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HomeMy WebLinkAbout217-022Guhl, Meredith D (DOA)
From: Guhl, Meredith D (DOA)
Sent: Friday, March 29, 2019 1:33 PM
To: Eller, J Gary
Cc: Loepp, Victoria T (DOA); Boyer, David L (DOA)
Subject: KRU 3E-201-1, 1-1-01, 1-1-02, 1-1-03, PTDs 217-022, 217-023, 217-024, 217-025: Expired
Hello Gary,
The following Permits to Drill, issued to ConocoPhillips Alaska, have expired under Regulation 20 AAC 25.005 W. The
PTDs will be marked expired in the AOGCC database.
• KRU 3E-20 L1, PTD 217-022, Issued 14 March 2017
• KRU 3E-20 1-1-01, PTD 217-023, Issued 14 March 2017
• KRU 3E-20 L1-02, PTD 217-024, Issued 14 March 2017
• KRU 3E-20 1-1-03, PTD 217-025, Issued 14 March 2017
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.eov.
THE STATE Alaska Oil and Gas
o1AT ASKA Conservation Commission
GOVERNOR BILL WALKER
G. Eller
CTD Team Lead
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-20L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 217-022
Surface Location: 4869' FNL, 224' FEL, SEC. 16, T11N, RI OE, UM
Bottomhole Location: 912' FNL, 1167' FEL, SEC. 22, T11N, RI OE, UM
Dear Mr. Eller:
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. 183-005, API No. 50-029-
20895-00-00. 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
ACathy. Foerster
Chair
DATED this J day of March, 2017.
STATE OF ALASKA
ALA; OIL AND GAS CONSERVATION COMMIS J
�r.t.;civru
FEB 21 2017
PERMIT TO DRILL
20 AAC 25.005
AQGCG
1 a. Type of Work:
1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑
1 c. Specify if well is proposed for:
Drill ❑ Lateral -21
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 Q • Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska Inc
Bond No. 5952180 •
KRU 1 E-20L1
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 11300' ' TVD: 6200' '
Kuparuk River Field /
4a. Location of Well (Governmental Section):
7. Property Designation (Lease Number):
Kuparuk River Oil Pool
Surface: 4869' FNL, 224' FEL, Sec 16, T11 N, R10E, UM
ADL 25651 `
Top of Productive Horizon:
8. Land Use Permit:
13. Approximate Spud Date:
3296' FNL, 1256' FEL, Sec 15, T11 N, R10E, UM
ALK 469
3/6/2017
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property:
912' FNL, 1167' FEL, Sec 22, T11 N, R10E, UM
2560
17300'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 106'
r15SDistance to Nearest Well Open
Surface: x- 550300 y- 5960000 Zone- 4
GL Elevation above MSL (ft): 67'
me Pool: 324', 1E-03
16. Deviated wells: Kickoff depth: 7967' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 101 degrees
Downhole: 3034 ' Surface: 2412
18. Casing Program:
Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole
Casing
Weight
Grade
Coupling
I Length
MD
TVD
MD
TVD
(including stage data)
3"
2-3/8"
4.6#
L-80
ST-L
1950'
9350'
6185'
11300'
6200'
Slotted 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):
8650'
6756'
N/A
8538'
6668'
7980'
Casing
Length
Size
Cement Volume
MD
TVD
Conductor
76'
16"
290 sx AS II
110,
110,
Surface
2347'
10-3/4"
1300 sx AS III & 235 sx AS 1
2380'
2172'
Production
8591'
7"
1050 sx Class G
8622'
6734'
Perforation Depth MD (ft): 7945' - 8094', 8349' - 8362',
Perforation Depth TVD (ft): 6210' - 6325', 6521' - 6532',
8382' - 8410'
6547' - 6569'
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis ❑
Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑� 29JAC 25.050 requirements Q
21. Verbal Approval: Commission Representative: � /16/2017
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Keith Herring @ 263-4321
be deviated from without prior written approval. Contact
Email Keith. E. Herring(cD_cop.com
Printed Name G. Eller Title CTD Team Lead
Signature Phone 263-4172 Date 7 Z O 2
Commission Use Only
Permit to Or "
API Number:
Permit Approval
See cover letter for other
Number: ! - Q
50- QV5 - 0 -Qtj
Date:
I
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: V
Other: BDP �C ho 3 00 / 2 ) Samples req'd: Yes ❑ No[►r Mud log req'd: Yes❑ No[�
'
LL No
!vt f Y✓ � /u Z 500 zjS �easures: Yes [j4 Noo Directional svy req'd: Yes [
h v/a ❑
f jet ✓ /
�7�"CV
Spacing !Jon req'd: Yes ❑ No u Inclination -only svy req'd: Yes ❑ Nog
Post initial injection MIT req'd: Yes ❑ No IFEr'
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: 3 _.1
i-
O R
Submit Form and
Form 10-a01 (Revised 11/2015) ' T i r i i i f 4 months from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate
ConocoPhillips
p
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 16, 2017
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
RECEIVED
FEB 21 2017
OGGO
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a quad -lateral out of the KRU 1 E-20
(PTD# 183-005) using the coiled tubing drilling rig, Nabors CDR3-AC.✓
The scope of the window exit for KRU 1 E-20 has been modified from a cement pilot -hole casing exit to utilizing a
3-1/2" x 7" high expansion wedge exit. For this reason, please cancel the previously issued sundry (316-630).
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC
25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being
limited to 500' from the original point.
The CTD objective will be to drill four laterals (1E-201-1, 1E-201_1-01, 1E-201-1-02, & 1E-20L1-03), targeting the
Kuparuk C-sand intervals./ The work is scheduled to begin March 2017.
Attached to this application are the following documents:
— Permit to Drill Application Forms (10-401) for 1E-201-1, 1E-201_1-01, 1E-201_1-02 & 1E-20L1-03
— Detailed Summary of Operations
— Directional Plans for 1 E-201-1, 1 E-201_1-01, 1 E-20L1-02 & 1 E-201_1-03
— Current wellbore schematic
— Proposed wellbore schematic
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
i
i"
K ith Herring
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
T
Kuparuk CTD Laterals NABORSrAALLASKA
1 E-201-15 1 E-201-1-015 1 E-20L1-02 & 1 E-201-1-03
Application for Permit to Drill Document 2RC
1.
Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(f) 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
8.
