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HomeMy WebLinkAbout218-154Winston, Hugh E (CED)
From:
Winston, Hugh E (CED)
Sent:
Tuesday, December 22, 2020 2:46 PM
To:
tom.g.polasek@conocophillips.com
Cc:
Loepp, Victoria T (CED)
Subject:
MT6-07 Permit Expired
Hi Tom,
The permit to drill for well MT6-07 which was issued to CPAI on December 6th 2018 has expired under regulation 20 AAC
25.005 . 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
hugh..winston alaska,gov
907-793-1241
THE STATE
°'ALASKA
--
GOVERNOR MIKE DUNLEAVY
Graham Alvord
Drilling Manager
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99501-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Greater Mooses Tooth Field, Lookout Oil Pool, MT6-07
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 218-154
Surface Location: 275' FNL, 3208' FEL, SEC. 6, TION, R3E, UM
Bottomhole Location: 3149' FNL, 1682' FEL, SEC. 36, TI IN, R2E, UM
Dear Mr. Alvord:
Enclosed is the approved application for the permit to drill the above referenced service 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
DATED this (',0 day of December, 2018.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
NOV 0 7 2018
A C) r. r.
1a. Type of Work:
1 b. Proposed Well Class: Exploratory -Gas ElService - WAG El • Service - Disp ❑
1 c. Specify I well is rop posed for:
Drill Q . 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 0 Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. l
MT6-07
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 14766 TVD 7,966
Greater Mooses Tooth Unit
Lookout Pool /
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 275' FNL, 3208' FEL, Sec. 6, T10N, R3E, UM
AA092346 , AA081798,�AA092342
Top of Productive Horizon:
8. DNR Approval Number:
13. Approxim a Spud Da
1605' FNL, 2772' FEL, Sec. 1, T10N, R2E, UM
932533 340760 340763
1/1 19
Total Depth:
9. Acres in Property:
14. Dist6nce to Nearest Property:
3149' FNL, 4682' FEL, Sec. 36, T11 N, R2E, UM
607, 2557, 3837
4518' to AA081818
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 89 0
15. Distance to Nearest Well Open
Surface: x- 317023 y- 5945530 Zone-4
GL / BF Elevation above MSL (ft): 52.4 #
to Same Pool: 2250' to MT6-06
16. Deviated wells: Kickoff depth: 437 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 95 degrees
Downhole: 3625 Surface: 2824
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)
42"
20"
94
H-40
Welded
80
34
34
115
115
10 yds
16"
13.375"
68
L-80
TXP/BTC-IV
2091
34
34
2125
2029
1001 sx 11.0 ppg DeepCrete,330 sx 15.8 ppg G
12.25"
9.625"
40
L-80
BTC-M
9126
34
34
9160
7417
218 sx 15.8 ppg tail
8.75"
7. 0"
26
L-80
Blue
10541
34
34
10575
8012
147 sx 15.8 ppg tail
6"
4.5"
12.6
L-80
ITXP 1
4341
104251
79811
147661
79661
uncemented perf pup liner
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes ❑ No , mus 1g
20. Attachments: Property Plat ❑ BOP Sketch
Drilling Program Time v. Depth Plot Shallow Hazard Analysis
❑ ❑ 8 e
Diverter Sketch
Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval. Contact Name: Tom Polasek
Authorized Name: Graham Alvord (265-6120) Contact Email: Tom. . oIasek ConocoPhilll S.
Authorized Title: Drilling Manager Contact Phone: 907-263-3740
Authorized Signature: ��- G✓r Date: t % W ! Z o (ti'j
Commission Use Only
Permit to Drill
API Number:
Permit Approval
See cover letter for other
Number: a
50- p 3 p �� Q o
Date: 1 2
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: SaTn les re d: Yes No Mud to
� ftS .7� b 1 y (7 O / p q' ❑ g req'd: Yes ❑ No
/� v g r- ✓ 7 /� /T f � f f ra 2 5 U(%Ij 0Z8 r asures: Yes ❑ No Y Directional svy req'd: Yes [pNo ❑
p % ✓r r" r vcf, r-7 Gt n C Spacing exception req'd: Yes ❑ No EV Inclination -only svy req'd: Yes � No Y
Post initial injection MIT req'd: Yes No ❑
q�-q � to <1 `J
'bb5(/rvzmeq
,
,�i/�rn� f G°i!1Mf�f )w (-7
�f�
ati in�t✓rn�c,li #f Z 615 Soovi Gt5
CpL-r5v/fs and ,v��Yrp�ct��/�, a5 sovrr CI �t✓a�labt e .
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
fo�� Submit Form and
Form 10-401 Revised 5/2017 his rmis valid o
V N
Lproval per 20 AAC 25.005(g) Attachments in Duplicate
i
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
October 17th, 2018
Alaska Oil and Gas Conservation Commission
333 West 71h Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill MT6-07
Dear Sir or Madam:
ConocoPhillips
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the MT6 drilling pad. The
intended spud date for this well is January 1st, 2019. It is intended that Doyon Rig 19 be used to drill the well.
MT6-07 is planned to be a horizontal Alpine C sand injector. The 16" surface hole will TD above the C-30 sand and then 13-
3/8" casing will be set and cemented to surface. The intermediate hole will be drilled in two sections to mitigate issues with
shale instability over the long interval. The 12-1/4" intermediate #1 section will be drilled into the top of the FIRZ and landed
at an inclination of — 45°. A 9-5/8" casing string will be set and cemented from TD to secure the shoe and cover 500' above it
as no hydrocarbon -bearing zones are expected in this interval.
The second intermediate will be drilled with one of two options, ultimately landing in the Alpine C sand. Option 1, a 7"
steerable liner drilling assembly consisting of a 6" pilot BHA ahead of the casing shoe and incorporate a 8-3/4" underreamer
for increased annular clearance. The drilling assembly inner string will then be tripped and a cement assembly run into the hole
to cement the 7" drilling liner annulus. Option 2, will use an 8-3/4" drilling assembly and under reamed to 10 '/4". The section
will then be lined with a 7" Liner. Mana eg d Pressure Drilling technology will also be utilized to assist with providing stability
through the HRZ, Kalubik, and Miluveach formations. This interval will build from 45' to 85' inclination..
The production interval will be comprised of a 6" horizontal hole that will be geo-steered in the Alpine C sand. The well will
be completed as an unstimulated injector with 4.5" liner with pre -perforated pup joints and tied back to surface with a 4.5"
tubing upper completion string.
It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there has not been a
significant indication of shallow gas or gas hydrates through the surface hole interval.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Tom Polasek at 263-3740
(tom.g.polasek@conocophillips.com) or Chip Alvord at 265-6120.
Since i"y, �f cc:
MT6-07 Well File /Ann Haggerty-Sherrod ATO 1530
Johnson rATO 10
Chip Alvord ATO 157570
Tom Polasek John Cookson ATO 1750
Drilling Engineer
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
MT6-07
Application for Permit to Drill Document
e'Ye'b+.
