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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout218-124Winston, Hugh E (CED)
From: Winston, Hugh E (CED)
Sent: Tuesday, December 22, 2020 2:49 PM
To: Larry Vendl
Cc: Schwartz, Guy L (CED)
Subject: Mustang 1 B Permit Expired
Hi Larry,
The permit to drill for well Mustang 1B which was issued to Brooks Range Petroleum on November 28' 2018 has expired
under regulation 20 AAC 25.005 (g). The permit has been marked expired in the well history file and in the AOGCC
database.
Please let me know if you have any questions. Thanks
Huey Winston
Statistical Technician
Alaska Oil and Gas Conservation Commission
huAh.winston a@alaska.gov
907-793-1241
THE STATE
1 0 a I I
4F611 X W441DI&Wy
GOVERNOR BILL WALKER
Lawrence J. Vendl
Exploration Manager
Brooks Range Petroleum Company
510 L Street, Suite 601
Anchorage, AK 99501
Alaska Oil and Gas
Conservation Commission
Re: Southern Miluveach Field, Kuparuk River Oil Pool, Mustang 1 B
Brooks Range Petroleum Corporation
Permit to Drill Number: 218-124
Surface Location: 2426' FSL, 1667' FEL, SEC. 2, T10N, R7E, UM
Bottomhole Location: 1876' FSL, 837' FEL, SEC. 36, T11N, R7E, UM
Dear Mr. Vendl:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.olaska.gov
Enclosed is the approved application for the permit to redrill the above referenced development
well.
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,
Hollis S. French
Chair
�I
DATED this day of November, 2018.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
on aar oG nnr
1 a. Type of Work:
1 b. Proposed Well Class: Exploratory -Gas 0
Service - WAG L Service - Disp ❑
1 c. Specify if well is proposed for:
Drill ❑ Lateral ❑
Stratigraphic Test ❑ Development - Oil ❑✓
, Service - Winj ❑ Single Zone ❑✓
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑� - Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑
Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket ❑� 1 Single Well ❑
11. Well Name and Number:
Brooks Range Petroleum Corporation
Bond No. LPM 8842179
Mustang 1 B
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
510 L St. Suite 601, Anchorage Alaska 99501
MD: 14,735' TVD: 6086'•
Southern Miluveach Unit
S Miluveach
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 2426 FSL 1667 FEL S2 T10N R7E UM
ADL 390680, 390691
Kuparuk River Oil - 764150
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
2694 FSL 819 FEL 1 T1ON R7E UM
Land Use Permit: LAS 27505
1/1/2019
Total Depth:
9. Acres in Propertv:
14. Distance to Nearest Property:
1876 FSL 837 FEL 36 T11 N R7E UM
5120
837'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 115
15. Distance to Nearest Well Open
Surface: x- 465312.31 ' y- 5940809.93 , Zone-4
GL / BF Elevation above MSL (ft): 75.1
to Same Pool: 1741' SMU M-02
16, Deviated wells: Kickoff depth: 9,124 feet 1
17. Maximum Potential Pressures in psig (see 20 AAC 25,035)
Maximum Hole Angle: 99 degrees
Downhole: 3,423 psig ` Surface:
2,816 psig
18. Casing Program:
Specifications
Top - Setting Depth - Sottorn
Cement Quantity, c.f. or sacks
Hole
Casing
Weight
Grade
Coupling
Length
MD
TVD
MD a
TVD
(including stage data)
6-1/8"
4-1/2"
12.6
L-80
Hydril563
5,768'
8,967'
5955'
14,735'
6086,
None
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
9,525'
6107'
8,903'
8,903'
5914
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
80,
20"
—140 ft3Arctic Grade
108,
108'
Surface
3,040'
9-5/8,
460 bbls Lead / 46.2 bbls Tail
3.069'
2A48'
Intermediate
9,081,
7"
67 bbis
9,110'
6,044'
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes No ❑
20. Attachments: Property Plat F-11 BOP Sketch Drilling Program Time v. Depth Plot
Diverter Sketch B Seabed Report B Drilling Fluid Program
Shallow Hazard Analysis
B 20 AAC 25.050 requirements e
21. Verbal Approval: Commission Representative:
Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name: L4,24,7 � ®
/ /ram �
Authorized Name: L/ tl '7VG� tiT VGA' De--
Contact Email �nJo� Z-2,0
Authorized Title: %Xo O aN MAtj Az '�
Contact Phone:
Authorized Signature:
Date:
Commission Use Oniy
Permit to Drill 1API
Number:
Permit approval
See cover letter for other
Number: ($
50- iU -- -406
Date: i`„
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: 1500 3O `S /
/
Samples req'd: Yes ❑ No [�
Mud log req'd: Yes ❑ No [�
��� �/
H2S measures: Yes ❑ No E-i
Directional svy req'd: Yes [?No ❑
re Spacing
�n ®
exception req'd: Yes ❑ No[� Inclination -only svy req'd: Yes ❑ No []�
Post initial infection MIT req'd: Yes ElNo ❑
/`1ctv�lr"1 /'r� L►� j� cX�'Lt.1
Ccs�.�.e� [✓r �Xif�
(e}
Approved by:
APPROVED BY
tl lei �t
COMMISSIONER THE COMMISSION
Date:
Form 10-401 Revised 5/2017
Submit Form and
This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate
ORIGINAL o .,6�,�.,f
,�miyl c�
l {g d., • ?J. �. I o/23/18
Brooks Range Petroleum
Conductor
20"
108' MD / TVD
Surface Casing
9-5/8" 40# L80 BTC
9-5/8" Tam Collar
500' MD / 499' TVD
Cement to surface
3.069' MD / 2448' TVD
54° INC / 103` AZMTH
Intermediate Casing
7" 26# L80 BTC-M
TOC: 6,997' MD (est.)
9.117' MD / 6087' TVD
Wellbore Fluids
Diesel Freeze Protect
0' - 1,500' MD
9.8 ppg Inhibited Brine
11500' - 8,903' MD
Mustang 1A
Nabors 16E RKB: 34.5'
3-1/8" OD 5k Dry Hole Tree
5k Multi Bowl Wellhead
■ 3" H BPV Installed
Base of Permafrost
1,371' MD / 1358' TVD
Upper Completion
3-1/2" 9.3# L-80 8rd EUE
1,415' MD
TOC
8,903' MD / 5914' TVD
EZSV
9,020' MD / 5998' TVD
----—-----—-----—-—-—-—---
Open Hole
6-1/8"
9,525' MD / 6107' TVD
Rev.0 10/19/2018
Brooks Range Petroleum
Conductor
20"
108' M D / TVD 96
Surface Casing
9-5/8" 40# L80 BTC
9-5/8" Tam Collar
500' MD / 499' TVD
Cement to surface
3,069' MD / 2448' TVD
54" INC / 103' AZMTH
Intermediate Casing
7" 26# L80 BTC-M
TOC: 6,997' MD (est.)
9,117' MD / 6087' TVD
Wellbore Fluids
Diesel Freeze Protect
0' - 1,500' MD
9.8 ppg Inhibited Brine
1,500' - 8,903' MD
Tubing Jewelry
X Nipple Profile
Gas Lift Mandrel
Gas Lift Mandrel
Gas Lift Mandrel
X Nipple Profile
Production Packer
Mustang 16 ^Q;7
411R
Doyon 25 RKB. 39.91 LLC
4-1/16" FMC Gen V 5k Production Tree
5k Multi Bowl Wellhead
4" H BPV Installed
GLM
GLM
GLM
Base of Permafrost
1,371' MD / 1358' TVD
bh
Upper Completion
4-1/2" 12.6# L-80 VAM TOP
8,977' MD / 5955' TVD
Lower Completion
4-1/2" 12.6# L-80 HYD 563
14,735' MD / 6086' TVD
ZXP Liner Top Packer
Flex Lock V Liner Hanger
Swell Packers
5.5" OD, 3 ft Element
NCS Frac Sleeves
Float Collar
Float Shoe
Rev.1 11/5/2018
'A'� AO RINING
Brooks Range Petroleum uc
Application for Permit to Drill Document
Development Well Mustang #113
Table of Contents
WellName.....................................................................................................................................................3
Requirements of 20 AAC 25.005 (f)..........................................................................................................3
LocationSummary........................................................................................................................................3
Requirements of 20 AAC 25.005 (c)(2).....................................................................................................3
Requirements of 20 AAC 25.050 (b).........................................................................................................3
Blowout Prevention Equipment Information...............................................................................................3
Requirements of 20 AAC 25.005 (c)(3).....................................................................................................3
DrillingHazards Information.........................................................................................................................3
Requirements of 20 AAC 25.005 (c)(4).....................................................................................................3
Procedure for Conducting Formation Integrity Tests...................................................................................4
Requirements of 20 AAC 25.005 (c)(7).....................................................................................................4
Casingand Cementing Program....................................................................................................................4
Requirements of 20 AAC 25.005 (c)(6).....................................................................................................4
DiverterSystem Information........................................................................................................................4
Requirements of 20 AAC 25.005 (c)(7).....................................................................................................4
DrillingFluids Program..................................................................................................................................4
Requirements of 20 AAC 25.005 (c)(8).....................................................................................................4
Abnormally Pressured Formation Information.............................................................................................4
Requirements of 20 AAC 25.005 (c)(9).....................................................................................................4
SeismicAnalysis............................................................................................................................................4
Requirements of 20 AAC 25.005 (c)(10)...................................................................................................4
SeabedCondition Analysis............................................................................................................................5
Requirements of 20 AAC 25.005 (c)(11)...................................................................................................5
Evidenceof Bonding.....................................................................................................................................5
Requirements of 20 AAC 25.005 (c)(12)................................................................................................... 5
ProposedDrilling Program............................................................................................................................5
Requirements of 20 AAC 25.005 (c)(13)................................................................................................... 5
Discussion of Mud and Cuttings Disposal and Annular Disposal..................................................................5
Requirements of 20 AAC 25.005 (c)(14)...................................................................................................5
August 20, 2018 Mustang #1� 1
/A "/',�,\
Brooks Range Petroleum
HIRE
Uc
Attachments.................................................................................................................................................. 5
Attachment1 Surface Platt.......................................................................................................................5
Attachment2 Directional Plan..................................................................................................................5
Attachment 3 BOP Configuration............................................................................................................. 5
Attachment 4 Drilling Hazards Summary..................................................................................................5
Attachment 5 Formation Integrity and Leak Off Test Procedure.............................................................5
Attachment 6 Drilling Fluids Program.......................................................................................................5
Attachment 7 Drilling Procedure..............................................................................................................5
August 20, 2018 Mustang #1 4°
2
/A ~
Brooks Range Petroleum
Well Name
Requirements of 20 AAC 25.005 (f)
Well Name: Mustang #1B
Location Summary
Requirements of 20 AAC 25.005 (c)(2)
Surface Location
2426 FSL 1667 FEL S2 T10N R7E UM
ASP Zone 4 NAD 27 Coordinate
Northing 5,940,810' Easting 465,312'
Pad Elevation
75.1' above mean sea level
RKB Elevation
115' above mean sea level
Top of Productive Horizon (Heel)
2694 FSL 819 FEL 1 T10N R7EUM
ASP Zone 4 NAD 27 Coordinate
Northing 5,941,052' Easting 471,440'
Measured Depth (ft)
9,687' MD
Total Vertical Depth Subsea (ft)
5979' TVDss
TD (Toe)
1876 FSL 837 FEL 36 T11N R7EUM
ASP Zone 4 NAD 27 Coordinate
Northing 5,945,514' Easting 471,439'
Measured Depth (ft)
14,735' MD
Total Vertical Depth Subsea (ft)
5971' TVDss `
Please see Attachment 1 Surface Platt
Requirements of 20 AAC 25.050 (b)
Please see Attachment 2 Directional Plan
The applicant is the only affected owner.
Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005 (c)(3)
Please see Attachment 3 BOP Configuration
Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
The expected reservoir pressure in the Kuparuk C Sand is 0.562 psi/ft, or 10.8 ppg equivalent mud
weight. The maximum potential surface pressure (MPSP) based on the above expected pressure
gradient, a methane gradient of 0.10 psi/ft, and the known vertical depth of the Kuparuk C formation
(6094' TVD) is:
August 20, 2018 Mustang #46 3
Brooks Range Petroleum
MPSP = (6094 ft)*(0.562-0.10 psi/ft) = 2816 psi
Mud weights will be targeted initially at 10.1 ppg while drilling, with Managed Pressure Drilling (MPD)
utilized to hold approximately 375 psi back pressure, equivalent to an 11.3 ppg static mud weight.
Please see Attachment 4 Drilling Hazards Summary - -�- -�
N'kP
Procedure for Conducting Formation Integrity Tests �—
Requirements of 20 AAC 25.005 (c)(7)
As two previous LOT/FITS have been performed on the 7" casing shoe, no additional FIT is planned
during this drill out. This will help to mitigate the potential for shale instability below the 7" casing shoe
while drilling the proposed sidetrack. (r_) F7 �_ �,fqt ✓4i!)
Please see Attachment 5 Formation Integrity and Leak Off Test Procedure XL //` l`, if
Casing and Cementing Program
Requirements of 20 AAC 25.005 (c)(6)
Completion Liner
CSG OD
Hole Size
Weight
Grade
Connection
Length
Top
Bottom
Cement Program
(in)
(in)
(Ib/ft)
(ft)
(MD/TVD)
(MD/TVD)
4-1/2"
6-1/8"
12.60
L-80
Hydril 563
5,768
8,967' / 5955'
14,735' / 6086'
None
Please see attached 10-401 for existing Casing and Cementing information
Diverter System Information
Requirements of 20 AAC 25.005 (c)(7)
Diverter will not be used to drill this section as surface casing is already set. BOPE M
tested prior to drilling out.
Drilling Fluids Program
Requirements of 20 AAC 25.005 (c)(8)
Please see Attachment 6 Drilling Fluids Program
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(1O)
N/A - Application is not for an exploratory or stratigraphic test well.
August 20, 2018 Mustang #1,K1 4
/~-Y�
Brooks Range Petroleum
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A — Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for Brooks Range Petroleum Corporation is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
Please see Attachment 7 Drilling Procedure
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
All drilling waste fluids and cuttings will be disposed of at either the ConocoPhillips 1B Grind & Inject
Facility or the Hilcorp Milne Point Grind & Inject Facility. Waste fluids and cuttings will be hauled via
truck to either 1B or Milne Point for processing and injection in an approved disposal well.
Attachments
Attachment 1 Surface Platt
Attachment 2 Directional Plan
Attachment 3 BOP Configuration
Attachment 4 Drilling Hazards Summary
Attachment 5 Formation Integrity and Leak Off Test Procedure
Attachment 6 Drilling Fluids Program
Attachment 7 Drilling Procedure
August 20, 2018 Mustang #1A 5
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WELL #
LATII DE(N)
LONGITUDE(W)
NORTHING
EASTING
SECTION LINE OFFSET
F.S.L. F.E.L.
PAD ELEVATION
4* A
N 070' 14' 57.101"
W 150' 16' 52.-171"
5940772.89
465198,38
2,389'
'.780'
73.6
B
N 070' 14' 57.147"
w 150' 16' 51.761'
5940777.52
+65212.52
2,393'
1.766'
73.7
c
N 070' 14' 57.194"
W 150' 16' 51.346"
5940/82.'.S
465226.79
2.398'
1.752'
73.8
D
N 070' 14' 57.240"
W 150' 16' 50,932"
5940786.78
465241.05
2,403'
1,738'
73.9
** E
N 070' 14' 57.291'
W 150' 16' $0.514"
594-0791-90
465255,45
2,408'
1,723'
73.9
F
N 070' 14' 57.332"
W 150' 16' 50.104"
5940796,05
465269.58
2.412'
1.709,
74.0
G
N 070' 14' 57.379"
W 150' 16' 49,690"
5940800.69
465283.85
2.417'
1.695'
74.1
H
N 070' 14' 57.425"
W 150' 16' 49.275"
5940805.32
465298.11
2.422'
1,681'
74.2
tr I
N 070' 14' 57.471"
W 150' 16' 48.863"
5940809.93
465312.31
2,42W
1,667'
74.2
J
N 070' 14' 57.517'
W 150' 16' 46.447"
5940814.59
465326.64
2.431'
1.652'
74.3
K
N 070' 14' 57.564"
W 150' 16' 48.033"
5940819.23
465340.90
2.436"
1,638'
74.4
L
N 070' 14' 57.610'
W 150- 16' 47.6'W
5940823.85
465355.17
2,440'
1,624'
74.5
++ M
N 070' 14' 57,655"
w 150' 16' 47.213"
5940828.42
465369.14
2,445'
1,610'
74.5
N
N 070' 14' 57,702"
W 150' 16' 46.790"
59408311,3
465383,70
2,450'
1.595'
74,6
O
N 070' 14' 57.749"
W 150' 15' 46.376"
5940837.77
465397.96
2.454'
1,58?'
74.7
P
N 070' 14' 57.795"
W 150' 16' 45961"
5940842.40
485412.23
2.459'
%567'
14.8
O
N 070' 14' 57,841'
W 150' 16' 45,547"
5940847.04
465426.49
2.464'
1.553'
74.8
R
N 070' 14' 57,887"
W 150' 16' 45.133"
5910851.57
465440.76
2,468'
1.538'
74.9
LL
N 070' 14' 57.933"
W 150' 16' 44-719"
5940856.31
465455.02
2.473'
1,524'
75.0
S
N 070' 14' 56.354"
W 150' 16' 51,446"
5940696.80
465222.98
2.3`3'
1.756'
73.8
T
N 070' 14' S6.400"
W 150' 16' 51.032"
5940701,44
465237 24
2,317'
1,741'
73.9
u
N 070' 14' 56.446"
W 150' 16' 50.617"
5940706,07
465251.51
2.322'
1.727'
74.0
v
N 070' 14' 56,493"
W 150' 16" 50.203"
5940710.71
465265.77
2,327'
1.713'
74.1
w
N 070' 14' 56.539"
W 150' 15' 49.789'
5940715.34
465280,04
2,331'
11699'
74.1
%
N 070' 14' 56.585"
W 150' 16' 49.375"
5940719.98
465294.30
2,335'
1,584'
74.7
Y
N 070' 14' 56.631'
W 150' 16' 40,950"
5940724.61
465308.57
2,341'
1,670'
74.3
Z
N 070' 14' 56.678"
W 150' 16' 48.546"
5940729.25
465322,83
2,346'
1,656'
74.4
AA
N 070- 14' 56.724"
W 150- 16' 48.132'
5947733-88
465337.09
2,350'
1,542'
74.4
8B
N 070' 14' 56.770"
W 150' 16' 4.7,718"
5940738.52
465351.36
2,355'
1.,621'
74.5
cc
N 070' 14' 56.816"
W 150' 16' 47.303"
5940743.15
465365.62
2,360'
1,613'
74.6
DD
N 070' 14' 56.863"
W 150' 16' 46.889"
5940747.79
465379,89
2,364'
1,599'
74-7
EE
N 070' 14' 56.909"
W 150' 16' 46-475"
5940752.42
465394.15
2,369'
1.585'
74.7
FF
N 070' 14' 56.955"
W 150' 16' 46.061"
5940757.06
465408 42
2,374'
1,570'
74.8
GG
N 070' 14' 57,001'
w 150' 16' 45.646"
5940761.69
465422.68
2,370'
1,556'
74.9
HH
N 070' 14' 57.048"
W 150' 16' 45.232"
5940766.33
465436.95
2,383'
1.542'
75.0
II
N 070' 14' 57,094"
W 150' 15' 4-4.818"
5940770,96
465451,21
2,388'
1.528'
75.0
JJ
N 070- 14' 57.140'
W 150- 16' 4-4.404'
5940775.60
465465.47
2,393'
1,513'
75.1
KK
N 070' 14' 57.186-
W 150' 16' 43.989"
5940780.23
465479.74
2,397'
1.499'
'75.2
** Indicates Asbuilt Well Conductor Coordinates
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Brooks Mustang 1 B (129) Proposal Geodetic Report Schlamherser
(Def Plan)
�
CIIerM
BrooW Range Petroleum Cotporetlon
survey r-wmpuar":
Vertical Saegon Aaimuth:
-1.
