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219-023
n Z1 1?-_G) 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.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: REQUESTTO 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) <jody.colombie@alaska.gov>; tom.mckay@bluecrest.com Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Roby, David S (CED) <dave.roby@alaska.gov>; Schwartz, Guy L (CED) <guy.schwartz@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: REQUESTTO 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-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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. From: Colombie, Jody J (CED) <iody.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.mckay@bluecrestenergy.com THE STATE 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 BlueCrest Alaska Operating, LLC Permit to Drill Number: 219-023 Surface Location: 2344' FSL, 1524' FEL, SEC. 2, T4S, R15W, SM Bottomhole Location: 702' FSL, 314' FEL, SEC. 20, 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 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, dI /i55;0�- Daniel T. Seamount, Jr. Commissioner DATED this f day of March, 2019. STATE OF ALASKA AL/ a OIL AND GAS CONSERVATION COMMIS N PERMIT TO DRILL h- R�WE ,x � r: 1 a. Type of Work: 1 b. Proposed Well Class: ato - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill - Q Lateral tratigraphic Test Q Development - Oil ❑ Service - Winj ❑ Single Zone 0 Coalbed Gas ❑Gas Hydrates ElRedrill Reentry xploratory - Oil Developme_n = Gas Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket - Q Single Well ❑ 11. Well Name and Number: BlueCrest Alaska Operating LLC Bond No. 5511251547 ' H13 3. Address: 6. Proposed Depth: >T� 5 12. Field/Pool(s): 3301 "C" Street, Suite 202, Anchorage, AK 99503 MD: 23,727' TVD: 6ggg Hansen, Undefined Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designations ? 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: 2274' FSL, 5141' FEL, Sec. 27, T3S, R15W SM LOCI 14-007 3/10/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 702' FSL, 314' FEL, Sec. 20, T3S, R15W SM 14423 2061' (Y01665) 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 180.65 15. Distance to Nearest Well Open Surface: x- 168845 - y- 2144793.15 Zone- 4 GL / BF Elevation above MSL (ft): 146.2 to Same Pool: 3200' - H14 16. Deviated wells: Kickoff depth: 300 feet , 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 115 degrees Downhole: 3,549 psi ` Surface: 2,842 psf (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 1 4.5 1 15.2 1 P110 IHyd 563 1 6500 1 17227 1 7118 1 23727 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): I Total Depth TVD (ft): I Plugs (measured): I Effect. Depth MD (ft): 1 Effect. Depth TVD (ft): 1 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 Drilling Program Time v. Depth Plot Shallow Hazard Analysis ❑ Diverter 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(d)bluecrestenergy.com Authorized Title: Alaska Manager Contact Phone: 907-794-A."6 Authorized Signature: Date: Commission Use Only Permit to Drill / _ ] � �! `! �Ll� JAPI Number: v o�� 2 ` Permit Approval See cover letter for other Number: 50- 7-� -" G i! c- Date: 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. C" 35, �D Zoe � f- Samples req'd: /0 1� I HZS measures: Yes ❑ No � Yes ❑ No © Mud log req'd- � Directional svy req' : Yes o , 4� e-� �� c�, ✓�t C u t/1 Spacing exception req'd: SLC Yes [i] No ❑ ► �� Inclination -only svy req'd: Yes o El ; - r<_ �tJ2�/+�'r UJc1WC� 20AAC- ZS. U 3 S -A)CZJ Post initial injection MIT req'd: Yes E]No ❑ APPROVED BY Approved COMMISSIONER TIE COMMISSION Date: r v Submit Form and '�Fm 10-401 Revised 5/2017 This permit is valid for 2 Rt t a al per 20 AAC 25.00 (g) Attachments in Duplicate ZuNst Ene gy 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 — Fishbone Producer 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 — Fishbone 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 1-113 well will be another grass roots producer on this pad, to be drilled from the 1-113 slot. i 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, for which the justification for the Waiver can be providedon 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 H13 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 3 "4t open hole sidetracks off the mainbore. As per AOGCC regulations, each rib requires its own unique name and APD. If you have any questions or require further information, please do not hesitate to contact Tom McKay at 907-754-9566 (office) or 907-350-9544 (cell). Sincerely, Larry Burgess Alaska Manager BlueCrest Alaska Operating LLC .� A TO i r CL O � 0 rw O `: cc L c w C m .w aJ O 3 C o C m a , z O+ J � i E O • V 32 J •p ` 01 W O C O m d -W W O ` C E � V M t O u y w N C YI L p C c % O VY O LA c CI V l0 C. Y O E •�z•M _' i O a+ _ c �_ C = 0 D •L a Q C X t O *' O L. LL Q C to C m •i 1A O J C1 = rn ti. O N C m O N m X U 7 Q C O dN a Q7 0a N a to to m aJ L m a _0>> a m vwo N o m n m O °) m to 0 a u \ n Q N Q C N x E m 00 Q O Q Ol M C3 a0 Q 00 v m O�c H LF 0 N (n (J fa N N p N N N A� a -0 W m U� W v v u U O Ln o F Q ,�-� N o ri N a O a, 00 o 2 � V O Y U LO (DF 3 C w I -� 3 a I o — � u Y 3 I m m v I o _� m O N 00 7 M co o I o 0 r-I O ^ _ o I m N o m a \ 1 n, (D w cr w K U 0 0 vO Z LL � a O a N L aj N Q O U X aL M O F 0 CI n fl. a)0 F o v o rn a Q6 a0 Xrya \ CI 04 c�crn �nn -Rgnn -68nn -r,Rnn S anon - -78on6j W a 1-6 / o O fJ 0 0 u) rn g rn Lr cc o Y S 0 U') pp U O ` F cc }+ O O O co LL O Y S O O LO � O U Ix H �+ O O n V ^ LL 0 W U O O O O O CY _ / M } O O "' v C. N � O O N N 7 � R m � o c� p M C 6 d E c o H13 Fishbone Multilateral Application for Permit to Drill Package Mainbore 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 H13 New Well Rig Elevation Form - to be provided when rig is on well 2 � 2 2 2 2 2 2 2 2 c C c G N Ln N N N N Ln un Ln S� N Ln � � N ?N > ? � >N 7 � � � >N N N Ln Ln ?: Ln In Ln N Ln N N > N > N 7 Ln > Lf1 Lrlc-i LI)L-i L!1 -4 -1 H ri H ci ri IH 11 ci L, N K cc = = K K = = K = M ci = ci �[ N Ln c-i cl: (n N N N Ln N N N N N of to Of n n M Y M m M m m cn ro M m M M F- F- H F- F- F- F- F- F- M F- m t` Cn ~ 00 00 00 00 00 00 00 00 00 06 00 F- r, N N F- W N N N LV N N N N N N N V U U p N u LJ L.i V U U U U U u N L.i N N N UJ N N (1) O1 N N Na) a)0J 4J a1 N N NI N N N Ln N N N N N NV) J J J N J J J J J J J J J J U% J Ln W W W N W W W W W W W W W W W LL LL LL J W LL W LL LL LL W LL LL LL LL w W W V r� ri W LD an O lD al M U) r� LL V LL n M N N N N 00 n � N N rj O N 00 m `3 O r, n Ql r, tD O N ` .-i (N Lf) M .--I .--1 N IH N N M M V J J J N N N N N N N N N N N Ln LL LL LL N LL LL LL LL LL LL LL LL LL LL LL N LL N O Ln 00 LL' 00 LL t [Y H n fV 00 't 00 -t N N �' n c-I Ol N m .--I N O lD M O W Ln m al r- M c-I n N M J N V N t\ N M m m M V M � «1 V .-i Ln z{ rl Ln m m r- r-lD m m wLn M M 00 01 m � H V O -4 .� .