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HomeMy WebLinkAbout214-159Guhl, Meredith D (DOA)
From: Guhl, Meredith D (DOA)
Sent: Wednesday, March 01, 2017 2:13 PM
To: Phillips, Ron L
Cc: Loepp, Victoria T (DOA); Bettis, Patricia K (DOA)
Subject: PTD 214-159 KRU 1L-04AL1 and PTD 214-160 KRU 1L-04A L2
Hello Ron,
The permits to drill for KRU 1L-04A L1, PTD 214-159, issued 23 October 2014 and KRU 1L-04A L2, PTD 214-160, issued 23
October 2014, have expired under Regulation 20 AAC 25.005 (g). The PTDs will be marked expired in the AOGCC
database.
There is a letter in both well files dated Feb 2 2015 referencing canceling of driller permits for KRU 1L-04A L3 and 1L-
04AL3-01, but the letter does not refer to the permits listed above.
If you have any questions, please contact me.
Thank you,
Meredith
Meredith Guhl
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at
907-793-1235 or meredith.guhl@alaska.aov.
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 2, 2015
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
�4i�,GEIVED
i EEC Q 2 2015
A0_GGC
ConocoPhillips Alaska, Inc. has experienced complications while drilling the KRU 1 L-04A sidetrack (214-158)
that have forced us to abandon drilling efforts of all coiled tubing drilling laterals to the north of 1 L-04. We are
progressing with drilling of the previously p southern laterals, but the loss of the planned 'A' sidetrack
requires that the names of these southern laterals be changed —so--That production can ultimately be properly
booked to this well.
Accordingly, ConocoPhillips requests the AOGCC to do the following:
• Please cancel the drilling permits for KRU 1 L-04AL (214-161) and 1 L-04AL3-01 (214-162)
• Please approve replacement permit -to -drill applications 1 L-04B and 1 L-049C1, respectively.
Please note that these replacement permit -to -drill applications are identical to the previously approved
applications for 1 L-04AL3 and 1 L-04AL3-01 except for the naming convention. Window milling of the 1 L-04B
sidetrack is expected to commence on February 3, 2015 (i.e. tomorrow) so your prompt attention to this matter
is greatly appreciated.
Attached to this application are the following documents:
- 10-401 Applications for 1 L-04B and 1 L-04131_1
- Detailed Summary of Operations (revisions shown in red)
- Directional Plans for 1 L-04B and 1 L-04131_1
- Proposed CTD Schematic
If you have any questions or require additional information please contact me at 907-263-4172.
Sin, rely,
Gary Eller
ConocoPhillip ska
Coiled Tubing Drilling Engineer
Loepp, Victoria T (DOA)
From: Loepp, Victoria T (DOA)
Sent: Wednesday, December 17, 2014 3:59 PM
To: 'Phillips, Ron L'
Subject: RE: KRU 1L-04A (PTD 214-158) Delay in CTD Operations
Ron,
Thank you for the notification.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave, Ste 100
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loepp aaalaska.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 Ferguson at (907)793-1247 or Victoria. Ferguson@alaska.gov
From: Phillips, Ron L [mailto: Ron. L.PhillipsCcbconocophillips.com]
Sent: Wednesday, December 17, 2014 3:39 PM
To: Loepp, Victoria T (DOA)
Cc: Venhaus, Dan E
Subject: KRU IL-04A (PTD 214-158) Delay in CTD Operations
Well
Drilliny- Permit #
Obiective
API #
IL-04A:
214-158
A4-Sand
50-029-21179-01
1L-04AL1:
214-159
A5-Sand
50-029-21179-60
IL-04AL2:
214-160
M-Sand
50-029-21179-61
IL-04AL3:
214-161
A4-Sand
50-029-21179-62
1L-04AL3-01:
214-162
A5-Sand
50-029-21179-63
Victoria - ConocoPhillips is delaying CTD operations in KRU 1L-04 due to a contaminated cement plug in the 7" casing
of the mother -bore. Drilling operations of PTD 214-158 had not yet begun in that window milling operations had not yet
begun. ConocoPhillips anticipates returning to 1 L-04 to drill the approved CTD program in —4 weeks' time to allow for
remedial well work and re -cementing.
Nabors CDR2-AC rigged up on well KRU 1 L-04 on 12/13/14 to drill a penta-lateral CTD sidetrack. Incompetent cement
was encountered in the 7" casing while drilling the pilot hole for whipstock placement. Hard cement is critical to the
durability of 3'/2" x 7" cement pilot hole window exits, especially in 1 L-04 which is planned for 2 whipstocks and 13,000'
of open hole drilling. We have elected to rig down CDR2 and move to 1 H-04 sometime tomorrow. The rig is currently
under -reaming the cement thereby prepping the well for service CTU to re -cement.
Please let me know if you have any questions.
Thanks,
Ron L. Phillips
Senior CTD Engineer
ConocoPhillips Alaska
Phone 265-6312
Cell 317-5092
THE ��r^
GOVERNC)R SEAN i'ARNELL
D. Venhaus
CTD Engineering Supervisor
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
333 Wes? Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 L-04AL 1
ConocoPhillips Alaska, Inc.
Permit No: 214-159
Surface Location: 403' FSL, 144' FEL, SEC. 30, T11N, RI OE, UM
Bottomhole Location: 2493' FSL, 1675' FEL, SEC. 19, T11N, RIOE, UM
Dear Mr. Venhaus:
Enclosed is the approved application for permit to re -drill the above referenced development
well.
The permit is for a new wellbore segment of existing well Permit No. 214-158, API No. 50-029-
21179-01-00. Production should continue to be reported as a function of the original API
number stated above.
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 a AOGCC order, or the terms and conditions of this permit may result in
the revocation or suspension of the permit.
Sincerely,
Cathy P/Foerster
Chair
DATED this Z day of October, 2014.
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: Development - Oil ❑✓ > Service - Winj ❑ Single Zone ❑.
Drill r ,I Lateral Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
i] Redrill Reentry Exploratory ❑ Service - WAG ❑ Service - Disp ❑
1 c. Specify if well is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: - Lj, Blanket LJ Single Well
Bond No. 59-52-180 t
11. Well Name and Number: 49
(Zv 1 L-04ALl 14.4ta•l
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth:
MD: 11700' • TVD: 6078'
12. Field/Pool(s):
Kuparuk River Field,
Kuparuk River Oil Pool ,
4a. Location of Well (Governmental Section):
Surface: 403' FSL, 144' FEL, Sec. 30, T11 N,�10E, UM
Top of Productive Horizon:
720' FNL, 887' FEL, Sec. 30, Tl l N, R10E, UM -
Total Depth:
2493' FSL, 1675' FEL, Sec. 19, T11 N, R10E, UM
7. Property Designation (Lease Number):
ADL 25659, 25652 •
8. Land Use Permit:
2585, 2578
13. Approximate Spud Date:
12/7/2014
9. Acres in Property:
24881 59� i
14. Distance to
Nearest Property: 23745
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 539915 y- 5949371
10.