1.000 *(Two North)
Field:
SMU Mustang
Verticel8ecgon OHgin:
0,000 ft, 0.000ft
fiww h rel Blot;
Muebng Pad I Muefang l (I)
ND Reference DM=
RotaryTable
Well:
Muatang1
`
! ND FI-I.-ce ENvegon:
11S-ft.-Mean Soo Level
Bonhola:
Mueang IA v2
Ground Ebvetion:
75.i00R above Mean See La.el
APW
E=32065201
Perplli
Magnetic Declination:
Burvy None:
Mustang 18(P9) Pi�A
Tobl Greviy FieM S.Vh:
I WI 9954mgn(9.60685 Based)
Bnrvy Dab:
Augu521,2018
Grav'dy Model:
DOX
Tort f AHD I DDI I ERD Rode
261.933 ° 111975,160 ft 16,87711.01
Total Wg-ic Field StrengM:
574la156 nT
Coordinate Reference Syetonc
NAD27 Alaska Stab Plane, Zone 04, US Feel
Magnetic Dip Angle:
W.760°
Lowgon Lot I Long:
N 70° 14' 57.4708T, W 150° 16' 48.86292"
Declinafon Date:
G toter 31, 2018
Eecedan Odid WE Ya:
N 5940809.930 I61S, E 465312,310 ftUS
Magnetic Dxllnotion Model:
13GGM 201a
CRBGHd Convergence Angle:
-0.2638°
North Rebrenae:
True North
Grid Scala Facbr:
09W90137
Odd Convargeime Ueed:
0.00W °
Version I Patch:
2.10544.0
Tobl Curt Meg NoMoTrue Nath:
16.6947 °
Comnenb
MD
In<I
Azlm True
NDBB
ND
YBEC
NB
EW
TF
DIA
DlracNonel Eaclualon Zone
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(ft)
l%
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(ft)
IRI
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lftl
1'1
1°no0ft) DNRculty Inds: aert
Meta
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(nT)
(ftus)
(RUB)
• Kf
9064.86
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3684
51-70
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8042.04
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2000
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9218.88
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2000
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841511
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6134.94
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8137.85
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950000
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8137.56
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5940579.83
471447 O
471447.20
End Cry
9879.25
%.50
359.82
59140
60MQ
-15.56
-122.W
6135,12
HS
4.00
6,476
79.74
5664933
5940659.D6
4r 1448.18
"W00
%.W
35B.82
5971.94
6GBB94
5.17
-101.91
6134.69
HE
am
6.47
79.74
5 95 34
594057980
4]144.5.85
1 DDW.00
88,50
35B.82
5974.W
608856
106,07
-1 Be
:132.62
HS
0.Do
6.48
79.74
5654941
5MO779.74
471444.24
Tcp KUPC
101WW
'017732
SB.W
88,50
35882
358.82
5977.18
597920
6092.18
6094.20
204.96
262.19
97.%
/7526
6130.56
6128.97
HS
HS
0.00
0,00
649
6W
79.74
76.74
56549.48
56549.53
SM79.68
594095696
47144244
47f441.40
C MDO
10196.86
88W
358.82
5979.71
6094.71
30112
194,79
6128.57
6.92R
OM
6 0
79,74
56549,54
5940W6.49
471441.09
10200.00
88.W
358.83
5979.79
6094.79
304.e5
197.%
6128W
6.92R
2.00
6.W
79.SO
56560,58
5940979.61
4'71441.04
Tg12
1027240
90.%
359.00
5960.70
60%.70
377A9
270,30
6127. is
SO R
2.W
6.51
81.23
W 50
5941052.00
471440.00
1030000
9000
3%.55
59 30
6095.;0
404.79
297.90
8128.78
DOR
2W
8.52
81.20
56792.40
5941079,60
471QS 78
End Cry
1M10.T7
10400.00
SOW
%.W
359.77
3W. T7
5%0.70
5960,70
W95.I0
6 9 70
415.58
SN 78
3%.W
397,90
6126.71
6126.35
HS
HS
2.00
O.W
6.52
8.53
81.19
81,19
56790.63
M79087
5941090.37
594117959
471439.76
471439,81
1DW000
90.W
3W.77
59W.70
6095.70
ON 74
497,90
6125.95
HE
0.00
6.54
81.18
567W91
5941279,58
471Q 87
1 DSO0.00
10700.W
90.00
W.W
359.77
359.77
5980 0
59M 70
am,]0
BO%.TO
704.72
604.69
597.%
697.90
612554
6125.14
HS
HS
0,00
0.00
6.55
655
81.19
81.19
56790.96
56791.00
5941379.57
5941479.55
47143B.92
47143998
Cry 111DO
10741.69
90,00
359.7
59W.70
609b.70
846.37
739.59
612497
%L
0.00
856
81.19
56791M
5841521.25
47144D.W
T913
1C743.44
90M
359.75
5%07C
S0%.70
948.13
741.35
6124%
2.33E
100
656
81.19
56791.14
594152300
471440.00
End Cry
10778.W
9035
359,74
5960.W
SD%.59
BB3.17
776.40
612480
HS
1,00
8.W
81.54
56B43.94
5941558.05
4714 W
10300,00
90.W
359.74
5980.46
6095. 16
90467
797.90
6124.70
HS
D00
656
81.54
56843.95
%41579.55
471440.00
I0900.DO
90.35
3W.74
5W9.85
6094.%
JON64
897.90
612414
HS
GOD
6,57
81.54
5684.3.98
5941679.54
471440A0
110000p
9035
359.74
597924
608424
1104.62
Was
6123.7.
HS
0,00
6.58
81.54
56844.02
59417M53
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if 0%.34
W36
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HS
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81.54
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5WI78586
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11100W
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35934
5978.63
609363
1204.59
1097.89
1121.12
HS
0.00
6.59
81.54
58844.05
5941879.51
471440.00
Cry 11100
112Do 0'
11201.48
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359.74
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54/8.02
5979.01
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11 W'89
11%.36
6122.86
6122.85
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179.87E
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81.54
81.54
56844,09
558"09
5941979W
5941%0M
4?1440.W
471440.00
Tgl4
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90.00
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amm
1341.06
1234.39
612269
WR
1.00
6.81
81.19
56I91.44
594201600
971440.00
End Cry
11236,67
90DO
359.74
5977.%
6092.%
1341.22
12XW
612269
HS
100
681
61.19
5679143
5942016.17
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90.00
359.74
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6092.90
1404.54
1297.89
6122.40
HS
0,00
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4)1440D0
11400.00
50.00
359,74
587790
6092.90
1504.51
1397.88
612114
HS
0.00
6.62
81.19
56791.49
5942179.48
4714Q..00
1150 00
90.00
339.74
5977.90
6092.90
16N 49
1497.88
5121.48
HS
030
60
81.19
56791.54
5942279.47
471440.00
11630. Co
90.00
359.74
5977.SO
6092,90
1704.47
1597.88
6121.02
HS
000
6.fi4
81.19
56791.58
5942379,46
471440.00
Cry TOO
11607.87
9000
359.74
5977,90
6M,90
1712.34
1605,76
612098
90L
000
6.64
81.19
55791,59
594238733
471440.00
T915
11613.54
50.00
359.68
5977.90
6092.90
1718.00
161142
6120.9E
16.62L
1.00
6.64
81,20
56)92.00
5942393.00
471440.00
EM Cry
11828.01
90,14
359.64
5W7.88
6G82.6S
1)3247
1625.89
fi120.67
HS
7.00
6.64
81.34
56813.39
5942407.47
471439.98
11700.00
90,14
359.64
5977.71
6092.71
1804,44
1697.88
612041
HS
0.00
3.65
81.31
5681342
5942479.45
471439.86
11 BOO 00
90.14
359.64
SB77.47
6092.47
1IN 41
1797,88
6119.78
HS
0,00
669
al 34
56813A8
5942579. 4
411439.69
11900.00
90, 14
3 ,64
597722
6M.22
2004.38
1897.88
6119.1E
HS
CDO
666
8134
SU13.50
5942879.43
471439.52
120DO 00
SO.14
359.64
5976.98
6091.96
2104.35
1997.87
611852
HS
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667
81.34
53813.54
59477]9.42
471439.35
1210D.00
90.14
359.fi4
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6091.74
22N 32
2097.87
6117,89
HS
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6,68
81.34
56813.58
5942879.41
471439,18
Cry Ill 00
12192, 13
90.14
359,64
59]6.52
6091.52
2296A3
2190.00
8117.3'
:117.26
163.38R
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6.69
81.34
56813.62
5942971.53
471439.02
Tgte
12200.00
12206.80
90.06
90. DO
359.66
359.0
5976.50
5976.50
6091.50
6091, 50
2304.30
2310.M
219787
2204.47
6117.22
163.38R
166.89R
1 O
1.00
669
669
81.26
81.20
5fi802.M
56792.23
5942979.40
5942986.00
47143901
471439,00
End Cry
12220.99
89.87
359.74
5976.52
6091.52
2325.28
Me 85
6117.15
HS
1.D0
6.89
E1.06
56771.42
5943000.38
471438.99
12300.00
89.87
359.74
5976.70
6091,70
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2297,87
6116.79
HS
CDC
670
81.06
56771.45
5943]7939
471436.99
12400,00
89.87
359.74
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6091.93
2504.26
2397.87
611633
HS
0.00
B.l1
81,06
56771,50
5943179.38
471439.00
12500.00
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6092.16
2604.22
2497,87
6115,87
HS
0.00
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81.06
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5843279.37
4i 143900
12600.00
89.B1
359.74
5977.39
609239
2704.20
2597.86
611541
HS
0,00
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81,00
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5943379,36
471Q9.W
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89,87
359,74
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6092.62
2804.17
2697B6
6114.9E
HS
0.00
6,73
81.06
56771,63
5943479.35
471439,00
12WOOD
89.87
353.74
58]7.85
6092.85
2904.15
271711
6114.49
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0,00
6.74
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5943879.34
471439.00
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359.74
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6092.B8
2918.60
2812.32
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56771.68
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12827.67
90.00
359.74
5977,90
6092.SO
2931.81
2825.53
6114.36
D.1L
1.00
6.74
8120
56782.10
59Q607O0
471439.00
End Cry
12847.45
90.20
359,74
597787
6092.87
2951.58
M$5.31
6114C7
HS
1.D0
6.74
8139
56822. 10
5943826,78
471439.00
12900.00
W20
359,74
5977.6E
6092.68
3004.12
2897.86
6114.03
HS
0,00
6.70
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5943679.33
4)143900
1300O 00
90.20
359.74
5977.34
6092.34
3104.10
2997,88
511357
HS
0.00
675
81.39
56522.16
5943779.31
471439.00
131M 00
13200.00
90.20
90.20
369.74
359.74
3976,99
5976.6E
SOW 99
6091.65
3204,07
3304CS
3097.86
3197.86
611011
8112:15
HS
HS
0.00
000
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177
81.39
81,39
56821.20
56822.24
5943879.30
5943979.29
411439.00
47143930
13300.00
9020
359.74
5976,30
6091.30
3404.02
329785
6112.19
HS
000
6,77
81.39
56822.20
594407928
471439.00
13400.00
9CM
359.74
5975.96
6090.96
35040O
339785
6111.73
HS
COD
6.18
8139
5882 W
5944179.27
47143900
135DO 00
9CM
3 34
5975.61
6090.61
3603.97
3497.85
6111.27
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0.00
6.]9
81.39
56B22,36
5944279.26
471439.00
13600.00
90.20
359.74
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W90.27
3703.9E
3597.85
611011
HS
0.00
6.80
81.39
56822.3E
5944379,25
471439.10
Crvt/1W
13627.13
90.20
359.74
5975.17
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3731.48
3625.38
6110.M
HS
0.00
6.SO
81.39
86822,41
5944406.78
47143900
Tgta
13642.7E
30.3E
35974
5975.10
6090,10
3746,69
3fi40.60
6110.61
HS
1.00
680
81.55
56845.03
5944422.00
471439.D0
EM Cry
13W 45
90.50
359.74
5974,99
6089.99
3761.38
3655,29
611054
HS
1.1b
680
81.69
568654E
5944436.69
471439.00
137MM
SO. SO
359,74
5974.62
fi0�.81
3803.92
3697.84
611 D.35
HS
0.00
830
81.69
56866.50
5944479.24
471439 O
13800.00
SO. SO
174
5913:71
6066.76
3903.89
379784
6109.89
HS
000
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81.fi9
56863.53
5944579.22
471439.00
139DO 00
90,50
359.74
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6087.e9
4003.87
3897.64
610943
HS
COO
682
81.69
56066.57
59446)9.21
47143900
14000.00
90.50
359.74
5872.02
6087.02
4103.84
3997.83
6108.97
HS
0.00
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8169
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5944779.20
47143900
;411101
90.50
359.74
5971.15
6OB6.15
42M 81
4097.83
6108.51
HS
0.00
613
E1.69
56866.63
5944879.18
471439.00
Cry TOO
74118. 13
90.50
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5971:00
5086.00
4221.93
4115.95
6108.42
LS
0.00
6.83
81.69
56866.fi4
594489731
471439.00
TO
14130.82
SOX
359.74
597090
6085.90
42U 62
4128,65
6108.37
LS
1.00
6.83
81.57
56848.14
5944910.M
471439.D0
End Cry
141"31
9D.24
359.74
5970.83
6065.83
4248.11
4142,13
6108.30
HS
1.00
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81.43
56828.17
594492349
471439.D0
14200,00
90.24
359.74
5970.60
SOW SO
4303.)8
4197.82
610805
HS
0.00
684
81.43
56828.19
5NQ79.17
471439.00
14300.00
90.24
359.74
5970.19
6065.19
4403.78
429782
6107.59
HS
COO
685
81.43
56828.23
5945079,16
471Q 00
144O000
90.24
359.74
5969.78
6094.78
4503.73
4397.82
6107.13
HS
0.00
- 685
81.43
5682828
59451]9.15
4I1439.00
Cry 1/100
Tpt 10
14456.35
14479.86
90.24
90.00
359.74
339.74
SB69.55
5869.50
6084.SS
6084.50
4560.07
4583.5]
4454.18
4477.6E
810687
6106.76
LS
LS
000
1.00
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686
8143
E1.20
568Y8.29
56792.73
5945235.49
5945259,00
471439,00
471439.00
14500.00
89.80
359,74
596954
6084,54
4603.71
4497.82
6106.67
LS
1,00
6.88
E1.00
56761.51
5945279,14
471439.D0
EIM Cry
14513.54
Was
359.74
596960
60SCSO
4617.24
4511.3E
6106.60
HS
1.00
6.86
80.86
56740.14
59452M 67
01439.00
14600.00
89. E6
359.]4
5970.11
6095.11
47D3.68
4597.81
6106.21
HS
0.00
6.87
SO.86
56740.18
5945379,13
471439.00
14700.O'
89,66
359.74
597069
SCSI .69
4803.66
4697,81
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HS
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fie?
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5674022
5945479.12
471439.00
TD
14]34.89
89.66
359.74
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4732.70
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80.86
5674024
5945514.00
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6urvey ERor Madsl:
ISCN5A Rev 0 -3D
95.000%Canflden®
2.7955 pgme
fiurvey Ptognn:
decHp[bn
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MD From
MD To
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Act Ens
126
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218.480
9825
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SLB_M INCONLVFILLER
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1
1
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9092.518
9092.518
9132.000
A W.
11100. D00
9500
112fi
1,000
6.125
SLS MINDST"
SLB MWDSTD
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M_Q 1B (P9)
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3.125
4.500
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1
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10800CDO
1/100000
6,125
4.500
SLB_MVDrSAG
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2
928D 000
147U NO
1/100000
6.125
4.5M
SLB MVJD+GMAG
Mustang 18 (P9)
legal
N-1pgon:
Northi
EAetlnp (%)
SUrlece: 2426.1
FSL 1666.6
FEL 32 T10N WE UM
IP
5•i0
�5 1
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5939902.530
5945514.000
41349.630
471439.000
B:hIum64r Pdv4te
vivt Schlumberger
Brooks Range Petroleum
Borehole:
Well:
Field:
Structure:
Mustang 1B
Mustang 1
SMU Mustang
Mustang Pad
& Magnetic Parantetera
Surfaae Location NAD27 Alaska State Plane, Zone 04, US Feet
Miscellaneous
IGravity
Model: BGGM 2018 Dip: 80.78° Date: 31-0et-2018
Lat N 7014 57.47 Northing: 5940809.83ftUS Grid Conv: .0.2838°
Slot: Mustang 1 (1) TVD Ref: Rotary TabIN115ft above Mean Sea Level)
ity w MagDec: 16.895° FS: 57418.166nT GravFS: 1001.995mgn (9.80(tO Bad)
Lon: W 15016 48.86 Easting: 465312.31ftUS Scale Fact: 0.99990137
Plan: Mustang 1B (P9)
-2000 -1000 0 1000 2000 3000 4000 5000 6000
0
0
1000
1000
2000
-
2000
QQ�
X
3000
3000
u
4
4000
4000
suo elu m�e No .m rvo ilels
irvn Ilene Dena ivp I°t�l rvo
MD 'Id
5000"m°e"^'
c.
a I ry M
ry uoami rvo I�.w Ye aaemm
"Ica Ilda i om. , Mo aanivo
5000
Td e'Y
eaairvD I
M6
_ Mustang 18 (P9)
6000
.._._.._.._•_-___.._._.._._._._.._..___...._.._._..___.._._._...._...__..—.—
._._..__..._._.._.._.___ _...._.._..__..___-__.._.._ �-_.__._._._.._._._...........
s000
Mustang 1 Mustang 1APB1
-2000 -1000 0 1000 2000 3000 4000 5000 6000
Vertical Section (ft) A21m - 1,00' Scale a 1:1200.00(ft) Origin = ON/-S, OE/-W
Schlumherger,
Brooks Range Petroleum
Borehole:
Well:
Field:
Structure:
Mustang 1B
Mustang 1
SMU Mustang
Mustang Pad
Gravity S Magnetic Parameters
Su ace Location NA027 Alaska State Plane, Zone 04, US Feat
Miscellaneous
Model: BGGM 2016 Dip: 80.78° Date: 31-0ot-2018
Let: N 7014 57.47 Northing: 5940809.93kUS Grid Cmn•: -0.2838°
Slot Mustang 1 (1) TVD Ref:
Rotary Table1115h above Mean Sea Leven
MegDee: 18.895° FS: 57418.156nT Gravity FS: 1001.991 an(9.80685 Based)
Lon: W15018 {8.88 Fasting: 485312.31kU5 Scale Feet: 0.99990137
Plan: Mustang 1B(P9)
-500 0 500
1000 1500 2000 2500 3000 3500
4000 4500
5000
a gaacn e
i ei.aa m rvo
5000
wD
M.
a .ova o as are o,.
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8000
.......
Mustang 1APB1
Mustang 1B (Pg)
6500
Mustang 1
6500
-500 0 500
1000 1500 2000 2500 3000 3500
4000 4500
Vertical Section (ft) Azirn = 1.00° Scale = 1:850.00(ft) Origin = ON/-S, OE/-W
Borehole:
Well:
Field:
Structure:
Mustang 16
Mustang 1
SMU Mustang
Mustang Pad
Gravity & Mapnetic Peremefers
Surrace Location NAD27 Alaska State Plane, Zone O4, US Feet
Miscellaneous
Model; BGGM 2018 DID: 80.78° Date: 31-0ct-2018
1-at:; N 70 14 57.47 Northing: 3 40809.99RU Grid Conv: -0.2638°
Slot: Mustang 1 (U ND Ref: Rotary Table(115ft above Mean Sea Level)
MapDx: 76.695° FS: 3/418.156n7 GravityFS: 1001.995mgn (9.808658asetl)
Lon: W 15016 48.66 Eaatln8: 465312.31RUS Scale Feet: 0.99990137
Plan: Mustang iB (P9)
Schiumherger,
Brooks Range Petroleum
0 1000 2000 3000 4000 5000 6000
5000 Mustang 1 B (P9)
5000
D
N 14735 MD 6086 ND
Entl,�
W14 MO 6085I1��
Tot
14480 MD 6X5 W
CZ
144M MO"
EM Cry
14144 MO 6066 ND
Tar 1
4000 14131 MO 6086 ND
Cry 1l1 w4000
14118 MO 90'6 NDEnd Cry
1356090 ND
Tot'
13643 MND
1I100
13828 0 TVO
d Cry
12847 MTVO
3000
Tg 7 3000
12828 MND
1Hop
12814 3 TVD
o Cry
12221 MNDT..12207 92 ND
Cry Woo
12192 MD 8092 TVD
0 2000 Enacry 2000
11628 MD 6093 ND
CD
O T,1 5
O
11814 MD 6093 TVD
Cry 1H00.