-i O O O 0) 0 h m M LD c-I w 00 M n V M n M m 00 H Ln oo N Ln CD M a) r-O LD lD Ol Ln wLn V M M N r" -1 O H Ln 00 LD 01 1-4 m m H N 00 LD N O LD M CD r,m ci LD 00 CD 00 00 Ct 00 wLn 0000 Ln 00 Ln 00 lD 00 lD 00 lD 00 lD c0 n 00 LD 00 r, 00 1- 00 1, 00 r- 00 00 H 1-4 IH ci H c-1 ri ri H 11 H .--I rl ri Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln CO C O J n lD f--I n Ol 01 00 m N .H '- rn N m 0) m m 0) 00 O lD 0) N Ct lD O N LD m O N m 00 r, M 0) n lD M m -tY M O Ol N r- W O n M 00 V N lD " r'N wLn O V O a m 0) 00 Ln m N co O TTr,-Ln 00 m V r- Ln r- 00 00 m 00 w m r,00 H O CDH m m -1 -Itm -1 -1 Ln M 'T O Lo N Ln 00 to Ln In 00 m co of 00 m m rn 09 am m m m 0) m m Cl? 00 c0 00 m N o0 o0 00 00 m c0 00 00 00 W o0 00 m m m m Ln m m m D1 Ln M m m m m Qj Ol Ln Ln Ln Ln N Ln Ln Ln Ln Ln N Ln Ln Ln Ln m J } M 00 Q Q Z X Ln r-I H O m O Ln O H O ci 0 M O N O O O 'I N m O cq O n O N O n O LD O 00 O rl O M M M Ih lD Ln N M O 00l0 Ln lD M r,Ol O CD N m Cr m M 1p to N LD lD Q1 m O 00 N N O H r", lD Ln M Ol lD M .--i 00 tD rl O ll V c 00 D .--I } V LD Ln m Ln ID lD r, Lo r, n 00 n 00 00 00 00 m �t v Ln c-i Ln c-1 Ln .--I Ln c-i Ln rl Ln c-I Ln c-I Ln -I Ln - Ln .--I Ln c-1 Ln c-I N l Ln c-I Ln c-I Ln rl N N N N N N N N N N N N N N N cV N N f\ N Q Q Z r, 00 Ol O l0 CD mO M CD O mO O O r,O V m O V O m O N O lD O n O Ln O 111 O N O N r, N N Ln N m 00 r- N M N CDw 00 � N M m Ql O 00 00 .--I O lD N .--I Ol � M V lD O 00 Ln N Ln r, lD O 17 lz c-I n Ln O Ol lz: V r- O x 00 O Ct m 00 01 n 00 r- N lD n Ln lD Ln Ln Ln lD to lD Ln Ln Ln Ln Ln Ln N m L.n Ln Ln Ln Ln Ln N ri ri rl r-I �--I rl ci H H L-i rl H c-I H rl ci O n r, N V n n r 00 r, 00 rl- 00 r, r, r, 00 r\ O L.o M rV Ln ci LD H n H lD rl 1p �--I 1p i--I lD rl O n n 00M O m 0 N O M O M O M O M O N lD m N O1 N M N 00 fV Ol N fV m N to N O Ol rl lD c-i 1p I-i Ln .-I Ln - lD rl r -i 00 N M n LD to n lD r, LD r, to n w r, to rl to O O O N O O O M O m O c-I O O O r O r-I O W O V O Lo O 00 O 00 O ri O V O Ln O n CD 00 O r- CD 00 O r O Ln O m O It O H CD Q 0) r- rV Ln LD O O N N O O O 00 O n O lD C r" 00 r- Ln 00 M 00 r� Ql U1 rl I -I Lf1 Il M N C '7 lD M r, 00 00 m m O 01 -1 O N -i N N M H H rl N r-1 N N N N N N N Q! U i s V U o a O O a O o a O m a O o a O o a O 1 a O D Ln N F Y F Y F Y H ]C F- `1 F Y F Y F- Ln to O O O J O O O M M M M M M M M 2 2 S 2 2 2 2 2 lueNest Energy Application for Permit to Drill Document Cosmopolitan Project H13 10-401 APD Discussion Sections Horizontal Multilateral Producer H13 — Mainbore Horizontal Table of Contents 1. Well Name...................................................................................................................3 Requirementsof 20 AAC 25.005(f).............................................................................................................. 3 2. Location Summary........................................................................................................3 Requirements of 20 AAC 25.005(c)(2).......................................................................................................... 3 Requirements of 20 AA C 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 10. 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 H13 10-401 APD Discussion Sections llueNest Energy Cosmopolitan Project H13 10-401 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 21Page H13 10-401 APD Discussion Sections ZuNest Energy Cosmopolitan Project H13 10-401 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: H13 To include the main bore and 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: H13-1-01, H13-1-02, H13-1-03, H13- 1-04, H13-L05, H13-L06, and H13-L07. 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 (1-113) is for the mainbore H13 drilling and completion operations. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; (D) other information required by 20 AAC 25.050(b); Location at Surface 2344' FSL, 1524' FEL, Sec. 2, T4S, R15W SM ASPZone 4 NAD 27 Coordinates Northing: 2,144,793.15' Easting: 168,845.47' RKB Elevation 180.65' AMSL Pad Elevation 146.2'AMSL Location at Top of Productive Interval 2274' FSL, 5141' FEL, Sec. 27, T3S, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,155,523.91' Easting: 160,232.19' Measured Depth, RKB: 16,870' Total Vertical Depth, RKB: 7,067' Total Vertical Depth, SS: 6,886' Location at Total Depth 702' FSL, 314' FEL, Sec. 20, US, R15W SM ASP Zone 4 NAD 27 Coordinates Northing: 2,159,393.00' Easting: 154,599.00' Measured Depth, RKB: 23,727' Total Vertical Depth, RKB: 6,998' Total Vertical Depth, SS: 6,817' 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 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 (8) 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 APD Discussion Sections llueNest Energy Cosmopolitan Project H13 10-401 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 (BOPE) as required by 20 AAC 25,035, 20 AAC 25.036, or 20 AAC25.037, 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) (B) data on potential gas zones; The Sterling, Beluga and Tyonek sands within the Kenai group have been known to contain gas. The intermediate section will be drilled with a minimum mud weight of 10.5 ppg, the maximum known pressure through these sections is 9.66 ppg @ 3,841' TVDss per MDT's taken on Cosmopolitan 1. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see the Drilling Hazards Overview below. 4 1 P a g e H13 10-401 APD Discussion Sections llueNest Energy Pressure Model (EMW) /1/ 4000 0 Z d 5000 Cosmopolitan Project H13 10-401 APD Discussion Sections UpperTyonek, 3292.44 Lower Tyonek, 6059.01 Starichkof, 6874.84 Hemlock, 6902.77 8 000 I_ _ �.._ ._..._ _ . �_v.__�_ _____. i _ _. a a __ _.._.. _ J 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 5 1 P a g e H13 10-401 APD Discussion Sections nuest Energy Drilling Hazards Summary: 17-%" Hole Section / 13-%" Casing Cosmopolitan Project H13 10-401 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 HZS 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 H2S drills, detection systems, alarms, standard well control practices, mud scavengers. 61Page H13 10-401 APD Discussion Sections llueNest Energy Cosmopolitan Project H13 10-401 AP Discussion Sections 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for on item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20AAC 25.030(f), Please see Attachment 4: Formation Integrity and Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre -perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Volume Calculation Summary Csg/Tbg OD in (1 Hole Size Weight (Ib/ft) Grade Conn Length (ft) Top MD/TVD Btm MD/TVD Cement Program (in) (ft) (ft) 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 Hydri1563 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' TVD No cement required 4-1/2" 8-1/2" 15.2 P-110 Hydri1563 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 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. V" 71Page H13 10-401 APD Discussion Sections ^uest Energy Cosmopolitan Project H13 10-401 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 f' 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 Versa Pro VersaPro 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 (Ibs/100ft) <28 <28 API Fluid Loss (cc/30min) NC HTHP 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 on item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application 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 an offshore platform, mobile bottom -founded structure, Jack up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 8 1 P a g e H13 10-401 APD Discussion Sections nuest Energy Cosmopolitan Project H13 10-401 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 o well is proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic fracturing, a person must make a separate request by submitting an Application for Sundry Approvals (Form 10- 403) 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 Procedures. 