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............................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................6
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6
15. Directional Plans for Intentionally Deviated Wells....................................................................... 6
(Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6
16. Attachments.................................................................................................................................... 7
Attachment 1: Directional Plans for 1 E-201-1, 1 E-201-1-01, 1 E-201-1-02 & 1 E-201-1-03..................................................7
Attachment 2: Current Well Schematic for 1 E-20............................................................................................................7
Attachment 3: Proposed Well Schematic for 1 E-201-1, 1 E-201-1-01, 1 E-20L1-02 & 1 E-201-1-03....................................7
Page 1 of 7 February 16, 2016
PTD Application: 1E-20L1, 1E-201_1-01, 1E-201_1-02 & 1E-201_1-03
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 1E-20L1, 1E-201-1-01, 1E-20L1-02 & 1E-20L1-03. 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 C sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 1E-20L1, 1E-201_1-01, 1E-201_1-02 & 1E-20L1-03.
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 CDR3-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 to 3,500 psi. Using the
maximum formation pressure in the area of 3,034 psi in 1 D-03 (i.e. 9.4 ppg EMW), the maximum
potential surface pressure in 1 E-20, assuming a gas gradient of 0.1 psi/ft, would be 2,412 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2,500 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))
The formation pressure in KRU 1 E-20 was measured to be 2,728 psi (8.4 ppg EMW) on 7/4/2016. The
maximum downhole pressure in the 1 E-20 vicinity is to the west in the 1 D-03 injector at 3,034 psi (9.4 ppg
EMW) from March of 2016.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Wells on 1 E pad have injected gas, so there is a chance of encountering free gas while drilling the 1 E-20
laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank
away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1 E-20 laterals will be losses to the formation. Managed
pressure drilling (MPD) target pressure will be reduced in order to manage losses to the formation.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 E-20 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 7 February 16, 2016
PTD Application: 1 E-201-1, 1 E-201_1-01, 1 E-201_1-02 & 1 E-201_1-03
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
MD
MD
TVDSS
TVDSS
1E-20L1
9350'
11300'
6079'
6094'
2-3/8", 4.7#, L-80, ST-L slotted liner;
aluminum billet on to
1E-201-1-01
8725'
11300'
6188'
6037'
2-3/8", 4.7#, L-80, ST-L slotted liner;
aluminum billet on top
1E-201-1-02
8017'
11300'
6156'
6081'
2-3/8", 4.7#, L-80, ST-L slotted liner;
aluminum billet on to
1E-201_1-03
7785'
11300'
5980'
6148'
2-3/8", 4.7#, L-80, ST-L slotted liner;
up into 3-1/2" tubing
Existing Casing/Liner Information
Category
OD
Weight
(ppf)
Grade
Connection
Top MD
Btm MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
65.0
H-40
Welded
34'
110,
34'
110,
1640
670
Surface
10-3/4"
45.5
K-55
BTC
33'
2380'
33'
2172'
3580
2090
Production
7"
26.0
K-55
BTC
31'
8622'
31'
6734'
4980
4320
Tubing
3-1/2"
9.3
J-55
BTC-MOD
28'
7807'
28'
6103'
6990
7400
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-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
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based FloVis mud (8.6 ppg)
— Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: BHA's will be deployed using standard pressure deployments and the well will
be loaded with 8.6 ppg FloVis completion fluid to provide formation over -balance and wellbore stability
while running completions. If higher than expected pressure is encountered while drilling the laterals,
then an overbalanced completion fluid will be utilized to provide formation over -balance. The last
lateral will be displaced to a 10.0 ppg NaCl completion fluid to allow a swell packer to be run into this
hole section.
i Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud
weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled
tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 1 E-20 laterals we will target a constant BHP of 8.6 ppg EMW at the window. The constant BHP target will
be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if
Page 3 of 7 February 16, 2016
PTD Application: 1E-20L1, 1E-201-1-01, 1E-201_1-02 & 1E-20L1-03
increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. 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 1 E-20 Window (7967' MD, 6227' TVD) Using MPD
Pumps On 1.5 bpm)
Pumps Off
A -sand Formation Pressure (8.4 pp)
2728 psi
2728psi'
Mud Hydrostatic (8.6 pp)
2784 psi
2784 psi
Annular friction (i.e. ECD, 0.08 psi/ft)
637 psi
0 psi
Mud + ECD Combined
(no choke pressure)
3421 psi
(overbalanced -693psi)
2784 psi
(overbalanced -56 psi)
Target BHP at Window (8.6 )
2784 psi
2784 psi
Choke Pressure Required to Maintain
Target BHP
0 psi
0 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AA 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AA 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AA 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AA 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AA 25.005(c)(13))
Summary of Operations
Background
Well KRU 1E-20 is a Kuparuk A -sand and C-sand producer equipped with 3-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize four laterals to target the C sands to the south of the 1E-20. The
laterals will add new resources and improve existing recovery.
A mechanical whip -stock will be set inside the 7" production casing at the planned kick off point of 7967'
MD. The 1E-20L1 lateral will exit the 7" production casing at 7967' MD and TD at 11300' MD, targeting
the C sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 9350' MD with an
aluminum billet for kicking off the 1E-20L1-01 lateral.
The 1E-20L1-01 lateral will drill to the south to TD at 11300' MD targeting the C sand. It will be
completed with 2-3/8" slotted liner from TD up to 8725' MD with an aluminum billet for kicking off the
1 E-20L 1-02 lateral.
The 1E-20L1-02 lateral will drill to the south to TD at 11300' N4D targetingthe C sand. It will be
completed with 2-3/8" slotted liner from TD up to 8017' MD with an aluminum billet for kicking off the
1 E-20L 1-03 lateral.
Page 4 of 7 February 16, 2016
PTD Application: 1E-201_1, 1E-20L1-01, 1E-201_1-02 & 1E-201_1-03
The 1E-20L1-03 lateral will drill to the south to TD at 11300' MD targeting the C sand. It will be
completed with 2-3/8" slotted liner from TD up to 7785' MD. The liner will include a swell packer, blank
2-3/8" liner, and a sealbore deployment sleeve to allow for future isolation of the 1E-20 motherbore, but it
is not proposed at this time.
Pre-CTD Work
1. RU Slickline: Obtain SBHP, dummy off gas lift mandrels, and pressure test.
2. RU E-Line: Mill out "D" nipple to 2.80" ID.
3. Prep site for Nabors CDR3-AC and set BPV.
Rid Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 1E-20L1 Lateral (C sand - south)
a. Set top of whipstock at 7967' MD.
b. Mill 2.80" window at 7967' MD.
c. Drill 3" bi-center lateral to TD of 11300' MD.
d. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9350' MD.