11
wl
!7
Al
ConocoPhillips
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (9)...............................................................3
2. Location Summary (Requirements of 20 AAC 25.005(c) (2))..............................................3
Requirements of'20 AAC 25.050(b)......................................................................................................... 3
3. Blowout Prevention Equipment Information(Requirementsof20AAC25.005(c)(3)) 3
4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ..........................4
5. Procedure for Conducting Formation Integrity Tests (Requirements of20AAC25.005
0 (5))...............................................................................................................................5
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))............5
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) ...........................5
8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c) (8)) ......................................6
9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9))
........................................................................................................................................7
10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10))............................................7
II.Seabed Condition Analysis (Requirements gf20 AAC 25.005 (c)(11)) ..........................7
12. Evidence of Bonding (Requirements of20AAC 25.005(c)(12)).....................................7
13. Proposed Drilling Program (Requirementsof20AAC25.005(c)(13))...........................7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ........................9
(Requirements of 20 AAC 25.005 (c)(14))................................................................................9
15. Attachments..................................................................................................................11
MT6-07 APD
Page 1 of 19
Printed. 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Attachment 1 Cement Summary ........................................................................................................... 11
Attachment 2 Drilling Hazards Summary .............................................................................................. 11
Attachment 3 Completion Schematic.................................................................................................... 11
Attachment 4 Area of Review............................................................................................................... 11
Attachment S Directional Plan............................................................................................................ 11
MT6-07 APD
Page 2 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
1. Well Name (Requirements of 20 AAC 25.005 (9)
The well for which this application is submitted will be designated as MTU MT6-07
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface
275' FNL, 3208' FEL, Sec. 6, T10N, RM, UM
NAD 1927
RKB Elevation
89' AMSL
Northings: 5,945,530
Eastings: 317,023
Pad Elevation
52.4' AMSL
Top of Productive Horizon eel
1605' FNL, 2772' FEL, Sec. 1, T10N, R2E, UM
NAD 1927
Northings: 5,944,313
Eastings: 312,410
Measured Depth, RKB:
10,558'
Total Vertical Depth, RKB:
8,009'
Total Vertical Depth, SS.
7,920'
Total Depth Toe
4177' FNL, 4158' FEL, Sec. 36, T11N, R2E, UM
NAD 1927
Northings: 5,948,096
Eastings: 310,593
Measured Depth, RKR:
14,766'
Total Vertical De th, RKB:
7,966'
Total Vertical De th, SS:
7,877'
Requirements of 20 AAC 25.050(b)
Please see Attachment 4: Directional Plan
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information (Requirements of20AAC25.005(c)(3))
Please reference BOP schematic on file for Doyon 19.
MT6-07 APD
Page 3 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
4. Drilling Hazards Information (Requirements of20AAC25.005 (c)(4))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well:
Casing
Size in
Csg Setting Depth
MD/TVD ft
Fracture
Gradient(psi)
Pore pressure
ASP Drilling
(psi)
20
1151115
10.9
52
54
13.375
2125 / 2029
14.5
918
1327
9.625
9160 / 7417
13.5
3356
2824 •
7
10575 / 8012
12.5
3625
2808
4.5
14766 / 7966
12.5
3605
N/A
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient
to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows:
1) ASP = [(FG x 0.052) - 0.1]*D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP =FPP - (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.4525 x TVD
1. ASP CALCULATIONS
Drilling below 20" conductor
ASP = [(FG x 0.052) - 0.1] D
_ [(10.9 x 0.052) - 0.1] x 115 = 54 psi
OR
ASP = FPP - (0.1 x D)
= 918 - (0.1 x 2029) = 714 psi
2. Drilling below surface casing (13-3/8")
ASP = [(FG x 0.052) - 0.1] D
= [(14.5 x 0.052) - 0.1] x 2029' = 1327 psi
OR
ASP = FPP - (0.1 x D)
= 3356 - (0.1 x 741 T) = 2614 psi
Drilling below first intermediate casing (9-5/8")
ASP = [(FG x 0.052) - 0.1] D
_ [(13.5 x 0.052) - 0.1 ] x 7417 = 4465 psi
OR
ASP = FPP - (0.1 x D)
= 3623- (0.1 x 8012') = 2824 psi •
MT6-07 APD
Page 4 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
4. Drilling below production liner (7)
OR
ASP = [(FG x 0.052) — 0.1 ] D
= [(12.5 x 0.052) — 0.1] x 8012 = 4407 psi
ASP = FPP — (0.1 x D)
= 3605 — (0.1 x 7966) = 2839 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation
zones, and zones that have a propensityfor differential sticking;
Please see Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of20 AAC 25.005 (c)(5))
Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT / FIT procedure that
ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing and Cementing
Program
CsglTbg
Hole
Size
weight
Grade
Conn.
Length
Top MD/TVD
Btm MD7TVD
Cement Program
OD (in)
(Ib/ft)
(ft)
(ft)
(ft)
in
20
42
94
H-40
Welded
80
Surf
115 / 115
Cemented to surface with
10 yds slurry
H563/
Cement to Surface with
13-3/8
16
68
L-80
TXP
2,091
Surf
2,125 / 2,029
1001 sx DeepCrete Lead at 11.0 ppg,
330 sx Class G Tail Slurry at 15.8 ppg
TXP/
9-5/8
12-1/4
40
L-80
TN-80
9,126
Surf
9,160/ 7,417
218 sx Class G Tail at 15.8 ppg
HC
7
63/4
26
L-80
B C/
lue
10,541
Surf
10,575 / 8,012
147 sx Class G Tail at 15.8 ppg
4-1/2
n/a
12.6
L-80
Tue
10,391
Surf
10,425 / 7,981
n/a
4 1/2
6
12.6
L-80
TXP
4,341
10,425 / 7,981
14,766 / 7,966
Uncemeneted open hole liner w/ pre -
perforated pup joints
7. Dlverter System Information (Requirements of20AAC25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT6, there
have been five surface penetrations that have been completed and there has not been a significant indication of
shallow gas or gas hydrates above the C30 where casing will be set.
MT6-07 APD
Page 5 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
S. Drilling Fluid Program(Requirementsof20AAC25.005(c)(8))
Surface
Intermediate
Intermediate
Production
#1
#2
Hole Size in.
16
12.25
6.0 x 8.75
6.0
Casing Size in.
13.375
9.625
7
4.5
Density PPG
9.0-10.0
9.4-10.5
10.0-11.0
88-95
w/MPD •
PV cP
13
10
10
15
YP Ib./100
35-50
20- 28
20 - 28
15 - 20
Funnel s/qt.
200
40 - 50
40 - 50
60 - 80
Viscosity
Initial Gels Ib./100
50
10
10
10
10 Minute Ib./100
Gels ftz
60
15
20
15
API Fluid cc/30
Loss min.
N.C. — 15.0
5.0
5.0
4.0
HPHT Fluid cc/30
n/a
8.0 — 12.0
8.0 — 12.0
10.0
Loss min.
pH 1
11.0 1
9.5 — 10.0
9.5 — 10.0
9.0 — 9.5
Surface Hole:
A mixed -metal oxide freshwater drilling fluid (Drilplex) will be used for the surface interval. Keep flow line
viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud
weight <10.0 ppg by use of solids control system and dilutions where necessary.
Intermediate #1:
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid
annular velocity. Maintain mud weight from 9.4-10.5 ppg and be prepared to add loss circulation material. Good
filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in
maintaining wellbore stability.
Intermediate #2 with MPD:
Fresh water polymer mud system. Ensure good hole cleaning by maximizing fluid annular velocity. There is a slight
potential for lost circulation, particularly after the reservoir is penetrated. Ensure adequate LCM material is available
on location and in the field to address any expected losses. Maintain mud weight from 10.0-11.0 ppg. Good filter
cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in
maintaining wellbore stability. The mud will be weighted up to 10.3 ppg or higher before pulling out of the hole.
Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate /
shale instability and cycling.
Production Hole with MPD:
The horizontal production interval will be drilled with a water -based mud drill -in fluid FloPro weighted to 8.8-9.5
ppg with calcium carbonate. MPD will be used to hold back pressure, keeping the well dynamically balanced. V
Diagram of Doyon 19 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
MT6-07 APD
Page 6 of 19
Printed. 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program (Requirements of20AAC25.005(c)(13))
The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic.
L MIRU Doyon 19 onto GMTU MT6-07 over pre -installed 20" insulated conductor.