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 on annular disposal operation in the well.; Solid and liquid wastes generated during the drilling process will be disposed of at Hilcorp Alaska, LLC's Kenai Gas Field (KFG) Grind & Injection (G&I) Facility or AIMM Technologies' (hydrokinetics) facility in Kenai. 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 APD Discussion Sections llueNesf Energy 11ing Procedure Cosmopolitan Project H13_10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments BlueCrest Energy H13 MAINBORE & FISHBONE LOWER LATERAL Drilling and Completion General Well Plan for AQGCC APD Package Tom McKay Tom.mckay@BlueCrestEnergy.com llueNest Energy Well Plan Summary Rig BlueCrest Rig #1 Well Name & Type H13 - Multilateral Fishbone Design Producer Well Design 13-3/8" Surface x 9-5/8" Intermediate x 4-1/2" Slotted Liner Lower 4-1/2" 15.2# P110 H563 Slotted Liner Lateral Completion Upper N/A Design Lateral Tubing 3-1/2" 9.3# L80 IBT-MOD Production Tubing String String AFE TBD PTD Lower Lateral TBA by AOGCC API # TBA by AOGCC Well Overview Cosmopolitan Project H13_ APD Well Plan Well Schematic Section Review Fishbone Cross Sectional View 0 1 P a g e H13_ APD Well Plan Ze)erst Energy Drilling Cosmopolitan Project H13_ APD Well Plan Surface Intermediate Production 1IPage H13_ APD Well Plan llueNest Energy General Procedure Pre -Rig Operations Cosmopolitan Project H13—APD Well Plan 1. Post Well Sign for H13 on rig in normal location. 2. Post approved APD for H13 as standard procedure. NOTE: H13 will have seven (7) laterals, each with its own APD (Permit to Drill) and API Number, and all APD's must be available in Drilling Supervisor's office, and in the Rig Dog House. MIRU Operations 3. Skid BlueCrest Rig No. 1 over H13 well slot. 4. Center rig over 20" conductor previously set. 5. 20" landing ring was previously installed. 6. Fill out rig elevation form and submit copy to office. 7. Lower riser and nipple up same on 20" landing ring. 8. NOTE: A waiver of the Diverter requirement has been requested of the AOGCC. 9. Rig up bell nipple and check for leaks. 10. Mix spud mud and check all piping for leaks. 11. Make dummy run with 13-3/8" casing hanger. 12. Pick up all drill pipe and stand back same for surface section. 13. Ensure bit breakers for all bits are on hand. 2 1 P a g e H13_ APD Well Plan /1ue)rest Energy Surface Section Overview Cosmopolitan Project H13_ APD Well Plan 17.5 13.375 9.8-10.0 Spud Mud RSS PDC 4,799' 3,528' 69' Fluids Gel Spud Mud 9.8-10.0 150' 4,799' 14-17 NC <2,000 8.5 — 9.5 *Allow fluid to weight up naturally — Do not exceed 10.0 ppg BHA RSS 8.25" Bit Wif[li 1 PD X6 PowerPulse Surface Section Drilling Procedure PDC MSi 619 Min Max G R/Res 600 1200 6x12,3x13 1.052 14. Make up 17-1/2" mill tooth bit on drill collars for clean out BHA. 15. Clean out 20" conductor down to kick off point using fresh water spud mud. 16. Check for any leaks or broaching of the conductor. 17. POOH w/ clean out BHA. 18. Make up RSS Drilling BHA with 17-1/2" PDC bit. 19. RIH and kick off well as per directional plan. 20. Drill 17-1/2" surface section as per directional plan. 21. Planned section TD is 4799' MD; drill hole to fit casing. 22. Casing seat is to be in shale interval as called by Operations Geologist. 23. Circulate hole clean, and backream out as per onsite K&M guidelines. 24. Lay down BHA and stand back drill pipe. 3 1 P a g e H13_ APD Well Plan llueNest Energy Casing Program Cosmopolitan Project H13_ APD Well Plan 13.375 12.347 72 L-80 BTC 12.25 2,670 5,380 1,661,000 Connection Make Up Operational Limit Mha M hMNQ Operating in. in. in. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. 14.375 12.335 10.825 Average 10 to the Diamond 25. Rig up and run 13-3/8" 72# L80 BTC casing with centralizers. 26. Land out casing using fluted mandrel casing hanger. 27. Circulate and condition for cementing. 28. Be prepared to efficiently deal with excess cement returns at surface. 29. Be prepared to perform a top job using 1" pipe if cement fallback occurs which it has on the previous wells on this pad. Cementing ..' .. Mud Push II 80 bbl. Density: 11.0 ppg N/A 0 ppg 17-1/2" 13-3/8" Kenai Surface Lead Class A 564 bbl. Density: 13.20% Yield: 2.44 ft3 /sk Kenai Suface Tail Class G Density: 15.8 ppg 154 bbl. s 15% Top of Tail @ 3,799 MD Yield: 1.16 ft /sk 30. Mix and pump: a. pre -flush b. drop first bypass plug c. lead cement slurry as per program d. second bypass plug e. tail cement slurry as per program f. shutoff plug g. displace with mud h. slow pumps to bump plug and try to minimize cement fallback. 4 1 P a g e H13_ APD Well Plan r+Z�V7; 3 l5 lueNesf Cosmopolitan Project Energy H13 APD Well Plan 31. Record volume of pre -flush and cement circulated to surface. 32. Carefully observe cement top for any fallback. Monitor surface cement samples. 33. If cement falls back, report to office immediately. 34. AOGCC will be asked to approve top job plan using 1" pipe. Notify AOGCC for a field inspector to witness the top job as desired. 35. Cut slot in 20" conductor below casing hanger, and slide 1" pipe into 13-3/8" x 20" annulus until 9 cement top is tagged. ': 36. Mix and pump cement to surface and take photo of cement returning to cellar for AOGCC. 37. Cut off and leave 1" pipe in well. Weld plate back on slot in 20" conductor when cement can be observed and confirmed to visibly set up in the 13-3/8" x 20" annulus without further fallback. �38. Drain and wash cement from riser. Flush all lines. 39. Lay down 13-3/8" landing joint, and remove 20" riser and bell nipple. 40. Nipple up 13-5/8" 5K starter head on to 13-3/8" casing hanger. 41. Test seal between casing hanger and wellhead to 2,000 psi for 10 minutes. 42. Measure elevations from rig floor to top of wellhead flange and record results. 43. Nipple up 13-5/8" 10,000 psi BOP stack and lines. 44. Connect 10K choke and kill lines, and return line above BOP. 45. Notify AOGCC of BOP test 48 hours in advance. } 46. Set test plug. Open wellhead valve below test plug in case test plug leaks. 