3. 1 E-20L 1 -0 1 Lateral (C sand - south)
a. Kickoff of the aluminum billet at 9350' MD.
b. Drill 3" bi-center lateral to TD of 11300' MD.
c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8725' MD.
4. 1E-20L1-02 Lateral (C sand - south)
a. Kick off of the aluminum billet at 8725' MD.
b. Drill 3" bi-center lateral to TD of 11300' MD.
c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8017' MD.
5. 1 E-20L 1-03 Lateral (C sand- south)
a. Kick off of the aluminum billet at 8017' MD.
b. Drill 3" bi-center lateral to TD of 11300' MD.
c. Run 2-3/8" slotted liner from TD up to 7785' MD. Liner will include a swell packer, blank 2-
3/8" liner, and a sealbore deployment sleeve.
6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Pull BPV.
2. Return to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. 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 slick -line lubricator can be used. 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.
Page 5 of 7 February 16, 2016
PTD Application: 1E-201_1, 1E-201_1-01, 1E-201_1-02 & 1E-201_1-03
— 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.
Liner Running
— The 1 E-20 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
— While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide
secondary well control while running 2-3/8" 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 AAC 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plans
— 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 open hole section.
— Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
Distance
1 E-20L1
17300'
1 E-20 L1-01
17315'
1 E-20L1-02
17280'
1 E-201_1-03
17280'
— Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1 E-20L1
324'
1 E-03
1E-20L1-01
265'
1E-03
1 E-20L1-02
305'
1 E-03
1 E-20L1-03
332'
1 E-03
Page 6 of 7 February 16, 2016
PTD Application: 1E-201-1, 1E-201-1-01, 1E-20L1-02 & 1E-201-1-03
16. Attachments
Attachment 1: Directional Plans for 1 E-20L 1, 1 E-20L 1-01, 1 E-20L 1-02 & 1 E-20L 1-03 laterals
Attachment 2: Current Well Schematic for 1 E-20
Attachment3: Proposed Well Schematic for 1E-20L1, 1E-20L1-01, 1E-20L1-02 & 1E-20L1-03laterals
Page 7 of 7 February 16, 2016
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ConocoPh i I I i ps
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1 E Pad
1 E-20
1 E-20L1
Plan: 1 E-20L1_wpO3
Standard Planning Report
09 February, 2017
VIA Pp' 2
BAKER
HUGHES
ConocoPhillips WGaI
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1 E Pad
Well:
1 E-20
Wellbore:
1 E-20L1
Design:
1 E-20L1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
Project 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 E Pad
Site Position:
Northing:
5,959,760.24 usft Latitude:
70° 18' 3.022 N
From:
Map
Easting:
549,889.51 usft Longitude:
149° 35' 45.358 W
Position Uncertainty:
0.00 usft Slot Radius:
0.000 in Grid Convergence:
0.38 °
Well
1 E-20
Well Position
+N/-S
0.00 usft Northing:
5,960,000.68 usft Latitude:
70° 18' 5.359 N
+E/-W
0.00 usft Easting:
550,300.56 usft Longitude:
149° 35' 33.326 W
Position Uncertainty
0.00 usft Wellhead Elevation:
usft Ground Level:
0.00 usft
Wellbore
1 E-2011
Magnetics
Model Name
Sample Date
Declination Dip Angle
Field Strength
BGGM2016 5/1/2017
17.66 80.93
57,541
Design
1 E-20L1_wp03
Audit Notes:
Version:
Phase: PLAN
Tie On Depth:
7,900.00
Vertical Section:
Depth From (TVD)
+N/-S +E/-W
Direction
(usft)
(usft) (usft)
(I
0.00
0.00 0.00
180.00
2/9/2017 3:08:54PM Page 2 COMPASS 5000.1 Build 74
ConocoPhillips MAP aI
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1 E Pad
Well:
1 E-20
Wellbore:
1 E-201-1
Design:
1E-20L1_wp03
Plan Sections
Measured
TVD Below
Depth
Inclination
Azimuth
System
+N/-S
(usft)
(°)
(°)
(usft)
(usft)
7,900.00
39.27
64.97
6,069.61
1,555.86
7,967.00
39.54
64.47
6,121.38
1,574.02
7,988.00
42.48
64.47
6,137.22
1,579.96
8,058.00
71.88
64.47
6,174.75
1,605.03
8,160.00
72.81
109.53
6.207.21
1,609.86
8,260.00
89.94
148.49
6,222.75
1,548.49
8,385.00
89.96
200.99
6,222.86
1,428.33
8,485.00
95.32
205.50
6,218.25
1,336.60
8,610.00
97,52
214.03
6,204.25
1,228.87
8,750.00
99.10
223.80
6,183.96
1.121.21
8,865.00
99.71
215.66
6,165.13
1,034.04
8,965.00
99.64
208.56
6,148.30
950.60
9,365.00
100.85
180.13
6,075.71
573.46
9,565.00
93.25
168.27
6,051.10
376.52
9,765.00
90.75
154.48
6,044.08
187.59
9,900.00
89.11
163.79
6,044.25
61.58
10,175.00
85.22
182.67
6,057.97
-209.87
10,245.00
85.24
187.59
6,063.79
-279.33
10,445.00
90.11
174.45
6,071.93
-478.63
10,600.00
90.11
163.60
6.071.63
-630.57
10,800.00
88.90
177.55
6,073.37
-827.37
10,975.00
86.19
165.59
6,080.90
-999.99
11,125.00
88.06
175.93
6,088.44
-1,147.65
11,300.00
88.11
188.19
6,094.31
-1,322.11
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
Dogleg
Build
Turn