2. Rig up and test riser, dewater cellar as needed.
r
3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR).
4. Run and cement new 13-3/8" 68 ppf L-80 surface casing to surface.
5. Install BOPE with the following equipment/configuration: 13-5/8" annular preventer, 3-1/2" x 6" VBR, blind
ram and 3-1/2" x 6" VBRs.
6. Test BOPE to 250 psi low / 3500 psi high (24-48 hr. AOGCC notice, 72 Hr BLM notice).
7. Pick up and run in hole with 12-1/4" drilling BHA to drill intermediate #1.
8. Chart casing pressure test to 2500 psi for 30 minutes.
9. Drill out shoe track and 20' of new hole.
10. Perform LOT to maximum EMW of 18.0 ppg. Minimum LOT required to drill ahead is 12.5 ppg EM W.
Forward data to the AOGCC.
11. Displace well to 9.4 ppg LSND mud.
12. Drill 12-1/4" hole to the casing point as per directional plan. (LWD Program: GR/RES).
13. Circulate wellbore clean and POOH. 3 SOS
14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 2,0 psi high.
15. Run 9-5/8" intermediate casing to TD.
16. Pump single stage cement job to isolate the casing shoe and 500' MD or 250' TVD, whichever is larger, above
uppermost hydro -carbon bearing zone (none expected).
17. Change upper 9-5/8" solid body rams to 3-1/2" x 6" VBRs. Test BOPE to 250/3500 psi.
18. Pick up and run in hole with 8-3/4" bit and clean out assembly. Perform a LOT down the 13-3/8" x 9 5/8"
casing annulus with Ball Mill and freeze protect. Forward data to AOGCC.
19. Pressure test casing to 3000 psi for 30 minutes and record results.
20. Drill out shoe track and 20' of new hole.
MT6-07 APD
Page 7 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
21. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 12.5 ppg EMW.
22. Circulate wellbore clean and POOH.
23. Perform either Option 1 or Option 2
Option I
a. Pick up and run in hole with the 7" steerable drilling liner. Pick up and stab in 6" pilot BHA assembly.
(LWD Program: GR/RES).
b. RIH to bottom with 7" SDL on 5" drill pipe.
c. Drill 6" x 8-3/4" SDL hole to production casing point into the Alpine sand using Managed Pressure
Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES). ✓
d. Land 7" liner at TD. Disconnect SDL and POOH to surface with inner string and pilot.
e. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition mud in
preparations for cementing.
Option 2
a. Drill 8-3/4" x 10'/4" Int. 2 to production casing point into the Alpine sand using Managed Pressure
Drilling to maintain constant bottom hole pressure on connections. (LWD Program: GR/RES).
b. Circulate hole clean and POOH.
c. Pick up and run 7" liner to TD.
d. Circulate and condition mud in preparations for cementing.
24. Cement 7" liner from shoe to 250' TVD above Alpine Formation. Set liner top packer. Circulate bottoms up
from top of liner. POOH laying down 5" drill pipe.
25. Run 7" tie -back and engage seals. Space out to land hanger.
26. Displace 9-5/8" x 7" annulus to corrosion inhibited brine and diesel freeze protect. Land the 7" tie back hanger
and pressure test annulus and seals to 2000 psi for 30 min and chart.
27. Pick up 4" DP. Test BOPE to 250 psi low / 3,500 psi high.
28. Pick up and RIH with 6" drilling assembly. (LWD Program: GR/Azimuthal RES).
29. Chart casing pressure test to 3500 psi for 30 minutes and record results.
30. Drill out and perform FIT to 12.5. Minimum acceptable leak -off for drilling ahead is 11.0 ppg EMW.
31. Drill 6" horizontal hole to section TD (L)VD Program: GR/ Azimuthal RES).
32. Circulate the hole clean and POOH with drilling BHA.
33. Run in hole with 4.5" liner with pre -perforated pup joints on 4" drill pipe (CBL 7" Liner on way out of hole) '
34. Set liner top packer and release from liner. 4-6 ffD�
whir LiVa/labl�
35. Displace well to kill weight brine.
36. Run 4.5" upper completion.
37. Space out and land hanger.
38. Install HP back pressure valve and pressure test hanger seals to 5000 psi. Nipple down BOP.
39. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove back pressure valve.
MT6-07 APD
Page 8 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
40. Test tubing to 3500 psi/ 30 min and chart. Test tubing -casing annulus separately to 3300 psi / 30 mins and chart.
41. Shear circulation valve in GLM.
42. Circulate tubing to diesel and install freeze protection in the annulus.
43. Set BPV and secure well. RDMO.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AA 25.005 (e)(14))
Incidental fluids developed from drilling operations on well MT6-07 will be injected into a permitted surface casing
x production casing annulus on the MT6 pad or dedicated Class 1 disposal well CD1-01A.
The MT6-07 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze
protecting with diesel to 2000' TVD. Significant hydrocarbon zones include only the Alpine sand based on pre -drill
interpretations. There will be 250' TVD of cement placed above the top of the Alpine reservoir.
Once MT6-07 has been drilled and completed, consideration may be given to permit this well for annular injection.
An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to
drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any
zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no
USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the
enclosed directional drilling plan for other formation markers in this well.
Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500' thick shales are
part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas.
The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the
specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling
fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular
injection, the maximum pressure at the surface casing shoe is estimated by:
Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi
= (12.0 ppg) * (0.052) * (2,025') + 1,500 psi
= 2764 psi
Pore Pressure = 910 psi
Therefore
Differential = 2767 — 910 = 1854 psi.
The internal casing pressure is conservative, since frictional losses while pumping have not been taken into
consideration. The surface and intermediate casing strings exposed to the annular pumping operations have
sufficient strength by using the 85% collapse and burst ratings listed in the following table:
MT6-07 APD
Page 9 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
OD
wt
Grade
Range
Connection
Collapse
85%of
Burst
85%of
(ppf)
Type
Collapse
Burst
13-3/8"
68
L-80
3
BTC-M
2260 psi
1921 psi
5020 psi
4267 psi
9-5/8
40
L-80
3
BTC-M
3090 psi
2626 psi
5750 psi
4887 psi
MT6-07 APD
Page 10 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
15. Attachments
Attachment I Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Area of Review
Attachment S Directional Plan
MT6-07 APD
Page 11 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Attachment 1 — Cement Summary
GMTU MTS-07 wp05
Proposed Casing & Cementing Schematic (Lodated 10119118)
16" Open Hole
Planned TOC _ 8660 MD1708V TVD
15.8 ppg Tail Class G slurry
Planned Top of 7" Liner
9,110' MD 17,386' TVD
12-4/4" Open Hale
Planned TOC - 9,790' MD 17759' TVD
15.8 ppg Tail Class G slurry
6" x 8-Y." Open Hole
i
r
6" Open Hole
14,765' MD 17,966' TVD
20" HAO VNekled
Conductor
13-3f8" 68# L-80 TXPPBTC-M
2,125' MD12,029' TVD
33` tnc1181' a2j
7" 260 L-80 TSH Blue
_. Tie Back
9e1 G0'_MD 17,417' TVD
520 Inc I2W azi
7" 26# L-80 TSH Blue Liner
10,575' MD 18,012- TVD
'W Inc 1324 azt
I
i
4-/.- 12.6# L-80
TXP Liner with
Perf Pups
MT6-07 APD
Page 12 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
13-3/8" Surface Casing run to 2,213' MD / 2,103' TVD.
Cement from 2,213' MD to 1,713' (500' of tail) with Class G+ Adds. @ 15.8 PPG, and from 1,713'to surface
with 11.0 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the
permafrost (1,106' MD), zero excess in 20" conductor.