Zone- 4 '
KB Elevation above MSL: 116 feet
GL Elevation above MSL: 86 feet
15. Distance to Nearest Well Open
to Same Pool: 1 F-09 , 350'
16. Deviated wells: Kickoff depth:
Maximum Hole Angle:
10300 ft. 17.
• 1001 deg
Maximum Anticipated Pressures in psig (see 20 AAC 25,035)
Downhole: 4135 psig Surface: 3531 psig -
18. Casing Program:
Specifications
Top - Setting
Depth - Bottom
Cement Quantity, c.f. or sacks
(including stage data)
Hole
Casing
Weight
Grade
Coupling
Length
MD
TVD
MD
TVD
3"
2.375"
4.7#
L-80
ST-L
3600'
8100'
6094'
11700'
6078'
slotted liner
19
PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
7668
Total Depth TVD (ft):
6371
Plugs (measured)
none 1
Effective Depth MD (ft):
7538
Effective Depth TVD (ft):
6259
Junk (measured)
7134
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
65'
16
210 sx Cold Set II
96'
96'
Surface
2312'
9.625
830 sx AS III, 250 sx Cl G
2343'
2243'
Intermediate
Production
7597'
7
600 sx Class G, 150 sx AS 1
7625'
6334'
Liner
Perforation Depth MD (ft):
7201'-7214', 7316'-7331', 7347'-7377'
Perforation Depth TVD (ft):
5971'-5982', 6070'-6082', 6096'-6122'
20, Attachments: Property Plal ❑ BOP Sketcl- ❑
Diverter Sketch ❑
Drilling Program o Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑
21. Verbal Approval: Commission Representative:
22. 1 hereby certify that the foregoing is true and correct.
Printed Name VD.Vhaus
Signature —
Date:
Contact Gary Eller @ 263-4172
Email J.Gary. Eller(abcop.com
Title CTD Engineering Supervisor
Phone:263-4372 Date
Commission Use Only
Permit to Drill
Number: dI _ jSQ
API Number:
50- C)a9 - a / I �9 _ 6d — cc
Permit Approval
Date: I O a3I
See cover letter
for other 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:
- Samples req'd: Yes ❑ No A Mud log req'd: Yes❑ No
Other: 3 6 p rcSf 4aao �sr
td
H ram! a V_ / CS f 70 2 SOOpS H2S measures: Yes ✓[� No ❑ Directional svy req'd: Yes � No ❑
Spacing exception req'd: Yes ❑ No d Inclination -only svy req'd: Yes ❑ No171
/ APPROVED BY THE
Approved by: COMMI Si N Date: — —�
Form 10-401 (Rev sed 10/2012) This permit is vali f r
n hs
f
e Ile
f approval (20 AAC 25.005(g)) Y � �/
r c //i_l[`t- - c-% `7
ConocoPhillips
p
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 6, 2014
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a penta-lateral out of the Kuparuk
Well 1 L-04 using the coiled tubing drilling rig, Nabors CDR2-AC.
CTD operations are scheduled to begin in December 2014. The objective will be to drill laterals KRU 1 L-04A,
1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01 targeting the Kuparuk A -sand. A separate sundry application is
attached to plug the KRU 1 L-04 (184-154) perfs to allow these laterals to be drilled. As detailed in the
attachments, ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A -
sand perfs in 1 L-04.
Attached to this application are the following documents:
10-401 Applications for 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
— Detailed Summary of Operations
— Directional Plans for 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
— Proposed CTD Schematic
— 10-403 Application to Abandon KRU 1 L-04 (184-154)
— Operations Summary in support of the 10-403 application
If you have any questions or require additional information please contact me at 907-263-4172.
Sin erely,
Gary Eller
ConocoPhillips Aaska
Coiled Tubing Drilling Engineer
Kuparuk
t
ti
ji.Y,ALI, AL2, AU & r,
Application Permit to Drill Document
1.
Well Name and Classification........................................................................................................
2
(Requirements of 20 AAC 25.005(t) and 20 AAC 25.005(b))...................................................................................................................
2
2.
Location Summary..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................
2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................
2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................
2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................
3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................
3
0.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................
3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................
4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11.
Seabed Condition Analysis............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12.
Evidence of Bonding......................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................
4
13. Proposed Drilling Program............................................................................................................. 5
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 5
Summaryof Operations...................................................................................................................................................5
PressureDeployment of BHA..........................................................................................................................................6
LinerRunning...................................................................................................................................................................7
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 7
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 7
15. Directional Plans for Intentionally Deviated Wells....................................................................... 7
(Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7
16. Attachments....................................................................................................................................7
Attachment 1: Directional Plans for 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01.......................................7
Attachment 2: Current Well Schematic for 1 L-04............................................................................................................7
Attachment 3: Proposed Well Schematic for 1 L-04 CTD Laterals...................................................................................7
Page 1of7 J R IGI N L—*'
October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
1. Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01.
All laterals will be classified as "Development— Oil' wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the A sand package in the Kuparuk reservoir. See the attached 10-401 form for
surface and subsurface coordinates of the 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC.
BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 4000 psi. Using the
maximum formation pressure in the area of 4135 psi in well 1 L-05, the maximum potential surface
pressure, assuming a gas gradient of 0.1 psi/ft, would be 3531 psi. See the "Drilling Hazards
Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
A static bottom hole pressure of 1 L-04 in June 2014 indicated a reservoir pressure of 2796 psi or 8.9 ppg
equivalent mud weight. The maximum down hole pressure in the 1L-04 pattern is at 1L-04. The highest
pressure in an offset well is at the 1 L-05 injector to the east with 4135 psi, or 13.1 ppg EMW. Using the 1 L-05
pressure as the maximum possible, the maximum possible surface pressure, assuming a gas gradient of 0.1
psi/ft, would be 3531 psi.
We do not expect to encounter this magnitude of formation pressure while drilling the 1 L-04 laterals since they
are oriented drilled north -south along a line of producers. In fact, it's likely that we will drill into areas of reduced
formation pressure. Well 1 F-09 to the north recently measured A -sand formation pressure of 7.3 ppg EMW.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
No specific gas zones will be drilled but both the 1 L and 1 F pads are active gas injection sites. There is a
distinct potential that free gas could be associated with any formation influx.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
An expected risk of 1 L-04 is the hole stability through the A5 & A4 basal shales. We will use MPD techniques
to target a constant 11.4 ppg formation pressure while drilling and completing all laterals. There is a risk of
differential sticking since we're drilling into areas of reduced formation pressure. There are limited backup
window exit locations in 1 L-04.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
N/A for this thru-tubing drilling operation.