+E/-W
Rate
Rate
Rate
TFO
(usft)
(°/100ft)
(°/100ft)
(°/100ft)
(°)
4,205.66
0.00
0.00
0.00
0.00
4,244.12
0.62
0.40
-0.75
-49.81
4,256.55
14.00
14.00
0.00
0.00
4,309.05
42.00
42.00
0.00
0.00
4,403.13
42.00
0.91
44.18
96.00
4,477.65
42.00
17.13
38.96
70.00
4,488.71
42.00
0.02
42.00
90.00
4,449.31
7.00
5.36
4.51
40.00
4,387.73
7.00
1.76
6.82
75.00
4.300.84
7.00
1.13
6.98
80.00
4,228.38
7.00
0.53
-7.08
275.00
4,176.01
7.00
-0.07
-7.10
270.00
4,079.37
7.00
0.30
-7.11
275.00
4,099.55
7.00
-3.80
-5.93
238.00
4,163.24
7.00
-1.25
-6.89
260.00
4,211.27
7.00
-1.22
6.89
100.00
4,243.57
7.00
-1.41
6.87
102.00
4,237.33
7.00
0.02
7.02
90.00
4,233.83
7.00
2.44
-6.57
290.00
4,263.30
7.00
0.00
-7.00
270.00
4,295.98
7.00
-0.61
6.97
95.00
4,321.55
7.00
-1.55
-6.83
257.00
4,345.56
7.00
1.25
6.90
80.00
4,339.28
7.00
0.03
7.00
90.00
Target
2/9/2017 3:08:54PM Page 3 COMPASS 5000.1 Build 74
ConocoPhillips rigs
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site:
Kuparuk 1 E Pad
North Reference:
True
Well:
1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 E-20L1
Design:
1E-201-1_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)
(1
(°)
(usft)
(usft)
(usft)
(usft)
(°/100ft)
(°)
(usft)
(usft)
7,900.00
39.27
64.97
6,069.61
1,555.86
4,205.66
-1,555.86
0.00
0.00
5,961,584.50
554,495.30
TIP
7,967.00
39.54
64.47
6,121.38
1,574.02
4,244.12
-1,574.02
0.62
-49.81
5,961,602.92
554,533.63
KOP
7,988.00
42.48
64.47
6,137.22
1,579.96
4,256.55
-1,579.96
14.00
0.00
5,961,608.94
554,546.03
End 14
dls, Start 42 dls
8,000.00
47.52
64.47
6,145.71
1,583.61
4,264.21
-1,583.61
42.00
0.00
5,961,612.65
554,553.66
8,058.00
71.88
64.47
6,174.75
1,605.03
4,309.05
-1,605.03
42.00
0.00
5,961,634.37
554,598.35
4
8,100.00
70.94
83.06
6,188.24
1,616.12
4,347.07
-1,616.12
42.00
96.00
5,961,645+71
554,636.29
8,160.00
72.81
109.53
6,207.21
1,609.86
4,403.13
-1,609.86
42.00
90.03
5,961,639.83
554,692.39
5
8,200.00
79.13
125.59
6,216.97
1,591.92
4,437.36
-1,591.92
42.00
70.00
5,961,622.11
554,726.73
8,260.00
89.94
148.49
6,222.75
1,548.49
4,477.65
-1,548.49
42.00
66.08
5,961,578.96
554,767.31
6
8,300.00
89.94
165.29
6,222.79
1,511_83
4,493.29
-1,511.83
42.00
90.00
5,961,542.41
554,783.19
8,385.00
89.96
200.99
6,222.86
1,428.33
4,488.71
-1,428.33
42.00
89.98
5,961,458+89
554,779.17
End 42
dls, Start 7 dls
8,400.00
90.77
201.67
6,222+76
1,414.36
4,483.25
-1,414.36
7.00
40.00
5,961,444.88
554,773.81
8,485.00
95.32
205.50
6,218.25
1,336.60
4,449.31
-1,336.60
7.00
40.00
5,961,366.90
554,740.39
8
8,500.00
95.59
206.52
6,216.82
1,323.18
4,442.76
-1,323+18
7.00
75.00
5,961,353.44
554,733.94
8,600.00
97.35
213.34
6,205.54
1,237.12
4,393.23
-1,237.12
7.00
75.10
5,961,267.06
554,684.98
8,610.00
97.52
214.03
6,204.25
1,228.87
4,387.73
-1,228.87
7.00
75.87
5,961,258.77
554,679.54
9
8,700+00
98.57
220.30
6,191.65
1,157.89
4,333.93
-1,157.89
7.00
80.00
5,961,187.44
554,626.22
8,750.00
99.10
223.80
6,183.96
1,121.21
4,300.84
-1,121+21
7.00
80.88
5,961,150.54
554,593.38
10
8,800.00
99.39
220.27
6,175.92
1,084.56
4,267.80
-1,084.56
7.00
-85.00
5,961,113.68
554,560.59
8,865.00
99.71
215.66
6,165.13
1,034.04
4,228.38
-1,034.04
7.00
-85.57
5,961,062.90
554,521+51
11
8,900.00
99.71
213.18
6,159.23
1,005.58
4,208.88
-1,005.58
7.00
-90.00
5,961,034.32
554,502.20
8,965.00
99.64
208.56
6,148.30
950.60
4,176.01
-950.60
7.00
-90.42
5,960,979.12
554,469.71
12
9,000.00
99.85
206.09
6,142.37
919.96
4,160.18
-919.96
7.00
-85.00
5,960,948.38
554,454+08
9,100.00
100.33
198.99
6,124.84
829.09
4,122.46
-829.09
7.00
-85.42
5,960,857.26
554,416.98
9,200.00
100.66
191.88
6,106.60
734.37
4,096.30
-734.37
7.00
-86.66
5,960,762.39
554,391.45
9,300.00
100.83
184.76
6,087.94
637.23
4,082.09
-637.23
7.00
-87.96
5,960,665.16
554,377.90
9,365.00
100.85
180.13
6,075.71
573.46
4,079.37
-573.46
7.00
-89.29
5,960,601.38
554,375.60
13
9,400.00
99.54
178.02
6,069.51
539.02
4,079.93
-539.02
7.00
-122.00
5,960,566.95
554,376.39
9,500.00
95.75
172.08
6,056.20
440.35
4,088.50
-440.35
7.00
-122.37
5,960,468.34
554,385.62
9,565.00
93.25
168.27
6,051.10
376.52
4,099.55
-376.52
7.00
-123.16
5,960,404.59
554,397.10
14
9,600+00
92.82
165.85
6,049.24
342.46
4,107.38
-342.46
7.00
-100.00
5,960,370.59
554,405.16
9,700.00
91_57
158.96
6,045.40
247.27
4,137.57
-247.27
7.00
-100.13
5,960,275.61
554,435.98
9,765.00
90.75
154.48
6,044.08
187.59
4,163.24
-187.59
7.00
-100.39
5,960,216.11
554,462.05
15
9,800.00
90.32
156.90
6,043.75
155.69
4,177.65
-155.69
7.00
100.00
5,960,184.32
554,476.67
9,900.00
89.11
163.79
6,044.25
61.58
4,211.27
-61.58
7.00
100.02
5,960,090.44
554,510.91
16
10,000.00
87.66
170.64
6,047.07
-35.84
4,233.38
35.84
7.00
102.00
5,959,993A8
554,533.67
21912017 3:08:54PM
Page 4
COMPASS 5000.1 Build 74
`- ConocoPhillips RAN