Lead slurry from 1,713' MD to surface with DeepCrete @ 11.0 ppg
Conductor
(115'— 360 X 1.0190 ft3/ft X 1.0 (0% excess) = 81 ft3
Permafrost to Conductor
(1,106'— 115� X 0.4206 ft3/ft X 3.5 (250% excess) = 1,459 ft3
Top of Tail to Permafrost
(1,713'— 1,106� X 0.4206 ft3/ft X 1.5 (50% excess) = 382 ft3
Total Volume = 81 + 1,459 + 382 = 1922 ft3 => 1001 sx of 11.0 ppg DeepCrete @ 1.92 ft3 /sk
Tail slurry from 2,213' MD to 1,713' MD with 15.8 ppg Class G + additives
Shoe to Top of Tail
(2,213'—1,713� X 0.4206 ft3/ft X 1.50 (50% excess) = 315 ft3
Shoe Joint
(80') X 0.8407 ft3/ft X 1.0 (0% excess) = 68 ft3
Total Volume = 315 + 68 = 383 ft3 => 330 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk
9-5/8" Intermediate casing to 9,160' MD / 7,417' TVD
Cement 500' up from 9-5/8" casing shoe from 9,160' MD to 8,660' MD. Assume 40% excess annular volume.
Tail slurry from 9,160' MD to 8,660' MD with 15.8 ppg Class G + additives
Shoe to Top of Tail
(9,160'— 8,660� X 0.3132 ft3/ft X 1.40 (40% excess) = 219 ft3
Shoe Joint
(80') X 0.4257 ft3/ft X 1.0 (0% excess) = 34 ft3
Total Volume = 219 + 34 = 253 ft3 => 218 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk
MT6-07 APD
Page 13 of 19
Printed. 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
7" Intermediate liner run to 10,575' MD / 8,012' TVD
Top of slurry is designed to be — 250' TVD up from the 7" liner shoe. Assume 30% excess annular volume. 6"
x 8-3/4" underreamer to be 100ft behind the drill bit.
Tail slurry from 10,575' MD to 9,790' MD with 15.8 ppg Class G + additives (250' tvd)
8-3/4" Hole to Top of Tail
(10,575' — 9,790� X 0.1503 ft3/ft X 1.30 (30% excess) = 153 ft3
Shoe Joint
(80') X 0.2148 ft3/ft X 1.0 (0% excess) = 17 ft3
Total Volume = 153 + 17 = 170 ft3 => 147 sx of 15.8 ppg Class G + additives @ 1.16 ft3/sk
MT6-07 APD
Page 14 of 19
Printed. 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Attachment 2 — Drilling Hazards Summary
(To be posted in Rig Floor Doghouse Prior to Spud)
16" Hole / 13-3/8" Casing Interval
Event
Risk Level
Mitigation Strategy
Conductor Broach
Low
Monitor cellar continuously during interval.
Well Collision
Low
First well on Pad, traveling cylinder diagrams
Gas Hydrates
Low
If observed — control drill, reduce pump rates and
circulating time reduce mud temperatures
Clay Balling
Medium
Maintain planned mud parameters and flow rates,
Increase mud weight, use weighted sweeps,
reduce fluid viscosity, control ROP
Abnormal Pressure in
Low
Diverter drills, increased mud weight. Shallow
Surface Formations
hazard study noted minimal risk
Lost Circulation
Medium
Reduce pump rates, mud rheology, add lost
circulation material, use of low density cement
slurries, port collar, control pipe running speeds
12-1/4" Hole / 9-5/8" Casinq Interval
Event
Risk Level
Mitigation Strategy
Lost circulation
Low
Reduce pump rates, reduce trip speeds, real time
ECD monitoring, mud rheology, add lost circulation
material
Hole swabbing on trips
Medium
Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
monitoring, MPD stripping ractices
Abnormal Pressure in
Low •
Well control drills, check for flow during
Overburden Formations
connections, increase mud weight. Shallow hazard
study noted minimal risk
Hole Cleaning
Low
Monitor ECD and torque/drag trends, control drill
and use best hole cleaning practices
6" x 8-3/4" Hole / 7" Liner - Casinq Interval
Event
Risk Level
Mitigation Strategy
Sloughing shale, Tight
High
MPD for shale stability, Steerable Drilling Liner,
hole
Increase mud weight, control ROP, connection and
trip speeds, sweeps, and real time equivalent
circulating density (ECD) monitoring, run casing as
liner
Lost circulation
Low
Reduce pump rates, reduce trip speeds, real time
ECD monitoring, mud rheology, add lost circulation
material
Hole swabbing on trips
Medium
Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
monitoring, Liner will be in place at TD
MT6-07 APD
Page 15 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Abnormal Reservoir
Low
Well control drills, check for flow during
Pressure
connections, increase mud weight
Hydrogen Sulfide gas
Low °
HzS drills, detection systems, alarms, standard well
control practices, mud scavengers
6" Hole / 4-1 /2" Pre -Perforated Liner - Horizontal Hole
Event
Risk Level
Mitigation Strategy
Lost circulation
Low
Reduce pump rates, reduce trip speeds, real time
ECD monitoring, mud rheology, add lost circulation
material
Hole swabbing on trips
Medium
Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
monitoring
Abnormal Reservoir
Low
Well control drills, check for flow during
Pressure
connections, increased mud weight
Differential Sticking
Low
Uniform reservoir pressure along lateral, keep pipe
moving,control mud weight
Hydrogen Sulfide gas
Low s
HzS drills, detection systems, alarms, standard well
control practices, mud scavengers
MT6-07 APD
Page 16 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Well Proximity Risks:
MT6-07 will be the seventh well drilled on the pad. Directional drilling / collision avoidance information as
required by 20 ACC 25.050 (b) is provided in the following attachments.
Drilling Area Risks:
Reservoir Pressure: Offset production has the potential to reduce the reservoir pressure. LCM material will be on
location to deal with losses.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the
intermediate section.
Lower Shale Stability: HRZ/Kalubik/Miluveach in the pilot and intermediate #2 hole sections will require higher
mud weights than historically used to enhance wellbore stability. Steerable Drilling Liner and Managed Pressure
Drilling will be used in conjunction with a 4-string casing design to mitigate shale instability in the aforementioned
formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with
lost circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
MT6-07 APD
Page 17 of 19
Printed: 6-Nov-18
Attachment 3 —Completion Schematic
MT6-07, Injector Completion Schematic wp05
20" 79 ppf H40 Insulated
Conductor
80 feet. cemented to surface
13-3W 68 ppf L-80 TXP (Surf
to—1200)IBTCM to TU
Surface Casing
ig 2123 MD 12029 TVD
cemented to surface
412' 12.6 ppf L-80 Tenaris Blue
to 10425' MD
7" 26 ppf L-80 Tenaris Bke MSO
Tee Back
9 518" 40 ppf L-80 TXP (to 7330' rod)
9 5M" 40 ppf TN-80 HC TXP (to TD)
Lam' 9,169 MD17,417-TVD
TOC at least 30a MD
Strove Packer 8 250'
TVD above Alpine C_
Top Alper C o fl
10, 559' MD 18009' TVD
7" 26 ppf L-80 Tenaris BitWH563
Liner
to 10 575' M I 801Z TVD @ 80 deg
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Tubing I Liner Completion:
1) 4- 4" Landing Nipple (3.813" ID)
2) 4 `,/x" X 1' GLM
3) 4'/V Landing Nipple (3.725" DB NoGo)
set at 74 deg
4) Li ner Top Packer I Ha nger
wlTie Hack slezae
5) 4 M." TN Blue Blank Pipe
6) 4 'IV TN Blue Unarwith Pod Pups
414" 12.60 L-80 Tenaris Blue
With Perff Rps
O b fl 8 P 4 0
6" Hole, Tl3 at
at 14,765' 1VID f 7,965' TVA
MT6-07 APD
Page 18 of 19
Printed: 6-Nov-18
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
Attachment 4 — Area of Re vie w
MT6-07 Area of Review:
This Area of Review is required as MT6-07 is being permitted as an Alpine C Sand Injector. There are
currently not any wells or planned wells that fall within '/4 mile of the well's entry point into the Alpine C
sand.