47. Pressure test BOPE and choke manifold to 3500 psi high / 250 psi low, and record results. 48. Test annular to 2500 psi high / 250 psi low. 49. Hold BOP closing and rig abandonment drill, and record same on IADC Drilling Report. 50. Remove test plug. 5 1 P a g e H13_ APD Well Plan llueNest Energy Intermediate Section Overview Cosmopolitan Project H13_ APD Well Plan 12.25 9.625 RSS PDC ACTIMUL RD 10.50 17,427' 7,125' 770 Fluids ACTIMUL RD RSS ppg 10.50 From 4,799' 8.25" PD Xceed To 17,427' TeleScope L' 13-15 arcVISION ml/30 min <5 ME 80:20 mlVolts >600 1200 • Make Type Name Nozzles TFA Smith •D Intermediate Section Drilling Procedure 51. Install wear bushing. 52. Make up 12-1/4" mill tooth bit on clean out BHA, or PDC bit on RSS BHA. 53. RIH on 5-1/2" drill pipe. 54. Tag upon cementing plug / float collar. s ,_�_ 55. Pressure test 13-3/8" casing tosi for 30 minutes. 56. Chart record and graph the pressure test results. 57. Drill out shoe track, and clean out rathole. 58. Displace fresh water spud mud with 10.5 ppg OBM for drilling the intermediate section. 59. Drill 20' of new hole, circulate hole clean, and ensure mud weight in equals mud weight out. t ( 60. Pull into shoe and perform FIT to 13.0 ppg minimum EMW. 61. Plot FIT results on same graph with casing test and submit same to office. 62. Do not drill ahead until office staff has reviewed FIT resul with AOGCC. 63. Drill 12-1/4" intermediate section as per directional plan. 64. Locate TD of intermediate section as per casing pick in the Starichkof Formation as confirmed by the Operations Geologist. 6 1 P a g e H13_ APD Well Plan llueNest Energy Cosmopolitan Project H13_APD Well Plan 65. Circulate hole clean and backream back into 13-3/8" casing where well inclination is less than 30 degrees to clean out any cuttings beds. 66. POOH and lay down BHA. Casing Program 9.625 8.681 47 P-110 H563 8.525 5,300 9,440 1,493,000 Pipe I Connection IMake Up I Operational Limit lbs. in. in. in. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. 47 10.625 8.681 9.25 I 13,200 15,800 23,000 I 69,000 103,000 Centralizer Placement +/- 38 9-5/8" x 12" VariForm Weatherford 67. Pull wear bushing and install test plug. 68. Change and test BOP rams to 9-5/8 . 69. Remove test plug. 70. Rig up and run 9-5/8" casing to TD. Break circulation at incremental depths while RIH. 71. Land casing using mandrel casing hanger. 72. Break circulation and condition mud for cementing. Cementing Mud Push II 100 bbl. Density: 13.0 ppg 12-1/4" 9-5/8" / Class "G" Density: 15.8 ppg Top of Cement @ 15,927' MD 132 bbl. Yield: 1.16 ft3/sk -7q N/A 633SX 50% 73. Rig up cementing head, and pressure test lines to 3,500 psi. 74. Drop first bottom bypass plug and pump approx. 1Q0 bb Is of 13.0 ppg Mud Push II Spacer. 75. Drop second bottom bypass plug and mix and pump 132 bbls 15.8 ppg Class G cement. 76. Drop top shutoff plug and displace cement with 10 bbis of Mud Push II and 10.5 ppg OBM. 77. Slow pumps as plug approaches float collar. If plug does not bump, pump one half of the shoe track volume in addition to the calculated displacement. 7 1 P a g e H13_ APD Well Plan nuest Energy Cosmopolitan Project H13_ APD Well Plan 78. If plug still does not bump, shut in and hold pressure for 5 minutes. 79. Bleed off and check floats. If floats do not hold, hold pressure on casing for at least six (6) hours before re -checking the floats. 80. After WOC period, lay down landing joint and set the 9-5/8" casing packoff, and test same. 81. Remove 9-5/8" rams and re -install VBR's in BOP stack. 82. Pick up drill pipe for production section and stand back in derrick. 83. Clean pits and prepare to swap mud systems for production section. 84. Install test plug and test BOPE to 3,500 psi high / 250 psi low. 85. Test annular to 2,500 psi high / 250 psi low. 86. Remove test plug and install wear bushing. 8 1 P a g e H13_ APD Well Plan IlueNest Energy Production — Lower Lateral Mainbore / Fishbones L01- LO7 Overview Cosmopolitan Project H13_ APD Well Plan 8.50 4.5 RSS PDC ACTIMUL RD 8.8-9.4 22,122' 7,063' 115° Fluids ACTIMUL RD BHA RSS go ppg From To 8.8-9.4 15,481' 22,122' 6.75" Xceed675 Telescope/ GeoSphere/ PWD/ MVC EcoScope Smith PDC XS616 ml/30 min <5.0 80:20 Min 300 7x12 mlVolts >600 Max 600 0.773 9 1 P a g e H13_ APD Well Plan llueCest Energy Cosmopolitan Project H13APD Well Plan Drilling Main Bore and Laterals (8 total laterals planned - 8-1/2" Production Section) (NOTE: This one page of the Drilling Procedure is included in each of the APD Packages for Laterals L01-L07, under Attachment 1, Drilling Procedure.) 87. Make up 8-1/2" PDC bit on RSS BHA and RIH. 88. RIH with drilling BHA on 5-1/2" drill pipe (combination of HT-55, XT-54 and XT-50 drill pipe). 89. Tag float collar and circulate and condition OBM. 90. Pressure test 9-5/8" casing to 3,500 psi for 30 minutes. Chart and report results. 91. Drill out shoe track and clean out rathole below shoe. 92. Swap mud systems and drill 20' of new hole. 93. Perform FIT to 13.5 ppg EMW. 94. Chart results and plot on same graph as casing test. Submit same to office for review with AOGCC staff. 95. 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 1-113-1-01. 96. Directionally drill well to L01 target and drill L01 lateral to 1-01 TD as called by Geologists. 97. Circulate and backream the L01 lateral back to the main bore. 98. Run back in to TD of the main bore. 99. Displace the 1-01 lateral with LVT. 100. Strip out using MPD without backreaming if possible to the main bore. 101. Initiate trenching and time drilling to execute an open hole sidetrack away from L01 and to the kickoff point for the L02 lateral. 102. Directionally drill the L02 lateral using the same procedure as L01. 103. Repeat these steps for drilling laterals 2 through 8 in H13. 104. After drilling and displacing Lateral 8 with LVT, pull back to mainbore. 105. Backream and displace main bore to LVT is 1000' stages. 106. Continue backreaming and displacing to LVT until inside the 9-5/8" casing above the window. 107. Spot high viscosity pill and cap well to surface with a 9.7 ppg low solids mud without barite. 108. Backream / strip out to the BHA using MPD. 109. Remove the RCD element, and pull out with the BHA. 110. Lay down same and report wear patterns to office on all BHA components. 111. 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. 112. 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. 101 Page H13_APD Well Plan ZeNrst Energy Cosmopolitan Project H13_ APD Well Plan Completion: Lower Lateral Lower Lateral - Slotted Liner Run 111 Page H13_ APD Well Plan llueNest Energy Slotted Liner Run (4-1/2") Overview Cosmopolitan Project H13_ APD Well Plan 8.500 4.500 RSS PDC ACTIMUL RD 9.2 - 9.5 23,727' 6,998' 115.000 4.500 3.826 15.2 P-110 H563 3.701 14,340 13,460 422,000 Connection I Make Up Operational Limit Loss Min•Max Operating in. in. in. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. 