmopolitan Project RE: Application for Permit to Drill: Horizontal Production Well H13-L07 Fishbone Producer Lateral H13-11-07 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 H13-L07 — Fishbone Lateral Producer. This well will be drilled and completed using BlueCrest Rig #1. The planned spud date could be as early as 10 March 2019. H13 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 H13-L07 well will be an open hole sidetrack off the H13 mainbore, to be drilled from the H13 slot. The H13 Fishbone Producer 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 as needed. A Diverter Waiver is also requested for well H13 mainbore, for which the justification for the Waiver can be provided on request. 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 1-113 well have already been submitted to the AOGCC. Also note that seven (7) additional yet abbreviated APD packages will be submitted for each well "rib" numbered L01 through L07, which are proposed to be open hole sidetracks off the mainbore. As per AOGCC regulations, each rib requires its own unique name and APD. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office) or 907-350-9544 (cell). Sincerely, / 5 �-- Larry Burgess Alaska Manager BlueCrest Alaska Operating LLC H13 Fishbone Multilateral Application for Permit to Drill Package H13 — L07 H13 BlueCrest H13 Fishbone APD Package - Main Bore + Fishbone Lower Laterals Section Topic A Cover Letter B APD Table of Contents C Form 10-401 1 Well Name 2 Location Summary 3 BOPE Information 4-a Drilling Hazards Information 4-b Pressure Model Plot 4-c Drilling Hazards Summary 5 LOT/FIT Procedure 6 Casing & Cementing Program 7 Diverter System Information 8 Drilling Fluid Program 9 Abnormally Pressured Formation Information 10 Seismic Analysis 11 Seabed Condition Analysis 12 Evidence of Bonding 13 Proposed Drilling Program 14 Discussion of Mud & Cuttings Disposal and Annular Disposal 15 Attachments 15-1 Drilling Procedure - Proposed Drilling Program 15-1a Wellbore Schematic - Cross Sectional Color View 15-1b Wellbore Schematic - Excel Section Review 15-1c Wellbore Schematic - Visio Version 15-2 Directional Plan 15-3 Casing Design & Cement Volume Calculations 15-4 Formation Integrity & LOT Procedures 15-5 BOP & Choke Manifold Configuration 15-6 Wellhead & Tree Configuration 15-7 Diverter Configuration & Schematics 15-8 H13 Lease Map 15-9 H13 As -Staked Surface Slot Location 15-10 IH13 New Well Rig Elevation Form - to be provided when rig is on well N N N N � t>>o N N >N> > ?N? > >N> > � � � >N> � 7N7 >N> N N >N > N Ln N Ln N N Ln N > N Ln > N 7 N > N Ln LnLn .--I >> r-1 rl I--1 rl ci c-1 a-1 c-I rl rl r-I cc N c-1 Of to N Ln N Ln Lr N LN N to N V) vi M M M M m rn M m M M M M M F- F- H F- F- F- F- F- H F- M ~ LN n M F- 00 00 CD o0 00 CO o0 00 00 00 F- W F- rV N N F- CO fV N N IV N N N N N N N N Q N U 6 j U LJ U U U LJ Li N L.! �y N N N N N N N U1 v Q1 N N N Q! 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Well Name...................................................................................................................3 Requirements of 2OAAC 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 Requirementsof 20 AAC 25.005(c)(6)........................................................................................................1. 7 7. Diverter System Information.........................................................................................7 Requirementsof 20 AAC 25.005(c)(7).........................................................................................................17 8. Drilling Fluid Program...................................................................................................8 Requirements of 20 AAC 25.005(c)(8).......................................................................................................... 8 9. Abnormally Pressured Formation Information................................................................8 Requirementsof 20 AAC 25.005 (c)(9)......................................................................................................... 8 10. Seismic Analysis...........................................................................................................8 Requirements of 20 AAC 25.005 (c)(1O)....................................................................................................... 