M45, Augimt 27 2018
MT6-07wp02
WMI
UTF-M
31) Quarter Mile View
MT6-07 APD
Page 19 of 19
Printed: 6-Nov-18
Attachment 5 — Directional Plan MT6-07
MT6-07wp05
Objective: Planned final wellpath for Injector GMTU MT6-07
Application for Permit to Drill, Well MTU MT6-07
Saved: 6-Nov-18
MT6-07 APD
Page 20 of 19
Printed. 6-Nov-18
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ConocoPhillips
ConocoPhiIli ps(Alaska) Inc.
-WNS
Western North Slope
GMT1 Lookout Pad
MT6-07
MT6-07
MT6-07 wp05
Anticollision Summary Report
31 October, 2018
BER
TCH0
ES
GEcompany
ConocoPhillips BA_ KER
ConocoPhillips Anticollision Summary Report IGHES
BAT
GE company
Company:
ConocoPhillips(Alaska) Inc. -WNS
Project:
Western North Slope
Reference Site:
GMT1 Lookout Pad
Site Error:
0.00 usft
Reference Well:
MT6-07
Well Error:
0.00 usft
Reference Wellbore
MT6-07
Reference Design:
MT6-07 wp05
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well MT6-07
New MT6-07 @ 89.00usft (Plan D19)
New MT6-07 @ 89.00usft (Plan D19)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference
MT6-07 wp05
Filter type:
NO GLOBAL FILTER: Using user defined selection & filtering
criteria
Interpolation Method:
MD Interval 25.00usft
Error Model:
ISCWSA
Depth Range:
Unlimited
Scan Method:
Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,672.85 usft
Error Surface:
Pedal Curve
Warning Levels Evaluated at: 2.00 Sigma
Casing Method:
Added to Error Values
Survey Tool Program
Date 10/31/2018
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
37.20
1,000.00 MT6-07 wp05 (MT6-07)
GYD-CT-DMS
Gyrodata cont.drillpipe m/s
1,000.00
2,125.00 MT6-07 wp05 (MT6-07)
MWD
MWD- Standard
1,000.00
2,125.00 MT6-07 wp05 (MT6-07)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
2,125.00
9,160.00 MT6-07 wp05 (MT6-07)
MWD
MWD- Standard
2,125.00
9,160.00 MT6-07 wp05 (MT6-07)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
9,160.00
10,575.00 MT6-07 wp05 (MT6-07)
MWD
MWD - Standard
9,160.00
10,575.00 MT6-07 wp05 (MT6-07)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
10,575.00
14,765.71 MT6-07 wp05 (MT6-07)
MWD
MWD - Standard
10,575.00
14,765.71 MT6-07 wp05 (MT6-07)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usftl
(usftl
(usftl
(usft)
GMT1 Lookout Pad
MT6-03 - MT6-03 - MT6-03
573.51
575.00
77.09
65.78
6.817 CC
MT6-03 - MT6-03 - MT6-03
672.57
675.00
78.02
64.93
5.961 ES, SF
MT6-03 - MT6-03PH - MT6-03PH
573.51
575.00
77.09
65.78
6.817 CC
MT6-03 - MT6-03PH - MT6-03PH
672.57
675.00
78.02
64.93
5.961 ES, SF
MT6-04 - MT6-04 - MT6-04
648.72
650.00
51.66
36.23
3.349 CC
MT6-04 - MT6-04 - MT6-04
722.94
725.00
52.14
35.39
3.113 ES, SF
MT6-04 - MT6-04 - MT6-04 wpl0
424.60
425.00
59.97
50.97
6.661 CC
MT6-04 - MT6-04 - MT6-04 wpl0
573.46
575.00
61.23
49.26
5.112 ES, SF
MT6-05 - MT6-05 - MT6-05
599.00
600.00
33.07
20.68
2.669 No Errors, CC
MT6-05 - MT6-05 - MT6-05
623.63
625.00
33.41
20.58
2.604 No Errors, ES, SF
MT6-05 - MT6-0511 - MT6-051-1
599.00
600.00
33.07
20.68
2.669 No Errors, CC
MT6-05 - MT6-051-1 - MT6-0511
623.63
625.00
33.41
20.58
2.604 No Errors, ES, SF
MT6-05 - MT6-05PB1 - MT6-05PB1
599.00
600.00
33.07
20.68
2.669 No Errors, CC
MT6-05 - MT6-05PB1 - MT6-05PB1
623.63
625.00
33.41
20.58
2.604 No Errors, ES, SF
MT6-05 - MT6-05PB2 - MT6-05PB2
599.00
600.00
33.07
20.68
2.669 No Errors, CC
MT6-05 - MT6-05PB2 -. MT6-05PB2
623.63
625.00
33.41
20.58
2.604 No Errors, ES, SF
MT6-06 - MT6-06 - MT6-06
549.37
550.00
16.23
3.25
1.250 No Errors, CC
MT6-06 - MT6-06 - MT6-06
574.14
575.00
16.66
3.12
1.231 No Errors, ES, SF
MT6-06 - MT6-06PB1 - MT6-06 PB1
549.37
550.00
16.23
3.25
1.250 No Errors, CC
MT6-06 - MT6-06PB1 - MT6-06 PB1
574.14
575.00
16.66
3.12
1.231 No Errors, ES, SF
MT6-06 - MT6-06PB2 - MT6-06PB2
549.37
550.00
16.23
3.25
1.250 No Errors, CC
MT6-06 - MT6-06PB2 - MT6-06PB2
574.14
575.00
16.66
3.12
1.231 No Errors, ES, SF
MT6-08 - MT6-08 Lower Lat - MT6-08
575.33
575.00
15.56
4.05
1.352 No Errors, CC
MT6-08 - MT6-08 Lower Lat - MT6-08
650.17
650.00
16.13
3.23
1.250 No Errors, ES, SF
MT6-08 - MT6-08PB1 Lower Lat - MT6-08PB1
575.33
575.00
15.56
4.05
1.352 No Errors, CC
MT6-08 - MT6-08PB1 Lower Lat - MT6-08PB1
650.17
650.00
16.13
3.23
1.250 No Errors, ES, SF
MT6-09 - MT6-09 - MT6-09 wpl3
349.50
350.00
39.95
32.52
5.378 CC
MT6-09 - MT6-09 - MT6-09 w 13
424.49
425.00
40.67
31.71
4.540 ES, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
10/312018 7:24:04AM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips BA_ �CER
ConocoPhillips Anticollision Summary Repoli IGHES
BAT
GE company
Company:
ConocoPhillips(Alaska) Inc. -WNS
Project:
Western North Slope
Reference Site:
GMT1 Lookout Pad
Site Error:
0.00 usft
Reference Well:
MT6-07
Well Error:
0.00 usft
Reference Wellbore
MT6-07
Reference Design:
MT6-07 wp05
Summary
Site Name
Offset Well - Wellbore - Design
GMT1 Lookout Pad
Plan: MT6-01 - MT6-01 - F-wp02
Plan: MT6-01 - MT6-01 - F-wp02
Plan: MT6-02 - MT6-02 - E-wp02
Plan: MT6-02 - MT6-02 - E-wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well MT6-07
New MT6-07 @ 89.00usft (Plan D19)
New MT6-07 @ 89.00usft (Plan D19)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Depth
Depth
Centres
Ellipses
Factor
(usft)
(usft)
(usft)
(usft)
419.00
400.00
119.97
111.16
13.609 CC
591.49
575.00
121.58
109.31
9.912 ES, SF
419.00
400.00
100.05
91.24
11.349 CC
567.25
550.00
101.18
89.40
8.584 ES, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1013112018 7:24:04AM Page 3 COMPASS 5000.14 Build 85D
10-1 ConocoPhillips BA_ �(ER 11
ConocoPhillips Anticollision Summary Report h1 IGHES
BAT
GE company
Company:
ConocoPhillips(Alaska) Inc. -WNS
Project:
Western North Slope
Reference Site:
GMT1 Lookout Pad
Site Error:
0.00 usft
Reference Well:
MT6-07
Well Error:
0.00 usft
Reference Wellbore
MT6-07
Reference Design:
MT6-07 wp05
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well MT6-07
New MT6-07 @ 89.00usft (Plan D19)
New MT6-07 @ 89.00usft (Plan D19)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference Depths are relative to New MT6-07 @ 89.00usft (Plan D19) Coordinates are relative to: MT6-07
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4
Central Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: -1.39'
Ladder Plot
1800
1350
0
`m
Q
U)
v
900
0
c
au
U
450
0
0
2500 5000
7500 10000 12500 15000
Measured Depth
LEGEND
MT603. m-3, MT6U3Vo
MT60.5P 11, MT605PHI �— M609. Mt'6L�vP81 Laver Lal. MOUeP B1V0
$� MI6N VJ
@VOVO �♦ MI603.