0 11908 MO 6093 ND EnO Cry
U 11231 MO 6093 ND
[n Tp14
11237 MD 8093 ND
Cry 1l1
N 11201 MD 8093 ND
Z 1000
Ewo 10QQ
10T79 MD 6096 ND
Tot 3
10743 MO WM ND
Cry 1/100
10]42 MO Was ND
EnE Cry
IM11 MD6096ND
Tgt2
t0212 MD 60861YD
Cry vino
10197 MO 6095 ND
Q End Cry 0
..Mo.
8]B MD 8we ND
Crv41100
9615 MO6104 ND
Cry 2w10o
9133 MO W63 ND -
90°
7^ D6139ND M tang 1APB1
9 ye„ 9124 MO 6058 ND
$083 MO 2462 ND TiW Survey
9093 MD 8038 TVD
M stang 1
-1000
-1000
G
eA-+
-2000 -2000
0 1000 2000 3000 4000 5000 6000
EW (ft) Scale = 1: 1 000.00(ft)
4500
3000
0
0
1500
qN
U
N
v
2
0
-1500
Brooks Range Petroleum
-1500 0 1500 3000 4500 6000 750C
SMU M-02 Mustang 1B (P9)
a 6Tvo
-- - } SMU M-02PB1
True %,146 s sTVc
Grid ar
Meg
True NoAh '� � �a
Tot Corr(M-,T 1B.B95°)-------- - 'Lo
Meg Dec(18.895°) s� �o
Grid Cony (-0.2U') 20 3 T10
�y 'Lo srvD
�O
A o B1 3—
�O
8 3N0
ma
North Tern 1A
s
rvD
North Tarn 1 �oosry g n
12 1n
6 q,� 6405 TV0 s gRN ¢ Mustang 1APB1
Mustang 1
5e05 ND � S
,. SMU M-03
eoas ND
ND
-iFnn n 'IFnn 'loon dann anon Bann
EW (ft) Scale = 1:1310.00(ft)
3000
1500
0
-1500
Mustang 1A (P9) Proposal EOU Report
(DO Plan)
..
pbmmr 1,N B-1 I
Burvry omputatkn:
Minimum Curvabrol u in.ki
Client:
ndd:
Brpob '.'N,P Wm C00cratlon
SMU M_m
Vartkal S..ion A—-
Vankel B.diw Onain:
1.- (True N..)
OOOOR co.I
Slructuro/BIM
Au PadlMu MI(ln
TVD Re.n..Dabm:
Retry TOW
W.Io
B..hel.:
M-M1
m mm lAVl
TVD RN.nrce 1111.6 n:
_nd Ebatllon:
115 WO Rad.a Maan Sae L-1
7a1W It— Maan SN L-I
AP*
SDIM 065201
Ma Ik Dwlimtkn:
16.M5'
Wrvry Nam.:
WrvryO..:
Y-W IA(P91
A4.11, 2pIS
T 1Oraviry Riep 6t,nath:
O-W Mc0.l:
10010B5dmgn(I _SS ON.)
-
TonIAND 10011SAORaft 2.1.9N'11 lasaeo6 ft1631a 1104E
1.a1 Id n.ie Pia. Blr.,Wh:
5711SIN nT
owneinat.R 11m. SyabM:
bamicn Lat l bng:
NA,cr AM.M all Pbm, l,U. US FI.
N TO- 14' S1470BT, IN1%' 16 4. 88N2'
Magmtk Dip Angl.:
Deallnalkn Dab:
Si
0.Y0Ber31, 41.
Lami.n Ond NA1 YIY:
N 50408099N WS, E 48%12.310 WS
maii-k Ozrimtion NiSGOM
201E
CRB Ond Co q; me AngM:
Old Beal. Fact.:
-0.2834
OB9B9013>
Nonh Reb N:
One evnaalgarce ua.d:
True N..
o,0900'
W.I.1 PMah:
2A.,564.
1 C.r Mag 44 1'.. Nadh: 156817'
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SMU Mustang\Mustang PadlMustang 1\Mustang 1A v2\Mustang to (P9)
Dnumg Office 2.10.544.0 Schlumberger-Private 10117/2018 3:54 PM Page l of 3
Commems MD
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SMU Mustang\Mustang Pad\Mustang 11Mustang to v2\Mustang 1A (P9)
ommng Office 2,10.544.0 Schlumberger-Private 10/17/2018 3:54 PM Page 3 of 3
Mustang 1A (P9) Anti -Collision Summary Report
Analysis Date-24hr Time: September 21, 2018-10:29
Analysis Method:
Normal Plane
Client:
Brooks Range Petroleum Corporation
Reference Trajectory:
Mustang I (P9) (Def Plan)
Field:
SMU Mustang
Depth Interval:
Every 10.00 Measured Depth (ft)
Structure:
Mustang Ped
Rule Set:
D&M AntiCollislon Standard S002 v5.115.2
Slot:
Mustang 1 (1)
Min Pt.:
All local minima Indicated.
Well:
Mustang 1
Version I Patch:
2.10.5".0
Borehole:
Mustang 1A v2
Database I Project:
Iocalhostklrilling-North Slope West
Scan MD Range:
9092.52fl-14734.SN
ISCWSA03-D 95.000%Confidence 2.7955 sigma, forsubject
well. For
Traiectory Error Model:
offset wells, error model version is speclfled with
each well
respectively,
Offset Selection Criteria
Offset Trajectories Summary
Wellhead distance scan:
Not perfonnedl
Selection filters:
Detnitive Surveys - Definitive
Plans - Definitive surveys exclude deflnitive plan
-AII Non-Def Surveys when no Def-Survey is set
in a borehole - All Non-Def Plans
when no Def-Plan is set in a boreho
Offset Trajectory
separation
Allow
Sept..
Controlling
RaPotence Trajectory
Risk Level
Alert
Status
Ct-Ct fl MAS ft
EOU it
Oev, ft
IFRule
MD ft
TVD(fit)
Alert
Minor major
Mustang to (Def Survey)
Fail Meer
0.00 475.23
-317.15-475.23
0.00
06F7.50
8092.52
6038.26 OSF<5,00
G6F<7.50 OSF<1 .00
Enter Major
0.00 234.02
-156.34 234.01
-O.D1
OSF1.50
9098.3D
6040.66
MinPbO-SF
5.80 151.8
-95,
-146.06
0.05
OSF1.50
9276.32
612T86
MINPTOEOU
6.33 152.56
79571
14623
0.05
OSF1.50
9288.34
6130.28
MInPt-O-ADP
1903.168,77
-93.81
-149.74
016
O8F1.50
9531.71
6116.70 OSF>5.00
OSF>1.50 OSF>1.00
Exit Major
869256 31.12
8671.49 8661.45
432.66
OSF1.50
9360.66
6139.03
Ming-"F
3242.74 84.50
3179.42 3148.24
52.0
OSF1.50
9415.43
6134.89
MinPts
8342,75 4927
83D9.58 8293.48
259.13
08FL50
9976.26
60a8.84
TD
Mustang 1 (Daf Surrey)
Fell Major
0.00 473.95
-316.30 -47 Z
0.00
OSF1.50
9092.52
0038.26 OSF<5.00
OSF<1.50 0SF0.00
Enter Major
0.00 301.05
-201.D3 _301.05
0.00
O8F1.50
9124.20
6058.23
MinPts
0.01 336,54
-224,02-335,53
0.00
OSF1.50
9134.20
6064.45
MmPts
59.80 223.49
-89.52-163.69
0.40
OSF1,50
9305.56
6134.12 OSF>5.00
OSF>1,50 0SF>1.00
Exit Major
B673.84 31.05
6652,81 8642.79
432.71
OSF1.50
9360.66
6139.03
MInPtO8F
3244.75 94,
3187.5 3150.41
52.12
08F1.50
9416.02
6134,80
MinPts
834431 4927
8311,13 8295.04
25921
OSF1.50
9976.26
6088.94
TD
SMU M-02 (Def Survey)
pass
5254.40 216,34 5109.85 5038.06
36.59
OBF1.50
9092.52
6038.26
MmPts
8119.53 32,81
8099,37 8086,72
423.29
MAS=iom(m)
9357.48
6138.99
MInPt-(}SF
842027 32,81
839B.30 8387.46
421.1
MA6= 10.00 (m)
9358.61
6138.02
MinP[OSF
8635.41 32,81
8614.51 8802.60
433.44
MPS=10.00 (m)
9359.80
6139.02
MInPt08F
7711,01 55.72
7673,53 7W5.29
21130
OSF1.50
10195.20
6094,67
MinPt-Ctct
7711.01 55.
7673.35 7855.01
21024
08F1 SO
10200.69
6094.81
Mirpts
6804.77 76.
8753.20 6727.90
134.50
OSF1.50
10794.96
6095,49
Mirpts
1741.73 192.94
1612.78 1548.79
13.60
OSF1.50
14W6.21
6084.91
mirpts
SMU M-02PBI (Def Survey)
Pass
5254.40 216,3411
5109,8511 5038,0611
36.
0SF1.50
9082.52
6038,26
Min Pts
SMU MustanglMustang Pad\Mustang 1\Mustang 1Av2\Mustang 1A(P9)
Drilling Office 2,10.544.0 . SchIumberger-Private Page 1 of 2
Offset Trajectory
Ct--t (fit)
Se aration
MAS ft
EOU ft
Allow
Dell. ft
Sep.
Fact.
Controlling
Rule
Reference
Tra eeto
Risk Level
Alert
Statue
MD ft ND ft
Alert Minor
Major
8119.53
32.a1
8089.3,
8086.72
423.29
MAS =10.00(m)
9357.48
6138.99
MinR-0-SF
UZ27
32.81
8399.30
8387.46
421.1
MAS =10.00(m)
8359.61
6139.02
Ming-OSF
863541
32.81
8614.51
8602.6.
433.44
MAS =10.00(m)
9359,80
6139.02
MinR-0-SF
771101
55.72
7673.53
7655.29
211.30
OSF7.50
10195.20
6094.67
MInPt-CtCt
7711.01
55.99 7673.35 7655.01 210.24
OSF1.50
10200.69
6094.81
Minks
6604.77
76,
8753.211
672790
13d50
OSF1.50
1171:1
1 5.41
MlnPts
1906.27
200.89
1772.01
1705.38
14.30
OBF1.50
1435711
6084.96
MinPts
SMU M-03 (Def Survey)
Pan
481000
87.60 4751.21 4722.40
94238
6134.11
Min Rs
8532.22
32.8
578499,41
MAS 1000(m)
9358.67
6139.01
MInPt-"F
8587.34
32.81
856655
855454
fl8�5,07
MAS=100(m)
8358.71
61390
MingOSF
7148.02
589
.1
7089.11
OSF1.50
10172.94
6094.09
Minns
North Tam 1A (De/ Survey)
Pass
8733 67
32,111
8712.351
8700.861
MAS = 10.00 (m)
9362 36
6139.04
Min Rs
6504.98
97.88
6439.40
8407.10
t00.6B
08F1.50
8385.31
6138,28
Ming.CtCt
a386.99
46.99
835d.00
a338.00
262.02
OBF1.50
9942.14
6086.05
TD
6495.31
104.04
6425.62
6391.27
94.52
OSF1.50
9859.62
6086.02
Ming-ctct
North Tam 1 (Dot Survey)
Pass
6733.87
32.81
8772.35
6700.86
429.
MAS =10.00(m)
9362.36
6139.04
MinPls
6860.28
83.94
6804.00
6776.35
12403
OSF1.50
9410.11
6135.68
Ming-CtCt
6860.45
84.48 6803.80 6775.97 123.23
OSF1.50
9410.88
6135.57
MINPTOEOU
6860.78
84.89
6803.86
6775.89
122.63
OSF1.50
9411,47
6135.49
Ming-O-ADP
6866.45
87.19
6807.99
8779.25
719.46
OSF150
94111
1134.70
MinROSF
6859,94
86.65
6801.84
6773.22
120.11
OSF1.50
9481.79
6124.51
Ming-O-ADP
6859.91
89.92
8807.a4
fi773.29
120.14
0SF7.50
9484.48
6124.09
MINPTOEOU
8859.91
86.60
6801.85
6773.31
120.17
09F1.50
9486.51
6123.77
MinPt-=t
8386.99
48.99
8354.00
8338.00
262.02
OSF1.50
9942.14
6088,06
TD
SMU Mustang\Mustang PaMMustang 1\Mustang 1A v2\Mustang 1A (P9)
Drilling office 2.10.544.0 Schlumberger-Private Page 2 of 2
Traveling Cylinder Prot
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2
280
270
260
North
350 0 10
190 180 170
Well Ticks Type:
MD on Mustang 1 B (139)
Calculation Method:
Normal Plane
Ring Interval
10.00 ft
Azimuth Interval:
10.00 deg
Start Depth:
9100.00 ft
End Depth:
14734.89 ft
Offset Well Count:
7
TRAVELING CYLINDER PLOT
Client
Corporation
Field
SMU Mustang
Structure
Mustang Pad
Well
Mustang 1
Borehole
Mustang 1Bv2
Date
21-Aug-2018
80
90
100
Traveling Cylinder Plot
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2
280
270
260
North
350 0 10
190 180 170
Well Ticks Type:
MD on Mustang 1 B (P9)
Calculation Method:
Normal Plane
Ring Interval
5.00 ft
Azimuth Interval:
10.00 deg
Start Depth:
9100.00 ft
End Depth:
114734.89 ft
Offset Well Count;
17
TRAVELING CYLINDER PLOT
Client
Field
SMU Mustang
Structure
Mustang Pad
Well
Mustang 1
Borehole
Mustang 1 B v2
Date
21-Aug-2018
80
90
100
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Attachment 4 Drilling Hazards Summary
Pore Pressure Uncertaint
Risk: High --
Description: Estimated pore pressure based on North Tarn 1A well test, North Tarn 1 SIDPP, and
upcoming CPAI offset wells is a 10.8 ppg EMW. Potential for reservoir overpressure up to 12.2 ppg EMW
has been encountered in offset wells.
0
Mitigation: Managed Pressure Drilling (MPD) will be used to monitor pore pressure in order to
accurately determine the Kuparuk C reservoir pressure. MPD will also be used to hold surface
backpressure to keep bottomhole pressure at or above reservoir pressure at all times. In the event high
reservoir pressure (11.3 ppg - 12.2 ppg) EMW is encountered, the NaBr killweight fluid that will be on
location can be used as a base to build a suitable drilling fluid prior to drilling ahead. i
Shale Instabilit
Risk: Medium
Description: Mechanical instability in the exposed Kalubik beneath the 7" casing shoe can cause
significant packoff issues while tripping out of the hole with the drilling BHA and while running larger OD
completion jewelry into the hole.
Mitigation: An inhibited mud and managed pressure drilling will be utilized to control shale instability.
6% KCI and minimum 2% KLA-SHIELD will be run in the production drilling fluid at all times. Managed
pressure drilling will be utilized to maintain a constant bottomhole pressure across the exposed shales
by trapping pressure equal to drilling ECD at the shoe, while maintaining a static wellbore pressure
above reservoir pressure, in order to reduce pressure cycles and the resulting mechanical fatigue on the
shales.
Lost Returns
Risk: Medium
Description: Partial or complete loss of returns while drilling due to circulating pressure above reservoir
pressure or fracture gradient as well as potential losses due to fault crossings.
Mitigation: MPD with a Coriolis meter will be used during well operations to keep circulating pressures
low by reducing static mud weight and allowing real time, precise measurement of flow out to spot
losses as soon as they occur. No significant fault crossings are expected on this lateral. Should losses
occur, the below LCM decision tree has been prepared.
Seepage losses < 10 bbl(hr
Add SAFE -CARS 250 to
active at 2-5 ppb.
Spot pill (30-40 bbls):
SAFE -CA" 40 5 ppb
SATE -CARS 500 5 ppb
Differential Sticking
Risk: Low
Attachment 4 Drilling Hazards Summary
I Losing fluid while drilling I
Measure fate of loss
I Partial losses 10-100 bbllw 1
I N. :-- I
Spot pill (3040 bbls):
SAFE -GARB 40 10 ppb
SAFE -C A" 250 20 ppb
SAFE -GARB 500 5 ppb
SAFE-CaRB 750 5 ppb
Note — Thin fluid back
slightly if possible with
6% KCI brine.
1 Total loss of returns
Squeeze pill:
FOR\1-A-BLOK
Ne :+ :: 40 ppb in 3 % KC brine
H-77:7
weighted up to
desired density.
Note — Pill should be a minimum
of 1.5 i nes the length of thief
zone
Coulact project engineer prior
for approval
Spot plug:
Gunk Squeeze or Cement
Plug
Description: Stuck pipe due to drilling fluid overbalance in a permeable sand zone.
Mitigation: Pipe movement through rotation and reciprocation at all possible times will significantly
reduce the risk of differential sticking. The use of a statically underbalanced mud system with MPD
further reduces the risk of differential sticking by removing the pressure differential that causes stuck
pipe. Finally, minimal wellbore bridging material is being used in the production mud system which
should lead to thinner wall cake thickness and reduced risk of differential sticking.
Attachment 5 Formation Integrity and Leak Off Test Procedure
Previous 7" casing shoe FIT work:
Well:
Mustang #1
Mustang #1A ST
Date:
2/17/12
5/15/15
Mud Weight:
12.8 ppg
12.3 ppg
TVD:
6044'
6051'
Pressure:
1134 psi
1100 psi
FIT:
16.4 ppg LOT
15.8 ppg FIT
Attachment 6 Drilling Fluids Program
PROPERTIES AND
SPECIFICATIONS
PRODUCTION
Hole Size
6.125"
From MD
9,124
To MD
14,738
Length of Section
5, 614'
Hole Angle
51 - 90099°Sum
Mud System
FLO-PRO NT
Mud Weight - ppg
10.1
Plastic Viscosity - cP
ALAP
Yield Point - Ib.1100ft2
13-25
LSYP - WIMP
4-7
Gel Strengths 10s/10m
6-10/8-15
API Fluid Loss - cc/30 min
<6
Modified HTHP Fluid Loss - =130min@a 160°F
<10
H
9.0 -10.5
Chlorides - m /L
100k -160k
Hardness as Ca++ - inglE
<100
Sand Content
<0.25%
MB T - lbJbbL
<3
Drill Solids - % Vol
<3
Attachment 7 Drilling Procedure
Brooks Range Mustang 1A Side Track Operations Procedure
Pre -Rig Work
1) Install wellhead shelter for pre -rig work.
2) Function test and pressure test Vetco Gray wellhead and tree.
3) Pressure test and chart 7" casing to 250 psi low / 3500 psi high for 15 mins using
Little Red Services.
4) Secure well with backpressure valve in the tubing hanger.
5) Grade and prep pad for Doyon 25.
6) Remove wellhead shelter prior to Doyon 25 spotting over well.
Rig Operations
1) MIRU Doyon 25,
2) Pressure test and chart 7" casing to 250 psi low / 3500 psi high for 15 mins.
3) Pull Vetco Gray tree.
4) Rig up BOPE.
5) Pull BPV and install two-way check valve in tubing hanger.
6) Test BOPE and choke manifold to 4,000 psi, annular to ,3 300 psi.
7) Pull two-way check valve.
8) Circulate out freeze protect through kill string at 1,415' MD with fresh water or
seawater.
Po -1 , 9) Unseat tubing hanger and pull kill string.
L4_'J� 10)Pick up and rack back sufficient 4" DP to TD the well.
1 1)PU and RI H with drill out BHA. Lo/ so
12)RIH on 4" DP to 3500' MD.
13)Perform MPD bearing installation and connection ramp training with crews.
NOTE: Managed Pressure drilling will be utilized for drilling this sidetrack. See
the below Managed Pressure Drilling Procedures & Guidelines for detailed
information.
14)RIH on 4" DP to-8,903' MD and tag cement above top of EZSV.
15)Circulate out the 9.8 ppg completion brine, replacing with 10.1 ppg Flopro NT
system.
16)Drill out cement to the top of the EZSV at 9,020' MD.
Attachment 7 Drilling Procedure
17)Begin drilling out EZSV, drilling in 1' increments, shutting down to check for
reservoir pressure after each increment.