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 1IPage H13 10-401 L07 APD Discussion Sections Ilu es[ Energy Cosmopolitan Project H13 10-401 L07 APD Discussion Sections 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................................9 Requirements of 20 AAC 25.005 (c)(14)....................................................................................................... 9 15. Attachments................................................................................................................9 Attachment 1 Drilling Procedure................................................................................................................. 9 Attachment2 Directional Plan.................................................................................................................... 9 Attachment 3 Casing Design Calculations.................................................................................................... 9 Attachment 4 Formation Integrity And Leak Off Test Procedure..................................................................... 9 Attachment 5 BOP & Choke Manifold Configuration..................................................................................... 9 Attachment 6 Wellhead & Tree Configuration.............................................................................................. 9 Attachment 7 Diverter Schematics .............................................................................................................. 9 Attachment8 Lease Map....................................................................................................................................... 9 Attachment9 As -Built Slot Survey.......................................................................................................................... 9 Attachment 10 New Well Elevation Form.............................................................................................................. 9 2 1 P a g e H13 10-401 L07 APD Discussion Sections llueNest Energy Cosmopolitan Project H13 10-401 L07 APD Discussion Sections 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. Well Name: 1-113-11-07 To include the L07 Fishbone lower lateral drilling and completion only. ' NOTE: This well will be proposed as a "fishbone" design with a mainbore named as H13, and seven (7) open hole "barefoot" laterals drilled by open hole sidetrack from the mainbore to be named as: 1-113-1-01, H13-1-02, H13-1-03, H13- L04, 1-113-1-05, 1-113-1-06, and H13-1-07. The seven (7) laterals or "ribs" will be drilled upward into all the Hemlock and Starichkof reservoir layers at an inclination of approx. 115 degrees, and each will have its own APD package to be submitted. This particular package (H13-L07) is for the fishbone lateral H13-1-07 drilling and completion operations. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (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(b); Location at Surface — H13 2344' FSL, 1524' FEL, Sec. 2, T4S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,144,793.15' Easting: 168,845.47' RKB Elevation 180.65' AMSL Pad Elevation I 146.2'AMSL Location at Top of Productive Interval — 1-113-11-07 5228' FSL, 4404' FEL, Sec. 28, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,158,603.70' Easting: 155,769.67' Measured Depth, RKB: 22,300' Total Vertical Depth, RKB: 7,124' Total Vertical Depth, SS: 6,943' Location at Total Depth — H13-11-07 437' FSL, 5179' FEL, Sec. 21, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,159,117.00' Easting: 155,008.00' Measured Depth, RKB: 23,264' Total Vertical Depth, RKB: 6,860' Total Vertical Depth, SS: 6,679' Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application fora Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan Please see Attachments 7-8: Diverter Schematics / 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. 