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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout219-015Winston, Hugh E (CED)
From: Winston, Hugh E (CED)
Sent: Wednesday, March 10, 2021 9:14 AM
To: McLaughlin, Ryan
Cc: Loepp, Victoria T (CED)
Subject: KRU 1J Laterals: Expired Permits
Hi Ryan,
The following three permits to drill have expired under regulation 20 AAC 25.005 (?1. The permits have been marked
expired in their well history file and in the AOGCC database.
• KRU 1J-10L1-01 (issued to CPAI February 5th 2019)
• KRU 1J-101-1-02 (issued to CPAI February 5th 2019)
• KRU 11-10L1-03 (issued to CPAI February 5th 2019)
Please let me know if you have any questions. Thanks
Huey Winston
Statistical Technician
Alaska Oil and Gas Conservation Commission
hugh.winston@alaska.pov
907-793-1241
THE STATE
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1J-IOL1-03
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-015
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.claska.gov
Surface Location: 1996' FSL, 2536' FEL, SEC. 35, Tl 1N, RI OE, UM
Bottomhole Location: 526' FNL, 1348' FEL, SEC. 34, T11N, R10E, UM
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to redrill the above referenced development
well.
The permit is for a new wellbore segment of existing well Permit No. 201-071, API No. 50-029-
23010-00-00. Production should continue to be reported as a function of the original API number
stated above.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs
run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
DATED this _ day of February, 2019.
STATE OF ALASKA
AL <A OIL AND GAS CONSERVATION COMMi _iON
PERMIT TO DRILL
20 AAC 25.005
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 ❑�
Stratigraphic Test ❑ Development - Oil 0 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 ❑� Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180
KRU 1J 10L1-03
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth: WO: G-X02,° 62I; .l -
MD: 14,100' TVD`V 6088'
12. Field/Pool(s):
Kuparuk River Field / -
Kuparuk River Oil Pool `
4a. Location of Well (Governmental Section):
7. Property Designation: . flD(�2566 11,
Surface: 1996' FSL, 2536' FEL, Sec 35, T11 N, RI OE, UM
ADL 25660 At4<-� _ ,0
j
8. DNR Approval Number:
13. Approximate Spud Date:
Top of Productiva Horizo
t��NL 3t98 FEL,,,Sec.3�F t1NRfoC4
��,-..ter" tr&FF_E-5emsti 'riiii 7Tr�Poh-4
LONS83-137
2/13/2019
Total Depth SZti� fNL. 03 4-3 ' r-EL, 5ec-3df- TU N, fklo�(4N
9. Acres in Property:
14. Distance to Nearest Property:
2560
17,081'
4b. Location of Well ( tate Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 114'
15. Distance to Nearest Well Open
Surface: x- 558673 y- 5945808 Zone- 4
GL / BF Elevation above MSL (ft): 79'
to Same Pool: 2694' (1J-168)
16. Deviated wells: Kickoff depth: 12,150 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 95 degrees
Downhole: 2914 Surface: 2315
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"
4.7#
L-80
ST-L
3700'
10,400'
5927'
14,100'
6088'
Slotted
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):
10,845'
6326'
N/A
10,843'
6324'
10,400'
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
85'
16"
460 sx AS 1
115'
115'
Surface
6911'
9-5/8"
700 sx AS Lite & 450 sx LiteCrete
6938'
3991'
Production
10,199,
7"
170 sx G
10,231'
5944'
Liner
876'
4-1/2"
150 sx GasBlok
10,843'
6325'
Perforation Depth MD (ft): 10,446' - 10,466', 10,658' - 10,678'
Perforation Depth TVD (ft): 6073' - 6085', 6205' - 6218'
Hydraulic Fracture planned? Yes ❑ No 0
20. Attachments: Property Plat BOP Sketch
Diverter Sketch
Drilling Program
❑ Seabed Report
❑
Time v. Depth Plot
Drilling Fluid Program
Shallow Hazard Analysis
❑ 20 AAC 25.050 requirements ❑
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval. Contact Name: Ryan McLaughlin
Authorized Name: James Ohlinger Contact Email: Ryan. McLauhlln c0 .com
Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218
Authorized Signature:�Z Date:
Commission Use Only
Permit to Drill
API Number: Permit
Approval
See cover letter for other
Number: _JN t9 - O 15 150-07_5k--A30I0
-- 6 - 0 0
Date: 1
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: L?OF> rfs 7'-(7 _75z2c P , I ( v0 -Samples req'd: Yes ❑ No[q' Mud log req'd: Yes ❑ No[]�
vl ar p tJC V<vl 2' k- �lY U 7—s H� measures: Yes Y No ❑ Directional svy req'd: Yes [�J'� No ❑
4 v a r a LPG 7 D a CA4 Z)r- ljj r(JJJacing exception req'd: Yes ❑ No []° Inclination -only svy req'd: Yes ❑ No[?'