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1 E Pad
Well:
1 E-20
Wellbore:
1 E-201-1
Design:
1 E-20 L 1 _wp03
Planned Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
Measured
TVD Below
Vertical
Dogleg
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
(usft)
(1
(a)
(usft)
(usft)
(usft)
(usft)
(°/100ft)
10,100.00
86.25
177.51
6,052.39
-135.10
4,243.68
135.10
7.00
10,175.00
85.22
182.67
6,057.97
-209.87
4,243.57
209.87
7.00
17
10,200.00
85.23
184.43
6,060.05
-234.73
4,242.02
234.73
7.00
10,245.00
85.24
187.59
6,063.79
-279.33
4,237+33
279.33
7.00
18
10,300.00
86.57
183.96
10,400.00
89.01
177.40
10,445.00
90.11
174.45
19
10,500.00
90.11
170.60
10,600.00
90.11
163.60
20
10,700.00
89.50
170.57
10,800.00
88.90
177.55
21
10,900.00
87.34
170.72
10,975.00
86.19
165.59
22
11,000.00
86.49
167.32
11,100.00
87.74
174.21
11,125.00
88.06
175.93
23
11,200.00
88.07
181.19
11,300.00
88.11
188.19
Planned
TD at 11300.00
6,067.72
-333.90
6,071.59
-433.75
6,071.93
-478.63
6,071.83
-533.15
6,071.63
-630.57
6,071.97
-727.98
6,073.37
-827.37
6,076.66
-926.73
6,080.90
-999.99
6,082.49
-1,024.24
6,087.53
-1,122.76
6,088.44
-1,147.65
6,090.97
-1,222.56
6,094.31
-1,322.11
4,231.81
4,230.63
4,233.83
4,240.98
4,263.30
4,285.63
4,295.98
4,306.18
4,321.55
4,327.39
4,343.41
4,345.56
4,347.44
4,339.28
333.90
433.75
478.63
533.15
630.57
727.98
827.37
926.73
999.99
1,024.24
1,122.76
1,147.65
1,222.56
1,322.11
7.00
7,00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
7.00
Toolface
Map
Azimuth
Northing
V)
(usft)
101.81
5, 959, 894.00
101.44
5,959,819.24
90.00
5,959,794.37
89.85
5,959,749.75
-70.00
5,959,695.15
-69.74
5,959,595.30
-69.49
5,959,550.45
-90.00
5,959,495.98
-90.01
5, 959, 398.72
95.00
5,959,301.48
94.98
5,959,202.17
-103.00
5,959,102.89
-102.78
5,959,029.74
80.00
5,959,005.52
79.89
5,958,907.13
79.54
5,958,882.25
90.00
5,958,807.37
89.82
5.958,707.78
Map
Easting
(usft)
554,544.64
554,545.02
554,543.65
554, 539.25
554,534.10
554,533.59
554, 537.09
554, 544.60
554, 567.57
554,590.55
554,601.56
554,612.43
554,628.28
554,634.29
554, 650.97
554,653.28
554,655.66
554,648.17
2/9/2017 3:08:54PM Page 5 COMPASS 5000.1 Build 74
ConocoPhillips rigs
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1 E Pad
Well:
1 E-20
Wellbore:
1 E-201-1
Design:
1 E-20L1_wp03
Targets
Target Name
hit/miss target Dip Angle Dip Dir. TVD
Shape
(1) (1) (usft)
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
+N/-S +E/-W Northing
(usft) (usft) (usft)
1E-201-1_T03 0.00 0.00 6,203.00-6,660.691,144,497.66 5,961,002.00
plan misses target center by 1140033.66usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1_T10 0.00 0.00 6,094.00-9,203.701,144,454.63 5,958,459.00
plan misses target center by 1140011.71 usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1_T07 0.00 0.00 6,056.00-8,066.931,144,359.23 5,959,595.00
plan misses target center by 1139906.20usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-20 CTD Polygon
0.00 0.00 0.00
-6,188.001,144,253.79
5.961,473.00
plan misses target center by 1139803.50usft at 8300.00usft MD (6222.79 TVD, 1511.83
N, 4493.29 E)
Polygon
Point 1
0.00
0.00
0.00
5,961,473.00
Point
0.00
78.68
199.55
5,961,553.01
Point 3
0.00
57.85
325.42
5,961.533.02
Point
0.00
-69.21
482.60
5,961,407.03
Point 5
0.00
-235.45
515.50
5,961,241.03
Point
0.00
-525.72
400.56
5,960,950.02
Point 7
0.00
-921.52
212.90
5.960,553.02
Point 8
0.00
-3,001.00
397.11
5,958,475.02
Point 9
0.00
-3,311.71
349.04
5,958,164.02
Point 10
0.00
-3,289.69
45.15
5,958,184.01
Point 11
0.00
-2,985.44
13.17
5,958.488.01
Point 12
0.00
-1,368.57
-240.12
5,960,102.99
Point 13
0.00
-872.84
-190.82
5,960,598.99
Point 14
0.00
-595.74
-49.96
5,960,877.00
Point 15
0.00
-325.08
156.86
5,961,149.01
Point 16
0.00
0.00
0.00
5.961,473.00
1E-201-1_Fault2_M 0.00 0.00 0.00-8,066.931,144,359.23 5.959,595.00
plan misses target center by 1139923.17usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Rectangle (sides W1,000.00 1-11.00 D0.00)
1E-201-1_T01 0.00 0.00 6,223.00-6,333.281,144,592.86 5,961,330.00
plan misses target center by 1140126.56usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1_T09 0.00 0.00 6.075.00-8,759.381,144,414.60 5,958,903.00
plan misses target center by 1139967.59usft at 8300.00usft MD (6222.79 TVD, 1511.83 N. 4493.29 E)
Point
1E-20L1_Fault2 0.00 0.00 6,056.00-8,066.931,144,359.23 5,959,595.00
plan misses target center by 1139906.20usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Polygon
Point 1 6,056.00 0.00 0.00 5,959,595.00
Point 2 6,056.00 1.00 1.00 5,959,596.01
1E-20L1_T02 0.00 0.00 6,223.00-6,453.371,144,604.06 5,961,210.00
plan misses target center by 1140138.59usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-20L1_T05 0.00 0.00 6,062.00-7,391.771,144,198.73 5.960,269.00