3 1 P a g e H13 10-401 L07 APD Discussion Sections lueNest Energy Cosmopolitan Project H13 10-401 L07 APD Discussion Sections 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 on item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (80PE) as required by 20 AAC 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 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient, - The expected reservoir pressure in the Starichkof / Hemlock Sands is —0.472 psi/ft, or 9.07 ppg EMW at 6,951' TVDss taken per MDT's on Cosmopolitan 1. The maximum known pressure in the upper Kenai sands is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. To be conservative, the highest pressure gradient of 9.66 ppg or 0.502 psi/ft will be used to determine MPSP at the production interval of 6,900' TVDss. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.10), and the planned vertical depth of the Starichkof / Hemlock formation is: MPSP=(6,900TVDss) (0.502 - 0.1 psi/ft) =2,774 psi MPSP=(7,070TVD) (0.502 — 0.1 psi/ft) =2,842 psi (using TVD instead of TVDss for this calculation) MAX BHP=(7,070TVD) (0.502 psi/ft) =3,549 psi (using TVD instead of TVDss for this calculation) (e) data on potential gas zones; The Sterling, Beluga and Tyonek sands within the Kenai group have been known to contain gas. The intermediate section will be drilled with a minimum mud weight of 10.5 ppg, the maximum known pressure through these sections is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see the Drilling Hazards Overview below. 4 1 P a g e H13 10-401 L07 APD Discussion Sections IluNest Energy 11� 11, *I tIIA r-. 4000 w 0 t p 5000 111 Cosmopolitan Project H13 10-401 L07 APD Discussion Sections Pressure Model (EMW) ;W-=�- mill =50Mi i �c Er Eon UpperTyonek,3292.44 Lower Tyonek, 6059.01 - Starichko#, 6874.84 Hemlock, 6902.77 8 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 51Page H13 10-401 L07 APD Discussion Sections ZuNst Energy Drilling Hazards Summary: 17-%" Hole Section / 13-%" Casing Cosmopolitan Project H13 10-401 L07 APD Discussion Sections Event Risk Level Mitigation Strategy Clay Balling Maintain planned mud parameters, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP. Abnormal Pressure in Surface Formations Low Diverter drills, increased mud weight. Directional Control BHA design, on -sight geologic review, avoid "drilling the line". Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, control running speeds. 12-%" Hole Section / 9-%" Casing Event Risk Level Mitigation Strategy Reduced pump rates, reduced trip speeds, real time equivalent Lost Circulation Low circulating density (ECD) monitoring, mud rheology, Pre -planned LCM pills, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Sloughing Coals, Increased mud density and fluid composition according to plan, Tight Hole controlled trip speeds, ECD monitoring, optimized hydraulics for hole cleaning. Abnormal Reservoir Low Well control drills, increased mud weight. Pressure Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers. 8-%" Hole Section / 4-%" Slotted Liner Event Risk Level Mitigation Strategy Fluid density according to plan, reduced pump rates, reduced trip Lost Circulation Low speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material. Hole swabbing on Reduced trip speeds, mud properties, proper hole filling, real time trips Low equivalent circulating density (ECD) monitoring, weighted sweeps. Directional Control Low BHA design, on -sight geologic review. Abnormal Reservoir Pressure Low Well control drills, increased mud weight. Hydrogen Sulfide Gas Low 112S drills, detection systems, alarms, standard well control practices, mud scavengers. 61Page H13 10-401 L07 APD Discussion Sections ZuNest En&gy Cosmopolitan Project H13_10-401_L07_APD Discussion Sections 5. Procedure for Conducting Formation Integrity Tests (only applies to H13 mainbore) Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.03OM; Please see Attachment 4: Formation Integrity and Leak Off Test Procedure 6. Casing and Cementing Program (only applies to H13 mainbore) Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Volume Calculation Summary Csg/Tbg Hole Weight Length Top Btm OD (in) Size (►b/fi) Grade Conn (ft) MD/TVD MD/TVD Cement Program (in) (ft) (fi) 20" N/A .500 A525 weld 152' 41'/41' 193'/ 193' N/A all 718 TOTAL BBLS 13-3/8' 17-1/2" 72 L-80 BTC 4,759' 40'/40' 4 ,799'/ LEAD: 564 bbls 13.00 ppg Kenai "A" 3,528' Lead TAIL: 154 bbls 15.8 ppg Class "G" 9-5/8" 12-1/4" 47 P-110 Hydril 563 17,389' 38'/38' 17'427 / 132 TOTAL BBLS 7,125' TAIL: 