Post initial injection MIT req'd: Yes ❑ No
y►- � j�d a`low fht 1�ac�of �o,�, f be q� d,�-t alvvt
the-, � �t � t l �c /�-��
APPROVED BY��� I
Approved by: COMMISSIONER THE COMMISSION Date:
`j^ Submit Form and
�/ `Form 10-401 Revised 5/2017 This permit is valid for 24 months r �2#�f�v�p� 20 AAC 25.005(g) Attachments in Duplicate
ConocoPh i l lips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
January 23, 2019
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 four laterals out of the KRU 1J-10
(PTD# 201-071) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin on February 6, 2019. The objective will be to drill four laterals KRU 1J-
101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03 targeting the Kuparuk C-sand interval.
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.
Attached to this application are the following documents:
— Permit to Drill Application Forms (10-401) for 1J-101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03
— Detailed Summary of Operations
— Directional Plans for 1J-101-1, 1J-101-1-01, 1J-101-1-02 and 1J-101-1-03
— Current wellbore schematic
— Proposed CTD schematic
If you have any questions or require additional information, please contact me at 907-265-6218.
Sincerely,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
U-101-15 U-101-1-019 U-101-1-027 & U-101-1-03
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................
2
(Requirements of 20 AAC 25.005(o and 20 AA C 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....................................................................................................................................6
Attachment 1: Directional Plans for 1J-101-1, 1J-101-1-01, U-101-1-02, & 1J-101-1-03 laterals.......................................6
Attachment 2: Current Well Schematic for U-10............................................................................ ..............................6
Attachment 3: Proposed Well Schematic for 1J-101-1, 1J-101-1-01, U-101-1-02, & 1J-101-1-03 laterals .........................6
Page 1 of 6 January 15, 2019
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 1J-101-1, 1J-101-1-01, 1J-10L1-02, and 1J-101-1-03. The
laterals will be classified as "Development -Oil' wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the C4 sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 1J-10L1, lJ-101-1-01, lJ-101-1-02, and 1J-101_1-03 laterals.
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 3500 psi. Using the
maximum formation pressure in the area of 2914 psi in 1 L-29 (i.e. 9.2 ppg EMW), the maximum
potential surface pressure in 1J-10, assuming a gas gradient of 0.1 psi/ft, would be 2315 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 1J-10 was measured to be 2880 psi (9.2 ppg EMW) on 1/20/2019. The
maximum downhole pressure in the 1J-10 vicinity is the 1L-29 at 2914 psi (9.2 ppg EMW) measured on
2/19/2017.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
The offset injection wells to 1J-10 have injected gas, so there is a possibility of encountering free gas while
drilling the 1J-10 laterals. If 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 1J-10 laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 J-10 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 6 January 15, 2019
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
1J-101_1
10,200'
10,500'
5811'
5,982'
ORCA Liner Drilling BHA
1J-10L1-01
12,300'
15,200'
6045'
6120'
2-3/8", 4.7#, L-80, ST-L slotted liner;
aluminum billet on to
1J-101_1-02
12,150'
14,775'
6041'
6028'
2-3/8", 4.7#, L-80, ST-L slotted liner;
aluminum billet on to
1J-101_1-03
10,400'
14,100'
5,927'
6088'
2-3/8", 4.7#, L-80, ST-L slotted liner;
with shorty deployment sleeve on top
Existing Casing/Liner Information
Category
OD
Weight
(ppf)MD
Grade