3.826 4.093 I 5,100 6,100 8,900 I 8,900 26,000 Run 4-1/2" Slotted Liner Lower Completion 113. Test BOPE and choke manifold; notify AOGCC 48 hours in advance of test. 114. Rig up casing crew and run 4-1/2" slotted liner with Volant Hydroform rigid blade centralizers crimped on the liner joints. 115. Run the slotted liner with liner hanger and liner top packer, equipped with FIV (Schlumberger formation isolation valve) at the top of the liner. 116. Once liner top packer is below wellhead, install RCD element and run liner in on 5-1/2" drill pipe. 117. Exit window in 9-5/8" casing and run liner using rotation as needed, to the final TD of the well in L08. 118. With liner at setting depth, drop ball, and pump down same. 119. Land setting ball, pressure up, and set liner hanger per service company procedures. 120. Slack off to ensure liner hanger is set. )'l% 121. Release from hanger, and set down weight to set liner top packer. 122. Pressure test liner top packer and drill pipe annulus to 2500 psi; chart and report pressure test results. V 123. Pull out of liner hanger which will close the FIV, isolating the liner and open hole from the 9- 5/8" casing. 124. POOH with liner running tools. 1 12 1 Page H13_ APD Well Plan llueCi'est Energy Clean Out Run & Brine Displacement Cosmopolitan Project H13_APD Well Plan 125. P/U clean out BHA and TIH on 5-1/2" DP to 30" above the top of 7.625" tie -back extension. 126. Obtain pick-up and slack -off weights before entering the tie -back extension. 127. Establish a circulation rate of +/- 1 BPM and slowly run in the hole while rotating at +/- 30 RPMs. 128. Observe pressure increase when the BHA enters the 5.75" ID, 23' seal bore located directly below the liner hanger. Mark the drill pipe. 129. Shut down the pumps and proceed to clean the seal bore and FIV area while rotating at +/-30 RPM until the BHA No Go is at the lower crossover. 130. Pull up out of the PBR to 5' above the tie -back extension and proceed to circulate the 9.7 ppg OBM in the casing with 9.0 ppg KCl/NaCL brine as per the fluid displacement procedure_. , 131. Flow check the well. 132. POOH managing drill pipe as required. 133. Lay down clean out assembly and prepare to run upper completion 131Page H13_ APD Well Plan Ilue est Energy Upper Completion Cosmopolitan Project H13_APD Well Plan Production Tubing &Jewelry (3-1/2") 141 Page H13_ APD Well Plan Iue est Energy 3-1/2" Production Tubing String Overview Cosmopolitan Project H13_ APD Well Plan 3.500 2.992 9.3 L80 IBT-MOD 2.867 10,540 10,160 207,000 Connection Make Up Operational Limit •� ..Max Operating in. in. in. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. ft-Ibs. TBD TBD TBD I TBD TBD TBD I TBD TBD Run 3-1/2" Upper Completion / Remove BOP / Set Xmas Tree 134. Tally and Drift 3-1/2" 9.3# L80 IBT-MOD tubing string in pipe shed. Drift to 2.867". 135. Pull wear bushing and wash tubing hanger setting and sealing area as required. 136. Make dummy run with tubing hanger. 137. PU 15' 3-1/2" Seal Stack and FIV shifting tool and associated equipment. 138. PU and RIH with production tubing string. 139. Keep hole full of 9.0 ppg kill weight brine. 140. Use Best of Life 2000 NM as per TSA recommendations. 141. Include three (3) gas lift mandrels, one (1) SSSV, one (1) set of real time readout downhole temperature and pressure gauges, and one (1) downhole chemical injection mandrel with control lines and clamps as per running tally. 142. RIH to 100' above packer setting depth as per tally and slow running speed. 143. Run cables and lines through penetrations in tubing hanger. 144. RIH to liner top packer. 145. Enter seal bore above liner top packer with seal stack. Entering seal bore will re -open the FIV and re-establish communication between the tubing �k�146. and the reservoir. 147. Slack off weight per tubing movement calculation to be provided. 148. Measure for space out and pick up as required to lay down top joint. 149. Pup up as required 1 joint below tubing hanger point. 150. MU tubing hanger. Land tubing hanger. `Qc 151. Test tubing hanger packoff to 5000 psi for 10 minutes. Test tubing against PX plug and tubing by casing annulus�LLJ IJC52. 153. Install TWC (two way check valve) and observe well for flow. 154. Connect control line for SSSV to surface system. 155. Connect line for downhole chemical injection. 156. Connect I -wire for downhole pressure and temperature data transmission. 151 Page H13_ APD Well Plan Ilu est Energy Cosmopolitan Project H13_ APD Well Plan 157. Drain BOP stack. Nipple down riser and rig BOP Stack and place on stump. 158. Nipple up 4-1/2" 5K production tree and pressure test same to 5,000 psi. 159. Pull TWC. 160. Rig up slickline and pull PX plug in tubing. 161. Function test SSSV. 162. Close SSSV, pressure up and shear out downhole valve set in GLM, and pressure test SSSV from below as per AOGCC regulations. Report results to AOGCC and notify AOGCC to witness test 48 hours in advance. 163. Using slickline, replace dummy valves in GLM's with gas lift valves. 164. Function test SSV and SSSV with AOGCC witnessing. Place Well on Flowback and Production 165. Complete handover form and turn well operation over to the Production Operators. 166. Open wing valve and route production to well testing equipment spread. 167. Observe and record flow rate data using gas lift operation to observe assisted flow back. 168. Produce and flow back well as directed using gas lift. TWM, 06 Feb 2019 161 Page H13_ APD Well Plan ZuNest Energy Attachment 2: MIFI Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments C a `m G m' �� e Z� mm Z 2 = W Or�SB$ E c Ntm G m C C N ro N Y c o� comma X ao "0 mov 2 2 o Y O L 2 c mr 0 a e r .. 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M 2 cq \ \\ ca j k / E� 3 £! a /§ aw i R■ } 0 2� / ) v ■ g § k G G �o (« �§ , ,,,,, ;a � �� § 00000 kk aLL 0 9 , �> Zo o \ Hm ©, 2 . , §� , ) {_ u % ( � k §\� 2E! 2E»2Eƒ \ Traveling Cylinder Plot Noce Ropion EOU's based on. Cr�ontod EOLt D—"sion - Elinor Rak y Ant,-CdUsmn rule used D&M Anl Cop aicn Standard 5002 vS 115.2 , 280 270 260 North 350 0 10 rnu 180 itu Production TRAVELING CYLINDER PLOT Cbom 6'uocrost Feld Cosmopolitan unit Structure Cosmopolitan Pad Well H13 6oraholc H13 D.I. 27-Dec-2C18 30 90 100 Schlu mberger-Private llueNest Energy Attachment Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments nuest Energy Cosmopolitan Project H13 APD MASP & Casing Design H13 APD: Maximum Anticipated Surface Pressure (MASP): 17-1/2" Hole Section This hole section will be drilled with no diverter and no BOPE. While MASP will equal the formation pore pressure at the surface casing shoe depth of 3,528' TVD less a gas gradient to the surface, it cannot be shut in, only flowed into the mud pits. Offset well information indicates that the pore pressure at 3,528' TVD will be a maximum of 9.0 ppg (0.468 psi/ft). Calculation for MASP (17.5" hole) = (3,528') x (0.468-0.10) = 1,298 psi. 12.25" Hole Section The MASP for 12.25" hole section will be the formation pore pressure (less a full gas column to the surface) at 17,427' MD/ 7,125' TVD Offset well information indicates that pore pressure at 6,900' TVD will be a maximum of 9.66 ppg (0.502 psi/ft). Calculation for MASP (12.25" hole) = (7,125') x (0.502-0.10) = 2,867 psi. With MASP in the 12.25" open hole section calculated to be 2,867 psi, the 5,000 psi BOPE system to be used will be adequate. 