132 bbls 15.8 ppg Class "G" TOC: 15,927' MD/ 6,800' ND No cement required 4 1/2" 8 1/2" 15.2 P 110 Hydril 563 6,500' 17,227'/ 23,727'/ Slotted liner completion 7 118' 6,998' 200' liner lap Please see Attachment 3: Casing Design Calculations NOTE: Due to the high inclination at the 9-5/8" intermediate shoe, a tractor would be required to run a CBL/USIT log on this shoe. In addition, since the H13 well is not to be hydraulically fracture stimulated, it is requested that the AOGCC waive the CBL /USIT requirement on the 9-5/8" cement job on the H13 well. 7. Diverter System Information (only applies to H13 mainbore) 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 an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 5: BOP and Choke Manifold Configuration. NOTE: BlueCrest requests a waiver to the requirement for a diverter system while drilling the H13 surface section, just as was approved for wells H12 and H04. A justification package for this waiver can be provided by BlueCrest to the AOGCC on request. 71Page H13 10-401 L07 APD Discussion Sections llueNeslt Energy Cosmopolitan Project H13 10-401 L07 APD Discussion Sections 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including 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 drilling fluids having the following properties over the listed intervals in the following Table. NOTE: the base case drilling fluid program is to drill the surface section with a fresh water conventional barite based system. The intermediate section will be drilled with a oil based conventional barite mud system. However, based on the results seen in the H14, H12, and H16A flowback production test histories, it is planned to drill the H13 production section using a solids free oil based mud system with no barite, using only salt and calcium carbonate for weighting and bridging material, in order 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 with as light a mud weight as possible, and with as few solids as possible, in an effort to minimize formation damage. Parameter Surface Intermediate Production Type WBM OBM OBM Name Spud Mud VersaPro Versa Pro Density (ppg) 9.8 10.5 8.8-9.7 Oil:Water Ratio N/A 80:20 75:25 6/3 RPM 17-20 12-14 8-10 PV (lbs/100ft') <28 <28 API Fluid Loss (cc/30min) NC WHIP Fluid Loss (cc/30min) <5.0 <5.0 Electric Stability (mlVolts) >600 >600 pH 8.5-9.5 Chlorides <2,000 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 an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application 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 on 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 20AAC 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 an offshore platform, mobile bottom -founded structure, jack -up rig, or floating drilling vessel, on analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 8 1 P a g e H13 10-401 L07 APD Discussion Sections nluest Energy Cosmopolitan Project H13 10-401 L07 APD Discussion Sections 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 an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding)have been met; Evidence of bonding for BlueCrest Alaska Operating LLC is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for hydraulic fracturing as defined in 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 25.280 and 20 AAC 25.283; (13) a copy of the proposed drilling program; Please refer to Attachment 1— Drilling and Completion Procedure for Barefoot Fishbone Lateral Note: The H13 well 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. Dried water base cuttings from the surface section are planned to be properly disposed of in a local landfill after being tested using the filter paint test. No annular disposal is planned for this well. 15. Attachments Attachment 1 Drilling & Completion Procedures with Wellbore Schematics Attachment 2 Directional Plan Attachment 3 Casing Design and Cement Volume Calculations 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/, waiver requested Attachment 8 Lease Map Attachment 9 As Staked Slot Survey Attachment 10 New Well Elevation Form — to be provided when rig moves onto well slot 9 1 P a g e H13 10-401 L07 APD Discussion Sections Ilue est Energy Attachment 1: T_ @ rocedure Cosmopolitan Project H13_10-401_1-07_Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments BlueCrest H13 Horizontal Fishbone Lateral Producer Drilling (7) Fishbone Barefoot Laterals (8-1/2" Production Section) (NOTE: This one page Drilling Procedure is included in each of the APD Packages for Laterals 1-01-1-07, under Attachment 1, Drilling Procedure. NOTE: This Procedure does not involve using MPD or displacement of any drilling fluid with LVT) 1. Make up 8-1/2" PDC bit on RSS BHA and RIH. 2. RIH with drilling BHA on 5" and 5-1/2" drill pipe (combination of XT-50 and XT-54 drill pipe). 