Connection
Top
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
20"
91.5
H-40
Welded
0'
120'
0'
120'
1530
520
Surface
9-5/8"
40.0
L-80
BTC
0'
6945'
0'
3995'
5750
3090
Production
7"
26.0
L-80
BTC-MOD
0'
10,321'
0'
5944'
7240
5410
Liner
4-1/2"
12.6
L-80
NSCT
9967'
10,843'
5787'
6325'
8430
7500
Tubing
4-1/2"
12.6
L-80
IBT
0'
9992'
0'
5802'
8430
7500
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 PowerVis mud (8.6 ppg)
— Drilling operations: Chloride -based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide
formation over -balance and shale stability while running completions.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation 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 U-10 laterals we will target a constant BHP of 11.8 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
increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
Page 3 of 6 January 15, 2019
PTD Application: 1J-101-1, 1J-101-1-01, 1J-101-1-02, & 1J-10L1-03
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 U-10 Window (10,310' MD, 5991' TVD) Using MPD
Pumps On 1.8 b m
Pumps Off
C-sand Formation Pressure 9.2
2866 psi
2866 psi
Mud Hydrostatic 8.6
2679 psi
2679 psi
Annular friction i.e. ECD, 0.08 si/ft
825 psi
0 psi
Mud + ECD Combined
no chokepressure)
3504 psi
Overbalanced —638psi)
2679 psi
Underblanced —187psi)
Target BHP at Window 11.8nta
3676 psi
3676 psi
Choke Pressure Required to Maiin
Target BHP
172 psi
997 psi
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 for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
(A VP
KRU Well 1J-10 is a Kuparuk producer equipped with 4-1/2" tubing and 4-1/2" production liner. The
project targets stranded C-Sand resource to the south and east of 1J-10 into an area along the C-Sand
margin south of existing production and injection. This project will involve drilling four CTD laterals from
the 1J-10 parent wellbore. The first lateral will kickoff from a whipstock set at 10,310' and will drill out
200' from the motherbore to straddle the Kalubik shale with Northern Solution's Liner Drilling BHA. The
subsequent three laterals will target the Kuparuk C4 sand package with access gained from the 1J-IOLI
lateral.
Page 4 of 6 January 15, 2019
PTD Application: 1J-101_1, 1J-101_1-01, 1J-101_1-02, & 1J-10L1-03
Pre-CTD Work
1. RU Slickline: Drift tubing with dummy whipstock, obtain SBHP, C/O gas lift design
2. RU E-line: Caliper, set whipstock
3. Prep site for Nabors CDR3-AC rig.
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. U-10Ll Lateral (Straddle the Kalubik w/Liner Drilling BHA)
a. Mill 3.80" window at 10,310' MD.
b. Drill 3-3/4" lateral with ORCA liner drilling BHA to TD of 10,500' MD.
c. Hydraulically release off 3-1/2" liner drilling BHA leaving TOL at 10,200' MD
1 J-I OL 1 -0 1 Lateral (C4 sand - southeast)
a. Set top of whipstock in 3-1/2" drilled in liner at 10,420' MD
b. Mill 2.80" window at 10,420' MD
c. Drill 3" bi-center lateral to TD of 15,200' MD.
d. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,300' MD.
4. 1J-IOLI-02 Lateral (C4 sand- south)
a. Kick off of the aluminum billet at 12,300' MD.
b. Drill 3" bi-center lateral to TD of 14,775' MD.
c. Run 2-3/8" slotted liner with aluminum billet from TD up to 12,150' MD.
1 J-1 OL 1-03 Lateral (C4 sand - east)
a. Kickoff of the aluminum billet at 12,150' MD.
b. Drill 3" bi-center lateral to TD of 14,100' MD.
c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,400' MD.
6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
7. Obtain SBHP.
8. Return well 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.
— 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
Page 5 of 6 January 15, 2019
I • • 1 1 111
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 un-deployment, the steps listed above are observed, only in reverse.