8.5" Hole Section The MASP for the 8.5" hole section will be the formation pore pressure (less a full gas column to the surface) at 23,727' MD/ 6,998' TVD. Offset well information indicates that pore pressure at 6,900' TVD will be a maximum of 9.0 ppg (0.468 psi/ft). Calculation for MASP (8.5" hole) = (6,998') x (0.468 - 0.10) = 2,575 psi. With MASP in the 8.5" open hole section calculated to be 2,575 psi, the 5,000 psi BOPE system to be used will be adequate. H13 - 10-401 APD Attachments MASP & Casing Design nuest Energy H13 Casing Design Verification: Planned Casing Program: Cosmopolitan Project H13 APD MASP & Casing Design 13.375" 9.625 Surface Casing Intermediate Casing Depth (MD) 4,799' 17,427' - Depth (TVD) 3,528' 7,125' Hole size 17.5" 12.25" Weight (ppf) 72 47 Grade L-80 P-110 Connection BTC Hydril 563 Nominal ID (in) 12.347" 8.681" API Casing Design Factors Design factors are essentially "safety factors" that allow the design of safe, reliable casing strings. Each operator may have his own set of design factors based on his experience and the condition of the pipe. Here we use the Operator's recommended design factors. Design Factors: Tensile Joint Strength: Collapse (from external pressure): Burst (from internal pressure): Nt = 1.8 SF Nc= 1.125 SF Ni=1.25SF The pore pressures and fracture gradients used here are those derived from studies of offsetting Cosmopolitan 1, Hansen 1 and Hansen 1A. H13 - 10-401 APD Attachments MASP & Casing Design /1u est Energy Cosmopolitan Project H13 APD MASP & Casing Design H13 Casing Design Factor Calculations: Burst Requirements Use maximum anticipated surface pressures (MASP) for each casing string. For each casing string MASP is the formation pressure at the next casing point less a gas column to surface. 13.375", 72#, L-80, BTC Surface Casine: MASP at 12.25" hole section TVD of 7,125': MASP = (7,125') x ((10.5 ppg x 0.052)-0.10 psi/ft) = 3178 psi (burst stress) DFBurst = burst strength / burst stress = 5,380 psi / 3178 psi = 1.69 vs minimum SF of 1.25. 9.625", 47#, P-110, HVdril 563 Intermediate Casing: MASP at 8.5" hole section TVD of 6,998: MASP = (6,998') ((9.5 ppg x 0.052)-0.10 psi/ft) = 2,757 psi (burst stress) DFBUrst = burst strength / burst stress = 9,440 psi / 2,757 psi = 3.42 vs minimum SF of 1.25. H13 - 10-401 APD Attachments MASP & Casing Design llue)est Energy Collapse Requirements Cosmopolitan Project H13 APD MASP & Casing Design Use an external pressure consisting of the formation pore pressure at the casing shoe and an internal pressure of a gas column to surface. 13.375", 72#, L-80, BTC Surface Casing: External pore pressure = 9.0 x 0.052 x 3,528' = 1,651 psi Internal pressure w/gas only = 0.10 x 3,528'= 353 psi Collapse stress = 1,651 psi - 353 psi = 1,298 psi. DFcoiiapse = collapse rating / collapse stress = 2,670 / 1,298 = 2.06 vs minimum SF of 1.125. 9.625", 47#, P-110, Hydril 563 Intermediate Casing: External pore pressure Internal pressure w/gas only = 9.7 x 0.052 x 7,125' = 3,594 psi =0.10x7,125=713psi Collapse stress = 3,594 psi — 713 psi = 2,881 psi DFCoiiapse = collapse rating/collapse stress = 5,300 psi/ 2,881 psi = 1.84 vs minimum SF of 1.125. H13 - 10-401 APD Attachments MASP & Casing Design lIue'Cest Energy Axial Requirements 13.375", 72#, L-80, BTC Surface Casing: Weight in air = 4,799' x 72 Ib/ft (vertical hole) Pipe weight in mud = Pipe wt (in air) x Buoyancy Factor (BF) BF for 9.6 ppg mud = (65.5-9.6)/ 65.5 Pipe weight in mud = 345,528 lbs x 0.8534 = 345,528 lbs. = 0.8534 = 294,874 lbs. Cosmopolitan Project H13 APD MASP & Casing Design DFAxial = body tensile strength / buoyed wt. = 1,661,000 lbs. / 294,874 lbs. = 5.63 vs minimum SF of 1.8. 9.625", 47#, P-110, Hydril 563 Intermediate Casing: Weight in air = (17,427 x 47 Ib/ft) (vertical hole) = 819,069 lbs. Pipe weight in mud = Pipe wt. (in air) x Buoyancy Factor (BF) BF for 10.5 ppg mud = (65.5-10.5) / 65.5 = 0.8397 Pipe weight in fluid = 819,069 lbs. x 0.8397 = 687,772 lbs. DFAxial = joint tensile strength / buoyed wt = 1,493,000 lbs. / 687,772 lbs. = 2.17 vs minimum SF of 1.8. H13 - 10-401 APD Attachments MASP & Casing Design w w a) C a) C a c \ L .a tZ Y u N a) U U a) .!] � a) Uvmi a) !v I, n O V1 V) Ln 00 d• c 00 Ln 00 �O a--1 N O Ql Ln LD O LD cV N C) N N N Ln 00 O �4 V) LA 00 M 00 Lri -4 ^ O en 0) Lf) rV 1p N LO Ln N ri .-1 M LD M ti LO Ol 4 00 -4 Ln 1, C:)a--1 O 0D Q a -ma a a w w r t� N Q a) U U N a� '^ V) a) y a) E U C w 0 o c o p m U v °) 00 O x .2 c O c u UM m u- In C m 3 O0 `O Y a) a>-, E N E Vl 0) E in \ Y 3 c c= = U d m 0) o 0) N Q 2 N O c— > �D U C O 'a E E U c E v O i 0 a) a) F c— � a) '� a) -0 I - a) 3 y a a) _ 3 > m> o} c a) m ELL E c o .7 O '� -O > U a) n a1 a) a) G m u U U O V Y °� a+ O — O v E H E E E 0 —— L -a m 'm m N bcD C h v V1 M 0l E c c O � J U X w U U U .� 'v1 0 O J a,~ E O 0 c N N c — W---- O O c �@+ a@+ _ aF° m as z 10 Ht`—° UauiiLn z i°UF— >°fp- 0 a) a) N \ a Y U cu au U u n a o Y u w U u Vi Q) _ �+ \ R a�mi a) u a) u Ll a) 3 u a) u mm_ m m m o Ln m o r, 0 0 0 0 0 'It v '0 LO M oo r\ ct o 00 o Ln o Ln 0 00 Lo O1 01 Q1 O 1 n M V1 M rl O d: M N Ln 00 N Lri `~ 00 00 4V' n a1 Ln CO Q1 ^ .N-I N C) l0 a-i N `i e-I a-i t .--1 N M � �--I lD � LD Ln lD LD N 11 � � -1 C:)Ln c-i o Ln Lri m Ln 00 n0 p C: v wa v v a0i cu (U 0- a a)Q v m °�' LL 01 O 0) 'a Q U N N Q i u .a v0- a) m N a) a m O U m O c is y ,n O c � c v X p E c U c m U U 00 O N 00 O O w x +� c -0 O •- c O c u a+ M F1 a+ \ N Q) E O N L W LL > a) E= E a) _ a) Q. u> d C w 0D 0 a) �' a, E E oo m � X v E E a, 3 a) c o L o c t c = � a, va � > W O h O := E E Z.. O a) °° > °° > v v1 0! O O Q U` Q O i7 O c a) 1. '� a) N c -p > y U c a) c a) +. c 0 +. c d m 01 m U E t E N 75 a) E > m> } O O a) v Fa w c— E .., u E m u a) -o N 03 3 Q a) U +� u O +� c c0 N ++ c ++ c ++ c > ++ m m > �-+ O +-+ } ++ c a) —) m h 0) U LL a) U E a) LL. E N O O w a 4J _ U U Q O a) v) a) a) a) c N c C c al Y Y C U c u � � `C p p O -o > E u E E E al N N a) a) O c m m m O m - O— O c� be Y a y 00 v a a) U h x W a) U a) U a) U E Q) N E a) E a) E a) -— 0D 00 _ ,_ I— a) J a) J m V-- m F- a m Vf m V) N a/ Q Y N E v U U X W U U U c C O N E M E C t? W 0D .0 7 -a x _0 "6 x h N a) fa N fa [6 3 i0 f6 N C) U d O a1 J a1 J m tN6 U uNi Q c Q m J W D m J m J m J m J = f-- W— o �-- F— F— �— N U U O V) O V) F— U �— �-- U > llueNest Energy Attachment 4: k Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments IlueNest Energy BlueCrest LOT/FIT Procedure Cosmopolitan Project LOT/FIT Procedure 1. Drill out the shoe track and clean out any rat hole from the previous hole section below the shoe. From this depth, drill an additional 20 ft (minimum) to 50 ft (maximum) of new hole. 2. Circulate the wellbore clean and ensure MW in = MW out. Record this value. Lineup one mud pump on the kill line. Isolate the other pump(s). 