According to 20 AAC 25.030(o, thru-tubing drilling operations need not perform additional formation integrity
tests.
0RIrINAL
Page 2 of 7 October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral
Liner Top
Liner Btm
Liner Top
Liner Btm
Name
MD
MD
TVDSS
TVDSS
Liner Details
1 L-04A
10300'
11700'
6089'
6143'
2%", 4.7#, L-80, ST-L slotted liner; with
aluminum billet
1L-04AL1
8100'
11700'
6094'
6078'
2'/", 4.7#, L-80, ST-L slotted liner; with
aluminum billet
1L-04AL2
7240'
10200'
6004'
6064'
23/", 4.7#, L-80, ST-L slotted liner with
deployment sleeve
1 L-04AL3
8100,
10550'
6134'
6095'
2%", 4.7#, L-80, ST-L slotted liner; with
aluminum billet
1 L-04AL3-01
7120'
10575'
5902'
6054'
2%", 4.7#, L-80, ST-L slotted liner with
deplo ment sleeve
Existing Casing/Liner Information
Category
OD
Weight
(ppf)
Grade
Connection
Top
MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
62.50
H-40
Welded
0'
96'
0'
96'
1640
630
Surface
9-5/8"
36.0
J-55
BTC
0'
2343'
0'
2243'
3520
2020
Casing
7"
26
J-55
BTC
0'
7625'
0'
6334'
4980
4320
Tubing
3 %"
9.3
L-80
EUE-MOD
0' 1
7092'
0' 1
5879' 1
10160
10530
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
N/A for this thru-tubing drilling operation.
Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
Diagram of Nabors CDR2-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based Flo -Pro mud (9.6 ppg)
— Drilling operations: Chloride -based Flo -Pro mud (9.6 ppg). This mud weight should hydrostatically
overbalance reservoir pressure. However, if increased formation pressure is encountered then
overbalanced conditions will be maintained using MPD practices described below.
— Completion operations: 1 L-04 does not contain a subsurface safety valve (SSSV). The well will be
loaded with 11.6 ppg NaBr completion fluid in order to provide formation over -balance while running
completions.
— Emergency Kill Weight fluid: Two well bore volumes (-285 bbl) of 13.1 ppg emergency kill weight
fluid will be within a short drive to the rig during drilling operations.
Page 3 of 7 R- 1G"'
I N A L October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP
promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on
the reservoir.
Through experience with drilling CTD laterals in the Kuparuk sands, 11.4 ppg has been identified as the
minimum EMW to ensure stability of shale sections. The constant BHP target will be adjusted to maintain
overbalanced conditions if increased reservoir pressure is encountered during drilling. The constant BHP target
will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in
pump rates or change in depth of circulation will be offset with back pressure adjustments.
Pressure at the 1L-04A Window (7250' MD, 6013' TVD) Using MPD
Pumps On
1.5 b m
Pumps Off
A -sand Formation Pressure 8.9 p)
2783 psi
2783 psi
Mud Hydrostatic 9.6 p
3002 psi
3002 psi
Annular friction i.e. ECD, 0.060 si/ft)
435 psi
0 psi
Mud + ECD Combined
3437 psi
3386 psi
(no choke pressure)
(overbalanced
(overbalanced
—650psi)
—220psi)
Target BHP at Window (11.4 )
3564 psi
3564 psi
Choke Pressure Required to Maintain
130 psi
560 psi
Target BHP
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(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 exploratory or stratigraphic test 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.
Page 4of7 J RFINAL
October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(93))
Summary of Operations
Background
Well 1L-04 is a Kuparuk A -sand producer (development) well equipped with 3'/2" tubing and 7" production
casing. Five laterals from well 1L-04 will be drilled, three to the north (IL-04A, AL1 & AL2) and two to
the south (1L-04AL3 & AL3-01) to augment A sand production from 1F-09 to the north and 1L-02 to the
south. Operations will target the A4 and A5 sand intervals.
Well 1L-04 was completed into the Kuparuk A and C-sand intervals in 1984 as a commingled single
completion. In 1998 the C-sand perfs were cement squeezed to make an A -only producer. A RWO was
performed earlier this year to replace the existing tubing with a stacked packer completion above the failed
packer and change the IC packoffs.
Prior to CTD operations, the existing A -sand perfs in will be squeezed with cement to provide a means to
kick out of the 7" casing. ConocoPhillips has submitted at 10-403 sundry application for a variance
from the requirements of 20 AAC 25.112(c)(1) to plug the A -sand perfs in this manner. Immediately
prior to cementing the A -sand perfs, the D-nipple at 7128' MD will be milled out to a 2.80" ID and the
tubing tail will be perforated. Both of these operations are needed to prepare the well for CTD operations.
After plugging off the existing A -sand perfs with cement pre -rig, the Nabors CDR2-AC drilling rig will
drill a pilot hole to 7280' and set a whipstock in the 2.80" pilot hole at the planned kickoff point. All
northern laterals will exit through the 7" casing at 7250' MD and will target the A4 & A5 sands. All
southern laterals will exit through a second exit in the 7" casing at 7230' MD and will also target the A4 &
A5 sands. The laterals will be completed with 2%" slotted liner from TD with the final liner top located
inside the 3%2" tubing.
Pre-CTD Work
1. Slickline: Dummy all GLVs.
2. E-line: Shoot 2' of holes in the 3%2" tubing tail at 7120' MD.
3. Coil: Mill out Camco D-nipple at 7128' MD to 2.80"
4. Coil: Cement squeeze the A -sand perfs bringing cement up into the tubing tail.
5. Slickline: Drift tubing, tag top of cement and pressure test.
6. Prep site for Nabors CDR2-AC, including setting BPV
Rig Work
1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 1L-04A Sidetrack (A4 sand - north)
a. Drill 2.80" high -side pilot hole through cement to 7280' MD
b. Caliper pilot hole
c. Set whipstock at 7250' MD
d. Mill 2.80" window at 7250' MD
e. Drill 3'/4" bi-center lateral to TD of 11,700' MD
f. Run 2%" slotted liner with an aluminum billet from TD up to 10,300' MD
Page 5 of 7 ' ` October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
3. IL-04AL1 Lateral (A5 sand - north)
a. Kickoff of the aluminum billet at 10,300' MD
b. Drill 3'/4" bi-center lateral to TD of 11,700' MD
c. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD
4. IL-04AL2 Lateral (A5 sand - north)
a. Kickoff of the aluminum billet at 8100' MD
b. Drill 3'/4" bi-center lateral to TD of 10,200' MD
c. Run 2%" slotted liner from TD up to 7240' MD
5. IL-04AL3 Lateral (A4 sand - south)
a. Set whipstock at 7230' MD
b. Mill 2.80" window at 7230' MD
c. Drill 3" bi-center lateral to TD of 10,550' MD
d. Run 2%" slotted liner with an aluminum billet from TD up to 8100' MD
6. IL-04AL3-01 Lateral (A5 sand - south)
a. Kickoff of the aluminum billet at 8100' MD
b. Drill 3" bi-center lateral to TD of 10,575' MD
c. Run 2%" slotted liner from TD up to 7120' MD, inside the 3`/z" tubing tail
7. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2-AC.