Liner Running
— The 1J-10 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
1J-1011-1
11,020'
1J-10L1-01
16,913'
1J-10L1-02
7620'
1J-10L1-03
17,081'
— Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1J-10L1
2502'
KUP 34-11-10 1
1J-10L1-01
1845'
1L-29
1J-1011-1-02
2706'
1E-117
1J-1011-1-03
2694'
1J-168
16. Attachments
Attachment 1: Directional Plans for 1J-10L1, 1J-10L1-01, 1J-10L1-02, & 1J-10L1-03laterals
Attachment 2. Current Well Schematic for 1J-10
Attachment 3: Proposed Well Schematic for 1J-10L1, 1J-10L1-01, 1J-10L1-02, & 1J-10L1-03laterals
Page 6 of 6 January 15, 2019
ConocoPhillips
Kuparuk River Unit
Kuparuk IJ Pad
I J-10
I J-101-1
Plan: IJ-10L'I_wp01
Standard Planning Report
17 December, 2018
BA ER
UGHES
a GE company
ConocoPhillip5
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1J-10
Welibore:
1 J-10L1
Design:
1 J-10L1_wp01
ConocoPhllllps
BA�(ER
Planning Report
UGHES
a GE company
Local Co-ordinate Reference:
Well 1J-10
TVD Reference:
Mean Sea Level
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kuparuk 1J Pad
Site Position: Northing: 5,945,919.64 usft Latitude: 70° 1546.258 N
From: Map Easting: 558,789.95 usft Longitude: 149' 31' 29.007 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 °
Well 1 J-10
Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15' 45.169 N
+E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149° 31' 32.426 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1J-101-1
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(°) (°) (nT)
BGGM2018 2/1/2019 16.77 80.84 57,424
Design 1J-101-1 wp01
Audit Notes:
Version: Phase: PLAN Tie On Depth: 10,166.00
Vertical Section: Depth From (TVD) +N1S +E/-W Direction
(usft) (usft) (usft) (I
0.00 0.00 0.00 120.00
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Rate
Rate
Rate
TFO
(usft)
(°)
(I
(usft)
(usft)
(usft)
(°/100usft)
(°/100usft)
(°/10ousft)
(°) Target
10,166.00
52.95
295.12
5,790.91
3,587.77
-6,706.45
0.00
0.00
0.00
0.00
10,310.00
53.94
293.80
5,876.68
3,635.66
-6,811.74
1.01
0.69
-0.92
-47.36
10,335.00
56.55
292.00
5,890.93
3,643.65
-6,830.66
12.00
10.45
-7.19
330.00
10,500.00
56.55
292.00
5,981.87
3,695.23
-6,958.31
0.00
0.00
0.00
0.00
1211712018 10:37.55AM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips
#� (EIR
ConocoPhillips Planning Report t UGHES
a GE company
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1J-10
Wellbore:
1J-101-1
Design:
1J-10L1_wp01
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+Nl-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°)
(usft)
(usft)
10,166.00
52.95
295.12
5,790.91
3,587.77
-6,706.45
-7,601.84
0.00
0.00
5,949,343.13
551,939.76
TIP
10.200.00
53.18
294.81
5,811.34
3,599.24
-6,731.09
-7,628.92
1.01
-47.36
5,949,354.40
551,915.04
10,300.00
53.87
293.89
5,870.79
3,632.39
-6,804.35
-7,708.94
1.01
-47.17
5,949,386.98
551,841.53
10,310.00
53.94
293.80
5,876.68
3,635.66
-6,811.74
-7,716.97
1.01
-46.63
5,949,390.19
551,834.11
KOP
10,335.00
56.55
292.00
5,890.93
3,643.65
-6.830.66
-7,737.35
12.00
-30.00
5,949,398.03
551,815.13
End 12
dls, Start tangent
10,400.00
56.55
292.00
5,926.75
3,663.97
-6,880.95
-7,791.06
0.00
0.00
5,949,417.95
551,764.70
10.500.00
56.55
292.00
5,981.87
3,695.23
-6,958.31
-7,873.68
0.00
0.00
5,949,448.60
551,687.10
Planned TD at 10500.00
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
10,500.00 5,981.87 2 3/8" 2.375 3.000
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+Nl-S
+El-W
(usft)
(usft)
(usft)
(usft)
Comment
10,166.00
5,790.91
3,587.77
-6,706.45
TIP
10,310.00
5.876.68
3,635.66
-6,811.74
KOP
10,335.00
5,890.93
3,643.65
-6,830.66
End 12 dls, Start tangent
10,500.00
5,981.87
3,695.23
-6,958.31
Planned TD at 10500.00
12/17/2018 10:37.55AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips � aska) Mr,
-Kup1
Kuparuk River Unit
Kuparuk 1J Pad
1J®1 0
lJ-10LI
I-IOL1_wrpol
07 December, 2018
BER
Ta
GHES
GE company
ConocoPhillips BAKER
ConocoPhillips Travelling Cylinder Report UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
1 J-10
Well Error:
0.00 usft
Reference Wellbore
1J-101-1
Reference Design:
1J-10L1_wp01
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1J-10
1J-10:114.25 @ 114.25usft (1J-10:114.25)
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference 1J-10L1_wp01
-filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA
)epth Range: Unlimited Scan Method: Tray. Cylinder North
Results Limited by: Maximum center -center distance of 1,238.58 usft Error Surface: Pedal Curve
Survey Tool Program Date 12/7/2018
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
205.18 10,166.00 1J-10 (1J-10) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC
10,166.00 10,500.00 1J-10L1_wp01 (1J-101-1) MWD MWD- Standard
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
6,936.54
3,991.30 9 5/8"
9.625
12.250
10,142.96
5,891.30 7"
7.000
8.500
10,500.00
6,096.12 2 3/8"
2.375
3.000
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 1J Pad
1J-03 - 1J-03 - 1J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1 J-03 - 1J-031_1 - 1 J-031_1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
iJ-03 - 1J-03L2 - 1J-03L2
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03- 1J-03L2PB1 - 1J-03L2PB1
114.25
116.00
161.44
1.02
160.41
Pass- Major Risk
1J-09 - 1J-09 - 1J-09
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09- iJ-09A- 1J-09A
299.44
300.00
160.28
3.57
156.71
Pass- Major Risk
1J-09 - 1J-09AL1 - 1J-09AL1
299.44
300.00
160.28
3.57
156.71
Pass- Major Risk
11-10 - 11-10 - 1 J-10
10,499.33
10,500.00
14.99
13.99
5.31
Pass - Major Risk
1J-10- 1J-101-1-01 - 1J-10L1-01_wp02
Out of range
1J-10 - 1J-10L1-02 - 1J-101-1-02_wp01
Out of range
1J-10 - 1J-1OL1-03 - 1 J-10L1-03_wp01
Out of range
1 J-105 - 1 J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-105L1 - 1J-105L1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-1051_2 - 1 J-10512
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-105PB1 - 1 J-105PB1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1 J-107 - 1J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-107- 1J-1071-1 - 1J-1071-1
305.01
300.00
190.36
4.92
185.44
Pass- Major Risk
11-109 - 11-109 - 1 J-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109- 1J-109PB1 - 1J-109PB1
192.21
200.00
159.58
2.72
156.86
Pass- Major Risk
1J-115 - 1J-115 - 1 J-115
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115L1 - 1J-1151-1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L1PB1-1J-1151_1PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151-1 PB2 - 1 J-1151-1 PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151-2 - 1 J-1151-2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-1 15 - 1J-115L2PB1 - 1J-115L2PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115- 1J-115L2PB2 - 1J-1151_2PB2
403.76
400.00
159.15
6.67
152.48
Pass- Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
121712018 9:56:40AM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips HA@R
ConocoPhillips Travelling Cylinder Report UGHES
a U company
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Reference Site:
Kuparuk I Pad
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-101_1
Database:
EDT 14 Alaska Production
Reference Design:
1J-10L1 wp01
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-115-1J-115PB1-1J-115PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB2-1J-115PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB3 - 1 J-115PB3
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 -1 J-115P84 - 1J-115PB4
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-118-1J-118 - iJ-118
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-1181_1-1J-118L1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-iJ-1181_2-1J-1181_2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118PB1 - 1J-118PB1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-11813132-1J-118PB2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-120-1J-120 - 1J-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 -1 J-120L1 - 1 J-120L1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 -1 J-120L1 PB1 - 1J-12OL1 PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
iJ-120 - iJ-120L1 PB2 - 1J-1201-1 PB2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1P83-1J-120L1PB3
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 -1 J-120L1 PB4 - 1J-120L1 P134
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-120 -1 J-120L2 - 1 J-120L2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L2PB1-1J-1201-2P131
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-152 -1 J-152 - 1 J-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-1521-1-1J-1521-1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-1521-2-1J-1521_2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 -1 J-152L2P61 - 1J-152L2PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-lJ-152PB1 - 1J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152PB2-1J-152P132
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-154-1J-154 - 1J-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154-1J-154L1-1J-154L1
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1 J-154 -1 J-1541_2 - 1 J-1541_2
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1 J-156 -1 J-156 - 1 J-156
2,226.75
2,100.00.