16
��� MRaOI
MMT6T V Plan'. MT60M 601, F p03 UJ
V]
Plan—P
06, MTT606P 91� MT6O6 PBt V0 �� . MT60R, MT6M,02W
M S V010
MT605, MT 1, MT60.5L1 VO
�� MT6O6, MT606P61, MT606PBi V0
+ MT600. M16U9 Laver ldl. Ml6® VO
I
I
I
1
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I
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I
I
I I
I
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I
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I
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1
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1
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1
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f
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CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation
10/31/2018 7:24:04AM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillips BAT
ConocoPhillips Anticollision Summary Report I IGHES
a GE company
Company:
Conoco Phi Ilips(Alaska) Inc. -WNS
Project:
Western North Slope
Reference Site:
GMT1 Lookout Pad
Site Error:
0.00 usft
Reference Well:
MT6-07
Well Error:
0.00 usft
Reference Wellbore
MT6-07
Reference Design:
MT6-07 wp05
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well MT6-07
New MT6-07 @ 89.00usft (Plan D19)
New MT6-07 @ 89.00usft (Plan D19)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference Depths are relative to New MT6-07 @ 89.00usft (Plan D19) Coordinates are relative to: MT6-07
Dffset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4
Dentral Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: -1.39'
Separation Factor Plot
Measured Depth
LEGEND
Mr�SPB,, M B�sPB, va �_ M
M16-03PH, -PHW Mr605. NR6Q5PB2, MT605PB2 VO �� MTb�. MTd�PMT609 p�1w �PBt V0
v.'z: EwpO]-O
Mi60a W � � �� Plan: M1602. MT602.Ewp02W
hR605, Ml6IlSLrt, Mi 5L, VO �� Mp60B. MT60B Lauer Lai. MI'6+BV0
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
10/31/2018 7.24:04AM Page 5 COMPASS 5000.14 Build 85D
Loepp, Victoria T (DOA)
From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Sent: Monday, November 26, 2018 10:00 AM
To: Loepp, Victoria T (DOA)
Cc: Polasek, Tom G
Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria,
It is based on clearance factor. Anything greater than 1.0 does not require a TCR. We did not do a TCR for 2M-41, it was
put on the well plan as a suggestion by the well planner, but because the separation factor between 2M-19 and 2M-20
are greater than 1.0 it is not needed.
Madeline
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Monday, November 26, 2018 9:29 AM
To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Subject: [EXTERNAL]KRU 2M-41(PTD 218-151) GMTU MT6-07(PTD 218-154) Anti -collision
Madeline, Tom,
What is the criteria in the anti -collision analysis for a pass -major risk? That is, is it based on clearance factor? For the
drilling of KRU 2M-41, a TCRW was performed. Please provide analysis and results. The concern is the close approach to
offset wells while drilling the surface hole, MT6-07 may have a diverter waiver. There appears to be no intention of
shutting in offset wells/setting deep plug while drilling the surface holes.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp(o)alaska.gov
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 Victoria Loepp at (907)793-1247 or Victoria.Loepo@alaska.aov
From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Sent: Monday, November 26, 2018 7:17 AM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Cc: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) Anti -collision
Victoria,
"Our best practices and guidelines for major risk failures can be summarized as follows:
In case of major risk failure the well path must be changed. If that is not possible then the well must be minor risked by
the use of mitigating measures such as shutting in, setting a deep plug, using alternative surveying techniques, etc. If
either of these is not possible then the well cannot be drilled."
Thanks,
Madeline
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Tuesday, November 20, 2018 2:44 PM
To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151) Anti -collision
Tom, Madeline,
Please provide CPAI's best practices and guidelines for major risk failures on the anti -collision report submitted with the
PTDs.
I am sending this to both of you concerning your grassroots PTDs.
Thanx,
Victoria
From: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com>
Sent: Monday, November 19, 2018 3:50 PM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 2M-41(PTD 218-151)
Hi Victoria,
Sorry about that. This has the correct TVD and target reservoir. Please let me know if you need anything else.
Currently those wells pass our internal AC rules, but they were flagged with a note made to bring to my attention and a
TCR is not required.
Madeline
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Monday, November 19, 2018 3:10 PM
To: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.comm>
Subject: [EXTERNAL]KRU 2M-41(PTD 218-151)
Madeline,
Please check/correct the MPSP, maximum reservoir pressure and TVD depth information under 20 AAC
25.005(c)(4). Send me a corrected copy of the page.
The anti -collision report indicates close approach to 2M-19 and 2M-20 while drilling. What is the status of each of these
wells and will they be shut in at surface or a deep plug set?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. LoeppC&a laska.gov
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 Victoria Loepp at (907)793-1247 or Victoria. LoeppAolasks a.Gov
Loepp, Victoria T (DOA)
From: Loepp, Victoria T (DOA)
Sent: Tuesday, November 20, 2018 2:44 PM
To: 'Polasek, Tom G'
Cc: 'madeline.e.woodard@cop.com'
Subject: RE: [EXTERNAL]GMTU MT6-07(PTD 218-154) Anti -collision
Follow Up Flag: Follow up
Flag Status: Completed
Tom, Madeline,
Please provide CPAI's best practices and guidelines for major risk failures on the anti -collision report submitted with the
PTDs.
I am sending this to both of you concerning your grassroots PTDs.
Thanx,
Victoria
From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Sent: Tuesday, November 20, 2018 12:04 PM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]GMTU MT6-07(PTD 218-154) Anti -collision
Hi Victoria,
The approaches to MT6-06 and MT6-08 pass ConocoPhillips Major Risk Anti -collision criteria (see attached anti -collision
report) indicating we do not need to shut in those wells. When drilling this surface section we will be tracking our
progress on a travelling cylinder plot to ensure we do not cross into the error ellipse of MT6-06 or MT6-08. Also, we will
be running wireline gyro surveys down to approximately 1300' MD to ensure correct positioning.
Regarding step 14 of the drilling program: You are correct, the pressure is meant to say 3500 psi. We will test our 9-5/8"
solid body rams to 3500 psi on our high test.