plan misses target center by 1139740.23usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
Easting
(usft) Latitude Longitude
1,694,706.00 70' 2' 49.539 N 140' 24' 26.829 W
1,694,680.00 70° 2' 24.915 N 1400 24' 39.036 W
1,694,577.00 70° 2' 36.092 N 1400 24' 36.838 W
1,694,459.00 70° 2' 54.488 N 140° 24' 31.719 W
1,694,459.00
1, 694, 658.00
1, 694, 783.99
1, 694, 942.01
1, 694, 976.01
1, 694, 863.03
1, 694, 678.04
1, 694, 876.15
1, 694, 830.17
1,694,526.17
1,694,492.15
1, 694, 228.07
1, 694, 274.05
1,694,413.03
1,694,618.02
1,694,459.00
1, 694, 577.00
70° 2' 36.092 N 140' 24' 36.838 W
1,694,799.00 700 2' 52.577 N 1400 24' 22.708 W
1.694,637.00 70° 2' 29.288 N 140° 24' 38.255 W
1.694,577.00 70° 2' 36.092 N 140° 24' 36.838 W
1, 694, 577.00
1, 694, 577.99
1,694,811.00 70° 2' 51.395 N 140° 24' 22.909 W
1,694,412.00 70° 2' 42.883 N 140' 24' 38.484 W
1 E-201-1_T08 0.00 0.00 6,072.00-8.364.901,144,349.23 5.959,297.00 1,694,569.00 70° 2' 33.214 N 140° 24' 38.409 W
plan misses target center by 1139898.74usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1 E-20L1 Faultl M 0.00 0.00 0.00-6,660.691,144,497.66 5,961,002.00 1,694,706.00 70' 2' 49.539 N 140' 24' 26.829 W
2/9/2017 3:08:54PM Page 6 COMPASS 5000.1 Build 74
�,. ConocoPhillips
ConocoPhillips Planning Report
riFAa
BAKER
HUGHES
Database: EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company: ConocoPhillips (Alaska) Inc. -Kupl
ND Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site: Kuparuk 1 E Pad
North Reference:
True
Well: 1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore: 1 E-201-1
Design: 1 E-20L1_wp03
plan misses target center by 1140050.64usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Rectangle (sides W1,000.00 1-11.00 D0.00)
1 E-201-1_Faultl 0.00 0.00 6,203.00
-6,660.691,144,497.66 5,961,002.00
1,694,706.00 700 2' 49.539 N 1400 24' 26.829 W
plan misses target center by 1140033.66usft at 8300.00usft
MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Polygon
Point 6,203.00
0.00 0.00 5,961,002.00
1,694,706.00
Point 6,203.00
1.00 1.00 5,961,003.01
1,694,706.99
1E-20L1_T06 0.00 0.00 6,044.00
-7,726.441,144,292.50 5,959,935.00
1,694,508.00 70' 2' 39.496 N 140' 24' 37.264 W
plan misses target center by 1139836.66usft at 8300,00usft
MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-20L1_T04 0.00 0.00 6,134.00
-7,006.101,144,255.32 5,960,655.00
1,694,466.00 70' 2' 46.543 N 1400 24' 35.210 W
plan misses target center by 1139793.86usft at 8300.00usft
MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
Casing Points
Measured
Vertical
Depth
Depth
(usft)
(usft) Name
11,300.00
6,094.31 2 3/8"
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/-S
+E/-W
(usft)
(usft)
(usft)
(usft)
7,900.00
6,069.61
1,555+86
4,205.66
7,967.00
6,121.38
1,574.02
4,244.12
7,988.00
6,137.22
1,579.96
4,256.55
8,058.00
6,174.75
1,605.03
4,309.05
8,160.00
6,207.21
1,609.86
4,403.13
8,260.00
6,222.75
1,548.49
4,477.65
8,385.00
6,222.86
1,428.33
4,488.71
8,485.00
6,218.25
1,336.60
4,449.31
8,610.00
6,204.25
1,228.87
4,387+73
8,750.00
6,183.96
1,121.21
4,300+84
8,865.00
6,165.13
1,034.04
4,228.38
8,965.00
6,148.30
950.60
4,176.01
9,365.00
6,075.71
573.46
4,079.37
9,565.00
6,051.10
376.52
4,099.55
9,765.00
6,044.08
187.59
4,163.24
9,900.00
6,044.25
61.58
4,211.27
10,175.00
6,057.97
-209.87
4,243.57
10,245.00
6,063.79
-279.33
4,237.33
10,445.00
6,071.93
-478.63
4,233.83
10,600.00
6,071.63
-630.57
4,263.30
10,800.00
6,073.37
-827.37
4,295.98
10,975.00
6,080.90
-999.99
4,321.55
11,125.00
6,088.44
-1,147.65
4,345.56
11,300.00
6,094.31
-1,322.11
4,339.28
Comment
TIP
KOP
End 14 dls, Start 42 dls
4
5
6
End 42 dls, Start 7 dls
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
Planned TD at 11300.O1
Casing Hole
Diameter Diameter
(in) (in)
2.375 3.000
21912017 3:08:54PM Page 7 COMPASS 5000.1 Build 74
101-1 Baker Hughes INTEQ rigs
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1 E Pad
Site Error:
0.00 usft
Reference Well:
1E-20
Well Error:
0.00 usft
Reference Wellbore
1 E-2011
Reference Design:
1 E-20 L 1 _wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 E-20
1 E-20 @ 105.70usft (1 E-20)
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Reference 1E-20L1_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: 7,900.00 to 11,300.00usft Scan Method: Tray. Cylinder North
Results Limited by: Maximum center -center distance of 1,319.43 usft Error Surface: Elliptical Conic
Survey Tool Program
Date 2/8/2017
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
200.00
7,900.00 1 E-20 (1 E-20)
FINDER -MS
SDC Finder multishot
7,900.00
11,300.00 1E-201_1_wp03 (1E-20L1)
MWD
MWD - Standard
Casing Points
Measured Vertical
Casing
Hole
Depth Depth
Diameter
Diameter
(usft) (usft)
