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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-027Davies, 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: REQUEST TO CANCEL PTD_Hansen H13_PTD 219-023_23July2C19
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.roby@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-C23_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) <jody.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.mckav@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
FSa 1
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-L04
BlueCrest Alaska Operating, LLC
Permit to Drill Number: 219-027
Surface Location: 2344' FSL, 1524' FEL, SEC. 2, T4S, R15W, SM
Bottomhole Location: 4744' FSL, 3643' FEL, SEC. 28, 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. Seamount, Jr.
Commissioner 71-4
DATED this S' day of March, 2019.
RECEIVED
STATE OF ALASKA
ALA A OIL AND GAS CONSERVATION COMMIS.
_,N
PERMIT TO DRILL ���
20 AAC 25.005
1 a. Type of Work: roposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑1
c. Specify if well is proposed for:
Drill ` Lateral !atigraphic Test Development -Oil- ❑ Service - Winj ❑ Single Zone ❑✓
4xploratory
Coalbed Gas ❑ Gas Hydrates
Redrill Reentry - 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 - L04
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
3301 "C" Street, Suite 202, Anchorage, AK 99503
MD: 21,503' TVD: 6,590'
Hansen, Undefined Oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation:�y
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:
3941' FSL, 2379' FEL, Sec. 28, T3S, R15W SM
LOCI 14-007
3/10/2019
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property:
4744' FSL, 3643' FEL, Sec. 28, T3S, R15W SM
14423
4325' (YO1665)
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: 19900 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 1 4.5 1 15.2 1 P110 I Hyd 563 1 6500 1 17227 7118 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): I Total Depth TVD (ft): IPlugs (measured): I Effect. Depth MD (ft): I Effect. Depth TVD (ft): I Junk (measured):
Casing Length Size Cement Volume MD TVD
Conductor/Structural
Surface
Intermediate
Production
N/A (Perforation Depth TVD (ft):
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.mcka bluecrestener .com
Authorized Title: Alaska Manager Contact Phone: cw-754-g966
(Authorized Signature: 4 Date: ��✓�� ( /
Commission Use Only
Permit to Drill
API Number: _
1 -�j�j�
Permit Approval
See cover letter for other
Number:
50-
Date:
requirements.
Conditions of approval : If box is the ked, well may not be used to explore
' P -,T-��
for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: j J[) ��� `
f
Samples req'd:
Yes ❑ No Q
Mud log req'd: Yes oEl
HzS measures:
Yes ❑ No Q
Directional svy req' : Yes
Spacing
exception req'd:
Yes ❑v No ❑
_p�,lo
Inclination -only svy req'd: Yes o 0
Post initial injection MIT req'd: Yes ❑Vo ❑
APPROVED BY /
Approved by: COMMISSIONER THE COMMISSION Date: I i1
�� aO 1 \ fiGMA�Submit Form and
`Vo m 10-401 Revised 5/2017 This permit is v ida of approval per 20 AAC 25. 05(g) Attachm nts in Duplicate g
Iue rNest
Eneigy
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 H13-11-04
Fishbone Producer Lateral H13-L04
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-L04 — 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 1-113-1-04 well will be an open hole sidetrack off the
H13 mainbore, to be drilled from the 1-113 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 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
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 Burges�
Alaska Manager
BlueCrest Alaska Operating LLC
H13 Fishbone Multilateral
Application for Permit to Drill
Package
H13 — L04
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 lWellhead
& 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
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Ze)erst
Energy
Application for Permit to Drill Document
Cosmopolitan Project
H13 10-401 L04 APD Discussion Sections
Horizontal Multilateral Producer H13-1-04 — Fishbone Lateral
Table of Contents
1. Well Name...................................................................................................................3
Requirements of 20 AAC 25.005(f).............................................................................................................. 3
2. Location Summary........................................................................................................3
Requirements of 20 AAC 25.005(c)(2).......................................................................................................... 3
Requirements of 20 AAC 25.050(b).............................................................................................................. 3
3. Blowout Prevention Equipment Information..................................................................4
Requirements of 20 AAC 25.005(c)(3).......................................................................................................... 4
4. Drilling Hazards Information.........................................................................................4
Requirements of 20 AAC 25.005 (c)(4)......................................................................................................... 4