Post-RiI4 Work
1. Pull BPV
2. Obtain static BHP. Install GLV's.
3. Return to production
Pressure Deployment of BHA
The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a
system of double swab valves on the Christmas tree, double deployment rams, double check valves and double
ball valves in the BHA, and a slickline lubricator. This pressure control equipment listed ensures there are
always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process.
During BHA deployment, the following steps are observed.
— Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is
installed on the BOP riser with the BHA inside the lubricator.
— Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened
and the BHA is lowered in place via slickline.
— When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off
above the deployment rams.
— The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is
equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in
the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Page 6 of 7 ORIGINAL October 9, 2014
PTD Application: 1 L-04A, 1 L-04AL1, 1 L-04AL2, 1 L-u4AL3 & 1 L-04AL3-01
Liner Running
— The 1 L-04 CTD laterals will be displaced to an overbalancing fluid (11.6 ppg NaBr) prior to running liner.
See the "Drilling Fluids" section for more details.
— While running 2%" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 23/" rams will provide
secondary well control while running 23/" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18
or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable. ,
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AA 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plan
— Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
— MWD directional, resistivity, and gamma ray will be run over the entire openhole section.
— Distance to Nearest Property Line and nearest well in the same pool.
Sidetrack
Name
Directional
Plan
Distance to
Unit
Boundary
Distance
to
Nearest
Well
Nearest Well
1 L-04A
06
23,745'
340'
1 F-09
1 L-04AL1
06
23,745'
350'
1 F-09
1 L-04AL2
06
23,745'
380'
1 F-09
1 L-04AL3
10
18,630'
345'
1 L-02
1 L-04AL3-01
10
18,630'
370'
1 L-02
16. Attachments
Attachment 1: Directional Plans for 1 L-04A, 1 L-04AL 1, 1 L-04AL2, 1 L-04AL3 & 1 L-04AL3-01
Attachment 2: Current Well Schematic for 1 L-04
Attachment 3: Proposed Well Schematic for 1 L-04 CTD Laterals
Page 7 of 7 N A L
October 9, 2014
KUP PROD 1 L-04
LonocOF'noup5
Alaska, Inc.
Well Attributes IIIMax
Angle & MD TD
Wellbore API/UWI R-d Name Wellbore Status
500292117900 KUPARUK RIVER UNIT PROD
ncl V) MD (ftKB) Act
42.42 2,700.00
Elm (ftKB)
7,668.0
Comment 1-12S (pp.) I Date
SSSV: NIPPLE 90 8/142012
Annotation End Date
Last WO: 12/30/2013
KB-Grd (ft) Rig Release Date
34.90 9/13/1984
IL-04, 9/14rzo141;19:11 PM
edma mats (actual)
.................._...-_............ ...............
HANGER; 27.2
CONDUCTOR; 31.0.96.0
NIPPLE; 502.1
SURFACE; 31.0-2,343.2-
GAS LIFT; 2,807.0
GAS LIFT; 4,387.3
GAS LIFT; 5,573.E
GAS LIFT; 6,450.2
GAS LIFT; 6.904.9
LOCATOR; 6,9608
SEAL ASSY; 6,961.8
PBR; 6,967.8
PACKER; 6,990.9
NIPPLE; 7,043.3
LOCATOR; 7,090.4
SEAL ASSY; 7,091.2
PBR;7o922
PACKER: 7.105.9
NIPPLE; 7.127.9
SOS; 7,133.5
FISH; 7.133.5
IPERF; 7.201.0-7,214.0-�
IPERF; 7.316.0-7,331.0
FRAC; 7.316.0
IPERF; 7,347.0-7,377.0
PRODUCTION; 28.0-7,625.0
..._.._.._......
I
all
.motes:
9/29/2010
9/l/2014
9/122014
Annotation Depth (ftKB) End Date
Last Tag: SLM 7,356.0 6/302014
Annotation Last Mod By End Date
1 Rev Reason: FISH lehallf 9/142014
Casing ngs
I
_
Casing Description
CONDUCTOR
00 (in) ID (in)
16 15.060
Top (ftKB)
31.0
Set Depth (ftKB)
96.0
Set Depth (ND)...
96.0
WtlLen (I...
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in) ID (in)
95/8 8.921
Top (ftKB)
31.0
Se[ Depth (ftKB)
2,343.2
Set Depth (ND)...
2,242.8
WVLen (1...
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in) ID (in)
7 6.276
Top (ftKB)
28.0
Set Depth (ftKB)
7,625.0
Set Depth (ND)...
6,334.2
WtlLen (I...
26.00
Gratle
J-55
Top Thread
BTC
Tubing Strings
Tubing Description Stdng Ma... ID (In) Top (ftKB) Set Depth (ft.. Set Depth (ND) (... Wt (Iblit) Grade Top Connection
TUBING WO 31/2 2.992 27.2 7,092.2 5,878.9 9.30 L-80 EUE 8RD
Completion Details -
Top (ftKB)
Top (TVD) (ftKB)
Top Ind I')
Item Des
Co.