NOTE- The base plan for the initial clean -out of this well from just below the 7"
EZSV to the top of the Kuparuk C sand will be to shut down at various points in
the clean -out to confirm the actual pore pressure of the C-sand, assuming the
well will be in an under -balanced condition with the planned 10.1 ppg mud in the
well and over -balanced when circulating ECD's are in place. After confirming the
actual pore pressure of the well, the mud weight will be increased or reduced to
target a requirement for -300 psi backpressure during static well operations.
18)Continue to drill out cement to the 7" shoe at 9,117' MD.
19)Circulate 2x BU and shut in to check for wellbore pressure.
20)RIH with pumps on, attempting to stay in old wellbore. If cement or fill is
encountered, PU 5' then drill through cement or fill until WOB disappears, then
attempt to continue to wash in the hole.
21)RIH / clean out well to current TD and drill to the Kuparuk C sand target (-6907'
TVD).
a. If unable to stay in the old wellbore execute an open -hole sidetrack and
drill ahead per directional plan 9.
o b. If significant wellbore issues or shale stability problems are encountered in
the open hole below the 7" shoe, a contingency sidetrack from the 7"
f` casing will be considered (to be detailed in a separate procedure).
22)Circulate 2x BU. �---� �- r
f
23)Shut down and monitor wellbore pressure. /q "e"aj
24) Pump out of the hole with drill out BHA to 7" shoe, racking back 4" DP.
25)Swap 7" casing to kill weight brine. `'�
26)Strip out of the hole, utilizing MPD to hold backpressure to offset swab, to the
first drill collar.
27)Pull MPD bearing and element, POOH and lay down BHA.
28)MU geosteering BHA and RIH.
29)lnstall MPD bearing and element.
30)RIH on 4" DP to 7" shoe.
31)Swap 7" casing to Flopro NT mud system, weighted to allow 300 psi
backpressure with MPD during connections based on highest seen reservoir
pressure.
32)RIH to TD.
33)Begin drilling ahead per directional plan 9.
a. Utilize MPD to maintain constant bottom hole pressure on the exposed
shales.
Attachment 7 Drilling Procedure
b. Utilize ECD while pumping and MPD on connections to keep wellbore
pressure at or above reservoir pressure.
34)Drill to TD at-14,739' MD.
35)Circulate 3x BU at TD at full drilling rate, pulling 1 stand per BU.
36)Backream out of the hole to the 7" shoe.
a. Perform a wiper trip if hole conditions require.
37)Once the bit is in the 7" shoe, circulate 1 x BU with Flopro NT, then swap the
casing to kill weight brine.
38)Strip out of the hole, hold MPD backpressure to offset swab, until the last stand
of drill pipe. Continue to rack back 4" drill pipe.
39)Pull the MPD bearing and element on the last stand of drill pipe.
40)POOH and lay down the geosteering BHA.
41)Rig up casing running equipment.
42)Begin making up and RIH with 4-1/2". Iin-er completion per completion tally
a. Liner completion will have float equipment in the shoe to allow MPD
operations.
43)Make up liner top hanger & packer and running tool.
44)Cross over to 4" DP.
45)RIH with 4" DP to the 7" shoe.
46)lnstall MPD bearing and element.
47)Swap 7" casing to Flopro NT. 00.
48)RIH with liner to TD.
a. Hold backpressure with MPD to stay above reservoir pressure, and
minimize pressure cycles on the shale due to surge while running in the
hole.
49)Circulate 1x BU with liner at TD.
50)Set liner top hanger and packer. (et"-,Oe kd-()
51)Pressure test liner top packer to 3,500 psi.
52)Perform negative test on liner top packer and liner body.
a. Since the static mud weight will be underbalanced, shut in the chokes with
no trapped pressure and monitor for pressure buildup.
53)Swap the 7" casing to kill weight brine.
54)POOH, laying down drill pipe.
55)RU to run 4-1/2" upper completion.
�-b� 56)RIH with upper completion to the liner top.
Attachment 7 Drilling Procedure
57)Space out upper completion, and pick up 5' out of liner top.
58)Circulate well to completion fluid, with inhibited fluid from the liner top to the
lowest gas lift mandrel. Ensure wellbore is surface to surface with clean fluids.
59)Pick up and land tubing hanger.
60) Drop ball and rod.
61)Set tubing production packer. _
62)Pressure test tubing from the back side to 3,50_psi. 1 IT- 7-/ LM
63)Shear SOV in upper gas lift mandrel and circulate freeze protect.
64)Allow freeze protect to U-tube in tubing and annulus.
65)Set BPV in tubing hanger and test from below.
66)RD BOPE.
67) RU production tree.
68)Pull BPV and set two-way check.
69)Test tree against two-way check.
70)Pull two-way check, install BPV.
71) RDMO rig.
Post-Riq Work
1) Install wellhouse.
2) Pull BPV.
3) Rig up slickline.
4) Pull shear valve from upper GLM and install valves as required.
5) Pull ball and rod.
6) RDMO slickline.
7) Rig up workover coil.
8) RIH with coil and shift frac sleeves open.
9) Displace tubing if necessary to start production.
10)RDMO coil.
11)Put well on production.
-c VC- C- Y-,
lie
y l!
/I- ff_76 _./Y
Attachment 7 Drilling Procedure
Managed Pressure Drilling Procedures & Guidelines
As a Managed Pressure Drilling system (MPD) will be used to drill this well, please note
the following comments as they apply to the application of this technology as it relates
to this rotary sidetrack:
• MPD employs the use of a rotating head positioned above the rig's annular
preventer to seal around the drill string and a series of valves and chokes to
allow the operator to hold back -pressure on a well so that. the well can be safely
and efficiently drilled using an effective mud weight density below that of the pore
pressure of the well, as in the case of this well:
o Anticipated Pore Pressure: 10.8 ppg (3358 psi)
o Anticipated Mud Weight: 10.1 ppg (3140 psi)
o Modeled ECD at the Shoe: 11.3 ppg (3513 psi)
■ Modeled ECD at the shoe will be sufficient for the well to be
overbalanced with pumps on at drilling rate (-250 gpm)
o MPD Backpressure during Pumps Off: -375 psi
• Static mud weight plus backpressure gives a total static pressure
on the wellbore of -3,515 psi, sufficient to overbalance the well.
■ Ramp schedules will be created using hydraulics modeling software
and checked against downhole PWD data to allow the well to stay
overbalanced during the transition from drilling rate to pumps off.
■ The MPD system can be utilized to apply `mud weight on demand'
via surface pressures up to 700 psi (half the rated surface pressure
of the equipment, as an additional safety factor), equaling a static
mud weight of 12.3+ ppg (3,840 psi). This allows mud weights to be
increased prior to a well control event occurring.
• Use of the MPD system and the attached Coriolis meter will allow identification
and mitigation of wellbore breathing, brought on by the additional pressure
exerted on the wellbore by ECD.
o Precise pore pressure determinations can be made utilizing the MPD
system to improve the safety and efficiency of future development
operations.
• Additionally, use of the MPD system will reduce pressure cycles on the exposed
shale, mitigating the risk of mechanical breakdown of the shale and the hole
problems that follow.
• A kill weight brine, with adequate overbalance, will be used to displace the 7"
casing prior to surface trips.
Attachment 7 Drilling Procedure
e-balance System Diagram !!!-
K� - ConocoPhillips, Alaska jaw
WwKfbww G i
I —K Pow. _....
Spn TvrcfC
I 4�FtM
MI Swaco e-balance System Diagram
"Note: This is the same system currently being utilized by ConocoPhillips Alaska in the Kuparuk and Alpine Fields
Attachment 7 Drilling Procedure
Down 25 MPD System Rig Up Diagram
2" line manifolded to
0
the rig pumps allows
fluid to be pumped over
the top of the well while
Drilling fluid Is returned
stripping out of the hole
to pit system via 4"
or to compensate for
outlet line tied into flow
pressure bleed off /
line.
fluid losses downhole.
Flow
Box
Flow Line to shakers
Bearing assembly&
element seal in RCD and
around drill pipe to
direct flow down the 4'
line.
Choke controls
Rig Pumps 2' Un-
�
Annular
4" Une
1 1 1 1 1 I
backpressure on
wellbore.
pressure transducers )2
on the RCD and 1 on the
wellhead) monitor
system backpressure
Gut line allows chokes
to be bypassed if
necessary.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp ❑
Drill ❑ ❑
1 c. Specify if well is proposed for:
Lateral Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone 0
Redrill ❑ Reentry ❑
Coalbed Gas ❑ Gas Hydrates ❑
Exploratory - Oil ❑ Development -Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name: 5. Bond: Blanket 0 Single Well ❑
Brooks Range Petroleum Corporation
11. Well Name and Number:-,q�/a
Bond No. LPM 8842179
3. Address:
Mustang 1A GIl2=
6. Proposed Depth:
510 L St. Suite 601, Anchorage Alaska 99501 MD: 14,735' TVD: 6086,
12. Field/Pool(s):
il
Southern Mif6veach Unit
6...Nliluveach
4a. Location of Well (Governmental Section):
Surface:
7. Property Designation:
2426 FSL 1667 FEL S2 T10N R7E UM
ADL 390680, 390691
KupaF6k River Oil - 764150/ ;2
/
Top of Productive Horizon:
8. DNR Approval Number:
13. App ximate Spud Date:
2694 FSL 819 FEL 1 T1ON R7E UM
Total Depth:
Land Use Permit: LAS 27505
1/1pud
/2019
9. Acres in Property:
1A. Distance to Nearest Property:
1876 FSL 837 FEL 36 T11N R7E UM
5120
837'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 115 15. Distance to Nearest Well Open
Surface: x- 465312.31 y- 5940809.93 Zone- 4
GL / BF Elevation above MSL (ft): 75.1 to Same Pool: 174'1' SMU M-02
16. Deviated wells: Kickoff depth: 9,124 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 99 degrees
Downhole: 3,423 psig Surface: 2,816 psig
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)
6-1/8" 4-1/2" 12.6 L-80 Hydril563 5,752'
8,96T 9 '� 14,739' 6086' None
19. PRESENT WELL CONDITION SUMMARY (To be ompleted fer Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measure
epth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
80,
20"
-140 ft'Arctic Grade
108,
108'
Surface
3,040'
9 -1/ IV
460 bbls Lead / 46.2 bbls Tail
3,069'
2,448'
Intermediate
9,081,
.
47"
67 bbls
9,110'
6,044'
Production
Liner
/
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes Q , p ❑
20. Attachments: Property Plat ❑ BQ7) Sketch ❑
iivper Sketch
Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Seabed Report ❑ Drilling Fluid Program ❑
❑
20 AAC 25,050 requirements
21. Verbal Approval: Commission Representat'de:
Date
22 1 hereby certify that the foregoing is try6 and the procedure approved herein will not be
deviated from without prior written appTGal
a, vruD Contact
Authorized Name: LAauKFN J-, vE"
Name:
r- Contact Email: LVE71/D ?PC k.4F
Authorized Title: Al -a 4T_ doe- oQ A -17 oA Ae -SD'6 5y/j0C'4.r'e ,0/2QJVZ'rJ Contact Phone: q
Authorized Signature:
Date:
Commission Use only
Permit to Drill
PI Number:
Permit Approval
See cover letter for other
Number:
50-
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:
Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No ❑
H2S measures: Yes ❑ No ❑ Directional svy req'd: Yes ❑ No ❑
Spacing exception req'd: Yes ❑ No ❑ Inclination -only svy req'd: Yes ❑ No ❑
Post initial injection MIT req'd: Yes ❑ No ❑
APPROVED BY
by: COMMISSIONER THE COMMISSION Date:
Form 10-401 Revised 5/2017 This permit is valid forOs nt r(3tt L4 T tval er 20 AAC 25.005 Submit Form and
I\v' HPL p (g) Attachments in Duplicate
/^1000*N�
Brooks Range Petroleum
510 L St #601, Anchorage, AK 9950
Lawrence Vendl
Phone (907) 865-5811
Email: LVendl@brpcak.com
October 10, 2018
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Application for Permit to Drill Horizontal Production Well Mustang 1A
Dear Commissioners,
Brooks Range Petroleum Corp. hereby applies for a Permit to Drill for the onshore horizontal
production well SMU Mustang 1A. This well will be drilled and completed using Doyon Rig 25. The
planned spud date could be as early as 01/01/2019. --
Brooks Range Petroleum Corp. would like to request a 14 day BOP test schedule at the AOGCC's
discretion.
Please find attached for the review of the Commission forms 10-401 and the information required by
20 ACC 25.005 for this well bore.
If you have any questions or require further information, please contact Joseph Longo at 907-947-
4323.
Sincerely,
(L�afnce`
Brooks Range Petroleum Corp.
Manager, Exploration and Subsurface Projects
'A'� A HERE
Brooks Range Petroleum uc
Application for Permit to Drill Document
Development Well Mustang #1A
Table of Contents
WellName.....................................................................................................................................................3
Requirements of 20 AAC 25.005 (f).........................................................................................................3
LocationSummary........................................................................................................................................3
Requirements of 20 AAC 25.005 (c)(2).....................................................................................................3
Requirementsof 20 AAC 25.050 (b).........................................................................................................3
Blowout Prevention Equipment Information...............................................................................................3
Requirements of 20 AAC 25.005 (c)(3).....................................................................................................3
DrillingHazards Information.........................................................................................................................3
Requirements of 20 AAC 25.005 (c)(4).....................................................................................................3
Procedure for Conducting Formation Integrity Tests...................................................................................4
Requirements of 20 AAC 25.005 (c)(7).....................................................................................................4
Casingand Cementing Program....................................................................................................................4
Requirements of 20 AAC 25.005 (c)(6).....................................................................................................4
DiverterSystem Information........................................................................................................................4
Requirements of 20 AAC 25.005 (c)(7).....................................................................................................4
DrillingFluids Program..................................................................................................................................4
Requirements of 20 AAC 25.005 (c)(8).....................................................................................................4
Abnormally Pressured Formation Information.............................................................................................4
Requirements of 20 AAC 25.005 (c)(9).....................................................................................................4
SeismicAnalysis............................................................................................................................................4
Requirements of 20 AAC 25.005 (c)(10)...................................................................................................4
SeabedCondition Analysis............................................................................................................................5
Requirements of 20 AAC 25.005 (c)(11)................................................................................................... 5
Evidenceof Bonding.....................................................................................................................................5
Requirements of 20 AAC 25.005 (c)(12)...................................................................................................5
ProposedDrilling Program............................................................................................................................5
Requirements of 20 AAC 25.005 (c)(13)...................................................................................................5
Discussion of Mud and Cuttings Disposal and Annular Disposal..................................................................5
Requirements of 20 AAC 25.005 (c)(14)...................................................................................................5
August 20, 2018 Mustang #1A 1
/ -) v
Brooks Range Petroleum
Attachments.................................................................................................................................................. 5
Attachment1 Surface Platt.......................................................................................................................5
Attachment 2 Directional Plan..................................................................................................................5
Attachment3 BOP Configuration.............................................................................................................5
Attachment 4 Drilling Hazards Summary..................................................................................................5
Attachment 5 Formation Integrity and Leak Off Test Procedure.............................................................5
Attachment 6 Drilling Fluids Program.......................................................................................................5
Attachment 7 Drilling Procedure..............................................................................................................5
August 20, 2018 Mustang #1A 2
'NY*V\ Q �
Brooks Range Petroleum EflIR�I
Uc
Well Name
Requirements of 20 AAC 25.005 (f)
Well Name: Mustang #1A
Location Summary
Requirements of 20 AAC 25.005 (c)(2)
Surface Location
2426 FSL 1667 FEL S2 T10N R7E UM
ASP Zone 4 NAD 27 Coordinate
Northing 5,940,810' Easting 465,312'
Pad Elevation
75.1' above mean sea level
RKB Elevation
115' above mean sea level
Top of Productive Horizon (Heel)
2694 FSL 819 FEL 1 T10N R7EUM
ASP Zone 4 NAD 27 Coordinate
Northing 5,941,052' Easting 471,440'
Measured Depth (ft)
9,687' MD
Total Vertical Depth Subsea (ft)
5979' TVDss
TD (Toe)
1876 FSL 837 FEL 36 T11N R7EUM
ASP Zone 4 NAD 27 Coordinate
Northing 5,945,514' Easting 471,439'
Measured Depth (ft)
14,735' MD
Total Vertical Depth Subsea (ft)
5971' TVDss
Please see Attachment 1 Surface Platt
Requirements of 20 AAC 25.050 (b)
Please see Attachment 2 Directional Plan
The applicant is the only affected owner.
Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005 (c)(3)
Please see Attachment 3 BOP Configuration
Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
The expected reservoir pressure in the Kuparuk C Sand is 0.562 psi ft or 10.8 ppe equivalent mud
weight. The maximum potential surface pressure (MPSP) based on the above expected pressure
gradient, a methane gradient of 0.10 psi/ft, and the known vertical depth of the Kuparuk C formation
(6094' TVD) is:
August 20, 2018 Mustang #1A 3
/A.)A1
Brooks Range Petroleum
MPSP = (6094 ft)*(0.562-0.10 psi/ft) = 2816 psi
VAQ
EflIEIM
LLC
Mud weights will be targeted initially at 10.1 ppg while drilling, with Managed Pressure Drilling (MPD)
utilized to hold approximately 375 psi back pressure, equivalent to an 11.3 ppg static mud weight.
Please see Attachment 4 Drilling Hazards Summary
Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(7)
As two previous LOT/FITS have been performed on the 7" casing shoe, no additional FIT is planned
during this drill out. This will help to mitigate the potential for shale instability below the 7" casing shoe
while drilling the proposed sidetrack.
Please see Attachment 5 Formation Integrity and leak Off Test Procedure
Casing and Cementing Program
Requirements of 20 AAC 25.005 (c)(6)
Completion Liner
CSG OD
Hole Size
Weight
Grade
Connection
Length
Top
Bottom
Cement Program
(in)
(in)
(Ib/ft)
(ft)
(MD/TVD)
(MD/TVD)
4-1/2"
6-1/8"
12.60
L-80
Hydril 563
5,768
8,967' / 5955
14,735' / 6086'
None
Please see attached 10-401 for existing Casing and Cementing information
Diverter System Information
Requirements of 20 AAC 25.005 (c)(7)
Diverter will not be used to drill this section as surface casing is already set. BOPE will be installed and
tested prior to drilling out.
Drilling Fluids Program
Requirements of 20 AAC 25.005 (c)(8)
,/ Please see Attachment 6 Drilling Fluids Program
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A — Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A — Application is not for an exploratory or stratigraphic test well.
August 20, 2018 Mustang #1A 4
Brooks Range Petroleum
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A — Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for Brooks Range Petroleum Corporation is on file with the Commission. y
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
Please see Attachment 7 Drilling Procedure
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
All drilling waste fluids and cuttings will be disposed of at either the ConocoPhillips 1B Grind & Inject
Facility or the Hilcorp Milne Point Grind & Inject Facility. Waste fluids and cuttings will be hauled via
truck to either 1B or Milne Point for processing and injection in an approved disposal well.
Attachments
Attachment 1 Surface Platt
Attachment 2 Directional Plan
Attachment 3 BOP Configuration
Attachment 4 Drilling Hazards Summary
Attachment 5 Formation Integrity and Leak Off Test Procedure
Attachment 5 Drilling Fluids Program
Attachment 7 Drilling Procedure
August 20, 2018 Mustang #1A 5
Attachment 1 Surface Platt
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LA7MAWN41
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WWTH 4O
I E"MO
XC94R/ uNc Wr6cT
PAD ELn1A7104
.. a
4 CM' 14' S1.401'
r 150' 14 WIn'
5MI1289
wolp6.36
2,306'
' '.l80'
136
B
4 OJO• It 57.,4r
r ,Sr to- 9,.701•
59401" w
4119M 2
f z..WB
C
N 0M' '4' 57.1W
W 150' 16 5I J40-
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Z3ft'
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TJ 6
0
4 070' 14 51,240'
W IM' 165091r
8W0166. 76
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1.736-
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4 CAr 'W b1291'
W !W- 16' SQ W V
50407C W
465255 45
2.40W
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7
4 07W 14' 57.3U'
r 15C' 16- 50-IW
SW01w.05
45W69.661
2.41r
I, N9'
74.0
C
4 CM' If 57176'
W ISO' 15 4960W
624MW.69
4652"65
4.4'r
,.995'
74•
N
4 07C' 4' 67426'
W 150' 16 40, a IV
394 0M 32
46520e.II
2AWT
AV
74 2
.• I
4 4 o?4' o7.4n•
r •SP to: 4e66Y
t940009.03
w5312.31
Mn'
%oor
F4.f
,I
N C11 14' S751Y
W 150' 16 4844r
694C61459
465326.64
7.431'
•,65p'
14.3
1
k GlR 14' 37 M4'
W ISO' 16' 46033.