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-156L1-1J-1561_1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-156L1PB1 -1J-156LIPB1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561_2-1J-1561_2
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1 J-158 - 1 J-158 - 1 J-158
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158-1J-158L1 - 1 J-158L1
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1 J-159 -1 J-159 - 1 J-159
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1-1J-1591-1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 -1 J-159L1 P131 - 1J-159L1 P131
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1 P132 - 1 J-159L1 P132
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-159 -1 J-1591_2 - 1 J-1591_2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159PB1-1J-159PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-160 -1 J-160 - 1 J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-1601.1 - 1 J-160L1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160L1PB1 -1J-160LIPB1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - iJ-1601-2 - 1 J-160L2
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-162-1J-162-1J-162
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162L1 - 1 J-162L1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162L1 PB1 - 1 J-1621_1 PB1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162PB1-1J-162PB1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-iJ-162PB2-1J-162P82
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1 J-164 -1 J-164 - 1 J-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 -1 J-164L1 - 1 J-164L1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-164 -1 J-1641_2 - 1 J-1641-2
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164-1J-164L2PB1 - 1J-164L2PB1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-166 -1 J-166 - 1 J-166
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166L1 - 1J-166L1
703.30
700.00
122.72
12.34
110.38
Pass- Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
121712018 9:56:40AM Page 3 COMPASS 5000.14 Build 85D
"I',
ConocoPhillips
BA_ i CER
ConocoPhillips
Travelling Cylinder Report
t1UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Reference Site:
Kuparuk I Pad
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-101_1
Database:
EDT 14 Alaska Production
Reference Design:
1J-101_1_wp01
OffsetTVD Reference:
Offset Datum
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 1J Pad
1J-166-1J-166L1P81-1J-1661-1P131
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-1661-2 - 1J-1661-2
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166L2PB1-1J-1661_2PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-168 - 1J-168 - 1 J-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L1-1J-1681-1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
iJ-168 - 1 J-168L2 - 1 J-1681-2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-168L2PB1 - 1J-168L2PB1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-170 - 1J-170 - 1J-170
5,690.17
8,300.00
247.69
159.88
140.49
Pass - Major Risk
1J-170 - 1J-1701-1 - 1 J-1701-1
5,566.22
8,300.00
182.48
156.25
55.71
Pass - Major Risk
1J-170 - 1J-170L2 - 1J-1701-2
5,394.81
8,200.00
166.39
152.00
53.52
Pass - Major Risk
1J-170- 1J-17OP61 - 1J-170PB1
5,676.40
8,300.00
273.16
159.57
164.32
Pass- Major Risk
1J-1 70 - 1 J-1 70PB2 - 1 J-1 70PB2
5,690.17
8,300.00
247.69
160.14
140.23
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 - Prelim: 1J-
406.82
400.00
232.09
5.53
226.57
Pass- Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass- Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L2 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-109a-1J-109PB1x-1J-109PB1x
114.25
33.25
177.64
1.02
176.62
Pass - Major Risk
W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15
487.50
500.00
209.67
9.95
199.72
Pass - Major Risk