Nominal ID
(in)
27.2
27.2
0.16
HANGER
FMC GEN III TUBING HANGER
2.992
502.1
502.1
0.37
NIPPLE
DS LANDING NIPPLE w 2.875" Profile SN: T711315
2.875
6.960.8
5,770.0
34.89
LOCATOR
BAKER LOCATOR
2.990
6,961.8
5,770.8
34.88
SEAL ASSY
BAKER SEAL ASSY Stick up 7off Locator - Seals
Engaged 14.63'
2.940
6,967.8
5,775.7
34.80
PBR
BAKER PBR
4.000
6,990.9
5,794.7
34.51
PACKER
BAKER FHL FAKER w/ PBR (Center element on packer-
7002)
2.960
7,043.3
5,838.0
33.74
NIPPLE
DS LANDING NIPPLE w 2.813" Profile SN: T111322
2.812
7,090.4
5,877.4
33.02
LOCATOR
BAKER LOCATOR
2.990
7,091.2
5,878.1
33.00
SEAL ASSY
BAKER GBH-22 80-40 SEAL ASSY. Fully Located V
Spaced Off Locator Seals Engaged 10.84'
2.990
Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (ND) (... Wt gb/ft) Grade Top Connection
TUBING - Original 3112 2.992 7,092.2 7,134.1 5,914.2 9.30 J-55 EUE8RDMOD
Completion Details
Top (ftKB)
Top (ND) (ftKB)
Top Inc] I')
Item Des
Com
Nominal ID
(in)
7,092.2
5,878.9
32.99
PBR
BAKER 10' PBR
3.000
7,105.9
5,890.4
32.77
PACKER
BAKER FHL RETRIEVABLE PACKER
3.000
7,128.0
5,909.0
32.41
NIPPLE
CAMCO D NIPPLE NO GO
2.750
7,133.5
5,913.7
32,32
SOS
BAKER SHEAR OUT SUB
3.015
Other in Hole
(Wirellne retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
I (°)
I Des
Co.
Run Date
ID (in)
7,133.5
5,913.7
32.32
FISH
FISH INC DPPV, BOWEN JARS, HYD DISCO, 9/5/2014
DUAL CIRC VALVE BAKER MUD MOTOR,XO, DB
UNDERREAMER DAL 22.08'
Perforations & Slots
Top (ftKB)
Btm (ftKB)
Top (ND)
(ftKB)
Sim (ND)
(ftKB)
Zone
(shots/f
Date
Shot
Den
t)
Type
Com
7,201.0
7,214.0
5,971.1
5.982.2 C-4,
1L-04 7/10/1988
4.0 IPERF
21/8"
823198.
LinkJet. Squeezed
7,316.0
7,331.0
6,069.5
6,082.3 A-5,
1 L-04 10/7/1984
4.0 IPERF
4"
JJ II Csg Gun
7,347.0
7,377.0
6,096.0
6,121.7 A-4,1L-04
10/7/1984
4.0 IPERF
4"JJ
II Csg Gun
Stimulations & Treatments
Min Top Max
Depth
(ftKB)
Btm
Depth Top
(ftKB)
(ND)
(ftKB)
St. (ND)
(ftKB)
Type
Date
Com
7,316.0
7.377.0
6,069.5
6,121.7
FRAC
1/9/1985
A -SAND FRAC w/315 bbls OF GELLED WATER &
26,500N OF 12/20 SAND AS PROPPANT
Mandrel Inserts
at
N Top (ftKB)
Top (ND)
(ftKB)
Make
Model
OD (in)
Valve
a., Type
Latch
Type
Port Size
(in)
TRO Run
(psi)
Run Date
Com
2,807.0
2,599.2
CAMCO MMG
1 1/2 GAS
LIFT GLV
RK
1 0.1881
1,303.0
72/2014
2:00
2 4,387.3
3,793.6
CAMCO MMG
1 112 GAS
LIFT GLV
RK
1 0.1881
1,284.0
722014
5:00
3 5,573.8
4,688.4
CAMCO MMG
112 GAS
LIFT GLV
RK
0.188
1,266.0
722014
3:00
4 6,450.2
5,362.5
CAMCO MMG
11/2 GAS
LIFT GLV
RK
0.188
1,249.0
7/2/2014
8:00
_
5 6,904.9
5,724.3
CAMCO MMG
11/2 GASLIFT
OV
RK
0.188
0.0
7212014
7:00
General &.Safety
End Date
Annotation
NOTE: View Schematic /Alaska Schematic9.0
NOTE: Underreamed residual cement from 1998 cement squeeze from 7224' - 7289' MD
NOTE: Further wellwork will have to verify how much CT was left and where the Fish landed
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ORIGINAL
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 1 L Pad
1 L-04
1 L-04AL1
Plan: 1 L-04AL1 wp03
Standard Planning Report
02 October, 2014
Few a I
BAKER
HUGHES
ORIuIiVAL
ri.s
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project
Kuparuk River Unit
Site:
Kuparuk 1 L Pad
Well:
1 L-04
Wellbore:
1 L-04AL1
Design:
1 L-04AL1 _wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 L-04
Mean Sea Level
1 L-04 @ 116.00usft (1 L-04)
True
Minimum Curvature
3roject Kuparuk River Unit, North Slope Alaska, United States
Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Nap Zone: Alaska Zone 04 Using geodetic scale factor
Site
Kuparuk 1 L Pad
Site Position:
Northing:
5,949,190.90usft
Latitude:
70° 16' 19.650 N
From:
Map
Easting:
539,916.78
usft Longitude:
149° 40' 37.763 W
Position Uncertainty:
0.00 usft Slot Radius:
0.000 in Grid Convergence:
0.30 °
Well
1 L-04
Well Position
+N/-S
0.00 usft Northing:
5,949,370.89 usft Latitude:
700 16' 21.420 N
+E/-W
0.00 usft Easting:
539,914.96 usft Longitude:
149° 40' 37.789 W
Position Uncertainty
0.00 usft Wellhead Elevation:
usft Ground Level:
0.00 usft
Wellbore
1 L-04AL1
Magnetics
Model Name Sample Date
Declination Dip Angle
Field Strength
(°)
(°)
(nT)
BGG M2014 12/1 /2014
19.12 80.89
57,571
Design
1L-04AL1_wp03
Audit Notes:
Version:
Phase:
PLAN
Tie On Depth:
10,300.00