WV*,023
46Q34016
2,43{'
1,934'
744
l
4 ON, It 5J 610'
W tW 1r 47616'
594W.166
465355.17
2,440'
1.02W
74.5
47 Y
4 07W 4' 574W
W ISO. 16 472!3•
594082842
"ono 14
2.44.'
1.G,e
!46
N
N C70' It S71W'
W ISP 16 w 190'
SW04J313
15363.1!
2.450'
'.WS'
74.4
0
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W q4r to' w.3J0'
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JAW
1,56`
741
4 070' 14' S77"'
r -W 16' 45061•
5940642./0
465412.23
2,459'
',567'
J40
0
M 070' It 5/.441'
W I5o' 16 4654r
594094104
44542641
2.469
1.553'
- M 6
R
4 ON- It 6/.441'
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44544076
1.441W
I45,,1W
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5040856.3-
w6466.07
2.414'
1.624'
750
4
F 070' 14' S6.354'
19 ISC' 16' 51.440'
594OW 60
465222.M
j 2.313'
'.756'
23.6
1
N ON, 14' 59.4ow
W 15'r16' 51.632'
59407111 44
465237 24
7.3'r
1.74"
719
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110
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7l•
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F OM' t1' 66.530'
W 160' 16' 49 789'
66467'SJ/
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2.33t'
',0W
74,'
9
N 07C' It S9.365'
W 160' 16 49.315•
3940n9.28
40M 3C
1,3m
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74.7
7
N OM' It M43"
W 150' 16' 46VW
52407240'
4653W.57
4341'
%fry
'4.3
2
N OM' 14' SQ67r
W 15O' 16' me
59 0720 25
463372 a]
2316'
1.658'
744
AA
4 OM' 14' $4.124'
W 150' 16 48-13Y
tWIM, M
465337.q
2.350
I.542'
1*4
r8
4 Of' 14' 56.770'
W 150. 16' 47716'
31NC/3651
w5361.36
1..MY�'
',921'
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CC
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146
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1.599'
74.7
49
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W 15V 16' 4647T
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1. 399'
`.SW5•
141
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46540842
2.374'
1.570'
746
00
N CIO' It S7,C61'
r 1W W 41164r
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2,37r
1,65t'
740
M
4 C70' 14' S7048'
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1
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56407Jo.9ew54s1.21
2. M.
1.526'
15.0
ll
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W ISC' 16 4440t
50/077560
46W8341
2,313'
1,51S
49
4 C70' 14' 41194•
W 15c• 16' 43980'
S015 Jon 7.,I
as"%1.
7.791
6e Indicates Asbullt Well Conductor Coordinates
PROTRACTED SECTION 2. T. 10 N., R. 7 E., UMIAT MERIDIAN
Brooks Mustang 1A (P9) Proposal Geodetic Report Schlumher9er
(Def Plan)
._.
Cliem:
-
&ooW Range Petroleum Corporedan
wmPu®nan:
Vertical B'dian "moth:
upneai
1.000' (True North)
Field:
SMU Mustang
Vertical Berton Odgin:
O.OW R, OOW ft
III -'I Slot:
Mustang Pad I Moaning 1(1)
NO Referenda
efea Mo.-
Rotry aTable
ell:
Musteng 1
ND Referenda Elevation:
1150DO ft above Mean Sea Leval
So hole:
Mustang IAv2
rr11i Ground Elevation:
]5.100Rab Mean Seel -re
AFID:
501032065201 4�"
P ® Magnetic Oaclirotion:
16.695"
Survey Name:
Mueteng 1A(P9) PfP
Total Gravay Field Strengat:
IM19954mgn(9.80%5 Based)
Survey Wta:
August 21, 2018
Ganily Model:
ODX
TOHI AND / DDI / ERD Ratio:
261.933' / 11975.469 It /6,87711 951
Total Ma9neac Field Strength:
57418.166 nT
Coordinate Referenda Syetem
NAD27 Alaslai State Plane, Zone 04, US Feet
Megnetk Dip Angle:
80.780 °
,etlon Let/Long:
N 70° 14' 5747W", W 150°164186292"
Wclinegan Wte:
October 31, 2016
Location Gad WE Y/X:
N 5940809,930 MS, E 465312310 ftUS
Magnetic Declination Model:
BGGM 2018
CRS Grid Convargenoe Angle:
-02M8'
North Reference:
True Noah
Grid Scak Factor:
O9%K137
Gad W mergence Ueed:
O.MW °
Version / Peth:
2.10.544.0
Total Com Meg Noah-aTfue Nolh:
166947'
Corrprwnta
MD
Inel
A.I. Thu.
88
ND
VBEC
NB
EW
TF
D
Directional Exclusion Zone
Ex9luelanZone
GeoMegTh
No
Fearing
lfll
r)
0(R)
lfll
lRl
lfl)
(k)
I°)
(°HL8 OOK) DHtkutty lntlex Alert
�.�
(nT)
1flU81
("US)
ltlue)
Kf
9W4.88
50.8/
36.84
580570
6020. ]0
-774.11
- gali
6042.01
D3.53L
517
625
4Z
3B48D.50
593D90253
47134863
Tnh Survey
9092.52
50.54
34.99
592326
38
6026
-756.5E
-M 39
6054.57
55.65L
NIA
6.26
41.86
38351,26
5939919.77
471352.23
9100.M
5073
34.64
5928.01
6W1.01
-75178
-07.64
SW7.87
55.43E
4.41
626
42.01
38475.09
5939924.W
471365.56
7-
9124,W
5134
3361
5W3323
0058,23
-73002
-642.0
6068,41
54.72E
4.4/
826
42.M
38881.33
5939940.04
471376.17
Crv2O11W
9132.00
51.M
M15
5948,09
6063,09
-]WW
-836.B3
6071.76
40.3E
4.41
626
42,76
39013.92
5938845.12
477379.54
Top KupC
9187.61
80.30
24.91
597920
6OW.20
.60030
-786.77
6003.87
35.67L
2000
829
61,12
44733.W
593998620
471401,84
920(100
62.34
M.27
5985.19
6100,79
4580.22
-786,77
6098.34
34.88E
2000.
6.30
53,20
4601410
5939MS.18
471406,W
LCU/KupA
9218.88
85.46
20.89
599UM
6108.W
-OU,40
.77198
6101.71
33,WL
20.00
6,31
5627
47726.81
594001086
4714127E
9300.00
79.1E
11.78
601SA2
6133,12
-6W.07
497.0E
612615
31D4L
20.00
8.W
70.01
54W5.08
5940W4.72
471434.57
W'
9352.85
90,"
5.34
602404
6139.04
-528/7
-63534
6135.41
M. 43L
20.00
6.38
M27
55758.46
5940146,42
47/444.11
9400.00
96.40
156
S021.96
61W 96
-491.13
%am
6137.64
W64L
20DD
6.3E
87.51
57414,63
594pi83.41
471448.52
End Cry
W16.11
99.W
OM
M19.94
6134.94
-476.16
583.37
873785
OM
20.00
640
89.M
6746885
594IN37
471448.79
95M.W
99.M
0.W
SOCEN
6121.66
-392.33
-499,52
613785
01A
O.00
641
89.M
57468.]5
5940282.21
471"71]
LCU/KupA
D5B4.f2
99,00
0.00
599350
6108.50
-309,26
-410A4
6137.W
OM
0.00
642
8983
57488,66
594036528
47144755
9=M
99.0C)
0.00
5981.02
6106w
393.57
.400.76
613765
OM
OM
6.42
89.M
574 Iul
5940350,97
471447.63
Cry 4/100
961611
g9.W
O.W
598565
610365
-278.0
385.83
6137W
173.54L
O.W
6.42
Sim
57468. S2
5940M,89
471447.70
Top KupC
0086.82
B6.16
359.88
5979..20
W94.20
-207.5E
314.76
613764
173. 59L
4,00
6.44
8734
6740669
5WN8696
471447.82
97M.M
95.63
359.62
5977.65
6092.S5
-19A48
301.65
6137.56
173.59E
4.W
6.44
MID
5738004
594p400.07
47144780
moo
91.0
359.17
5971.SO
6086.50
-94.75
-201.87
67 M.51
173.62E
4.W
8.46
82.87
570238E
594057983
47144720
End Cry
9879.25
88,50
W8.82
5971.40
8086.40
.15.66
-122,55
6135.12
HS
4.M
6.47
7974
5654"
S40559M
471448.18
8900.DO
80.50
356,82
5971.94
6066.W
5.17
-101'91
6134.69
HS
OM
8.47
7974
5654934
5940579,60
471445.85
10000.00
88.60
358.M
5974.W
6089.56
10507
-1.96
6132.62
HIS
O O
5Q
79.74
58549.41
5940779.74
477444.24
101MW
8650
358,W
5877.16
6082.18
204.96
97.93
6130.56
HIS
0.DO
6.49
79.74
56549.48
594W RW
471442.64
Top KupC
10f7 )32
88.50
35E. B2
W79.20
80D4.20
2821E
175.26
6128.97
HS
0..00
650
79.74
WU963
5940956.26
471441,40
Cry 211W
10191
885O
358,82
5979.71
609,111
W1.72
194.7E
6128,57
6,92R
am
6,50
79.74
5654954
594097649
471441,09
102W.W
88.56
`3.b.&i
54197E
6084.78
304.B5
197.83
:128.50
6.92R
2.M
6,50
79.W
SIZED 56
5940979.0
471"1.04
Till
10272, 40
90.M
359.00
5 ..70
6095.70
377.19
27030
6127.13
9OR
2.M
6.51
81.23
567%50
5941052.M
471440.00
f03MM
M.11
Z159w
59S0.70
BOBS.;,.
404.79
297.90
6126.78
9OR
2.DD
6.52
81.20
56792.40
5941079.60
47143g.78
End Cry
1M1OT7
90.M
359,T7
59W.;0
6M5.]0
415.5E
X2w
612671
HS
2.W
6,52
81.19
56]M.83
5941090.37
471439.76
I WOOD
90,00
3W.77
5980.]0
609670
504.78
397.90
6126.W
HS
OM
663
81.1E
56790,07
594117959
471CQ981
10=,
90.M
359.7
5960..70
S6700
604..74
497.90
6125..
HIS
0,00
6...5
81,19
5570.91
5412795
47139.87
=00
9.M
3977
59070
6005
70472
59.
25
65.51
HIS
M
655
81.19
%70.96
5941379.5
471439921
90W
3597
SB70
6085,70
6E
2
S
B07M.00
81.19
56781.W
5841479.8
4714399E
.00
104169
K00
M9
5960.70
609570
8.37
.0111100
73959
6124,97
90L
000
656
81E
56791D2
5941521.25
471WDDTgl3
107Q"
M.M
9.75
598070
6M5.0
64813
741.35
612496
2.3
1.W
6.56
W791.14
5941523.00
471440.00
End Cry
10778,50
90.35
359.74
5980.59
6M5.50
8S3.17
776.40
6124,80
HIS
t OD
6.56
81.54
58843.94
5941558.W
4714 DO
10800.W
90.35
359.74
59W.48
6M5.4fi
90467
747.90
613470
HS
O.W
8.56
81.54
56893.95
594137B.55
4714d0.M
1000,00
90.35
359,74
5979.W
6094.85
1004.64
897.90
6124.24
HS
0.00
657
81.54
56841%
%41679.54
471440.00
1100OW
90.35
359,74
5979.24
6094.24
/f04.52
997.0E
612378
HS
0.W
6.56
81.54
56844.M
5941779.53
471440.00
Top KupC
11W6.34
90.35
359. 74
597820
W94.20
111095
'004,23
012375
ihS
000
658
81.54
58844.02
594178586
471440.M
112100..00
90..W
359.74
5978.0
6051.
120.5
1W7...89
6123..32
HIS
6..59
81.., 6
55844.W
5941879,.51
471440..M
90W
74
54/802
5083.02
1304.8
1187.8E
622.6
HE
W
,Cry
949.50
47144.MM.M
111W
112018
5
3.
.
so
568M.M
5941930911T
4
.
,
.
1
E
8119
5679144
5D4201600
47144400.M
End ry
11236H7
90.00
W9.74
5977.90
fiM2.M
731.
3422
2XM
6122,69
HIS
M
819
W791.43
5942016A7
47144D.M
SchlumbemerPdvafe
11300.00
90.00
359.74
5977.90
6092,90
1404.54
1297.89
B122.40
HS
0.00
661
81.19
5fi791.45
5942079.49
471440.00
11400.00
90.00
359,74
5977.90
6092.90
7504,61
1397.88
6121.94
HS
000
6,62
81.19
56791,49
5942179.48
471440.00
1,500.00
90.00
359.74
S977.90
6092.90
1604.49
1497.88
5121AS
HS
0.00
fi.83
81.19
56791,64
59422]9.47
471440.00
11600,00
90.00
359.74
5977.90
509190
1704.47
7597.BB
6121,02
HS
0,00
6.54
81.19
SB791.56
5942379.46
471440.00
cry 1/100
116D].07
90.00
359,74
W77.90
6092.90
1712:34
1605.76
6120.98
9OL
0.DO
6.64
81.19
56791.58
5942387,33
47 440.00
Tot
11613.54
90.00
359.68
5977.90
6092.90
1712800
1611.42
612095
16.62L
1.00
634
81.20
56792.00
5942393.00
471440,00
EM Cn
11728.01
9014
359,64
5977.88
S092.86
1732.47
1625.89
612087
HS
1.00
a64
8134
MS 3.39
59424OT47
47IQ9.98
11700.00
90.14
359.64
5977.71
6092.71
1804.44
1697,88
8120.41
HS
0.00
665
87 34
56813.42
5N2479,45
471439.86
11800.00
90.14
359.64
5977.47
IM2.47
1904.41
17897.88
6119.78
HS
0.00
6.68
81.34
56813A8
5942579.44
471439,69
11 ODD 00
90.14
359.64
597T22
6092.22
20D4.36
i897.88
6119.15
HE
0.00
am
81.34
56813.60
5942679,43
C143952
120DO.00
90.14
359.64
5978.98
6091.98
2104.35
1997.87
6118.52
HS
0,00
667
81.34
56813.64
594277942
47143925
12100.00
90.14
359.64
5976.74
6091.74
2204.32
209787
6117781
HS
O30
6.68
0134
55813.58
59428]941
471439.18
Crv1/1W
12192.13
90. 14
369.64
5976.52
6 1.52
2296.43
2190.00
6117.31
163.38R
0,00
669
8134
56813.62
5942971.53
4]1439.02
12200.00
90.06
359.66
597650
6091.50
2304.30
2197,87
6'17.2'
1fi338R
100
669
8126
56SM 03
59429]9,40
471439.01
T9t6
122C8.60
MOO
359.66
597650
6091,50
23f0.30
2204.47
8117.22
1%,69R
1.00
669
81.20
W792:23
5S4298fi.00
471439.00
EW Cry
12220.99
89.87
359.74
5976.52
6091.0
2325.28
2218.85
611].15
HE
1.00
6,69
81.06
56]71.42
5943D00.38
471438.99
12300.00
89.87
359.74
5976 0
6091 TO
24 17
2297.87
fi116.79
HS
0.00
6.70
B1.D6
M 71.45
594307939
471438.99
12400.00
69.87
359,74
5976.93
5091.93
2504.26
239T87
611633
HS
0.00
6.71
al."
56771.50
5943179.38
47143900
12500.00
89, 57
359.74
5977:16
6092.16
26 12
2497.87
6116B7
HS
0.00
671
81 W
66771.54
5943279.37
471439.00
12500. e0
89.B1
359,74
5977.39
6092.39
2704.20
2597.86
6115A1
HE
0.00
672
81.M6
56771.59
5943379.36
471439.00
12700.00
8987
359,74
597782
6092.62
2804.17
2697.66
5114,95
HS
000
6,73
81.06
58]71.63
5943479.35
471439.00
12800.00
89.87
359.74
597785
E09235
290 a
2797,88
6114.49
HS
000
6.74
81.06
567;1.87
594357934
471439,00
Crv1/100
12814.46
69.87
359.74
5977.88
6092.88
2918.80
2812.n
6114A3
0.13L
D.00
fi.74
81.06
56771, fib
5943M 79
471439.DO
Tgt7
12:27.87
90.00
359.74
5977:90
6092.90
2831.81
2825,53
6114.36
OAL
1.00
6,74
81.20
56]92.70
5943607.00
47143900
Ertl Cry
12647,45
90.20
359,74
5977.87
61332.87
2951M
2845.31
6114.27
HS
1.00
674
81.39
56822.10
5943526,78
471439.00
129W 00
60.20
359.74
597].86
6W M
3004.12
2897.86
6114,03
HS
O.00
674
81.39
56822.12
5943679.33
47143900
13000.00
90.20
359.74
5977.34
6092.34
3104.10
2997.88
811357
HS
0.00
675
8139
56822,16
594377931
471439.00
13100.00
90.20
359.74
597699
5091.99
32.4..7
3097'86
6113.11
HS
0.00
US
81.39
56M 20
5943879.30
471439.00
13200.00
9020
359.74
5976.65
6091.66
3304.05
3197.88
5112.65
HS
000
677
81.39
56B22.24
%4397929
471439.00
13300.00
9020
359.74
5976.30
609130
3404.02
329785
fi112.19
HE
0.00
6.77
8139
W22:28
5944079.28
471439.00
13400.00
90.20
359.74
5975,96
609096
3504.00
3397,85
6111.73
'111:27
HS
0.00
6,78
81.39
56822.32
39441i927
47143A00
13500.00
90.20
359.74
5975.61
61790.61
3603.97
3497.85
HS
0.OD
679
8139
56M 36
12]926
47143A0p
13fi00,00
90.20
359.74
5975.2]
E090.P
370395
3597.85
8110.81
HS
0,00
6.SO
81.39
56822.39
594437925
0]1439.00
Crv1/100
13627.53
90.20
359.74
5975.17
6390,17
3731.40
3625,38
6110.68
HS
0.00
6,80
81,39
SM2.41
5944406.78
471439.00
Tgt8
13642,75
90.35
359.74
5975.10
SD90.10
374889
3640.30
61;0.61
HS
1.00
6SO
81.55
5684503
5944422.00
4]143900
Ertl Cry
13657.45
90.50
359.74
5974.99
5089.99
376138
3655.29
6110.54
HS
TM
660
81.69
58966.49
5944436.89
471439.00
13700.00
90.50
35974
5974.82
6089.62
3803.92
369T84
611035
HS
000
8.00
81.69
56866.50
59444]9.24
471439.00
13800.DO
90,50
359.74
5973.76
SON 76
3903.89
3797.84
610989
HS
0.00
6.81
81.69
56866.53
594457922
471439.00
13900. CO
90.M
359.74
5972.89
SOaT89
4003.87
3897.84
610943
HS
0,00
6.82
81'69
56865.57
5944579.21
471439.00
1400030
90.50
359.74
5972.02
6087.02
4103.84
3997.83
610697
HS
0.D0
583
81,69
56868.fi0
59a477920
471439.00
14100.00
90.50
359,74
5971.15
6086.15
4203.81
4097.83
610&51
HS
0,00
am
81.69
56866.63
5944B79.18
471439.00
Crv1/100
14118. 13
90.50
359.74
5971.00
SOB6.00
4221.62
4i 15,95
61M 42
LS
0.00
6.63
B1�
56863.64
5944897.31
471439.OD
Tgt9
14130.82
90.37
359.74
5870.1
SOW 90
4234.62
4128M
61W 37
LS
100
an
81.57
56948.14
5944910.00
47743900
Ertl Cry
14144.31
9024
35974
597083
6035.83
42Q 11
4142,13
6108.30
HE
1.00
684
81.43
56828.17
594492349
47143900
14200. co
90.24
359.74
5970.60
60Mso
4303.78
4197.82
61MM
IS
0.00
684
B1.43
5fi82619
594A9]9.17
471439.00
14300.00
90.24
359.74
5970.19
6065.19
44 16
4297.82
6107.59
HE
0.00
am
81,43
56828,23
5945079,16
471439.M
14400.00
90.24
359.74
596978
SO84.78
4503.73
4397,82
6107.13
HS
0,00
6.M
81.43
56828.26
5945179.15
471Q 00
Cry MOD
14456.35
90.24
359.74
59W 55
6094.55
4560.07
4454.16
6105.87
LS
O.OD
am
81.43
56828,29
5945235.49
471439.00
Tgt 10
14479.86
MOD
359.74
59MSo
6084.50
458357
4477.68
B10fi.76
LS
1.W
686
8143
53782.73
59452:fl.W
471439.00
14500.00
89. BO
359.74
5969.64
6084.54
4503.71
4497A2
6106.67
LS
1.00
am
8100
56761,51
5945279.14
47143900
ErE C,
14513.54
69. fi6
359.74
5%9.60
6084.60
4617.24
4511M
610660
HS
s00
a
B0.86
5674014
5945292.67
471439.00
14600.00
89.66
359.74
5970.11
60M 11
4703.68
4597.81
810621
HS
OM
6.87
80.86
W40.10
59453]9.13
471439.00
14700. GO
89.E
359.74
3970.69
6085.69
4803.Bfi
4697.81
610675
HE
0.0]
6.87
80.86
56/40.22
5945479.12
971439.00
TO
14734,89
89.66
359,74
5970.90
6085.90
4638.54
4732.70
610658
0.DO
fi.BB
80.86
567Q 24
5945514.00
471439.00
Survey Error MW 1:
I9CVMSA Rev 0 - 3 0
95,000% Cmfid-
2.7955 sigma
Survey Program:
DecoHpBon
Pert
MD Fm
MD To
EOU Freq
Hole 3Z
Ce4lrig Dlarreler
Iftl
Ift)
(ft)
(I.)