W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2
396.03
400.00
184.70
5.72
178.98
Pass - Major Risk
W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20
810.09
800.00
83.61
17.14
66.47
Pass - Major Risk
W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3
503.17
500.00
184.73
11.21
173.52
Pass - Major Risk
W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4
491.49
500.00
196.71
7.54
189.18
Pass - Major Risk
W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5
486.33
500.00
231.04
10.16
220.89
Pass - Major Risk
Offset Design
Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03
Offset Site Error. 0.00 usft
Survey Program: 201-MVJD+IFR-AK-SCC
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Teolface +
Offset Wellbore
Centre
Casing -
Centre to
No Go
Allowable Waring
Depth
Depth
Depth
Depth
Azimuth
+NIS
+EI-W
Hole Size
Centre
Distance
Deviation
lush)
(usft)
(usft)
(usft)
(usft)
(usft)
(°I
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
114.25
114.25
116.12
116.12
0.00
0.00
46.71
110.69
117.51
8.875
161.44
0.74
160.70 Pass - Major Risk, CC, ES, SF
197.92
197.92
200.00
199.98
0.05
0.05
46.87
111.45
118.89
8.875
163.01
1.83
161.18 Pass - Major Risk
297.75
297.75
300.00
299.90
0.15
0.17
47.31
113.30
122.46
8.875
167.03
3.41
163.63 Pass - Major Risk
397.01
397.00
400.00
399.80
0.27
0.28
47.93
115.05
126.60
8.875
171.49
4.97
166.52 Pass- Major Risk
493.34
493.32
500.00
499.54
0.38
0.40
49.14
117.62
133.26
8.875
179.64
6.53
173.12 Pass - Major Risk
587.98
587.87
600.00
598.96
0.49
0.53
51.31
120.27
143.56
8.875
192.72
8.10
184.64 Pass - Major Risk
677.68
677.31
700.00
697.93
0.60
0.67
53.92
123.90
157.36
8.875
212.30
9.64
202.72 Pass - Major Risk
752.37
751.30
800.00
796.49
0.69
0.81
57.67
124.33
174.25
8.875
238.69
10.99
227.80 Pass- Major Risk
836.40
833.59
900.00
894.76
0.82
0.95
61.01
127.00
192.55
8,875
273.85
12.51
261.59 Pass - Major Risk
921.90
916.44
1,000.00
992.43
0.95
1.12
63.78
132.65
213.20
8.875
316.43
14.15
302.78 Pass - Major Risk
1,002.62
994.25
1,100.00
1,088.93
1.08
1.34
66.04
141.43
237.88
8.875
365.16
15.84
350A8 Pass - Major Risk
1,072.17
1,060.68
1,200.00
1,183.97
1.21
1.59
67.68
153.99
266.27
8.875
420.60
17.51
404.45 Pass - Major Risk
1,128.96
1,114.17
1,300.00
1,276.57
1.32
1.90
68.70
171.29
299.72
8.875
484.87
19.14
467.71 Pass - Major Risk
1,186.86
1,168.03
1,400.00
1,365.40
1.45
2.28
69.33
193.00
340.12
8.875
557.89
21.02
539.71 Pass - Major Risk
1,236.53
1,213.77
1,500.00
1,451.11
1.57
2.72
69.75
218.16
385.04
8.875
636.46
22.91
617.42 Pass - Major Risk
1,280.95
1,254.20
1,600.00
1,533.47
1.68
3.22
70.28
245.70
434.57
8.875
719.64
24.83
699.84 Pass - Major Risk
1.316.75
1,286.41
1,700.00
1,611.71
1.76
3.77
70.68
275.94
488.99
8.875
807.16
26.73
786.71 Pass - Major Risk
1,350.74
1,316.67
1,800.00
1,686.35
1.86
4.37
70.91
308.71
546.89
8.875
897.66
28.75
876.61 Pass - Major Risk
1,377.15
1,339.96
1,900.00
1,756.58
1.93
5.02
71.00
343.98
608.70
8.875
990.96
30.74
969.42 Pass- Major Risk
1,410.41
1,369.01
2,000.00
1,822.44
2.02
5.72
71.04
381.24
674.06
8.875
1,086.49
32.93
1,064.35 Pass - Major Risk
CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
121712018 9:56:40AM Page 4 COMPASS 5000.14 Build 85D
o. ConocoPhillips BAT
ConocoPhillips Travelling Cylinder Report 11GHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
1 J-10
Well Error:
0.00 usft
Reference Wellbore
1J-101-1
Reference Design:
1 J-10L1_wp01
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1J-10
1J-10:114.25 @ 114.25usft (1J-10:114.25)
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Offset Design
Kuparuk 1 J Pad - 1 J-03 - 1 J-03 - 1 J-03
offset site Error: 0.00 usf
Survey Program: 201-MWD+IFR-AK-SCC
Rule Assigned: Major Risk
Offset Well Error: 0.00 usf
Reference
Offset 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
+E1-W
Hole Size Centre
Distance
Deviation