Name
11,300.00 6,200.01 23/8"
2-3/8
3
—
Summary
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 1 E Pad
1 E-03 - 1 E-03 - 1 E-03
11,297.77
8,125.00
324.13
185.92
202.17
Pass - Major Risk
1 E-07 - 1 E-07A - 1 E-07A
8,200.00
10,898.00
604.24
175.23
429.44
Pass - Major Risk
1 E-07 - 1 E-07ALl - 1 E-07AL1
8,200.00
10,898.00
618.97
172.56
446.52
Pass - Major Risk
1 E-102 - 1 E-102 - 1 E-102
Out of range
1 E-102 - 1 E-10211 - 1 E-1021-1
Out of range
1 E-102 - 1 E-10211 - Plan 1 E-102 D Lat (wp05)
Out of range
1 E-102 - 1 E-10211 PB1 - 1 E-10211 PB1
Out of range
1 E-102 - 1 E-102PB1 - 1 E-102PB1
Out of range
1 E-102 - 1 E-102PB1 - Plan 1 E-102 B lat (wp5.0)
Out of range
1 E-102 - 1 E-102PB2 - 1 E-102PB2
Out of range
1 E-104 - 1 E-104 - 1 E-104
Out of range
1 E-104 - 1 E-104 - Plan 1 E-104 (wp04)
Out of range
1 E-105 - 1 E-105 - 1 E-105
Out of range
1 E-105 - 1 E-10511 - 1 E-10511
Out of range
1 E-105 - 1 E-1051_2 - 1 E-1051-2
Out of range
1 E-105 - 1 E-105PB1 - 1 E-105PB1
Out of range
1 E-105 - 1 E-105PB2 - 1 E-105PB2
Out of range
1 E-112 - 1 E-112 - 1 E-112
Out of range
1 E-112 - 1 E-112L1 - 1 E-112L1
Out of range
1 E-112 - 1 E-11212 - 1 E-11212
Out of range
1 E-112 - 1 E-112PB1 - 1 E-112PB1
Out of range
1 E-126 - 1 E-126 - 1 E-126
Out of range
1 E-126 - 1 E-126L1 - 1 E-126L1
Out of range
1 E-126 - 1 E-1261_2 - 1 E-1261_2
Out of range
1 E-18 - 1 E-18 - 1 E-18
Out of range
1 E-19 - 1 E-19 - 1 E-19
Out of range
1 E-20 - 1 E-20 - 1 E-20
7,975.00
7,975.00
0.07
2.45
-1.61
FAIL - Major Risk
1E-20-1E-2011-01-1E-20L1-01_wp03
9,350.00
9,350.00
0.00
0.33
-0.22
FAI L - Minor 1 /10
1E-20-1E-201-1-02-1E-2011-02 w 02
8,750.00
8,750.00
0.67
0.81
-0.08
FAI L - Minor 1 /10
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
21812017 12:26:38PM Page 2 COMPASS 5000.1 Build 74
Baker Hughes INTEQ MAP aI
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1 E Pad
Site Error:
0.00 usft
Reference Well:
1 E-20
Well Error:
0.00 usft
Reference Wellbore
1E-201_1
Reference Design:
1E-20L1_wp03
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1 E Pad
1 E-20 - 1 E-201_1-03 - 1 E-20L1-03_wp00
1 E-21 - 1 E-21 - 1 E-21
1 E-22 - 1 E-22 - 1 E-22
1 E-23 - 1 E-23 - 1 E-23
1 E-24 - 1 E-24 - 1 E-24
1 E-24 - 1 E-24A - 1 E-24A
1 E-24 - 1 E-24B - 1 E-24B
1 E-24 - 1 E-24BL1 - 1 E-24BL1
1E-24-1E-246L1PB1-1E-24BL1PB1
1E-24-1E-24131-1PB2-1E-24131_1PB2
1 E-24 - 1 E-24BL1 PB3 - 1 E-24BL1 PB3
1 E-24 - 1 E-24BL2 - 1 E-24131_2
1 E-24 - 1 E-24131-2-01 - 1 E-24131-2-01
1 E-24 - 1 E-24131-2-02 - 1 E-24BL2-02
1 E-33 - 1 E-33 - 1 E-33
1 E-33 - 1 E-33PB1 - 1 E-33PB1
Plan 1 E-108 - Plan 1 E-108 - Plan 1 E-108 (wp03)
Local Co-ordinate Reference:
Well 1E-20
TVD Reference:
1 E-20 @ 105.70usft (1 E-20)
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
OAKE DM P2
Offset TVD Reference:
Offset Datum
Reference Offset Centre to
Measured Measured Centre
Depth Depth Distance
(usft) (usft) (usft)
8,025.00 8,025.00 0.12
No -Go Allowable
Distance Deviation Warning
(usft) from Plan
(usft)
0.32 -0A5 FAIL- Minor 1/10
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
Offset Design
Kuparuk 1 E Pad - 1 E-03 - 1 E-03 - 1 E-03
Offset She Error: 0.00 usft
Survey Program: 200-FINDER-MS
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
onset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toolface+
Offset Wellbore
Centre
Casing-
Centre to
No Go
Allowable
Warning
Depth
Depth
Depth
Depth
Azimuth
+N/S
+E/-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(')
(usft)
(usft)
(")
(usft)
(usft)
(usft)
10,875.79
6,181.31
6,975.00
5,002.91
37.10
30.74
-161.14
-1,027.38
3,726.89
2-11/16
1,316,81
174.79
1,203.53 Pass -
Major Risk
10,880.05
6,181.48
7,000.00
5,021.47
37.13
30.87
-161.65
-1,033.12
3,742.61
2-11/16
1,293.90
175.29
1,180.52 Pass -
Major Risk
10,884.44
6,181.67
7,025.00
5,040.07
37.16
30.99
-162.17
-1,038.91
3,758.28
2-11/16
1,271.03
175.80
1,157.56 Pass -
Major Risk
10,900.00
6,182.36
7,050.00
5,058.71
37.26
31.12
-163.42
-1,044.74
3,773.89
2-11/16
1,248.31
177.18
1,134.15 Pass -
Major Risk
10,900.00
6,182.36
7,075.00
5,077.38
37.26
31.24
-163.66
-1,050.62
3,789.45
2-11/16
1,225.48
177.37
1,111.46 Pass -
Major Risk
10,900.00
6,182.36
7,100.00
5,096.08
37.26
31.37
-163.90
-1,056.52
3,804.95
2-11/16
1,202.73
177.56
1,088.86 Pass -
Major Risk
10,900.00
6,182.36
7,125.00
5,114.82
37.26
31.50
-164.14
-1,062.43
3,820.40
2-11116
1,180.06
177.74
1,066.34 Pass -
Major Risk
10,900.00
6,182.36
7,150.00
5,133.60
37.26
31.62
-164.40
-1,068.28
3,835.83
2-11/16
1,157.45
177.93
1,043.89 Pass -
Major Risk
10,913.10
6,182.99
7,175.00
5,152.42
37.35
31.75
-165.50
-1,074.08
3,851.24
2-11/16
1,134.77
179.16
1,020.67 Pass -
Major Risk
10.918.22
6,183.25
7,200.00
5,171.26
37.39
31.87
-166.10
-1,079.83
3,866.62