Inc it imtlMon
Idsol
purvey Tool Type
BorehoM / 8u "/ey
i
0.
1
12.2
ING R D
ustang
1
218.480
3044.660
A> Stns
12,250
9.625
SLB_MV.DSTO
Mu.0
1
3D64.660
3076800
Act St
8.5M
7.000
SLB_M INC ONLY FILLER
Mustangs
1
1
W76. BOO
Mats
9092:518
9132.000
Ad Stns
1I100000
8.500
6.125
7.000
6.125
SLB_MN45TD
SLB MWOSTO
Mustangs
Mustang!A(P9I
1
9132.000
9280.000
11100000
3.125
4.5M
SLB_M [NC ONLY FILLER
Mustang A (P9)
1
9280.000
1DODO ODC
11100.000
6.125
4.5�
SLBMVs4NSAG
Mustang to(P9)
2
9280.000
14734.889
11100000
6.125
4.500
SLB MVJD'GMAG
Mustang 1A (P9)
Legal Deegrlp6gn:
Northing (Y)
Eeetlao (I)
Surtece: 2426.1
FSL 1666.6 FEL S2 T10N WE UM
PROM.930
12.310
Tia,l 1544 FSL 905 FEL 1 T10N
WEUM
5939902.530
471349.630
ttl I BHL 1876 FSL 837 FEL 36 Tl l N R]EUM
'45614.000
471439.000
Schlum6ergerPrivate
/ ) ' \
Schiumherger,
Brooks Range Petroleum
Borehole:
Well:
Field:
Structure:
Mustang 1A
Mustang 1
SMU Mustang
Mustang Pad
Gravity S Magnetic Parametara
Surlaca location NAD27 Alaska State Plane, Zone 04, US Feet
Miscellaneous
Model: BGGM 2018 Dip: 80.78° Date: 31-0et-2016
LetN 7019 57.47
Northing: 1140808.83ftUS Grid Con,: -0.2636°
Slot: Mustang 1 III ND Ref:
Rotary Tahle(115ft above Mean Sea Level)
MagDee: 16.895° FS: fi7418.158nT Oravky FS: 1001.995mgn (8.80885 Based)
Lon: W 15016 48.86
Easting: 985312.31ftUS Scale FaR: 0.99890137
Plan: Mustang 1A (P9)
-2000 -1000 0
1000
2000 3000 4000 5000
6000
D
I I
i 0
1000
2000
r
0
S 3000
6
c
0
4000
5000
6000
2000
3000
4000
Ila ��e�Yo mm rv¢ II-
iwe Ilene e]e MO ewJ Jvo 1-1 rvo
Y I IN idle —a nm M¢eme N¢
5BN — oo nG �'
J 11.w ua wasrvg 5000
—1 ,aa.2zu o
a,��Tea
prw
a
Mustang 1 / Mustang 1AP61
)00 -1000 0 1000 2000 3000 4000 5000 6000
Vertical Section (ft) Azim = 1,00° Scale = 1:1200.00(ft) Origin = ON/-S, OE/-W
6000
/ " N
Schtumberger
Brooks Range Petroleum
Borehole:
Well:
Field:
Structure:
Mustang 1A
Mustang 1
SMU Mustang
Mustang Pad
Gravity & MaBnetie Param¢ters
S"nace Location 1AD27 Alaska State Plane, Zeno 04• US FM
Mixollan—,
Model: BGGM 2018 Dip: 80.7W Date: 31-Oct-2018
Let: N 7014 57.47
Northing: 5940809.93NUS Grid Conv: -0.2638°
Slot: Mustang 1111 TVD Rd:
Rotary Table(115h above Mean Sea Levi)
MagOee: 16.695° FS: 57418.156nT Gravity FS: 1001.995mgn (8.80665 Based)
Lon: W 150 16 48.89
Easting: 465312.31ftUS Seele Fact: 0.99990137
Plan: Mustang 1A (P9)
-500 0
500 1000 1500 2000 2500 3000 3500
4000 4500
5000
secs Me std rvo m rv4
lsl.4o mmlw
5000
Ild 0 ews i]e
rvo
I 1Va
5500
aoa]4
Mo�
M. '«>a
txxa, I,a
17'
Moe" «e11. °a..a-5500
.4aaoaa,va
,:4¢¢a�
¢rv4ta1154¢ s M4 5NxiV¢ iw ,Iptyl ]yA._"___.._ _._.._..._..�_ I .
._...._.._._.. I.xss 4
m._
6000
......... ._.._.._..._.._._.._.._ _.._.___.._. .._ _..
._..-—•-••_.. '_:.:_
neu
._.._.._._.._..___ _.._._.._.._._.._... .._._._.._...... ..
........._..___.._ __.._.._..__..:__. _._._.._...._.._ ...._.................. _.......__..-_--�._....
.._._...._._.._ _.._._ _ _..__
_._.._.._._.._
6000
x a.
www ro iv¢I'
a I t . rvol
.. .._ II ..
F
fTiJlaiie3'rvoi".--"'-"'"'—'"
Mustang tAP61
Mustang 1
Mustang 1A (P9)
6500
6500
-500 0
500 1000 1500 2000 2500 3000 3500
4000 4500
Vertical Section (ft) Azinn = 1.00¢ Scale = 1:650.00(ft) Origin = ON/-S, OEAW
Schlumherger
Brooks Range Petroleum
0 1000 2000 3000 4000 5000 6000
Mustang 1A (Pg)
5000 5000
D
N 14735 MD 6086 NO
End Cry
14514 MD 6085 ND
T9t 10
14480 MD 6085 NO
Cry 1I100
14456 MD 6085 ND
End Cry
14144 MD 6056 ND
To
4000 14131 MD 6086 ND
Cry 11100 4000
14115 MD BOBS ND End Cry
1 M57 MD 6090 NO
T08 tj
13643 MD 6090 ND
Cry Woo
13628 MD BO90 ND
En tl Cry
12647 MD GW3 ND
3000
Io 3000
12828 MD W. ND
Cry 11100
12al4 MD Eo93 ND
En tl Cry
12221 MD 6092 N0
T9t 6
1220] MD 8082 NO
Cry 1/100
C 12182 MD 6092 NO
0 2000 Endcry 2000
O 11628 MD SM3 ND
p TpI
11614MD8093N1
II - cry �11237MDMMrVD
N 11BOBMD6M3ND Entl Cn
03
u Tgt4
- 11237 MD 8-3 ND
Cry tit
N 11 MI MD 6093 ND
Z 1000 EdCn, 1000
107]8 MD 6096 ND
T9t3
10743 MD 6095 ND
Cry 11100
10742 MO"ND
Entl Cry
10311 MD 6096 ND
TM 2
102n MD aMa ND
Cry vtoo
10197 MD 6095 ND
Q _ End Cry O
9879 MO 608E ND
Crv4/100
W isMD 6104N0
Cn20/100
9132 MD W63 ND
9p•
T' 9 D6139ND M tang 1AP61
9124 MD 805E ND
Twin S—n,
SOBS MD 246� ND 9093 MD 6039 ND
M slang 1
-1000
-1000
-2000
-2000
0 1000 2000 3000 4000 5000 6000
EW (ft) Scale = 1:1000.00(ft)
Borehole: Well: field: Structure
:
Mustang 1A
Mustang 1
SMU Mustang
Mustang Pad
Gravity 8 Magnetic Parameters
Surtace
Location NAD27 Alaska State Plane, Zone O4, US Feet
ellMotlel:
BGGM 2018 Dlp; 80,78° Date:
31-0ct-2018
Let:
N 701657.47 Northing:
5940809.93ftUGritl Conv: -0.2638°lot:
Mustang 1 (Q ND Ref: Rotary Table(115tt above Mean Sea Level}
IM'I'a'n:
MagDec: 16.895° FS: 57418.156nT GravityFS:
1001.995mgn (9.80885 easetl)Lon:
W15018 48.86 Easting:
465312.31ftU5 ScaleFact: 0.99990137
Mustang 1A (P9)
4500
3000
c
0
0
i6YeIa1
/ ' - ` Schlumbarger
Brooks Range Petroleum
Borehole: Well: Field: Struoture:
Mustang 7A Mustang 7 SMU Mustang Mustang Pad
Grevity& Magnetic Pereme[era Suriece Location NAG17 Aleeke Stets Plane,Zone GI, US Fee[ MiecelleneouR
MOEeI: OGGM p018 Gip: Br... oete: J1-0ct-]O16 Let: N 7014 67,47 Nonhine: 9 40800. B3HU Gn on : -0.p838° Slm: Mustang 1 (N NG 11: Rotary T—(I15h aheve Mean Bee Level)
Meposc: 10.095° FS: 57118.158nT Oreviry FS: f001, BBSm pn (8.800053asetl) Lon: W160104880 E-mr: 405310.31 hU3 9c 0.99090137 Plen: Mustang to (PB)
-1500 0 1500 3000 4500 6000 7500
SMU M-02
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1.175LB MWD+GMAC
216m
BIAS
14.5E
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T910
End pv
13612.]E
13867.1E
00.3E
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3731.48
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611051
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808560
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246.1E
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M9 IA(P9)
SMU Mustang\Mustang Pad\Mustang 1\Mustang 1A v2\Mustang 1A (P9)
Drilling Office 2.10.544.0 . Schlumberger-Private 9/21/2018 11:24 AM Page 2 of 2
Mustang 1A (PS) Anti -Collision Summary Report
Analysts Date-24hr Time: September
21, 2018-10:26
Analysis Method:
3D Least Distance
Client:
Brooks Range Petroleum Corporation
Reference Trajectory:
Mustang 1A (P9) (Def Plan)
Field:
SMU Mustang
Depth Interval:
Every 10,00 Measured Depth (ft)
Structure:
Mustang Pad
Rule Set:
D&M AmiColllsion Standard S002 v5.1/5.2
Slot:
Mustang 1
(1)
Min Pt.:
All local minima indicated.
Well:
Mustang 1
Version / Patch:
2.10.544.0
Borehole:
Mustang 1A v2
Database l Project:
IocalhosUrllling-North Slope West
Scan MD Range:
9092.52ft - 14734.89ft
ISCWSAO 3-D 95.000% Confidence 2.7955 sigma, for subject
well. For
Traiectory Error Modal:
offset wells, error model version is specified with each well
respectively.
Offset Trajectories Summary
Offset Selection Criteria
Wellhead distance scan:
Not performedl
Selection fftere:
Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans
- All Non-Def Surveys when no Def-Survey is set in a borehole -Ail Non-Def
Plans when
no Def-Plan is set in a borehole
Offset Trajectory
Se aretion
Allow
Allow
Sep.
Controlling
Reference
Tra ecto
Risk Level
Alert
Status
Ct-0t ft
MAS ft EoU ff
ft
Fact.
Rule
MD ft
TVD ft Alert
Minor Major
Mustang 1A(Oaf Survey)
FellM.J.
O.W
475.23 -317.151 A75.23
0.00
0SF1.50
9092.52
6038,26 OSF<500
OSF-1.50 OSF<1.00
Ent. Major
0.01
232.93 -155,61) -232,92
-0.01
OSF7.50
9100.00
W43.01
Min%-O-SF
5.00
140.20 -92.-141.21
0.04
OSF1.50
928000
6123.29
MINPT-O-EOU
5,47
148.77 92.70 -141.
0.05
OSF1.50
9270.00
8128.18
MhPt-CADP
28.40
300.50-174.27 274.10
0.73
OSF1,
8550.00
8113.84
Mir,Pt-OSF
51.91
414.1 -224S 36224
0.18
OSF1.50
95M.00
6109.14
MINPT-O-EOU
61,32
425.75-222.81 364.43
021
0SF7.50
9590.W
6107.58
M1`Pt-O4DP
208.81
482.25 .9.69-183.44
0.97
0SF1.50
9830.00
6085.95
OSF>1,00
Exit Mejer
458.00
485.15 147.58 -7.15
1.48
09F1.50
9BB0.00
608930
OSF>1.50
Fail Minor
1557.07
488.37 1244.50 1088.70
499
OSF1.50
11090.00
0093,69 OSF>5.00
Exit AIM
5201.72
469.46 4888.42 4732.26
16,65
OSF1.50
14734.89
W8590
TD
Mustang 1 (Der Survey)
Fall Maly
O.W
473.85-3-1 5-3-6T .47995
O.W
OSF7.50
8082.52
8038.28 OSF<S.W
OSF<1.W OSF<i.W
Enter Major
O.W
29907-199.71-299.07
O.W
CSF1.W
9132.00
mmoa
-
MirPt-O-SF
0.09
338.23-224.39 -336.1
O.W
OSF1.50
9140.00
W58,00
Mirpts
.08
345.90 -207. 322.83
0.10
OSF1.W
9250.00
6120.12
MINPT-O-EOU
31.51
358.OB-206.21 -324.
0.13
OSF1.50
9270.00
6126.18
MhPt-0-ADP
82,59
449. -207A3-358.95
0.37
OSF1.50
111.1
MINPT-0-EOU
101.17
460.31 -2W.W 359.1
0.33
OSF7.50
:311
8380.00
8138,60
MInPI-0-ADP
331.04
497.55 -0.99 -16851
1.00
0SF1.50
9815.11
6103,85
OSFN.00
Exit Major
494.52
502.11 159.45 -7.59
148
CSF1.50
9780.00
W87.22
OSP1,50
Exit Mirror
1me On
509.80 1356.72 1187,11
5.00
OSF1.50
10990.00
W94.30 OSP5.00
Exit Alert
5440.14
510,04 509938 4933.10
1803
OSF1.50
14734A9
608.5,90
TD
SMU M-02 (Dar Survey)
Peas
5192.81
2rA.52 5022.80 408.2 W.72
OSF1.50
9092.52
803826
MInPt-0SF
3913,55
243.57 3760,84 366888
24.1
OSF7.50
108D0.00
6095.40
MinPt-O-SF
2886.33
206.87 2748.08 2679.
21.02
0SF1.50
12192,13
6091.52
MinPl-0SF
2073.70
230.05 1920.01 1843,
73.5
OSF1.50
13440.00
W90.82
MinPt-0SF
1743.87
192,32 1016.33 1551
13.88
OSF1.50
14179.88
608450
MinPt-SF
1741.74
193.02 1612,73 1548.72
13.60
OSF1.60
1457 O'0
6004,93
MInPt-CIC1
1741.90
/93. 181250
1541.45
13.57
OSF1.50
14590.00
6085.05
MINPT-O-ECU
1742,56
194.51 1612.5
1548.05
13.50
CSF7.50
14620.W
6085.22
MINPT-0-EOU
1743.75
195.85 161295
1647.89
13.41
OSF7.50
140550.00
8085,40
MhPt-0-ADP
7749,88
200.25 1616.05 1549,031
13,161
DSF1,50
14734.89
8085.90
MinPt-0-SF
SMU M-02P91 (Def Survey)
p«
5192.81
25/.52 5022.W 49382
30.72
0SF1.50
BOB2.52
8W8.28
MinPl-OSF
3013.55
243.57 3750.84 3689.
24.19
OSF1.50
10BW.W
6095.d8
MinPt-0-SF
2245.71
242.11 2083.98 2W3.
13.98
OSF1.50
13/70.W
8091,75
MinPl-0SF
1921.19
200.88 1786.04 1720.31
14.47
OSF7,50
14118,13
3088.W
MirP1-0SF
7906.27
200.95 1771.98 170532
14.29
OSF7.50
14380.W
808494
MinPtaCI
1906.55
201.62 1771.81 1704,03
14.25
DSF1.50
14390.00
0084,82
MINPT-O-EOU
1907.0()
202.12 1771.92 1704.BB
14.21
0SF1.50
1"10,00
6084.74
MInPt-0-ADP
1910.22
203.90 1773.95 7706.31
74.11
03F1.50
14479.88
1014.10
MinPt-OSF
194339
213.53 1600,71 1729.87
13.71
0SF1.50
14734.89
W85.90
MxPt-0SF
SMU M-03 (Der Survey)
pess
4684.33
92.98 4822.02 4581.
78.3
0SF7.50
9082.52
6038.26
Mirpts
501261
16550 49W,02 4847.18
45.
DSF7.50
108W.W
8085.46
MlnPt-O-SF
8380.87
287.83 8201.BB .11113
35.B8
OSF7.50
7368000
8089,80
MinPt-OSF
7099.26
290.56 8005.23 6808.71
38.77
OSF1,50
14734.89
6065,90
TD
North Tarn 1A (Def Survey)
pB68
8440.78
84.65 8361.W B356.71
115.46
OSF1.50
9092.52
6038.26
MinPts
8485.31
103.74 6425.82 6391,57
94,60
OSF1.50
890
9.00
6068.02
MinPt-QCI
8497,63
11.07= 6388.78
88.53
OSF1SO
100%00
608987
MINPT-0-EOU
8502.28
118A2 542433 6385.
84,48
OSF1.50
10170.1
1.11
MhPtmADP
6570.09
147.34 8471.54 6422.7
67.
OSF7.50
10800.00
BOB5.46
MinPt-O-SF
7819,05
257.07 7647.34 7561.08
45.7
OSF1.50
14130.82
6085.W
MinPt-SF
8005.3d
28.5.38 7828.10 7739.
45.42
OSF1.50
14458.35
8084.55
MinPl-OSF
8171.66
271.26 7890.48 79W.38
45.34
OSF1.50
14734.89
8085.90
MinPt-0SF
North Tam 1 (Def Survey)
p ass
8771.74
73.79 6722.22 8887.95
139.50
OSF1.50
9092.52
803828
Mirpts
885B.B7
86.74 6801.76 8773.17
119.98
OSF7.50
9490.00
6123.22
Mirpt-act
8861.70
92.44 8799.7 6769.27
112.53
DSF7.50
9650.00
6008.01
MINPT-0-EOU
686326
MAI BBW.W 6768.
110.18
OSF7.50
9710.DD
6091,90
MinPI-0-ADP
6902.59
117.83 6823.71 8784.7
88.80
0SF1.50
10272,40
3095,70
MirPt-OSF
6985.12
143.82 6889.04 6841A
73.14
OSF1.50
108W.W
8085.46
MxPt-OSF
828538
251.34 8117.BB 8034.
4954
OSF1.50
141 W.82
6085.90
MinPt-SF
8479,74
259.85 83D831 8220.
49.17
OSF1.50
11470.W
8084.51
MinPI-O-SF
8637,74
264.91 8480:70 8372,80
49.08
OSF1.50
14734.89
6065.90
MinPl-0SF
SMU Mustang\Mustang Pad\Mustang 1\Mustang 1A v2\Mustang 1A (139)
Drilling Office 2.10.544.0 . SChlumberger-Private Page 1 of 1
Mustang 1A (P9) Anti -Collision Summary Report
Analysis Date-24hr Time: September 21, 2018-10:29
Analysis Method:
Normal Plane
Client:
Brooks Range Petroleum
Corporation
Reference Trajectory:
Mustang 1A (P9) (Def Plan)
Field:
SMU Mustang
Depth Interval:
Every 10.00 Measured Depth (ft)
Structure:
Mustang Pad
Rule Set:
D&M AntiCollislon Standard S002 v5.115.2
Slot:
Mustang 1 (1)
Min Pt.;
All local minima indicated,
Well:
Mustang 1
Version / Patch:
2.10,544.0
Borehole:
Mustang to v2
Database l Project:
IocalhostWnlling-North Slope West
Scan MD Range:
9092.52ft-14734.89ft
ISCWSA03-D 95.000%Confidence 2.7955 sigma, for subject
well. For
Tmiectory Error Model:
offset wells, error model version is
specified with each well
respectively.