3. Circulate bottoms up at float collar. 4. Pressure test 9-5/8" casing to 3500 psi for 30 minutes; chart and report results. 5. Drill out float collar and shoe track. 6. Drill to TD; circulate and condition mud. Drill 20' of new hole. 7. Perform FIT to 13.0 ppg EMW; chart, graph with casing pressure test, and report results. 8. Review results with office staff and AOGCC staff; obtain AOGCC approval to drill ahead. 9. Establish parameters and drill ahead using an 8.8-9.2 ppg low solids, barite free MOBM drilling fluid, as per directional plan to first sidetrack point for 1-113-1-01. 10. Directionally drill well to L01 target and drill L01 lateral to L01 TD as called by Geologists. 11. Circulate and backream the 1-01 lateral back to the main bore. 12. Initiate trenching and time drilling to execute an open hole sidetrack away from L01 and to the kickoff point for the L02 lateral. 13. Directionally drill the L02 lateral using the same procedure as L01. 14. Repeat these steps for drilling laterals 2 through 8 in H13. 15. After drilling to well TD in Lateral 8, circulate hole clean. 16. Backream to 9-5/8" casing shoe. 17. Continue backreaming until inside the 9-5/8" casing above the shoe. 18. Spot high viscosity pill and cap well to surface with a 9.7 ppg low solids mud without barite. 19. Backream / POOH as directed. Manage and lay down drill pipe as wear patterns require. 20. Pull out with the BHA. 21. Lay down same and report wear patterns to office on all BHA components. 22. 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. 23. 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. 24. After well TD is reached, rig up to run 4-1/2" slotted liner lower completion as per approved program. .� L _a O y r •�1 974 ° 'a O L. Qj 0... 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OD m N V R (O cl� (n0 (00 n N to (p m n 'I Cl) (D CO N V O O n N N O It(O v Cl)Cl)7 H O 00 Cl) 7 M cp (p W n 00 W O O O O n M M V oD e0 Cl) oD .- (n M n N [f (V N N O p O p A N C C7yz C 0 N (0 N O O L Cl) a� N (p O C N C a U O N c c U O � �N 2-n E(0 ._ Q f,aoUo N_a _ ' _ y I.L mCOQ mO a ° J U L z 2 LL 0 Q N 0 V U N O C •y a N C N j/j 10 N m poa o w am y m C U 1 Q N a r- 0 J 1 M r 2 O � O C coiW Z) ILM N N N t Z o a r o N O O 0 C O O O 7 M M L7 aoJ U U 2 2 2 (v u N d d 0 A 0 A N ` • — d R C •_ C7 O N p C1 Q U li fA fA m N E E rn N � `o a N U N Q 7 d U X N (D O j N E pL N N N LO M c rn � N N U N C C N N c l O cr- o U O p U m N N ` d p c L H F 5 N d N d - w y m c O ° o G 0 0 LL LPL O O LL LL O O 0 0 Ln V U) NO (O C N V r rn v o o r N � N N M O O O N ODD � V LOO 7 (00 M � N N O N N N N N N LL LL LL LL LL O O 0 0 0 0 .D O O O 7 r n u) N� m vi (o oo Lri o (o o M ]�`o* N m m O V N N V N t N N N L6 (o O N N v o o (o o ao o v o eo (no M aro rn rn C O V R 00 (O d O O O O O M O N N M 0 a 0 J S C 3 ¢ a a 10 f0 a a w H Q w I L o 0 L N O m � CN N clo N N N l (O(1 W M o ro w N It f w m v N N o p o p o p o p N o p xaa xaa xaa =aa m =aa w Traveling Cylinder Plot NoGo Rogion EOU's based on. Otrentod EOU D,Monslon - Minor R,sk _4 An6-Coliis�on rule used. D&M AnUColhsion Standard $002 v5 115 2 280 270 260 North 350 0 10 1nu 180 1iu Production TRAVELING CYLINDER PLOT Client BWfcrest Freed Cosmopoliten Unit Structure Cosmopolitan Pad Nell H13 Borehole H13-L07 Date 30-Jan-2019 80 90 100 Schlumberger-Private Iue(ri'est Energy Attachment 3 -� � 1 4 0 r Cosmopolitan Project H13 10-401 L07 Fishbone APD Attachments H13_10-401_L07_Fishbone APD Attachments NOTE: The Rib Laterals in H13 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. Ieest Energy Attachment 4: Cosmopolitan Project H13_10-401_L07_Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments NOTE: The Rib Laterals in H13 are left as open hole completions