DrillingHazards Summary:..................................................................................................................... 6
S. Procedure for Conducting Formation Integrity Tests.......................................................7
Requirements of 20 AAC 25.005 (c)(5)......................................................................................................... 7
6. Casing and Cementing Program.....................................................................................7
Requirements of 20 AAC 25.005(c)(6).......................................................................................................... 7
7. Diverter System Information.........................................................................................7
Requirements of 20 AAC 25.005(c)(7).......................................................................................................... 7
8. Drilling Fluid Program...................................................................................................8
Requirements of 20 AAC 25.005(c)(8).......................................................................................................... 8
9. Abnormally Pressured Formation Information................................................................8
Requirementsof 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
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H13 10-401 L04 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 L04 APD Discussion Sections
11
It3 ue(..1`est
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Cosmopolitan Project
H13_10-401_L04_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: H13404
To include the L04 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: 1113-1-01, 1113-1-02, H13-1-03, H13-
L04, H13-1-05, H13-L06, and 1-113-1-07. 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 (1-113-1-04) is for the fishbone lateral H13-1-04 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 — 1-113-11-04
3941' FSL, 2379' FEL, Sec. 28, T3S, R15W SM
ASP Zone 4 NAD 27 Coordinates
Northing: 2,157,260.71' Easting: 157,758.60'
Measured Depth, RKB:
19,900'
Total Vertical Depth, RKB:
7,124'
Total Vertical Depth, SS:
6,943'
Location at Total Depth — H13-1-04
4744' FSL, 3643' FEL, Sec. 28, T3S, R15W SM
ASP Zone 4 NAD 27 Coordinates
Northing: 2,158,099.00' Easting: 156,517.00'
Measured Depth, RKB:
21,503' '
Total Vertical Depth, RKB:
6,590'
Total Vertical Depth, SS:
6409'
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
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
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H13 10-401 L04 APD Discussion Sections
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H13 10-401 L04 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)
(8) 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.
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0
s
p 5000
111
Cosmopolitan Project
H13 10-401 L04 APD Discussion Sections
Pressure Model (EMW)
!Ail
��-
=�mi
MM
�L
UpperTyonek, 3292.44
Lower Tyonek, 6059.01
- 5tarichko#, 6874.84
Hemlock, 6902.77
8000
8 9 10 11 12 13 14 15 16 17 18 19 20
EMW (PPG)
-Litho5tatic Stress * MDT Data Frac Gradient Moving Average -Planned Mud Weight
51Page
H13 10-401 L04 APD Discussion Sections
nueA
Energy
Drilling Hazards Summary:
17-%" Hole Section / 13-%" Casing
Cosmopolitan Project
H13_10-401_L04_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
HZS drills, detection systems, alarms, standard well control
practices, mud scavengers.
61Page
H13 10-401 L04 APD Discussion Sections
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H13 10-401 L04 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 an item already on file with the commission and
identified in the application:
(5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f);
Please see Attachment 4: Formation Integrity and Leak Off Test Procedure
6. Casing and Cementing Program (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
OD (in)
Hole
Size
Weight
(Ib/ft1
Grade
Conn
Length
(ft)
Top
Btm
MD/TVD
Cement Program
(in)
(ft)
(ft)
20"
N/A
.5001
A525
weld
152'
41'/41'
193'/ 193'
N/A
Wal
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
Hydril563
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
Hydril 563
6,500'
1 7,227'/
23,727'/
Slotted liner completion7
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 L04 APD Discussion Sections
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H13 10-401 L04 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 on item already on file with the commission and
identified in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 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/100ft2)
<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 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 an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a);
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and
identified in the application:
(11) for a well drilled from on offshore platform, mobile bottom -founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed
conditions as required by 20 AAC 25.061(b);
Not applicable: Application is not for an offshore well.