3. Turn on the pump to flood the kill line and to ensure the hole is full and that no air is present in the circulating system. 4. While pumping, ensure that the pump pressure gauge and the gauge on the chart recorder are reading the same pressure. 5. Shutdown the pump, position a tool joint at the rig floor and close the upper pipe rams. 6. Bring the mud pump online slowly at % - % bbl per minute and watch for pressure to start increasing. 7. Verify no fluid is leaking past the closed pipe rams. Record the pressure from the chart recorder vs strokes pumped every 2 or 3 strokes pumped. The pressure should increase in a linear fashion vs strokes (Volume) pumped. 8. To perform a LOT (Leak -off Test), continue pumping and recording pressure vs strokes until the pressure deviates from a straight line trend. Obtain two additional readings to confirm this deviation from linearity. 9. Shut down the pump and continue to record pressure vs time, initially every 30 seconds for 2 minutes and then every minute for an additional 8 minutes. 10. Plot the points for the pressure build up vs volume pumped on one chart and the pressure drop vs time on a second chart. 11. By looking at the chart of pressure vs volume pumped, the leak -off pressure is the point at which the curve deviates from a straight line trend. 12. Use the formula: MW + PressureLeak off MWEquivalent = TVDShoe x 0.052 13. Report using the format below: • XX.XX ppg EMW FIT/LOT w/ XXX psi and XX.XX ppg MW @ X,XXX' TVD 14. The FIT follows the same operational steps as previously described, except that the pressure is increased to a pre -determined value previously calculated, where the plot of pressure vs volume pumped does not deviate from a straight line. Using the same formula, the FIT value is obtained. If, however, deviation from a straight line does occur, do not keep pumping. The leak off pressure has been reached and additional pumping may cause the formation to break down. 15. The final step is to bleed off the pressure from the test and measure the volume of fluid returned to a small pit such as the trip tank or small pill pit. Depending on well design and depth, this volume bled back could be small — maybe no more than 1 bbl. 10-401 APD Attachments LOT/FIT Procedure /Iust Energy Attachment Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments O Z CD CD ry w Z w Cn w ry U W J m Ne O O Cn m O m Y 0 00 Ln O Y � O Ile,O O �— cn E U c E - U V) E L Lo LO Qm �LO \U0 Ln N m N \ O � — N � U) CD O U) N N V) Q U O >\ Ln U QLO0 coC i-' X 'N CD U) o� c Ems— N O O \O Q O U r� CD a a �a �� O Y O Q0 N r� C7) N V) O C N N i a O O U) _O O O 4- U) C O a 0) 0 c p 0 > 0 > 0 > 0 > 0 > a > a > 0 > 0 > 0 > 0 > Y T) -0 O "p O 'p O -p O _0 O 'p O "p O "p O 'p 0 -O O _p O O c O E C p E C p E c p E c p E c p E c p E c p E c p E c p E c p E Qj 1 L Y O U Un J Un J L, Un J L� Un J LL Un J LL Un J LL- (n J LL (n J LL (n J LL. Un J L. N .J LL Un J LL ° U - 75 N p c O L O E c O L N E c O L N E c O L N E c O L N E C O L N E c O L N E c O L N E c O L N E c O L. N E c O L. N E c O L N E p 'p > 41 7 O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O p U Y O O U Q N p C CO \ cD \ c° \ c° \ c0 \ c° \ O \ c0 \ cfl \ LO \ c0 \ cD \ c° \ cD \ N 00000000000000 M M M M M M M M M M M M M n n n 0 z � n E O - - CD U o U/ z � s U W O L� V J C) n- U W � O 1 C— m U L 0 'Ifif a� o c o > > > > > > > > > > > p O p p p p p p O 0 0 0 > > > > > > > > > > > Y "p a 'p 'O "p "p _0 _0 _0 _0 'p YO O O 0 0 0 0 O O O O O 0 p C C C CC ECC C C C C C a)C E o) E E E E E E E E E O L � U cn (n (n (n (n (n (n U) (n (n (n (n O N -J J J J J J J J J J J J U LL LL LL LL LL LL LL LL LL LL LL - O c 0 C C C C C C C C C C C p O O O O O O O O O O O O O L. p_ L L L. L L L L L L L L L "p O N N N N N N N N N N O E E E E E E E E E E E E _ p O p O O O O p p p p p U U U U U U U U U U U U O o U O Y Y Y Y Y Y Y Y Y Y Y Y Q p O O O O O O O O O O O O c0 c0 c0 c0 c0 c0 c0 c0 c0 cD c0 (0 co c0 \ \ \ \ \ \ \ \ \ \ \ \ \ \ cV r7 r7 M r7 r) r) r7 r7 to r7 000000000�0000 0 z U CD C rK E 0 (D c E U ( CO O W U z � w O cj� C) r U O W � D O m U n n n r L O U m IuNrst Energy Attachment 6: w.-ram Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments lueNep'st Entiigy I 20' oo esr. -_mot , usre-oo(-V --- 1 4 ws 2uS 1' 41114 spx fS. 4 V16 S.OIX PSI wr sr sEu ?rz? - 6 S: 13 Sn' S.Ow P�O l 2 1l16' 5.000 M MSP VACKW r S.O +.i Cosmopolitan Project Wellhead/Tree 10-401 APD Attachments Wellhead/Tree llueNCst Energy Attachment Cosmopolitan Project H13_10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments NOTE: BlueCrest requests a waiver allowing H13 to be drilled without a surface diverter. Four (4) recent wells have now been drilled on the same pad (H04,, H12, H14 and H16) in which no shallow gas or abnormal pressure was encountered in the surface section. As such, there are no Diverter Schematics to present in this section of the respective H13 Mainbore APD package. llueNest Energy Attachment Cosmopolitan Project H 13_10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments H-13 Spac ng Exception Map SEC S3,TJ9,R16M With 1000' Radius Around Production Interval H-13 26, T3S. R96W, SM H12 H-13 Surface Location: Northing:2,144,793.15ftUS Easti ng:168, 845.47ftU S CSC:2,344' FSL, 1,524' FEL, Sec. 2, T4S, R15W SM Depth:0'/0' Surface Casing: Northing:2,146,601.27ftUS Easti ng:167, 550.98ftUS CSC:4,117' FSL, 2,867' FEL, Sec. 2, T4S, R15W SM Depth: 4798.8'/3527.67' Top of Production: Northing:2,155,523.91 ftUS Easting:160,232.19ftUS CSC:2,274' FSL, 5,141' FEL, Sec. 27, T3S, R15W SM De pth:1687077067.37' Total Depth: /Northing:2,159,393.00ftUS Easti ng:154,599.00ftU S CSC:702' FSL, 314' FEL, Sec. 20, T3S, R15W SM Depth: 23727.42'/6998.22' SEC 6, Uk R16W, 9M H-13 Multi -Lateral Producer Scale Date 1:30000 04/01/2019 Prepared by Field ABuchanan Cosmopolitan ADL3844 SEC 21, T39, H- SEC 33. EEC 27, T39, ROW. 9M SEC 34,739, R16W, 9M SEC 4, T49. R16W, 9M D-L1879- SEC J, 43, R16W, Sm 0 1000 2000 3000 4000 5000ftUS 1:30000 eADL391903 0 SEC 26, US, R16W, 9EC J6, TM R16W. S6 SEC 2, US, ""Nest *I Energy Attachment Cosmopolitan Project H13 10-401 Fishbone APD Attachments H13 10-401 Fishbone APD Attachments TALL TREE AVE N 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' 3.77 -- WELL #13 @ NOTE: 1. STATE PLANE AND GEOGRAPHIC COORDINATES ARE ALASKA STATE PLANE, ZONE 4, N.A.D.83 AND AND N.A.D.27 AS LABELED. 2. COORDINATES ESTABLISHED FROM STATIC GPS OBSERVATIONS. 3. ALL DISTANCES SHOWN ARE GROUND. 4. THE NGS COORDINATE CONVERSION AND TRANSFORMATION TOOL (NCAT) WAS USED FOR NAD83(2011) TO NAD 27 CONVERSIONS. O = AS STAKED CONDUCTOR LOCATION I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION ARE CORRECT AS OF DECEMBER 19, 2018. 