after drilling, and the only FIT's taken in H13 will be below the 13-3/8" and 9-5/8" shoes in the mainbore. As such there are no FIT Procedures to present in this section of the respective L01 through L07 Lateral APD's. llueNest Energy Attachment 5: Cosmopolitan Project H13_10-401_L07_Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments O Z C� m CD m w z w w m U w J m v O O 4-1 cn m O m Y 0 0 �- C CD 0 n C:) C- C C U) L Of� L� CD N CL N N m d N =\ O N O CD O N \ 0 � N O _O \_O _O x + O a� � O LO O L O O O� N C � O (n — 4 = O cn x O (n � _ O O � 0 � O\ O Q O CDD U BCD 0 O m d- r� N 0 c O Q) Q) Q) (1) Q) Q) Q) N N Q) Q) V- > > > > > > > > > > > p p p 0 0 p 0 0 0 0 0 0 > > > > > > > > > > > Y -O _0 "p -a _0 a 'O _0 _0 'p "p YO O O O O O O O O O O O O m w t- � �t vt �t w 4- �L- �L- �t Q) :3 C C C C C C C C C C C U Y O p p 0 O 0 O p p p p Y O o) E E E E E E E E E E E 0 U (n (n (n Un Un (n Un (n N (n Un V) U J J J J J J J J J J J J (D LL LL LL Li LL LL- L LL LL LL LL V p C C C C C C C C C C C C p O O O O O O O O O O O O i 7 L O Q) N Q) Q) Q) N N N N Q) Q) >� p E E E E E E E E E E E E = p p p p p 0 p p 0 p p p p U U U U U U U U U U U U O p U Y Y Y Y Y Y Y Y Y Y Y Y Q C O O O O O O O O O O O O 0 cD O cD O O cD O O (D (D (0 O (D (0 \ \ \ \ \ \ \ \ \ \ \ \ \ \ N r7 n r7 r) rM r) r7 M r7 r) r7 r') r7 00aese8e000000 n n n 0 z � cD C n-- E a� c 0 U o C/� E Y z � U W O V / /W � Ly_ U O W � D O m U m a� 0 c O V, v N > 0 > N > 0 > 0 > 0 > N > 0 > N > 0 > N > 0 > N > 0 > N > 0 > N > 0 > O > 0 > N > 0 > Y T) -0 O 'v O "v O 'v O 70 O a O 70 O 'v O "v O "v O 'v 0 O 61 p m C v E C v E C 0 E C v E C v E C v E C v E C O E c v E c v C L C v E -C r `1 O U (n J LL Un J LL (n J LL- (n J LL (n J L� (n J LL (n J LL N J LL (n J Li (n J LL (n J LL (n J LL O O 75 _N c O L Q) E c O L (U E C O L 0) E C O L (V E c O L a) E c O L a) E c O L (V E C O L (V E C O L Q) E c O L Q) E c O L a) E c O L a) E p L 'p = U) :3 v U Y O U Y O U Y O U Y O U Y O U Y O U Y O U Y O U Y O U Y O U Y O U Y O O U Q � v O c t0 \ c0 \ c0 \ LO \ c0 \ c0 \ c0 \ 0 \ O \ (0 \ LD \ c0 17, (0 \ (0 \ cV 008 r� n PI) a n a r�) s V-) 8 M s rn 8 r7 00000 PO n r7 M O z u C c CY E 0 0 —C E U r Y 0 w z � w o U W � D O m U n�2 na) nc�� u L N m v 0 m llueNest Energy Attachment 6: Cosmopolitan Project H13 10-401 L07 Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments lue)est Energy Cosmopolitan Project Wellhead/Tree ) A�a o I/ r� S.C{7C1 VS 9 I I I I i 1 J 1I /f t / tttt p L ih i;.lp:i i2 >EAl 111, 3 L S!NS,GW F141 -.s 111G' S.000 PSI MSF' 1 111b. 5,00t) ni MSV ' ' 1 sm. VALCwf I 1 Sh4' CSG W.A #� I 13 !,M- 5gx P51 I -- I 318-FLUIE6 s 14MRtELM %ER +- I i i i i ?+ate Gk 31 6 GCz WaT SIC -- ".:.f'�'"` IE•777_Mo VELLREA% MTEM 014-I r16 5w T:EE W C:^:-.. - - I 4 . BIG 9"RE -EFTIr+L 'nRR,ER StE"00 RISOkri-Ica L 11t'00 TCu '-- ^{{ 10-401 APD Attachments Wellhead/Tree llueNest Energy Attachment Cosmopolitan Project H13 10-401 L07 Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments NOTE: The Rib Laterals in H13 are to be drilled below the 9-5/8" casing shoe 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. Zu est Energy Attachment 8: Cosmopolitan Project H13 10-401 L07 Fishbone APD Attachments H13_10-401_L07_Fishbone APD Attachments H-13-L07 Sp With 1000' Radius H-13�' H-13-L07 ADL3844 29, T3s, R16W, SM H14 �� 8ECM, flS, R16W.8Y H H12-L H-12-Lbk h, H-1 H- H-13-1-07 Top of Production: Northing:2,158,603.70ftUS E a sti n g:155, 769.67 ft U S CSC:5,228' FSL, 4,404' FEL, Sec. 28, T3S, R15W SM De pth:22300'/7123.68' Total Depth: North ing:2,159,117.00ftUS Easti ng:155,008.00ftUS CSC:437' FSL, 5,179' FEL, Sec. 21, T3S, R15W SM Depth: 23263.71'/6860.17' SEC 6.US,RIM SM H-13 Multi -Lateral Producer Scale Date 1:30000 04/01/2019 Prepared by.- Field ABuchanan Cosmopolitan SEC 33, cing Exception Map wound Production Interval SEC 27, T33, R1SW, SM SEC 34. T36, R16W, SM SEC 4. T4S, R16W, SM 7ADL1879 SEC1, 46, R16W, W 0 1000 2000 3000 4000 5000ftUS mt-m IN 1:30000 ADL39190' SEC 26, T33, R16W,'i SEC 36. 