Offset Trajectories Summary
Offset Selection Criteria
Wellhead distance scan:
Notperformedl
Selection fillers:
Defini ive Surveys - Definitive
Plans- Definitive surveys exclude definitive plane
-All Non-Def Surveys when no Def-Survey is set in a borehole
- All Non-Def
Plans when
no Det-Plan is set In a borehole
Offset Trajectory
Se aretion
HI
Allow
Sep.
Controlling
Reference
Tre ecto
Risk Level
Alert 64tus
CtCt ft MAS ft
EOU If
Dev. ft
Fact.
Rule
MD !t
TVD ft Alert
Minor Major
Mustang 1A (Der Survey)
Fall Major
0,00 475.23
_-317.151
475.23
0.00
OSF1.50
9082.52
6038.26 OSF<6.00
osizo.W OSF<1.00
Enter Major
0.00 234.02
-150.34
.234.011
03F1.50
9086.30
6040.66
MinPl4)SF
5.80 151A
95.7
-148,00
0.05
OSF1.50
9276.32
8127.86
MINPT-O-EOU
8.33 152.50
-95.71
-148.2
0.05
OSF7.50
0288.34
6130.28
Mn-A PI-ODP
19.03 168.77
.93.81
-149.74
0.16
CSF1.50
9531.71
6116,70 OSF1500
OSF.1.50 OSF-1.00
Exit Meor
8�2.58 31.12
6871.48
3681.45
432.68
OSF7.50
9380.88
6139.03
MinPl-0.3F
3242.74 1013178.42
3146.2
52,00
OSF1.50
9415.43
8134.89
MInPt.
8342.75 49.27
8309.58
829348
259.13
OSF1.50
9976.28
608884
TD
Mustang 1 (Def Survsy)
FM Major
OW 473A6
378,30
-473.85
000
OSF1.50
9082.52
603826 OSF<5.00
OSF<1.W OSF<1.00
Enter MejM
0.00 301.05
-201.03
301.05
0.00
OSF1.50
9124.20
6068,23
MnPts
0.01 335.
-224.02
-335.
0.00
05 1.50
94
91.20
8064.45
Minpls
59.80 223.49
-88.52
-163.e9
0.40
OSF1.60
9305.56
6134.12 OSF>5.00
OSF>1.50 OSFa1.00
Exit Major
8873,84 31.05
8652.61
8642.79
432.71
OSF1.50
9360,68
6139,03
MinPI-0-SF
3244.75 W.Ul
3181,5
3150.41
52,12
OSF1.50
941802
813480
MinPls
8344.31 49.21
8311.13
8295.04
25B 21
OSF1,50
9976.26
6088,94
TD
SMU M02 (Dot Survey)
P�
5254.40 218. 5109. 5038.
36.59
OSF1.50
BOB2.52
803826
MinPls
8119.53 32.81
8099.37
8088.72
423.29
MAS = 10.00 (m)
935T48
6138.99
MinPI-0-SF
842027 32.81
8999.90
83874
421.79
MAS=10.00 (m)
9359.81
8139.02
MinP1A5F
8635,41 32.81
887451
8602.
433.
MA3=t0.o0(m)
9359,80
6139.02
MmPr-0SF
7711.01 56.72
7673.53
7855.2E
211.30
0SF1.50
10195.20
6004.67
MInP1C1Ct
7711.01 55.89
7873.35
]855.01
210.24
O.SF1,50
10200.69
8004.81
Minpls
8.,77 78.
8753.20
8727.
134.5
IDSF1.50
10794.90
6095.49
Minpls
1741.73 182.94
1812.78
1548.79
13.80
0SF1.50
14586.21
8084,91
Minpls
SMU M-02PB1 (Der 6urvsy)
pass
r-SM-44 219.34 5109.85 5038.08
36.
OSF1.50
90&2.52
B03828
MinPb
8119.53 32.81
8099.37
W86 7211
423724
MAS =10.00 (m)
9357.48
6138.89
MinPt-0SF
$420:21 32,81
1.1
83B7.48
427.19
MAS =10.00(m)
9359.81
6139.02
MInPI-0-SF
8935.41 32.87
8014,51
8602.
433.44
MAS =10.00 (n)
935980
6139.02
MInPI-0-SF
7711.01 55.72
707383
76552P
211,30
0SF1.50
10195.20
8084.87
MinPILtCI
7711.01 55.99
7873.3
765501
210,24
OSF1.50
10200.69
W9481
MlnPts
8804.77 76.88
87532
672790
134.50
OBF1,50
1079488
6085.49
Min%
7808.27 200,8E
1772.01
17U538
14.30
OSF1.50
14357.11
8084.96
MnPts
SMU M03 (Def Survey)
pass
4810.00 87.60 4751.27 4722.40 8328
OSF1.50
942838
6134,11
Mirpts
8532 22 32.81
8511.57
$499.41
433.75
MAS =10.00 (m)
B35B.67
8139.01
MinPI-0-SF
8507.34 32.81
8586.55
8554,54
433.53
MAS =10.00(m)
935B31
613901
MinPl-0SF
7148.02 58.911
7108,421
7089.11
185.07
OSF1.50
10172,94
em'09
MinPts
North Tarn 1A (Der Survey)
-
p�
8733.8 32.87
8712.35
8700,80
42g.54
MAS = 10.00 (m)
g382.39
8139.04
Minpls
8504 97.80
843040
6407,10
10008
0SF1,50
9385.31
8138.28
MInPI-CtCI
8988.99 46.99
8354.00
833800
202.02
0SF1.50
0942,14
8086.05
TD
6I95.31 104 34
6425.62
6391.27
94,52
OSF1.50
9859.62
WIR1,02
MinPICtCt
North Tam 1 (Der Survey)
Pass873387
32,87
8712.
8700.86
429,
MAS =10.00(m)
9982.38
6139.04
MlnPls
8880.28 83,94
6804.00
6776.35
124,03
0SF1.50
9410.11
6135.88
MinptCtet
6860.45 84, &M.8 6775.97
123.23
0SF1,50
9410.88
0135.57
MINPT-0-EOU
6860.78 84.89
6803.86
0775.
122.03
0SF1.50
941147
8135.4E
MnPI-O-ADP
8808.45 87.1E
6W7.99
6779,25
118.48
OSF1.50
941060
6134.70
MinPt4)-SF
6869.94 86.85
6801.84
8773.29
120.11
OSF1.50
9401.78
6124.51
MnPt-OADP
6859.81 86.62
6001.B1
8773.29
120.14
OSF1.50
9484AB
6124.09
MINPT-0-EOU
BBSB.B1 86.00
6801.85
6773.31
120,17
OSF1.50
9480.51
6123.77
MinPt-CICt
8388.99 48.99
8354.00
8338.00
262.02
OSF1.50
9942.14
W8805
TD
SMU MustanglMustang Pad\Mustang 11Mustang 1A v2\Mustang 1A (P9)
Drilling Office 2.10.544.0 . SChlumberger-Private Page 1 of 1
Traveling Cylinder Plot
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
TRAVELING CYLINDER PLOT
Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2 ClienCorporatonn
t
Field SMU Mustang
Structure Mustang Pad
Well Mustang 1
North
Borehole Mustang 1A v2
350 0 10
Date 21-Aug-2018
340 100 20
330 90 30
320 80 40
310 70 50
60
300 60
50
40
290 70
30
280 20 80
10
270 Mustang 1A 90
oe
0-
91t�
9212 O�
Oer,
260 oa 97.0 w
o
gy39
O� 00 100
os
92�
Oy
00
250 �ziz Off' 110
Oip
O 00 O�
9za9 OO
V
240 9�z o° 120
Mustang 1
230 130
220 140
210 150
200 160
190 180 170
Well Ticks Type: MD on Mustang 1A (139)
Calculation Method: Normal Plane
Ring Interval 10.00 ft
Azimuth Interval: 10.00 deg
Start Depth: 9100.00 ft
End Depth: 114734.89 ft
Offset Well Count: 17
Traveling Cylinder Plot
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
Anti -Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2
IT -
280
270
260
North
350 0 10
190 180 170
Well Ticks Type:
MD on Mustang 1A (139)
Calculation Method:
Normal Plane
Ring Interval
5.00 ft
Azimuth Interval:
10.00 deg
Start Depth:
9100.00 ft
End Depth:
114734.89 ft
Offset Well Count:
17
TRAVELING CYLINDER PLOT
Client
iz?u
Field
SMU Mustang
Structure
Mustang Pad
Well
Mustang 1
Borehole
Mustang 1A v2
Date
21-Aug-2018
80
90
'ms
Attachment 3 BOP Configuration
VALVE LEGEND
BYPASS 1 ANNULAR
2 TOP PIPE RAM
3 BLIND RAMS
M...
5 BOTTOM RAMS
5 CHOKE
6 KILL
7 AU%
ACCU
TRIPLEX PUMPS: 2 eo.-173. 3D HP, 15 GPM, 3000 psi
T \ AIR PUMPS: 2 e T3. 50:1. 3000 psi
s
9e O O C vK uu p
'R "' � O O y MODE SELECTOR
Mi -
ACCUMULATOR MANIFOLD
0 O
22 SMES, 15 GALLONS EACH, O 3000 PSI
PeN m emse
80P STACK EI£/ATIOti
u+ A�rb
nu0 sea¢
E M ELECTRIC REMOTE Pe^'E1
NITROGEN Hi^J(UP 90I7LE5:
/—snu n n
WH —N �r Ivro wn uia 6 BQTRES, 11 GALLONS FI,C
�, +/4' rao P9 FlAYZ
MG 25
80P SYSTEM
SURFACE DN:RTFR CONTICtIRAPON AND f.GNIROL
Attachment 3 BOP Configuration
Ia. �w .
v+wJksN On a.MrU-P.d q.y4srs�
n...e.N ls� wbat.bergbr
I-ta4 YaY l'>.an
Mlunvn a'RI.N I�.m
A: IV
lu
Is,• lu
a AI
I;
u
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=Plan i.o4.r vm< SIM,
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121 {{ L
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l � fFehn eyp
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Al..p-. G.. Ilu,l.r 1,, . NC
_ t• pnF vaiv. Rig 25
'� .Qa
Attachment 3 BOP Configuration
F
E
Q
C
6 W
e y
aV o30 0S u
VTFW 'A'-'A-
z
➢ESCRIPTIDN
—Z v.LVE. ] V¢'-'1000 KI
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IJJY PLE CHIXE. D VB =5M,2• MD, pPIFSE F
m�sLLr, suxv 1NNe. s L/Y-]V
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SrulwD M.OGt, i) t V15'. !) ] Va•�SrSm KI w
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a.¢cE¢ sFmL ] v¢•KAw .a vH. 5 v¢• Lc.
SPDGER 6Fml. ] V¢'-SA6J PS! vP, l2 ]..• L4
DMSP ]VmL S VP-SA[U VP ¢r L4 E
>o� sF�L ] VP -SAD] PYI va, ¢) IVN' L4
T¢¢F6T R¢HIE. FA., ] V¢•d,PD KI VD
KE C wwc ¢ Vl6'-53 FLG, . D-6k K¢
DD�LE¢ FLNGE Y Vl¢'-5M0 KI W . r 315DP
VE EC3 FLU!£. 3 V -SAGO KI N a 3' ]¢H
SND. .ur3 � 9]VO w3]ET]
A:fFM1LE. TEST ] —T
C
0
Du3uP gym/ AOFVN. ��.eDd]
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PrRa � )��wR nc� ���/♦�
CHOKE MANIFOLD, A
• m. ] W-5,000 Pal WP
`"�• ,yw��Y`wo°.w^ DOYON DRILLING
QUOTATION
DOYMAN-t A.G3
a z
Seepage losses < 10 bbllhr
Add SAFE-CARB 250 to
active at 2-5 ppb.
Spot pill (30-40 bbls):
SAFE-CARB 40 5 ppb
S.A.FE-C ARB 500 5 ppb
Differential Sticking
Risk: Low
Attachment 4 Drilling Hazards Summary
Losing fluid while drilling i
I "Jeasttre rate of loss I
i Partial losses 10-100 bbl hr
Spot pill (30-40 bbls):
SAFE -GARB 40 10 ppb
No _ _•�:: S 4FE-C'ARB '_ W 20 ppb
SAFE-C ARB 500 5 ppb
SAFE-C ARB 750 5 ppb
Note - Thin fluid back
slightly if possible Mth
6% KCl brine.
Total loss of retturas
Squeeze pill:
FOR►I A-BLOK
HENo N gym: 40 ppb iu 3% KCl brine
weighted up to
desired density.
Note - Pill should be a nuiuiuunnt
of 1.5 itmes the length of thief
zone
Contact project enghteer prior
for approml
I No maces. I
Spot plug:
Gunk Squeeze or Cement
Plug
Description: Stuck pipe due to drilling fluid overbalance in a permeable sand zone.
Mitigation: Pipe movement through rotation and reciprocation at all possible times will significantly
reduce the risk of differential sticking. The use of a statically underbalanced mud system with MPD
further reduces the risk of differential sticking by removing the pressure differential that causes stuck
pipe. Finally, minimal wellbore bridging material is being used in the production mud system which
should lead to thinner wall cake thickness and reduced risk of differential sticking.
Attachment 4 Drilling Hazards Summary
Pore Pressure Uncertaint
Risk: High
Description: Estimated pore pressure based on North Tarn 1A well test, North Tarn 1 SIDPP, and
upcoming CPAI offset wells is a 10.8 ppg EMW. Potential for reservoir overpressure up to 12.2 ppg EMW
has been encountered in offset wells.
Mitigation: Managed Pressure Drilling (MPD) will be used to monitor pore pressure in order to
accurately determine the Kuparuk C reservoir pressure. MPD will also be used to hold surface
backpressure to keep bottomhole pressure at or above reservoir pressure at all times. In the event high
reservoir pressure (11.3 ppg - 12.2 ppg) EMW is encountered, the NaBr killweight fluid that will be on
location can be used as a base to build a suitable drilling fluid prior to drilling ahead.
Shale Instabilit
Risk: Medium
Description: Mechanical instability in the exposed Kalubik beneath the 7" casing shoe can cause
significant packoff issues while tripping out of the hole with the drilling BHA and while running larger OD
completion jewelry into the hole.
Mitigation: An inhibited mud and managed pressure drilling will be utilized to control shale instability.
6% KCI and minimum 2% KLA-SHIELD will be run in the production drilling fluid at all times. Managed
pressure drilling will be utilized to maintain a constant bottomhole pressure across the exposed shales
by trapping pressure equal to drilling ECD at the shoe, while maintaining a static wellbore pressure
above reservoir pressure, in order to reduce pressure cycles and the resulting mechanical fatigue on the
shales.
Lost Returns
Risk: Medium
Description: Partial or complete loss of returns while drilling due to circulating pressure above reservoir
pressure or fracture gradient as well as potential losses due to fault crossings.
Mitigation: MPD with a Coriolis meter will be used during well operations to keep circulating pressures
low by reducing static mud weight and allowing real time, precise measurement of flow out to spot
losses as soon as they occur. No significant fault crossings are expected on this lateral. Should losses
occur, the below LCM decision tree has been prepared.
Attachment 5 Formation Integrity and Leak Off Test Procedure
Previous 7" casing shoe FIT work:
Well:
Mustanq #1
Mustang #1A ST
Date:
2/17/12
5/15/15
Mud Weight:
12.8 ppg
12.3 ppg
TVD:
6044'
6051'
Pressure:
1134 psi
1100 psi
FIT:
16.4 ppg LOT
16.8 ppg FIT
Attachment 6 Drilling Fluids Program
PROPERTIES AND
SPECIFICATIONS
PRODUCTION
Hole Sire
6.125"
From (MD)
9,124
To (MD)
14,738
Length of Sect,'
5.614'
Hole Angle
51 - 900(99°Sump)
Mud System
FLO-PRO NT
Mud Weight - ppg
10.1
Plastic Viscosity- cP
ALAP
Yield Point - IbJI00ft2
13-25
LSYP - Ib./100ft2
4-7
Gel Strengths 10slf
6-10/8-15
API Fluid Loss - cc/30 min
<6
Modified HTHP Fluid Loss - W30ming 160°F
<10
pH
9.0 -10.5
Chlorides - mg1L
100k -160k
Hardness as Cam - mg/L
< 100
Sand Content
t0.25%
MBT - IbJbbl.
<3
Drill Solids - Y Vol
<3
Attachment 7 Drilling Procedure
Brooks Range Mustang 1A Side Track Operations Procedure
Pre-Rin Work
1) Install wellhead shelter for pre -rig work.
2) Function test and pressure test Vetco Gray wellhead and tree.
3) Pressure test and chart 7" casing to 250 psi low / 3500 paLhigh for 15 mins using
Little Red Services.
4) Secure well with backpressure valve in the tubing hanger.
5) Grade and prep pad for Doyon 25.
6) Remove wellhead shelter prior to Doyon 25 spotting over well.
Rig Operations
1) MIRU Doyon 25.
2) Pressure test and chart 7" casing to 250 psi low / 3500 psi high for 15 mins.
3) Pull Vetco Gray tree.
4) Rig up BOPE.
5) Pull BPV and install two-way check valve in tubing hanger.
6) Test BOPE and choke manifold to 4,000 psi, annular to 3,500 psi.
7) Pull two-way check valve.
8) Circulate out freeze protect through kill string at 1,415' MD with fresh water or
seawater.
9) Unseat tubing hanger and pull kill string.
10)Pick up and rack back sufficient 4" DP to TD the well.
11)PU and RI with drill out BHA.
12)RIH on 4" DP to 3500' MD.
13)Perform MPD bearing installation and connection ramp training with crews.
NOTE: Managed Pressure drilling will be utilized for drilling this sidetrack. See
the below Managed Pressure Drilling Procedures & Guidelines for detailed
information.
14)RIH on 4" DP to-8,903' MD and tag cement above top of EZSV.
15)Circulate out the 9.8 ppg completion brine, replacing with 10.1 ppg Flopro NT
system.
16)Drill out cement to the top of the EZSV at 9,020' MD.
Attachment 7 Drilling Procedure
17)Begin drilling out EZSV, drilling in 1' increments, shutting down to check for
reservoir pressure after each increment.
The base plan for the initial clean -out of this well from just below the 7"
EZSV to the top of the Kuparuk C sand will be to shut down at various points in
the clean -out to confirm the actual pore pressure of the C-sand, assuming the
well will be in an under -balanced condition with the planned 10.1 ppg mud in the
well and over -balanced when circulating ECD's are in place. After confirming the
actual pore pressure of the well, the mud weight will be increased or reduced to
target a requirement for -300 psi backpressure during static well operations.
18)Continue to drill out cement to the 7" shoe at 9,117' MD.
19)Circulate 2x BU and shut in to check for wellbore pressure.
20)RIH with pumps on, attempting to stay in old wellbore. If cement or fill is
encountered, PU 5' then drill through cement or fill until WOB disappears, then
attempt to continue to wash in the hole.
21)RIH / clean out well to current TD and drill to the Kuparuk C sand target (-6907'
TVD).
a. If unable to stay in the old wellbore execute an open -hole sidetrack and
drill ahead per directional plan 9.
b. If significant wellbore issues or shale stability problems are encountered in
t the open hole below the 7" shoe, a contingency sidetrack from the 7"
casing will be considered (to be detailed in a separate procedure).
22)Circulate 2x BU.
23)Shut down and monitor wellbore pressure.
24)Pump out of the hole with drill out BHA to 7" shoe, racking back 4" DP.
25)Swap 7" casing to kill weight brine.
26)Strip out of the hole, utilizing MPD to hold backpressure to offset swab, to the
first drill collar.
27)Pull MPD bearing and element, POOH and lay down BHA.
28)MU geosteering BHA and RIH.
29)Install MPD bearing and element.
30)RIH on 4" DP to 7" shoe.