Thanks Victoria and let me know if you have any other questions or if I can provide you with any other information,
Tom
Tom Polasek
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-3740
Cell: 760-920-2524
tom.g.polasek@conocophillips.com
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Monday, November 19, 2018 3:23 PM
To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Subject: [EXTERNAL]GMTU MT6-07(PTD 218-154) Anti -collision
Tom,
The anti -collision report indicates close approach for Wells MT6-06 and MT6-08. What is the status of each of these
wells and will they be shut in or a deep plug set during drilling of MT6-07? Please provide the anti -collision summary
report.
In step 14 of the drilling program, the test pressure is 2500 psig. Should this be 3500 psig?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. LoePPCcDalaska.gov
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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov
Loepp, Victoria T (DOA)
From: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Sent: Tuesday, November 20, 2018 12:04 PM
To: Loepp, Victoria T (DOA)
Subject: RE: [EXTERNAL]GMTU MT6-07(PTD 218-154) Anti -collision
Attachments: MT6-07wp05 ConocoPhillips - AC Clearance Summary.pdf
Follow Up Flag: Follow up
Flag Status: Completed
Hi Victoria,
The approaches to MT6-06 and MT6-08 pass ConocoPhillips Major Risk Anti -collision criteria (see attached anti -collision
report) indicating we do not need to shut in those wells. When drilling this surface section we will be tracking our
progress on a travelling cylinder plot to ensure we do not cross into the error ellipse of MT6-06 or MT6-08. Also, we will
be running wireline gyro surveys down to approximately 1300' MD to ensure correct positioning.
Regarding step 14 of the drilling program: You are correct, the pressure is meant to say 3500 psi. We will test our 9-5/8"
solid body rams to 3500 psi on our high test.
Thanks Victoria and let me know if you have any other questions or if I can provide you with any other information,
Tom
Tom Polasek
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-3740
Cell: 760-920-2524
tom.g.polasek(@conocophi lips.com
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Monday, November 19, 2018 3:23 PM
To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Subject: [EXTERNAL]GMTU MT6-07(PTD 218-154) Anti -collision
Tom,
The anti -collision report indicates close approach for Wells MT6-06 and MT6-08. What is the status of each of these
wells and will they be shut in or a deep plug set during drilling of MT6-07? Please provide the anti -collision summary
report.
In step 14 of the drilling program, the test pressure is 2500 psig. Should this be 3500 psig?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp@alaska.gov
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 Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.aov
From:
Polasek, Tom G
To:
Boyer, David L (DOA)
Cc:
Davies, Ste i)hen F (DOA)
Subject:
RE: [EXTERNAL]Digital Survey File for MT6-07
Date.
Thursday, November 15, 2018 3:02:00 PM
Attachments:
GMT1 Conductor As -Built CE-MT60-1007 Rev1 . 0
Dave,
As built survey attached.
Ground level elevation is 44.8 ft MSL, the Pad level elevation is 52.4 ft MSL, and our rig floor to pad
level is 36.6 ft making our RKB 89.0 ft MSL
Baker has the has the wrong ground level on the directional survey report, but they do have the
correct datum elevation/reference for RKB of 89 ft.
I will have Baker fix the ground elevation.
Thanks,
tom
OS
I<ER
UGHES
CA
,;-.t Co-ordinate K*WerlOr.
'*�'k MT13-07
TV,D Roference.
New MT"7 a 89-00usIt (Plan D19)
"n Refereme:
Now MT"7,3 WMAA (Plan 01W
North, 1110terfin'
Tiuu
Survey cawatwn method-
Mirumum Curvature
Diltaba",
E"OT, I Ua5,ta Production
system Datum:
Win Sea Lev,?)
U"g geodetic $ca* ractor
5.15,571 14 ustl LaiitudC
70* 1521251 N
317,134,52 usfl Lqwitude:
1 Sl * 28'40,782 W
0,000 M Grid Conveir q�nce: -I . 39
i, 530. IF, usft
LdbliAd@.
',D22-U usft
Longitude:
0 00 usft
From: Boyer, David L (DOA) <david.boyer2@alaska.gov>
70* 15'22.821 N
t5l 28' 44V4 W
37,20 usft
Sent: Thursday, November 15, 2018 2:21 PM
To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL] Digital Survey File for MT6-07
Tom,
Thanks for clarifying the frack item. Steve found an inconsistency in the GL elevation. I usually go to
the As Built plat for clarification but did not see one in the packet. In the permit details, the GL is
52.4'. On the BakerHughes directional plan, the GL for the pad is 37.20'. Since this affects both of
our programs using survey data, please check on which GL is correct for the M6 pad. The KB of 89.0'
was the same in both places, no issue there.
Thanks,
Dave Boyer
From: Polasek, Tom G <Tom.G.PolasekPconocophillips.com>
Sent: Thursday, November 15, 2018 11:38 AM
To: Boyer, David L (DOA) <david.boyer2Palaska.gov>
Subject: RE: [EXTERNAL] Digital Survey File for MT6-07
Dave,
Thanks for pointing that out. ConocoPhillips is not planning on fracking the Alpine C sand in MT6-07.
Thanks,
Tom
Tom Polasek
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-3740
Cell: 760-920-2524
tom. .nolasekPconocophillips.com
From: Boyer, David L (DOA) <david.boyer2Palaska.gov>
Sent: Thursday, November 15, 2018 11:07 AM
To: Polasek, Tom G <Tom G Polasek@conocophilli sp com>
Subject: RE: [EXTERNAL] Digital Survey File for MT6-07
Tom,
In reviewing the cover page of the PTD application, Steve pointed out that the box regarding fracing
REV
DATE
BY
CK
ALP
_ SCRIPTION
F"1TED PER K180003ACS
REV
DATE
F
� APP
DESCRIPTION
1
02/24/18
RR
CZ
GHt
ALPINE SATELLITE DEVELOPMENTLIJ
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GMT1 TO ALPINE
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ACCESS ROAD
LOCATION OF
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LEGEND:
O PROPOSED CONDUCTOR
• EXISTING CONDUCTOR
SECTION 31, T.11 N.,R. 3 E.,
U.M.
SECTION 6, T.10 N.,R. 3 E., U.M.
P p,0
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LCMF
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I
ALPINE SURVEY OFFICE
PHONE : 907-670-4739
ALPINE
MODULE:MT60 UNIT: MT
ConocoPhillips
ALPINE PROJECT
GMT1
WELL CONDUCTORS
Alaska, Inc.
AS
—BUILT LOCATIONS
CADD FILE NO.
18-02-01-1 02 23 2018
DRAWING NO:
CE-MT60-1007
PART:
1 of 3
REV:
1
REVI
DATE
BY
CK
APP
_r-SCRIPTION
Ur _ ,,TED PER K180003ACS
REV
DATE
P CI APP
DESCRIPTION
1
02/24/18
RR
CZ
GH
ALL CONDUCTORS ARE LOCATED IN
PROTRACTED SEC. 06, T 10
N, R 3
E,
U.M.
SFNLINEFWLS
EXIST.