73C R15W, S6 SEC 2, T48. lIue'Cest Energy Attachment 9 Cosmopolitan Project H13 10-401 L07 Fishbone APD Attachments H13 10-401 L07 Fishbone APD Attachments 7ALE TREE AVE IU WELL #13 N.A.D.83 N: 2144552.25 E: 1308873.45 LAT: 59'51'29.25"N LON: 151'48'13.05"W N. A. D. 2 7 N: 2144793.15 E: 168845.47 LAT: 59'51'31.42"N LON: 151"48'05.31"W 1504' F.E.L. 2285' F.S.L. GROUND (PAD) ELEVATION PLANT: 98.5' NAVD 88: 146.2' f__ 3.77 --�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ok MP 1so ?ANROSE 9�A srARSK n A NA OR D n� T4S R15W SEC 1 �THIS SURVEY P� COOP g7 74S R15W � SEC it �SSIV� JV.P,5, I VICINITY MAP N 0 5 10 I I I ( IN FEET ) 1 inch = 10 ft. *: 49 T .. ...... -.IACOB GERONDALE.. �o LS-11758bg �_- rr11�ptFESSIONPV AS STAKED SURVEY BLUECREST ENERGY WELL #13 WITHIN SECTION 2 T4S R15W S.M., AK. LOUNSBURY & ASSOCIATES, INC. Surveyors — Engineers — Planners 5300 A STREET, ANCHORAGE, ALASKA 272-5451 )ATE OF SURVEY: i 10 2019 STAKED: 1 10 2019 FIELD BOOK No.: 16-014-1 AS BUILT: GRID: ANCHOR POINT RECERT: llue)ep�st Energy Attachment 10: zsia€-,"W-tion Form Cosmopolitan Project H13_10-401_L07_Fishbone APD Attachments H13_10-401_L07_Fishbone APD Attachments TRANSMITTAL LETTER CHECKLIST WELL NAME: �� `�-t'�-� ?� ' l — 7 PTD: "/Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER / MULTI LATERAL The permit is for a new wellbore segment of existing well Permit No. -U API No. 50-2_L�!-}�� 1/ (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 o ny protgst t e spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool HANSEN, HANSEN UNDEF OIL - 290100 PTD#:2190300 Company BLUECREST ALASKA OPERATING LLC Initial Class/Type -Well Name: HANSEN H-13-1-07 Program DEV _ Well bore seg d❑ DEV / PEND _GeoArea 820_— Unit 10370 On/Off Shore On Annular Disposal ❑ Administration 117 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in Fee Hansen property, well passes through ADLO18790 and ADL 391309' 3 Unique well name and number Yes top of productive interval and TD in ADL 384403. 4 Well located in a defined pool - No HANSEN, HANSEN UNDEF OIL - 290100, governed by statewide spacing regulations._ 5 Well located proper distance from drilling unit boundary Yes 16 Well located proper distance from other wells No SPACING EXCEPTION NEEDED:_ Well branch lies within same governmental quarter section and 7 Sufficient acreage available in drilling unit Yes 1,000' of H-13 and separate, fish -bone lateral well branches. Order issued 2/22/2019. SFD 8 If 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 administrative approval Yes SFD 2/22/2019 13 Can permit be approved before 15-day_ wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA '15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA 18 Conductor string_ provided Yes See PTD 219-023 for details H-13 motherbore_ Engineering 19 Surface casing protects all known USDWs Yes I20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie-in long string to surf csg No '22 CMT_will cover all known -productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes '24 Adequate tankage or reserve pit Yes 25 If are -drill, has a 10-403 for abandonment been approved NA OH laterals of motherbore are being drilled. 26 Adequate wellbore separation proposed Yes 27 If-diverter required, does it meet_ regulations NA Diverter waived - Appr Date 28 Drilling fluid program schematic _& equip list adequate Yes GLS 3/4/2019 29 BOPEs, do they meet regulation Yes 30 �31 BOPE.press rating appropriate; test to -(put psig in comments) - _ - - - - - _ - Yes Choke manifold complies w/APL RP-53 (May 84)_ Yes - 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No H2S not expected ., Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For_ service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures Yes H2S not observed in nearby Hansen wells. Rig has sensors and alarms. Geology Data presented on potential overpressure zones Yes "J_ shaped" well branch targeting Starichkof sand and Hemlock. Planned mud weights in conjunction with Appr Date 136 I37 Seismic analysis of shallow gas zones NA Managed Pressure Drilling technique appear adequate to control maximum anticipated downhole SFD 2/13/2019 38 Seabed condition survey (if off -shore) NA pressure of 9.66 ppg, which_ is based on MDT measurements of reservoir_ pressure in nearby well. 39 Contact name/phone for weekly progress reports_ [exploratory only] NA Geologic Engineering Public Approval awaiting spacing exception order. SFD Order issued 2/22/2019. SFD Commissioner: Date: Date Date om ssioner: Commissioner