2-11/16
1,112.18
179.75
997.97 Pass -
Major Risk
10,923.47
6,183.52
7,225.00
5,190.15
37.42
32.00
-166.71
-1,085.63
3,881.94
2-11/16
1,089.64
180.37
975.33 Pass -
Major Risk
10,928.93
6,183.82
7,250.00
5,209.07
37.46
32.12
-167.33
-1,091.58
3,897.16
2-11/16
1,067.19
181.01
952.76 Pass -
Major Risk
10,934.59
6,184.13
7,275.00
5,228.03
37.50
32.25
-167.97
-1,097.67
3,912.27
2-11/16
1,044.84
181.66
930.28 Pass -
Major Risk
10,950.00
6,185.02
7,300.00
5,247.03
37.61
32.37
-169.24
-1,103.92
3,927.28
2-11/16
1,022.65
183.12
907.44 Pass -
Major Risk
10,950.00
6,185.02
7,325.00
5,266.05
37.61
32.49
-169.51
-1,110.26
3,942.21
2-11/16
1,000.40
183.32
885.37 Pass -
Major Risk
10,950.00
6,185.02
7,350.00
5,285.12
37.61
32.61
-169.79
-1,116.65
3,957.06
2-11/16
978.28
183.53
863.44 Pass -
Major Risk
10,959.16
6,185.58
7,375.00
5,304.22
37.67
32.74
-170.66
-1,123.09
3,971.85
2-11/16
956.23
184.49
841.08 Pass -
Major Risk
10,965.74
6,185.99
7,400.00
5,323.35
37.72
32.86
-171.37
-1,129.58
3,986.58
2-11/16
934.26
185.25
818.94 Pass -
Major Risk
10,975.00
6,186.60
7,425.00
5,342.54
37.79
32.98
-172.25
-1,136A5
4,001.19
2-11/16
912.37
186.24
796.75 Pass -
Major Risk
10,992.16
6,187.71
7,450.00
5,361.79
37.91
33.10
-171.43
-1,142.86
4,015.66
2-11/16
890.51
186.24
775.43 Pass -
Major Risk
11,017.18
6,189.21
7,475.00
5,381.12
38.09
33.22
-170.12
-1,149.69
4,029.97
2-11/16
868.51
186.10
754.15 Pass -
Major Risk
11,040.34
6,190.49
7,500.00
5,400.52
38.26
33.34
-168.94
-1,156.65
4,044.12
2-11/16
846.38
185.96
732.69 Pass -
Major Risk
11,061.73
6,191.56
7,525.00
5,419.93
38.43
33.46
-167.90
-1,163.67
4,058.23
2-11/16
824.14
185.82
711.08 Pass -
Major Risk
11,081.43
6,192.46
7,550.00
5,439.31
38.59
33.58
-167.01
-1,170.66
4,072.39
2-11/16
801.82
185.69
689.37 Pass -
Major Risk
11,099.58
6,193.21
7,575.00
5,458.65
38.74
33.70
-166.25
-1,177.63
4,086.61
2-11116
779.44
185.58
667.56 Pass -
Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: R R U—, I C— aO L
PTD: 1�4 �_0 ),9,
Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional
FIELD: ` �1 V 6r- POOL: K GJ J, �iVU cw 9',V6.r
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. I 1?3 - 0 OS , API No. 50-()�ZCJL 2Qg - Q 0 - O 0 .
(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 L PH) and API number (50- -
- from records, data and logs acquired for well
(name onpermit).
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 KUPARUK RIVER, KUPARUK RIV OIL - 490100
PTD#:2170220 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type
Well Name: KUPARUK RIV UNIT 1E-20L1 Program DEV Well bore seg Evi
DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
17
Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
NA
1
Permit fee attached
NA
2
Lease number appropriate
Yes
ADL25651, entire wellbore.
3
Unique well name and number
Yes
KRU 1 E-20L1
4
Well located in a defined pool
Yes
KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432D.
5
Well located proper distance from drilling unit boundary
Yes
CO 432D contains no spacing restrictions with respect to drilling unit boundaries.
6
Well located proper distance from other wells
Yes
CO 432D 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
10
Operator has appropriate bond in force
Yes
Appr Date
11
Permit can be issued without conservation order
Yes
12
Permit can be issued without administrative approval
Yes
PKB 2/23/2017
13
Can permit be approved before 15-day wait
Yes
14
Well located within area and strata authorized by Injection Order # (put IO# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only)
NA
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
NA
18
Conductor string provided
NA
Conductor set in KRU 1 E-20
Engineering
19
Surface casing protects all known USDWs
NA
Surface casing set in KRU 1 E-20
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 cover all 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
NA
26
Adequate wellbore separation proposed
Yes
Anti -collision analysis complete; 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 3034 psig(9.4 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD
VTL 3/7/2017
29
BOPEs, do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
MPSP is 2412 psig; will test BOPs to 3500 psig
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 1E-Pad are 112S bearing. 112S measures required.
Geology
36
Data presented on potential overpressure zones
Yes
Max. potential reservoir pressure is 9.4 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique.
Appr Date
37
Seismic analysis of shallow gas zones
NA
PKB 2/23/2017
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA
Onshore development lateral to be drilled.
Geologic Engineering Public
Date: Date Date
Commissioner: Commissioner- sinner