31)Swap 7" casing to Flopro NT mud system, weighted to allow 300 psi
backpressure with MPD during connections based on highest seen reservoir
pressure.
32)RIH to TD.
33)Begin drilling ahead per directional plan 9.
a. Utilize MPD to maintain constant bottom hole pressure on the exposed
shales.
Attachment 7 Drilling Procedure
b. Utilize ECD while pumping and MPD on connections to keep wellbore
pressure at or above reservoir pressure.
34)Drill to TD at —14,739' MD.
35)Circulate 3x BU at TD at full drilling rate, pulling 1 stand per BU.
36) Backream out of the hole to the 7" shoe.
a. Perform a wiper trip if hole conditions require.
37)Once the bit is in the 7" shoe, circulate 1 x BU with Flopro NT, then swap the
casing to kill weight brine.
38)Strip out of the hole, hold MPD backpressure to offset swab, until the last stand
of drill pipe. Continue to rack back 4" drill pipe.
39) Pull the MPD bearing and element on the last stand of drill pipe.
40)POOH and lay down the geosteering BHA.
41)Rig up casing running equipment.
42)Begin making up and RIH with 4-1/2" liner completion —per completion tally.
a. Liner completion will have float equipment in the shoe to allow MPD
operations.
43)Make up liner top hanger & packer and running tool.
44)Cross over to 4" DP.
45)RIH with 4" DP to the 7" shoe.
46)lnstall MPD bearing and element.
47)Swap 7" casing to Flopro NT.
48)RIH with liner to TD.
a. Hold backpressure with MPD to stay above reservoir pressure, and
minimize pressure cycles on the shale due to surge while running in the
hole.
49)Circulate 1x BU with liner at TD.
50)Set liner top hanger and packer.
51)Pressure test liner top packer to 3,500 psi.
52)Perform negative test on liner top packer and liner body.
a. Since the static mud weight will be underbalanced, shut in the chokes with
no trapped pressure and monitor for pressure buildup.
53)Swap the 7" casing to kill weight brine.
54)POOH, laying down drill pipe.
55)RU to run 4-1/2" upper completion.
56)RIH with upper completion to the liner top.
Attachment 7 Drilling Procedure
57)Space out upper completion, and pick up 5' out of liner top.
58)Circulate well to completion fluid, with inhibited fluid from the liner top to the
lowest gas lift mandrel. Ensure wellbore is surface to surface with clean fluids.
59) Pick up and land tubing hanger.
60) Drop ball and rod.
61)Set tubing production packer.
62)Pressure test tubing from the back side to 3,500 psi.
63)Shear SOV in upper gas lift mandrel and circulate freeze protect.
64)Allow freeze protect to U-tube in tubing and annulus.
65)Set BPV in tubing hanger and test from below.
66) RD BOPE.
67)RU production tree.
68)Pull BPV and set two-way check.
69)Test tree against two-way check.
70)Pull two-way check, install BPV.
71) RDMO rig.
Post -Rip Work
1) Install wellhouse.
2) Pull BPV.
3) Rig up slickline.
4) Pull shear valve from upper GLM and install valves as required.
5) Pull ball and rod.
6) RDMO slickline.
7) Rig up workover coil.
8) RIH with coil and shift frac sleeves open.
9) Displace tubing if necessary to start production.
10)RDMO coil.
11)Put well on production.
Attachment 7 Drilling Procedure
Managed Pressure Drillinq Procedures & Guidelines
As a Managed Pressure Drilling system (MPD) will be used to drill this well, please note
the following comments as they apply to the application of this technology as it relates
to this rotary sidetrack:
• MPD employs the use of a rotating head positioned above the rig's annular
preventer to seal around the drill string and a series of valves and chokes to
allow the operator to hold back -pressure on a well so that the well can be safely
and efficiently drilled using an effective mud weight density below that of the pore
pressure of the well, as in the case of this well:
o Anticipated Pore Pressure: 10.8 ppg (3358 psi)
o Anticipated Mud Weight: 10.1 ppg (3140 psi)
o Modeled ECD at the Shoe: 11.3 ppg (3513 psi)
■ Modeled ECD at the shoe will be sufficient for the well to be
overbalanced with pumps on at drilling rate (w250 gpm)
o MPD Backpressure during Pumps Off: -375 psi
■ Static mud weight plus backpressure gives a total static pressure
on the wellbore of -3,515 psi, sufficient to overbalance the well.
■ Ramp schedules will be created using hydraulics modeling software
and checked against downhole PWD data to allow the well to stay
overbalanced during the transition from drilling rate to pumps off.
■ The MPD system can be utilized to apply `mud weight on demand'
via surface pressures up to 700 psi (half the rated surface pressure
of the equipment, as an additional safety factor), equaling a static
mud weight of 12.3+ ppg (3,840 psi). This allows mud weights to be
increased prior to a well control event occurring.
• Use of the MPD system and the attached Coriolis meter will allow identification
and mitigation of wellbore breathing, brought on by the additional pressure
exerted on the wellbore by ECD.
c Precise pore pressure determinations can be made utilizing the MPD
system to improve the safety and efficiency of future development
operations.
• Additionally, use of the MPD system will reduce pressure cycles on the exposed
shale, mitigating the risk of mechanical breakdown of the shale and the hole
problems that follow.
• A kill weight brine, with adequate overbalance, will be used to displace the 7"
casing prior to surface trips.
�.
I EaaVK PoMr
Sqn Tlp[1C
� C�lS EtN
�EO1
Attachment 7 Drilling Procedure
e-balance System Diagram
ConocoPhillips, Alaska
MI Swaco e-balance System Diagram
n�u swag
*Note: This is the same system currently being utilized by ConocoPhillips Alaska in the Kuparuk and Alpine Fields
Attachment 7 Drilling Procedure
Down 25 MPD System Rig Up Diaclram
2" line manifolded to
the rig pumps allows
fluid to be pumped over
the top of the well while
stripping out of the hole
or to compensate for
pressure bleed off /
fluid losses downhole.
L.— _
Bearing assembly &
element seal in RCD and
around drill pipe to
direct flow down the 4"
line.
Rig Pumps 2" une�
Pressure transducers (2
on the RCD and 1 on the
wellhead) monitor
system backpressure
Dntlingfluid is returned
to pit system vla 4"
outlet line tied into flow
line.
Box
Choke controls
RCD 4" U _ backpressure on
1�=,I ,��1�_j�l� welibore.
Annular
Gut line allows chokes
to be bypassed If
necessary.
4" Une
Davies, Stephen F (DOA)
From:
Blake Ardrey <blake.ardrey@fairweather.com>
Sent:
Tuesday, October 23, 2018 11:27 AM
To:
Boyer, David L (DOA)
Cc:
Davies, Stephen F (DOA)
Subject:
Re: [*EXT*] RE: Mustang 1A Survey File
Attachments:
Mustang 1 B (P9) plan survey full.xlsx
Dave,
Attached is the full directional plan from SLB, matching the 14,735' TD on the cover page. Sorry for the confusion.
Thanks,
Blake Ardrey
Drilling Engineer- Fairweather
0: 907-270-6805
C: 713-503-4705
blake.ardrev@fairweather.com
On Tue, Oct 23, 2018 at 10:33 AM Boyer, David L (DOA) <david.boyer2@alaska.gov> wrote:
Blake,
I am working on the Permit to Drill for Mustang 1B. I noticed that the original directional plan for previous name of 1A
is WP 9 as is the new plan labelled 1B in the current submission. In the Excel file for 1A, the tops differ from the 1B
survey set and the T.D. is 14,738.70' vs. 14,734.89' (4' difference) in the 1B package. The 14,735' T.D. matches the data
on the cover page. Can you please send over the digital version of the current 1B directional plan from surface. It
appears that some minor tweaks were made even though it is also P9.
Thanks,
Dave Boyer
AOGCC
From: Blake Ardrey <blake.ardrev@fairweather.com>
Sent: Monday, October 15, 2018 11:49 AM
To: Boyer, David L (DOA) <david.boyer2@alaska.gov>
Subject: Re: [*EXT*] RE: Mustang 1A Survey File
1
David,
Attached is the full well plan in Excel format.
Please let me know if you need anything else.
Thanks,
Blake Ardrey
Drilling Engineer- Fairweather
O: 907-270-6805
C: 713-503-4705
blake.ardre\/@fairweather.com
On Mon, Oct 15, 2018 at 10:21 AM Boyer, David L (DOA) <david.boyer2@alaska.gov> wrote:
Hi Blake,
Please send over the full directional package for the wellbore to surface. That will be more straight forward for
loading into our program, starting with a fresh well file.
Thank you,
Dave Boyer
AOGCC
From: Blake Ardrey <blake.ardrey@fairweather.com>
Sent: Monday, October 15, 2018 10:08 AM
To: Larry Vend[ <Ivendl@brpcak.com>
Cc: Boyer, David L (DOA) <david. boyer2@alaska.gov>
Subject: Re: [*EXT*] RE: Mustang 1A Survey File
Good Morning David,
Will the directional file as its included in the Permit to Drill package work? The submitted directional package begins at
a tie in point to the currently existing Mustang 1A wellbore. Or I can send over a full directional package for the
wellbore to surface. Either is fine with me, just let me know what your preference is.
Thanks,
Blake Ardrey
Drilling Engineer- Fairweather
0: 907-270-6805
C: 713-503-4705
blake.ardrev@fairweather.com
On Mon, Oct 15, 2018 at 9:49 AM Larry Vendl <Ivendl@brpcak.com> wrote:
Hi Dave, good to hear from you!
I am going to cc this request on to Blake Ardrey. He is the primary contact for planning over at Fairweather. I have
the survey file, here, but I want to make sure that you get the most recent file which is included in the application.
Blake, can you forward the appropriate survey file to Dave?
Thanks,
L■ITJ
From: Boyer, David L (DOA) <david.boyer2@alaska.gov>
Sent: Monday, October 15, 2018 9:02 AM
To: Larry Vendl <Ivendl@brpcak.com>
Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: Mustang 1A Survey File
Hi Larry,
We meet again!
We received the Permit to Drill package on 10/11 for the Mustang 1A well and are beginning the review process. We
have been asking all operators, if possible, to e-mail over the survey file in Excel or ASCII digital format for faster
input into the Geographics program used here. The whole file is fine, but we only input MD, Inclination, and
Azimuth, and the program generates the rest. Due to the size of the print, I am sure that scanning errors would be a
problem on this one.
Thank you,
Dave Boyer
AOGCC
Davies, Stephen F (DOA)
From:
Larry Vendl <Ivendl@brpcak.com>
Sent:
Friday, October 19, 2018 1:03 PM
To:
Boyer, David L (DOA); Davies, Stephen F (DOA)
Cc:
'Blake Ardrey'
Subject:
Mustang #1 B cover page correction
Steve and Dave,
I just noticed that there is an error on the cover page for the Mustang 1B permit. I inadvertently left Joe Longo's name as
a contact (I should have changed it to Blake or 1), Joe was working for us during the last drilling phase. Please line that
out and replace his name with mine at (907)-865-5811 or my cell at 223-6837. Either Blake or I can answer any
questions you may have.
Sorry for the mix up.
DI
Lawrence I Vendl
Brooks Range Petroleum
Manager
Exploration & Subsurface Projects
907-865-5811 Work
(907) 223-6837 Mobile
(907) 274-4781 Home
Ivendl@brpcak.com
510 L Street, Suite 601
Anchorage, AK 99501
Davies, Stephen F (DOA)
From: Davies, Stephen F (DOA)
Sent: Wednesday, October 17, 2018 9:53 AM
To: 'Blake Ardrey'
Cc: Larry Vendl; Boyer, David L (DOA); Schwartz, Guy L (DOA)
Subject: RE: [*EXT*] Mustang 1A Re-entry Permit to Drill Application (PTD 218-124) - Comments,
Requests, and Questions
Blake,
Yes, please. That way, the record will be clear.
Thanks for your help,
Steve Davies
Alaska Oil and Gas Conservation Commission (AOGCC)
907-793-1224
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: Blake Ardrey <blake.ardrey@fairweather.com>
Sent: Wednesday, October 17, 2018 8:53 AM
To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Cc: Larry Vendl <Ivendl@brpcak.com>; Boyer, David L (DOA) <david. boyer2@alaska.gov>; Schwartz, Guy L (DOA)
<guy.schwartz@alaska.gov>
Subject: Re: [*EXT*j Mustang 1A Re-entry Permit to Drill Application (PTD 218-124) - Comments, Requests, and
Questions
Steve,
One final question: since we will be resubmitting the attachments per our earlier conversations, and the well name has
been changed from "Mustang 1A" to "Mustang 1B", would you like the 10-401 resubmitted as well with the updated
well name?
Thanks,
Blake Ardrey
Drilling Engineer- Fairweather
0: 907-270-6805
C: 713-503-4705
blake.ardrev@fairweather.com
On Tue, Oct 16, 2018 at 11:49 AM Davies, Stephen F (DOA) <steve.davies@alaska.gov> wrote:
Blake,
Regarding Attachment 2: For all of the pages that should be printed in landscape mode and the table of numbers
labeled Mustang 1A (139) Proposal EOU Report, most of the text is small enough that a magnifying glass is
required (in addition to my reading glasses) for me to see it clearly. Again, I'm focused on providing a complete
and legible scanned permanent record for each well.
Please provide copies of the finalized attachments. Whatever is in, or attached to, the application will be part of
the final, approved Permit to Drill.
Both the original and the duplicate copy of the Permit to Drill form and all attachments must be identical and
complete. Again, they will constitute the final, approved Permit to Drill.
Thank you for your help,
Steve Davies
AOGCC
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: Blake Ardrey <blake.ardrev@fairweather.com>
Sent: Tuesday, October 16, 2018 11:19 AM
To: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Cc: Larry Vendl <Ivendl@brpcak.com>; Boyer, David L (DOA) <david.boyer2@alaska.gov>; Schwartz, Guy L (DOA)
<guy.schwartz@alaska.gov>
Subject: Re: [*EXT*] Mustang 1A Re-entry Permit to Drill Application (PTD 218-124) - Comments, Requests, and
Questions
Steve,
1. I'm working on getting a better version of Attachment 1 and will send it over as soon as I have it. For Attachment 2,
which portion is illegible? Depending on where the issue is I might have to modify some portions of the submission
package so I want to make sure I'm not cutting out any information unnecessarily. Attached is an updated version of
Attachment 3 BOP Configuration that should be more legible.
2. Both Attachments 4 and 6 are correct versions, the mud program that the fluid loss flow chart and properties were
pulled from is still being finalized and therefore watermarked "DRAFT", but both those pieces are accurate.
3. 1 will check with Larry on the missing attachments for the submitted duplicate.
Thanks,
Blake Ardrey
Drilling Engineer- Fairweather
0: 907-270-6805
C: 713-503-4705
blake.ardrey@fairweather.com
On Tue, Oct 16, 2018 at 9:48 AM Davies, Stephen F (DOA) <steve.davies@alaska.gov> wrote:
Larry,
Brooks Range plans to re-enter the suspended Mustang 1A well, which in 2015 reached a TD of 9525' MD —short of
the originally permitted TD of 14,737' MD. Mustang 1A is currently suspended with a cement plug that has a top at
8903' MD. The AOGCC's well history, printed well log files, and digital well log files for this well contain a very large
number of items that are labeled with the well name "Mustang 1A, the Permit to Drill number 215-059 and the API
Number of 50-103-20652-01-00. The digital files submitted by Brooks Range for the existing wellbore (dataset
T26037) are stored in a folder labeled "Mustang 1A FINAL LOGS". An accompanying PDF file is labeled "Mustang 1A
FINAL END OF WELL REPORT." The digital directional survey data submitted by Brooks Range (dataset T26032) are
stored in a folder labeled "Final Survey Data."
To avoid any confusion between the existing data and data that will be collected from Brooks Range's planned re-
entry and drilling operations, the permanent record will be clearest if we label this planned re-entry with a new
wellbore name (Mustang 113), a new Permit to Drill number (218-124), and a new API Number (50-103-20652-02-00).
This will unmistakably separate existing information from records obtained during the planned drilling operations. The
alternative is for Brooks Range to re -submit a complete set of history, printed log, and digital well log files for the
existing Mustang 1A wellbore with every printed item re -labeled with the wellbore name "Mustang 1APB1" with an
API Number of 50-103-20652-70-00 and every digital file revised accordingly.
Regarding current Permit to Drill application:
1.Attachments 1, 2 and 3: The font size is within the provided displays so small and several of the reproductions
are so poor that the attachments are essentially unusable. All of the records in AOGCC's well history files are
scanned for archival purposes and processed using Optical Character Recognition (OCR) software for user
convenience. The quality of these attachments is insufficient for either of those purposes. Please re -submit
legible attachments.
2.Attachments 4 and 6 are watermarked "Draft." Are these the correct versions?
3.Please note that Attachments 5, 6, and the step-by-step drilling procedure in Attachment 7 are missing from the
submitted duplicate copy.
Thank you for your help,
Steve Davies
AOGCC
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.
TRANSMITTAL LETTER CHECKLIST
WELL NAME: M Us -f Ci to o
PTD:
VDevelopment _ Service _Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD:■.• . POO•
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
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sam le 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. hi 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 S MILUVEACH, KUPARUK RIVER OIL - 764150
Well Name: MUSTANG 1B — - -Program DEV _ Well bore seg ❑
PTD#:2181240 Company BROOKS RANGE PETROLEUM —_ -- Initial Class/Type
DEV / 1-OIL GeoArea 890 Unit 11965 —__ On/Off Shore On Annular Disposal ❑
Administration I17
Nonconven. gas conforms to AS31.05.030(j.1.A),0.2.A-D)
NA
1
Permit fee attached
NA
2
Lease number appropriate
Yes
3
Unique well name and number
Yes
4
Well located in a defined pool
Yes
5
Well located proper distance from drilling unit boundary
Yes
6
Well located proper distance from other wells
Yes
7
Sufficient acreage available in drilling unit
Yes
8
If deviated, is wellbore plat included
Yes
9
Operator only affected party
Yes
10
Operator has appropriate- bond in force -
Yes
Appr Date 11
Permit can be issued without conservation order
Yes
12
Permit can be issued without administrative approval
Yes
DLB 10/22/2018
13
Can permit be approved before 15-day_wait
Yes
14
Well located within area and strata authorized by Injection Order # (put 10# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only) -
NA_
16
Pre -produced injector: duration of pre -production Less than_ 3 months (For service well only)
NA
18
Conductor string provided
NA_
Mustang 1 well has conductor set
Engineering
19
Surface casing protects all known_ USDWs
NA
Permafrost area. No aquifers,
20
CMT vol adequate to circulate on conductor_ & surf csg
NA
21
CMT vol adequate to tie-in long string to surf csg
NA
22
CMT will cover all known productive horizons
Yes
Horizontal lateral will have 4.5 liner with frac sleeves and swell packers. No cement
23
Casing designs adequate for C, T, B & permafrost
Yes
24
Adequatetankageor reserve pit
Yes
All waste -to be transported toapproveddisposal well offsite.
25
If a re -drill, has -a 10-403 for abandonment been approved
Yes
Will administratively abandon wellbore Mustang 1A
!26
Adequate wellbore separation proposed
Yes
No issues with collision.
27
If diverter required, does it meet- regulations
NA
Wellhead in place. Will place BOPE on wellhead.
Appr Date 28
Drilling fluid program schematic & equip list adequate
Yes
Max form_ pressure= 3423psi _(10.8ppg EMW) will drill with MPD and 10.1 ppg mud. FloPro NT
GLS ITO3/2018
29
BOPEs, do they meet regulation
Yes
Rig has 13 5/8" 5000 psi BOPE
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
MASP = 2816 psi Will test BOPE to 4000 psi
�32
31
Chokemanifoldcomplies w/API RP-53 (May 84)
Yes -
Drilling well with Doyon Rig 25 - - -
Work will occur without operation shutdown
Yes
May frac well in future.,.-CBL_is required.
33
Is presence of H2S gas probable
Yes
H2S in area. 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
Geology
36
Data -presented on potential overpressure zones
Yes
Appr Date 137
Seismic analysis of shallow gas zones
NA
DLB 10/22/2018 '38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports_ [exploratory only]
NA
Geologic
Engineering
Public
Well is currently suspended with cement plug set across intermediate 7" casing shoe. Will drill out cement and finish the
Commissioner:
Date:
Commissioner:
Date C
Date horizontal lateral to complete. GIs