WELL 'Y'
'X'
LAT.(N)
LONG.(W)
GND
MT6-01
5,945,316.08
1,457,169.59
70'15'22.007"
151`28'52.032"
232'
1920'
44.8
52.1
MT6-02
5,945,309.25
1,457,150.88
7015'21.935"
151°28'52.571"
239'
1902'
44.4
52.1
MT6-03
5,945,302.35
1,457,132.05
70`15'21.863"
151°28'53.114"
247'
1883'
44.3
52.2
MT6-04
5,945,295.47
1,457,113.24
70`15'21,791"
151'28'53.656"
254'
1864'
44.7
52.2
MT6-05
5,945,288.65
1,457,094.47
70*15'21,719"
151*28'54.197"
261'
1846'
44.8
52.2
MT6-06
5,945,281.78
1,457,075.68
70*15'21.647"
151'28'54.739"
269'
1827'
44.9
52.2
MT6-07
5,945,275.02
1,457,056.87
70*15'21.576"
151°28'55.281"
276'
1809'
44.8
52.4
MT6-08
5,945,268.15
1,457,038.09
70*15'21.504"
151°28'55.822"
283'
1790'
44.3
52.3
MT6-09
5,945,261.33
1,457,019.34
70`15'21.433"
151 °28'56.363"
290'
1772'
45.0
52.3
NOTES
1. COORDINATES SHOWN HEREON
ARE ALASKA STATE PLANE, ZONE
KUUKPIK
4, NAD 83.
U M
I A Q
2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM
MEAN SEA LEVEL
(B.P.M.S.L.)
ALPINE SURVEY
OFFICE
PHONE : 907-670-4739
y.�
ALPINE
MODULE: MT60
UNIT:
MT
ConocoPhillips
ALPINE PROJECT
GMT1 WELL CONDUCTORS
Alaska, Inc.
AS -BUILT LOCATIONS
CADD FILE NO.
18-02-01-1 02/23/2018
DRAWING NO:
CE-MT60-1007
PART:
2 OF
3
REV:
1
1 102/24/181 RR I CZ I GH I OF _.,TED PER K180003ACS
NOTES:
1. ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83.
2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND
ELEVATIONS WERE DERIVED FROM THE TOPOGRAPHICAL DESIGN SURVEY DATED 09/09/2015.
3. BASIS OF COORDINATES: GMT1 PERMANENT CONTROL MONUMENTS PER SURVEY BY
KUUKPIK/UMIAQ, OCTOBER 2017.
4. DATES OF AS —BUILT SURVEYS: WELL CONDUCTORS MT6-01 THRU MT6-09, 02/23/18,
FB.2018-05 ,PG.1.
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS
AS —BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT
SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST
AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE
CORRECT.
DATE: REGISTRATION NO.
KUUKPIK
UMIAQ
ALPINE SURVEY OFFICE
PHONE : 907-670-4739
�� ALPINE MODULE: MT60 UNIT: MT
ConocoPhillips ALPINE PROJECT
GMT1 WELL CONDUCTORS
Alaska, Inc. AS —BUILT LOCATIONS
CADD FILE N0. DRAWING NO: PART: REV:
18-02-01-1 02/23/2018 CE-MT60-1007 3 of 3 1
I
From:
Polasek, Tom G
To:
Boyer David L ,DOA)
Cc:
Davies, Stephen F (DOA)
Subject:
RE: [EXTERNAL]Digital Survey File for MT6-07
Date:
Wednesday, November 14, 2018 9:26:50 AM
Attachments:
MT6-07 wo05 Canvas NAD83.txt
MT6-07 wp05 Petrel.txt
Hi Dave,
Yeah, No problem, ask anytime.
Well Path attached.
MD, Inc , Az is the same on both files. Canvas has well name and such, Petrel has only the MD, Inc
Az.
Thanks,
tom
From: Boyer, David L (DOA) <david.boyer2@alaska.gov>
Sent: Wednesday, November 14, 2018 9:06 AM
To: Polasek, Tom G <Tom.G.Polasek@conocophillips.com>
Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: [EXTERNAL] Digital Survey File for MT6-07
Hi Tom,
I just began the review of the Permit to Drill application for the MT6-07 well. Would it be possible to
e-mail a digital copy of the proposed survey file in Excel or ASCII format. This saves us a lot of time
vs. scanning the hard copy with associated optical reading errors. The whole survey file is fine. We
only input MD, inclination, and azimuth into the Geographics program.
Thank you,
Dave Boyer
Senior Geologist
AOGCC
Transform Points ✓ D P M r� Z X
Source coordinate system
State Plane 1927 - PJask-a Zone 4
Datum:
NAD 1927 - North America Datum of 1927 (Mean)
I
Target coordinate system
AJbers Equal Area (-150)
Datum:
NAD 1 S27 - North America Datum of 1927 (Mean)
I
,f,,p-e--+t-aj-u-e-s-into --the —spreadsheet ---or-copy -and —paste columns —cf—data —f"r"o,m-, —aspreadsheet `u—sin,g- —the keyboard shortcuts Ctd+C to copy and Ctrl+V to paste. Then click on the appropriate arTow button to transform the points to the desired coordinate system.
. I- -F - , ----
t Bade ]
Finish Cancel Help
TRANSMITTAL LETTER CHECKLIST
WELL NAME: M TC — ['� -
PTD:
Development V Service _ Exploratory Stratigraphic Test Non -Conventional
FIELD: G ILt Q-{V M o o S Q,S T0014 POOL: Lop o uT Pap l
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' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
/
Well Logging
\/
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, LOOKOUT OIL - 2821 Well Name: MOOS ES TOOTH 6-07 Program SER Well bore seg ❑
PTD#:2181540 Company CON-OCOPHILLIPS ALASKA, INC. _ Initial Class/Type SER / P_END GeoArea 890 _ - Unit 10750 On/Off Shore On Annular Disposal ❑
Administration '17 Non conven. gas conforms to AS31.05.0300.1.A),(j.2_.A-D) NA No restrictions as to well spacing except that no pay shall be opened to a well within 500 feet of an
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
I5
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
No
Area of Review for Alpine C sand injector_ is included.
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
112
Permit can be issued without administrative approval
Yes
DLB 11/14/2018
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
Yes
Area Injection Order No. 4-0, issued May 29, 2018, governs Lookout Oil Pool._
15
All wells within 1/4 mile area of review identified (For service well only)
Yes
None
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
Yes
Conservation Order No. 747, issued May 29, 2018, governs Lookout Oil Pool.
18
Conductor string provided
Yes
80' conductor set_
Engineering
19
Surface casing_ protects all known USDWs
Yes
Surface casing set to 2125' MD
120
CMT vol adequate to circulate on conductor & surf csg
Yes
158% excess
21
CMT vol adequate to tie-in long string to surf csg
No
22
CMT will coverall known productive horizons -
No
Productive interval will be completed with -an uncemented pert pup liner
23
Casing designs adequate for C, T, B & permafrost
Yes
24
Adequate tankage or reserve pit
Yes
Rig has steel tanks; all waste to approved disposal wells
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed -
Yes
Anti -collision analysis complete; no major risk failures; TCR reviewed 11/29/18 w/ CPAI
i27
If diverter required, does it _meet_ regulations
Yes
Diverter requirement waived per 20 AAC 25.035(h)(2)
Appr Date
28
Drilling fluid program schematic _& equip list adequate
Yes
Max formation_ pressure is 3625 psig(8.7 ppg EMW ); will drill w/ 8.8-11.0 ppg_EMW
VTL 11/19/2018
29
BOPEs,_do they meet regulation
Yes
30
BOPE-press rating appropriate; test to -(put psig in comments)
Yes
MPSP is 2824 psig; will test BOPs to 3500psig
31
Choke manifold complies w/API RP-53 (May 84)- -
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
H2S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
Yes
No wells in AOR
35
Permit can be issued w/o hydrogen sulfide measures
Yes
Only MT6-03 has been flowed back to date but no H2S was encountered in that well.
Geology
36
Data presented on potential overpressure zones
Yes
Appr Date
37
Seismic analysis of shallow gas zones
NA_
DLB 11/14/2018
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly -progress reports [exploratory only]
NA
Geologic Engineering Public
Commissioner: Date: Commissioner: Date er Date
SdL l`� i 5 1 2/(P/L $ OV7
l Z' 6 I,