Vertical Section:
Depth From (TVD)
+N/-S
+E/-W Direction
(usft)
(usft)
(usft)
(°)
0.00
0.00
0.00
348.07
Plan Sections
Measured
TVD Below
Dogleg Build Turn
Depth Inclination
Azimuth System +N/-S
+E/-W
Rate Rate Rate
TFO
(usft) (°)
(°) (usft) (usft)
(usft)
(°/100ft) (°/100ft) (°/100ft)
(°)
Target
10,300.00
89.36
316.82 5,972.40 6,179.20
-861.82
0.00 0.00 0.00
0.00
10,403.00
99.66
316.82 5,964.30 6,253.97
-931.99
10.00 10.00 0.00
0.00
10,473.00
99.59
323.92 5,952.58 6,307.09
-975.97
10.00 -0.10 10.14
90.00
10,573.00
90.02
321.01 5.944.21 6,386.00
-1,036.62
10.00 -9.57 -2.91
197.00
10,773.00
87.97
340.91 5,947.76 6,559.93
-1,133.21
10.00 -1.02 9.95
96.00
11,023.00
88.16
315.89 5,956.34 6,771.05
-1,263.09
10.00 0.08 -10.01
270.00
11,173.00
89.51
330.84 5,959.40 6,891.06
-1,352.32
10.00 0.90 9.96
85.00
11,373.00
89.71
350.84 5,960.76 7,079.01
-1,417.64
10.00 0.10 10.00
89.50
11,700.00
89.76
318.14 5.962.30 7,370.13
-1,556.58
10.00 0.01 -10.00
270.00
101212014 12:49:12PM Page 2 COMPASS 5000.1 Build 61
rG.I
ConocoPhillips Planning Report OMER
HUGHES
Database:
EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1 L-04
Company:
ConocoPhillips (Alaska) Inc. -Kup2
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 L-04 @ 116.00usft (1 L-04)
Site:
Kuparuk 1 L Pad
North Reference:
True
Well:
1 L-04
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 L-04ALl
Design:
1 L-04AL1_wp03
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(a)
V)
(usft)
(usft)
(usft)
(usft)
(°/10oft)
V)
(usft)
(usft)
10,300.00
89.36
316.82
5,972.40
6,179.20
-861.82
6,223.92
0.00
0.00
5,955,544.82
539,020.47
TIP/KOP
10,400.00
99.36
316.82
5,964.80
6,251.81
-929.96
6,309.05
10.00
0.00
5,955,617.07
538,951.95
10,403.00
99.66 '
316.82
5,964.30
6,253.97
-931.99
6,311.58
10.00
0.00
5,955,619.22
538,949.91
2
10,473.00
99.59
323.92
5,952.58
6,307.09
-975.97
6,372.64
10.00
90.00
5,955,672.09
538,905.65
3
10,500.00
97.01
323.12
5,948.69
6,328.57
-991.86
6,396.94
10.00
-163.00
5,955,693.49
538,889.65
10,573.00
90.02
321.01
5,944.21
6,386.00
-1,036.62
6,462.37
10.00
-163.11
5,955,750.67
538,844.59
4
10.600.00
89.74
323.69
5,944.27
6,407.37
-1,053.11
6,486.70
10.00
96.00
5,955,771.96
538,827.98
10,700.00
88.70
333.64
5,945.64
6,492.67
-1,105.04
6,580.89
10.00
95.99
5,955,856.97
538,775.61
10,773.00
87.97
340.91
5,947.76
6,559.93
-1,133.21
6,652.52
10.00
95.86
5,955,924.08
538,747.09
6
10,800.00
87.97
338.21
5,948.72
6,585.21
-1,142.64
6,679.20
10.00
-90.00
5,955,949.30
538,737.53
10,900.00
88.02
328.20
5,952.22
6,674.31
-1,187.63
6,775.67
10.00
-89.90
5,956,038.15
538,692.06
11,000.00
88.13
318.20
5,955.59
6,754.23
-1,247.43
6,866.22
10.00
-89.55
5,956,117.75
538,631.85
11,023.00
88.16
315.89
5,956.34
6,771.05
-1,263.09
6,885.92
10.00
-89.22
5,956,134.48
538,616.10
6
11,100.00
88.85
323.57
5,958.36
6,829.74
-1,312.81
6,953.61
10.00
85.00
5,956,192.90
538,566.08
11,173.00
89.51
330.84
5,959.40
6,891.06
-1,352.32
7,021.77
10.00
84.80
5,956,254.00
538,526.25
7
11,200.00
89.54
333.54
5,959.62
6,914.93
-1,364.92
7,047.74
10.00
89.50
5,956,277.81
538,513.52
11,300.00
89.64
343.54
5,960.35
7,007.88
-1,401.46
7,146.23
10.00
89.48
5.956,370.55
538,476.49
11,373.00
89.71
350.84
5,960.76
7,079.01
-1,417.64
7,219.17
10.00
89.41
5,956,441.59
538,459.94
8
11,400.00
89.72
348.14
5,960.90
7,105.56
-1,422.56
7,246A6
10.00
-90.00
5,956,468.10
538,454.87
11,500.00
89.72
338.14
5,961.39
7,201.13
-1,451.54
7.345.66
10.00
-89.99
5,956,563.52
538,425.40
11,600.00
89.74
328.14
5,961.86
7.290.23
-1,496.67
7,442.15
10.00
-89.94
5,956,652.36
538,379.80
11,700.00
89.76
318.14
5,962.30
7,370A3
-1,556.58
7,532.71
10.00
-89.89
5,956,731.94
538,319.47
Planned TD at 11700.00
10/2/2014 12:49:12PM ORIGINAL
PagCOMPASS 5000.1 Build 61
ConocoPhillips
Planning Report
BAKER
HUGHES
Database: EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1 L-04
Company: ConocoPhillips (Alaska) Inc. -Kup2
TVD Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
1 L-04 @ 116.00usft (1 L-04)
Site: Kuparuk 1 L Pad
North Reference:
True
Well: 1L-04
Survey Calculation Method:
Minimum Curvature
Wellbore: 1L-04ALl
Design: 1 L-04AL1_wp03
Targets
Target Name
hit/miss target Dip Angle Dip Dir.