8 1 P a g e
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H13 10-401 L04 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 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
91Page
H13 10-401 L04 APD Discussion Sections
/1ue)erst
Energy
Attachment 1:
, a 01J
Cosmopolitan Project
H 13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 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 L01 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.
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TRAVELING CYLINDER PLOT
Client
B1ueCres1
Field
Cosmopolitan Unit
Structure
Cosmopolitan Pad
We11
H 13
Borehole
1-113-1-04
Date
30-Jan-2019
IJV 180 Ifu
Ticks Type:
MO on 1-113-1.04 1P21
ulation Method:
Normal Plane
Interval
20.00 it
luth Interval:
10.00 deg
I Depth:
19140.00 ft
Depth:
21525,40 ft
st Well Count:
13
Production
10
90
100
Schlu mberger-Private
Ilu Nes[
Energy
Attachme
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 Fishhone 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.
IluCest
Energy
Attachment 4:
4.101
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 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.
Ilu est
Energy
Attachment 5:
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13_10-401_L04_Fishbone APD Attachments
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Energy
Attachment 6:
r r1,
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 Fishbone APD Attachments
lueNest
Energy
Cosmopolitan Project
Wellhead/Tree
1/ ib S,= PS
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10-401 APD Attachments
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Ilul est
Energy
Attachmen
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 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.
llueNeslt
Energy
Attachment 8:
Cosmopolitan Project
H13_10-401_L04_Fishbone APD Attachments
H13 10-401 L04 Fishbone APD Attachments
H-13-L04 Sp
(� I With 1000' Radius
H-13
I `I
H-13-L04
ADL38440
29, nS. R13W, SM H14
H1
H-
SEC 28, nA PUNK SM
cing Exception Map
Around Production Interval
SEC 27. T3S, RIM, SM
ADL39190IN
SEC 26, nS. R16W,
H H-t2-L _ -s
H L
H-13-L04 Top of Production: 8A-
Northing:2,157,260.71 ftUS
Ea sti n g:157, 758.60ftU S
CSC:3,941' FSL, 2,379' FEL, Sec. 28, T3S, R15W SM
De pth:19900'/7123.68'
Total Depth: aEo 32. n . RT
SEC.
>r, na, R76w, aM
Northing:2,158,099.00kU S SEC 26, ns, Raw, s
Easti ng:156,517.00kU S _
CSCA'744' FSL, 3,643' FEL, Sec. 28, T3S, R15W SM
Depth: 21503.11'/6590.17'
SEC a, US, RIM, SM ADL1879
SEC 1. TlS, RIM, SR
SEC 2, q, R18W, SSi
SEC 2, T43,
H-13 Multi -Lateral Producer
scale Date 1:30000 04/01/2019 0 1000 2000 3000 4000 5000ftUS
Prepared by Field
ABuchanan Cosmopolitan 1:30000
ZuNest
Energy
Attachment 9:
Cosmopolitan Project
H13 10-401 L04 Fishbone APD Attachments
H13 10-401 L04 Fishbone APD Attachments
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.27
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.
'd TALL 111H AVC
N
4S R15W
of NP ISO Iq
v
SEC 2 4
Z
STARISRI
pq
N 9T�
D
/I�
VP
OL'j
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U Z
A AN ROSE O
N
A
T4S R15W
n < SEC 1
THIS SURVEY
AL LOOP
A TDDDARD A
T4S R15W
y SEC 11
MP 151
VICINITY MAP 1" = 1/2 MILE
N
0 5 10
( IN FEET )
1 inch = 10 ft
OF
*:49 T
i
i
i
. . ....