4S R1SW of n MP 150 SEC 2 S 9�f STAR�yT pc, O V..1 4P KAT NA DR 0 z AMAN ROSE D T45 jl4 SECC I THIS SURVEY DOP LL SE iODDARD A T4S R15W y SEC 11 MP 151 VICINITY MAP N 0 5 10 I I I ( IN FEET ) 1 inch = 10 ft. OF :*.49T .... . JACOB GERONDALE.. ,o LS-11758 / /Ig 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: 1 10 2019 STAKED: 1 10 2019 FIELD BOOK No.: 16-014-1 AS BUILT: GRID: ANCHOR POINT RECERT: Schwartz, Guy L (DOA) From: Andrew Buchanan <abuchanan@bluecrestenergy.com> Sent: Wednesday, February 20, 2019 1:24 PM To: 'Tom McKay'; Schwartz, Guy L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: H13 APD - Diverter Waiver -Need Surface Csg Depths Map View Attachments: Petrel printing - Cosmopolitan Lease Map.pdf The distance 2D distance from the planned H-13 Surface casing to closest existing Surface casing point (H-14) is 730'. See attached map. Andrew Buchanan Subsurface Manager BlueCrest Energy Ph: 907-754-9563 Cell: 907-250-6545 From: Tom McKay <tom.mckay@bluecrestenergy.com> Sent: Wednesday, February 20, 201910:55 AM To:'Andrew Buchanan'<andrew.buchanan@bluecrestenergy.com> Cc:'Tom McKay' <tom.mckay@bluecrestenergy.com> Subject: H13 APD - Diverter Waiver Need Surface Csg Depths Map View Andrew: Re: H13 Diverter Waiver Guy called and needs for H13 the same exhibits we provided for H04 (see enclosed), showing a map view of the surface casing shoes and distances apart. He said he would ask for this on every well going forward, FYI. Let me know.....thanks I I TM Tom McKay Principal Drilling Engineer BlueCrest 907-350-9544 cell 907-754-9566 office tom.mckav@bluecrestenergy.com M r NZ Ilmw ie c 0 N n o fA cc N � 0 C G O W _ OCD C h t a o o N Q 0 O Remark: AOGCC PTD No. 219-023 Coordinate Check 12 February 2019 INPUT Geographic, NAD27 HANSEN H-13 Latitude: 59 51 31.42036 Longitude: 151 48 05.30675 OUTPUT State Plane, NAD27 5004 -Alaska 4, U.S. Feet Northing/Y: 2144793. 152 Easting/X: 168845.470 Convergence: -1 33 28.89640 Scale Factor: 1.000024810 Corpscon v6.0.1, U.S. Army Corps of Engineers TRANSMITTAL LETTER CHECKLIST WELL NAME: e � PTD: lam/ L � 2i-5 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: _'4 �� POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (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 an Name) Operator order approving a spacing exception. (rsacing assumes the liabil' y f any rotest to 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 Well Name: HANSEN H-13 Program DEV Well bore seg PTD#:2190230 Company BLUECREST ALASKA OPERATING LLC Initial Class/Type DEV / PEND GeoArea 820 Unit 10370 On/Off Shore On Annular Disposal Administration 17 Nonconven, gas conform toAS31.05.030GA.A),0,2.A-D) - - - - - - - NA- - - - - - - - - - - - - - -- -- - --- - - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 1 Permit_fee attached - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - Surface location in Fee Hansen property,_well passes through ADL0187.90 and ADL 391309' 3 Unique well -name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - top of productive interval and TD_in ADL 384403--------- - - - - - - - - - - - - - - - _ _ . 4 Well located in a_definedpool- - - - - - - - - _ _ - - _ _ - - - - - - - - - _ No_ _ - - - - - HANSEN, HANSEN UNDEF OIL _- 290100,governed_4y statewide spacing regulations- - - - - _ 5 Well located proper distance from drilling unit_bounda y- - - - - - - - - - - - - - - - _ _ Yes - - - - - - - - - - - - - - - - - _ - _ - - - - - - - - - - - - . 6 Well located proper distance from other wells- _ - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - - - - - - - SPACING EXCEPTION NEEDED:_ Well lies within same_ governmental quarter section and 7 Sufficient acreage available in -drilling unit _ _ - - - - - - - - - - - - - - - _ - Yes - - - - - - - within_ 1,000'_of 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_appropriatebond in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 11 Permit_can be issued without conservation order_ - - - - No_ - - - - - - - - - - - - - - - - - 12 Permit_ can be issued without administrative Yes SFD 2/22/2019 -approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - _ _ - - _ _ - _ _ - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - - - 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 1Amite-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 - - - - - - - 20-" conductor set_at 193 ft (Rotary- drilled) - - Engineering 19 Surface casing_protects all -known_ USDWs - - - - - _ Yes . - .. _ _ - Surface cssing set at 3528 ft TVD - - - - - - - 20 CMT_vol_ adequate to circulate on conductor & surf_csg . - - _ - - - - - _ - Yes - - - - - - - 13 3/8" surface casing will_ be -fully cemented_ 20% excess- - - _ - - _ - - _ - . - - - - 21 CMT_vol _adequate_to tie -in -long string to surf csg_ - _ _ - - - No- - - _ - _ _ _ 9 5/8"casing TOC planned at 15900 ft. MD - _ _ - - - - - - - - 22 CMT_will coverall known -productive horizons_ _ _ _ _ - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ _ OH lateral spokes are planned for production sections.- _ 23 Casing designs adequate for C,_T, B &_permafrost- - - - - - - - - - - - - - _ - - _ _ _ _ Yes _ _ - - - - - - - - - - - - - - 24 Adequate -tankage or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - ------------------------------------------ 25 If_a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - NA_ Grassroots well. - - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27 If_diverter required, does it meet_ regulations_ - - - - - - - _ - . NA_ _ _ _ Diverter waiver granted.- Several wells in close proxmity._ No shallow gas ---- ----------------- Appr Date 28 Drilling fluid program schematic & equip list -adequate - _ - - - - - - - - Yes - - - - _ _ _ Max formation_ press= 3549_psi_( 9.6_ppg EMW) Will -drill laterals with-9,5 -10 ppg OBM - - - - - - - - - - GLS 2!20/2019 29 BOPEs,.do they meet regulation _ - _ _ - _ _ _ _ Yes - - - - - - - Rig has 10K_13 51&' BOPE - - - _ _ _ _ _ - _ 30 BOPE_press rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - - - - - - - Yes - - - - - - - MASP = 2842_p5i_(will_test BOPE to 3500 psi) - - - - - - - - - - - - - - - - - - - - - 31 Choke_manifold complies w/API_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 - - . - - . _ H2$ not observed in nearby Hansen wells. -Rig has sensors_and alarms- - - - - - - - - - - - - - --- Geology 36 Data -presented on potential overpressure zones - - - - _ - - - - - - - - - - - - Ye. - 's -shaped" well targeting Starichkof_sand and -Hemlock. -Planned mud weights_ in conjunction with Appr Date 37 Sean alysis nalysis of shallow gas -zones _ - - - - - _ _ - _ - _ - - - - NA- Managed Pressure -Drilling technique appear adequate -to control_ maxim um- anticipated_ down hole_ SFD 2/12/2019 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - pressure of 9.60 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: commissioner: Date Commissioner Date 07