TVD
+N/-S +E/-W
Northing
Easting
Shape (1) V)
(usft)
(usft) (usft)
(usft)
(usft)
Latitude Longitude
1L-04A_Fault2 0.00 0.00
0.00
-297.691,139,410.37
5,955,116.00
1,679,199.00
70° 2' 16.173 N 140' 32' 13.562 W
plan misses target center by 1140306.22usft
at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
Rectangle (sides W310.00 1-11.00 D0.00)
1L-04AL1_T02 0.00 0.00
5,944.00
130.201,139,061.60
5,955,542.00
1,678,848.00
70' 2' 20.840 N 140' 32' 21.635 W
plan misses target center by 1139939.46usft
at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
Point
1L-04AL1_T03 0.00 0.00
5,959.00
589.761,138,778.00
5,956,000.00
1,678,562.00
70' 2' 25.718 N 140' 32' 27.720 W
- plan misses target center by 1139653.52usft
at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
- Point
1L-04 CTD Polygon_Sot 0.00 0.00
0.00
-2,926.751,138,988.38
5,952,485.00
1,678,791.00
70' 1' 51.266 N 140° 32' 36.845 W
plan misses target center by 1139902.21 usft
at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
Polygon
Point 1
0.00
0.00 0.00
5,952,485.00
1,678,791.00
Point
0.00
156.14 -23.18
5,952,641.00
1,678,766.99
Point 3
0.00
280.90 25.48
5,952,766.00
1,678,814.99
Point
0.00
374.25 150.98
5,952,860.01
1,678,939.98
Points
0.00
390.39 315.09
5,952,877.02
1,679,103.98
Point
0.00
309.42 498.68
5,952,797.03
1,679,287.98
Point
0.00
50.86 788.36
5,952,540.04
1,679,579.00
Point 8
0.00
-140.83 916.36
5,952,349.05
1,679,708.00
Point
0.00
-505.35 1,007.46
5,951,985.05
1,679,801.03
Point 10
0.00
-696.24 982.45
5,951,794.05
1,679,777.03
Point 11
0.00
-900.87 908.37
5,951,589.05
1,679,704.05
Point 12
0.00
-1,295.89 712.27
5,951,193.03
1,679,510.06
Point 13
0.00
-1,618.11 557.56
5,950,870.03
1,679,357.08
Point 14
0.00
-2,168.81 297.64
5,950,318.01
1,679,100.11
Point 15
0.00
-2,446.57 247.18
5,950,040.02
1,679,051.13
Point 16
0.00
-2,402.84 -81.63
5,950,082.00
1,678,722.12
Point 17
0.00
-2,118.02 -42.13
5,950,366.99
1,678,760.11
Point18
0.00
-1,501.26 207.14
5,950,985.01
1,679,006.08
Point 19
0.00
-1,148.30 414.01
5,951,339.02
1,679,211.05
Point20
0.00
-771.19 590.02
5,951,717.03
1,679,385.04
Point21
0.00
-642.50 652.70
5,951,846.03
1,679,447.03
Point22
0.00
-521.62 678.34
5,951,967.04
1,679,472.03
Point23
0.00
-246.25 613.78
5,952,242.03
1,679,406.02
Point24
0.00
-134.91 551.35
5,952,353.03
1,679,343.00
Point25
0.00
88.51 285.50
5,952,575.01
1,679,076.00
Point26
0.00
0.00 0.00
5,952,485.00
1,678,791.00
1L-04AL1_T04 0.00 0.00
5,962.00
1,073.911,138,570.55
5,956,483.00
1,678,352.00
70° 2' 30.723 N 140' 32' 31.537 W
plan misses target center by 1139443.80usft at 10300.00usft
MD (5972.40 TVD, 6179.20
N,-861.82 E)
Point
1L-04AL3_Faultl 0.00 0.00 0.00-3,454.221,139,819.67 5,951,962.00
1,679,625.00 70° 1' 44.924 N 140° 32' 15.496 W
plan misses target center by 1140737.80usft at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
Rectangle (sides W330.00 H1.00 D0.00)
1 L-04AL1_T01 0.00 0.00 5,950.00 24.771,139,141.05 5,955,437.00
1,678,928.00 70' 2' 19.699 N 140° 32' 19.830 W
plan misses target center by 1140019.47usft at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
- Point
1L-04 CTD Polygon_Noi 0.00 0.00 0.00-2,926.751,138,988.38 5,952,485.00
1,678,791.00 70° V S1.266 N 140' 32' 36.845 W
plan misses target center by 1139902.21 usft at 10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
Polygon
Point 1 0.00 0.00 0.00 5,952,485.00
1,678,791.00
Point 0.00 201.25 -43.95 5,952,685.99
1,678,745.99
Point 3 0.00 398.08 -6.91 5,952,883.00
1,678,781.98
Point 0.00 650.56 98.43 5,953,136.01
1,678,885.97
10/2/2014 12:49:12PM Page 4 COMPASS 5000.1 Build 61
OR I G I NA L
Y
ConocoPhilli s
p
Planning Report
BAKER
HUGHES
Database: EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1 L-04
Company: ConocoPhillips (Alaska) Inc. -Kup2
TVD Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
1 L-04 @ 116.00usft (1 L-04)
Site: Kuparuk 1 L Pad
North Reference:
True
Well: 1 L-04
Survey Calculation Method:
Minimum Curvature
Wellbore: 1 L-04ALl
Design: 1 L-04AL1_wp03
Points
0.00
929.59
288.91
5,953,416.02
1,679,074.95
Point
0.00
1,299.60
484.88
5,953,787.03
1,679,268.93
Point
0.00
1,738.35
542.19
5,954,226.03
1,679,323.91
Point
0.00
2,182.67
489.52
5,954,670.02
1,679,268.89
Point
0.00
2,463.33
369.98
5,954,950.02
1,679,147.87
Point 10
0.00
2,671.25
200.05
5,955,157.01
1,678,976.86
Point 11
0.00
2,864.40
-15.96
5,955,348.99
1,678,759.85
Point 12
0.00
3,269.73
-258.85
5,955,752.99
1,678,514.84
Point13
0.00
4,029.55
-589.90
5,956,510.97
1,678,179.80
Point 14
0.00
4,169.12
-315.14
5,956,651.98
1,678,453.78
Point 15
0.00
3,448.24
28.11
5,955,933.00
1,678,800.82
Point 16
0.00
3,127.22
214.45
5,955,613.01
1,678,988.84
Point 17
0.00
2,870.98
445.13
5,955,358.02
1,679,220.85
Point 18
0.00
2,632.01
625.89
5,955,120.03
1,679,402.86
Point 19
0.00
2,217.85
836.74
5,954,707.04
1,679,615.88
Point20
0.00
1,736.59
877.22
5,954,226.05
1,679,658.91
Point 21
0.00
1,182.96
795.30
5,953,672.05
1,679,579.94
Point22
0.00
805.98
592.30
5,953,294.03
1,679,378.96
Point23
0.00
485.10
371.59
5,952,972.02
1,679,159.98
Point24
0.00
189.60
270.03
5,952,676.01
1,679,059.99
Point25
0.00
91.49
288.51
5,952,578.01
1,679,078.99
Point26
0.00
0.00
0.00
5,952,485.00
1,678,791.00
1L-04A_Faultl 0.00 0.00
0.00
-2,534.581,139,153.47
5,952,878.00
1,678,954.00 70' 1' 54.831 N 140' 32' 30.471 W
- plan misses target center by 1140064.24usft at
10300.00usft MD (5972.40 TVD, 6179.20 N,-861.82 E)
- Rectangle (sides W330.00 H1.00 D0.00)
Casing Points
Measured Vertical Casing
Depth Depth Diameter
(usft) (usft) Name (in)
11,700.00 5,962.30 2-3/8" 2.375
Hole
Diameter
(in)
3 000
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+Nl-S
+E/-W
(usft)
(usft)
(usft)
(usft)
Comment
10,300.00
5,972.40
6,179.20
-861.82
TIP/KOP
10,403.00
5,964.30
6,253.97
-931.99
2
10,473.00
5,952.58
6,307.09
-975.97
3
10,573.00
5,944.21
6,386.00
-1,036.62
4
10,773.00
5,947.76
6,559.93
-1,133.21
5
11,023.00
5,956.34
6,771.05
-1,263.09
6
11,173.00
5,959.40
6,891.06
-1,352.32
7
11,373.00
5,960.76
7,079.01
-1,417.64
8
11,700.00
5,962.30
7,370.13
-1,556.58
Planned TD at 11700.00
101212014 12:49.12PM Page 5 COMPASS 5000.1 Build 61
ORIGINAL
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ConocoPhillips
ConocoPhillips (Alaska) Inc.