• JACOB GERONDALE •' �o
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:
ZuNest
Energy
Attachment 10:
Cosmopolitan Project
H13_10-401_L04_Fishbone APD Attachments
H13 10-401 L04 Fishbone APD Attachments
TRANSMITTAL LETTER CHECKLIST
WELL NAME:
PTD:
i Development _ Service _Exploratory Stratigraphic Test Non -Conventional
FIELD: C POOL: ' -vc < c�'
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
i
LATERAL
No. G , API No. 50- z5:8--'
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- -� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protestto the spaEng exception that may
occur. -F'-"�'f --
All dry ditch sample sets su mitted 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-13-1-04_ Program DEV Well bore seg d❑
PTD#:2190270 Company BLUECREST ALASKA OPERATING LLC Initial Class/Type
DEV / PEND GeoArea 820 Unit 10370 On/Off Shore On Annular Disposal ❑
Administration
17
Nonconven, gas -conforms to A531,05,030(t.1.A),(j,2.A-D)
NA_
- - - - - -
1
Permit fee attached_ - - - - - - _ - -
NA
2
Lease number appropriate_ _ _ _
Yes
Surface location in Fee Hansen property,_welI passes through ADL018790 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, govemed_by statewide spacing regulations._ _ _ _ _ _ _ - -
5
Well located proper distance from drilling unit -boundary ------------------------
Yes---
---------- ----------------------------------_-------
6
Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - -
No_ -
- - - - - - SPACING EXCEPTION NEEDED:_ Well branch lies -within same gQvernmental_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- -
- - - --- - - - - - - - - - - - -- -- - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - --
SFD 2/22/2019
12
Permit_can be issued without ad ministrativ_e_approval - - _ _ - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - -
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 wel_I only) - - - - - - - - - - - - -
NA_ -
- - - - - - - - - - - - - - - - - - - - - - - -
16
Pre -produced injector: duration of pre production Less than 3 months -(For service well only)
NA_
- - -------------------------
18
Conductorstring-provided - - - - - - - - - - - - - - - - - - - - -
Yes
See _PT_D_219-023for details. _ MotherboreH-13_
Engineering
19
Surface casing_prQtects all known USDWs - _ - - - - - - - - - - . - -
-----------
Yes -
- - .-------------------------
20
CMT_vol _adequate -to circulate -on conductor& surf_csg - - - -
Yes
21
CMT_vol_adequate- totie-inlongstringtosur csg--------- - - - - - - - - - - - - - - - - -
No_
- - - - - - - - - - - - - - - - - - - - - -
22
_C_MT_willcover-all known -productive horizons _ - - - - - - - - - _ - - - . _ _ _ -
Yes-
- - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
23
Casing designs adequate for C,_T,B&_permafr_ost_ - - -
Yes-
- - - - - - - - - -- - - -- - - - - - - - - - - - - - - - - -
24
Adequate -tankage- or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - . - - - - - - - - -
25
If a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - -
NA- -
- - - - - - - - - - - - - - - - - - _ - . - - - - -
26
Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - -
27
If-diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - _
NA- _
- - - _ - _ Diverter waived _ _ - _ _ _ - -
Appr Date
28
Drilling fluid program schematic 8 equip list adequate_ - - - - - - - _ - - _ _
Yes -
_
29
BOPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - -
30
BOPE_press rating appropriate; test to (put psig in comments)- - - - - - - -
Yes
- - - - - - - - - - -
31
Choke_ manifold complies w/API_RP-53(May 84)--------- -----
Yes
32
Work will occur without operation shutdown_ - - - - - - - -- --
-----------
Yes
- - - - - - - - - - - - - - -
33
Is presence of H2S gas probable _ - - - - - - - - - - - - - - - - - - - - -
No_ -
- - - - - - H2S is not expected but 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
36
Qata_p_resented on potential overpressure zones
p
Yes .
"J-shaped" ed well branch tar etm Stanchkof sand and Hemlock Planned mud wei hts in conjunction_with_
- - -- p ----g- g - - g --
Appr Date
37
Seismic analysis of shallow gas -zones- _ . - - - - - - - - - - - - - _ _ _ _ _ _
NA. -
. _ . _ - - Managed_ Pressure_ Drilling technique appear adequ_ate _to control_ maximum_ anticipated_ down hole_
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: Co issioner Date Commissioner Date