-Kup2
Kuparuk River Unit
Kuparuk 1 L Pad
1 L-04
1 L-04AL1
1 L-04AL1_wp03
Travelling Cylinder Report
02 October, 2014
WE a I
BAKER
HUGHES
ORIGINAL
rigs
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1 L Pad
Site Error:
0,00usft
Reference Well:
1 L-04
Well Error:
0 00usft
Reference Wellbore
1 L-04ALl
Reference Design:
1 L-04AL1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 L-04
1 L-04 @ 116.00usft (1 L-04)
1 L-04 @ 116.00usft (1 L-04)
True
Minimum Curvature
1.00 sigma
EDM Alaska Prod
Offset Datum
Reference
1L-04AL1_wp03
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft Error Model: ISCWSA
Depth Range:
10,300.00 to 11,700.00usft Scan Method: Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,358.40usft Error Surface: Elliptical Conic
Survey Tool Program
Date 10/2/2014
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
200.00
7,200.00 1 L-04 (1 L-04)
GCT-MS
Schlumberger GCT multishot
7,200.00
10,300.00 1 L-04A_wp06 (1 L-04A)
MWD
MWD - Standard
10,300.00
11,700.00 1 L-04AL1_wp03 (1 L-04AL1)
MWD
MWD - Standard
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name
11,700.00 6,078.30 2-3/8" 2-3/8 3
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1 F Pad
1 F-04 - 1 F-04 - 1 F-04
1 F-09 - 1 F-09 - 1 F-09
1 F-20 - 1 F-20 - 1 F-20
1 F-20 - 1 F-20PB1 - 1 F-20PB1
Kuparuk 1 L Pad
1 L-03 - 1 L-03 - 1 L-03
1 L-04 - 1 L-04A - 1 L-04A_wp06
Reference Offset Centre to No -Go Allowable
Measured Measured Centre Distance Deviation Warning
Depth Depth Distance (usft) from Plan
(usft) (usft) (usft) (usft)
10,321.62 7,225.00 331.13 241.49
10,300.00 10,300.00 0.00 0.22
Out of range
99.44 Pass - Major Risk
Out of range
Out of range
Out of range
-0.22 FAIL - Minor 1/10
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
10/2/2014 8:44:30AM Page 2 of 7 COMPASS 5000. 1 Build 61
J R N A L
TRANSMITTAL LETTER CHECKLIST
WELL NAME: Kl2(A- ) � — Oy Al_ I
PTD:
�Deveiopment _Service _Exploratory _ Str atlgr aphic Test Non Conventional
FIELD: I`UW\ ��1�E� POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI LATERAL
The permit is for a new wellbore segment of existing well Permit
(If last two digits
No. API No. 50- U�_ I �9 -ol -0(�).
in API number are
Production should continue to be reported as a function of the original
between 60-69)
API number stated above.
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 name
Pilot Hole
( 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
Spacing Exception
conservation 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 4/2014
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
Well Name: KUPARUK RIV UNIT 1 L-04AL1 Program DEV Well bore seg
PTD#:2141590 Company
CONOCOPHILLIPS ALASKA INC Initial Class/Type
DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal
Administration
1
Permit fee attached
NA
2
Lease number appropriate
Yes
ADL0025659, Surf & Top Prod; ADL0025652, TD
3
Unique well name and number
Yes
KRU 1L-04AL1
4
Well located in a defined pool
Yes
KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order 432C
5
Well located proper distance from drilling unit boundary
Yes
CO 432C contains no spacing restrictions with respect to drilling unit boundaries.
6
Well located proper distance from other wells
Yes
CO 432C has no interwell spacing restrictions.
7
Sufficient acreage available in drilling unit
Yes
8
If deviated, is wellbore plat included
Yes
9
Operator only affected party
Yes
Wellbore will be more than 500' from an external property line where ownership or landownership changes.
10
Operator has appropriate bond in force
Yes
11
Permit can be issued without conservation order
Yes
Appr Date
12
Permit can be issued without administrative approval
Yes
13
Can permit be approved before 15-day wait
Yes
PKB 10/10/2014
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
17
Nonconven. gas conforms to AS31.05.0300.1.A),(j.2.A-D)
NA
18
Conductor string provided
NA
Conductor set in KRU 1 L-04
Engineering
19
Surface casing protects all known USDWs
NA
Surface casing set in KRU 1 L-04
20
CMT vol adequate to circulate on conductor & surf csg
NA
Surface casing set and fully cemented
21
CMT vol adequate to tie-in long string to surf csg
NA
22
CMT will coverall known productive horizons
No
Productive_ interval will be completed with slotted 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
No
26
Adequate wellbore separation proposed
Yes
Proximity analysis performed; no major risk failures
27
If diverter required, does it meet regulations
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is 4135 psi(13.1 ppg EMW); will drill w/ 9.6 ppg EMW and maintain overbalance w/ MPD
VTL 10/20/2014
29
BOPEs, do they meet regulation
Yes
30
BOPE_press rating appropriate; test to (put psig in comments)
Yes
MPSP is 3531 psi; will test BOPS to 4000 psi
31
Choke_ manifold complies w/API RP-53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
H2S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA
35
-Permit _can be issued w/o hydrogen sulfide measures -
No
Wells -on 1L-Pad are H2S-bearing. H2S measures required.
Geology
36
Data -presented on potential overpressure zones
Yes
Expected reservoir pressure is _13.1 ppg EMW; will be drilled using 9.6 ppg mud and
Appr Date
37
Seismic analysis of shallow gas zones
NA
MPD technique. Two well -bore volumes of 13.1 ppg KWF will be available.
PKB 10/10/2014
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly -progress reports [exploratory only]
NA
Onshore development well. - - - - - - - -
Geologic Engineering Public
Date: Date Date
Commissioner: Commissioner- Commissioner
pry 1012311 y IJ-Tr.,, +0f 23 Pq