(usft) (usft)
(usft) (usft) (usft) (usft) (1
(usft)
(usft)
(in) (usft)
(usft)
(usft)
1,417.06 1,374.77
2,100.00 1,883.19 2.03 6.45 70.93
420.25
743.21
8.875 1,183.65
34.82
1,161.34 Pass -Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/7/2018 9:56:40AM Page 5 COMPASS 5000.14 Build 85D
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—ConocoPhilfips E- port Company
uparuk River Unit
Kuparuk 1J Pad
1J-10
1J-10L1-01
Plan: 1J-101-1-01_wp02
17 December, 2018
BA ER
UGHES
a GE company
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
i J-10
Wellbore:
1J-10L1-01
Design:
1 J-10 L1-01_wp02
ConocoPhillips
SA
(ER
Planning Report
UGHES
a GE company
Local Co-ordinate Reference:
Well 1J-10
TVD Reference:
Mean Sea Level
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kuparuk 1J Pad
Site Position: Northing: 5,945,919.64 usft Latitude: 70' 15' 46.258 N
From: Map Easting: 558,789.95 usft Longitude: 149' 31' 29.007 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 °
Well 1 J-10
Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70' 15' 45.169 N
+E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 1490 31' 32.426 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1J-10L1-01
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(`) (1 (nT)
BGGM2018 2/1/2019 16.77 80.84 57,424
Design 1J-101-1-01_wp02
Audit Notes:
Version: Phase: PLAN Tie On Depth: 10,420.00
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
(usft) (usft) (usft) (I
0.00 0.00 0.00 120.00
1211712018 10:42:18AM Page 2 COMPASS 5000.14 Build 85D
Conoc®Phillips BWEcoinpany
R
COnOCOPhillips Planning Report GHES
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk I Pad
Well:
1J-10
Wellbore:
1 J-10L1-01
Design:
1J-10L1-01 Wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft(1J-10:114.25)
True
Minimum Curvature
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Rate
Rate
Rate
TFO
(usft)
(")
(")
(usft)
(usft)
(usft)
(°1100usft)
("1100usft)
("/100usft)
(") Target
10,420.00
56.55
292.00
5,937.78
3,670.22
-6,896.42
0.00
0.00
0.00
0.00
10,441.00
59.11
290.29
5,948.96
3,676.63
-6,913.00
14.00
12.18
-8.15
330.00
10,517.97
90.00
273.78
5,969.34
3,691.06
-6,984.57
45.00
40.13
-21.45
330.00
10,800.00
90.00
146.87
5,969.34
3,494.42
-7,099.58
45.00
0.00
-45.00
270.00
11,125.00
90.00
124.12
5,969.34
3,264.16
-6,873.25
7.00
0.00
-7.00
270.00
11,330.00
77.61
116.83
5,991.46
3,160.95
-6,698.13
7.00
-6.05
-3.56
210.00
11,530.00
77.98
102.51
6,033.96
3,095.37
-6,514.58
7.00
0.19
-7.16
270.00
11,735.00
90.47
109.63
6,054.58
3,038.94
-6,319.14
7.00
6.09
3.47
30.00
12,035.00
91.15
130.62
6,050.29
2,889.25
-6,061.12
7.00
0.23
7.00
88.00
12,300.00
91.09
112.06
6,045.04
2,752.05
-5,835.82
7.00
-0.02
-7.00
270.00
12,700.00
83.54
139.07
6,064.11
2,522.19
-5,513.88
7.00
-1.89
6.75
106.00
13,050.00
89.04
115.14
6,087.08
2,313.28
-5,237.34
7.00
1.57
-6.84
282.00
13,300.00
89.69
132.63
6,089.88
2,174.45
-5,030.62
7.00
0.26
7.00
88.00
13,700.00
90.19
104.63
6,090.30
1,984.68
-4,683.02
7.00
0.13
-7.00
271.00
14,050.00
85.23
128.65
6,104.48
1,829.16
-4,372.76
7.00
-1.42
6.86
102.00
14,450.00
90.45
101.11
6,119.85
1,662.80
-4,013.70
7.00
1.30
-6.88
280.00
14,850.00
89.69
129.10
6,119.35
1,494.75
-3,655.09
7.00
-0.19
7.00
91.50
15,200.00
90.13
104.61
6,119.89
1,337.84
-3,345.21
7.00
0.13
-7.00
271.00
12/17/2018 10:42:18AM Page 3 COMPASS 5000.14 Build 85D
.., conocoiahitiips A (ER
ConocoPilliiip5 Planning Report t UGHES
a GE company
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1J-10
Company:
_ConocoPhillips Export Company
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1J-10:114.25 @ 114.25usft (1 J-1 0: 114.25)
Site:
Kuparuk 1J Pad
North Reference:
True
Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Wellbore:
1J-101-1-01
Design:
1J-101-1-01 wp02
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°1100usft)
(°)
(usft)
(usft)
10,420.00
56.55
292.00
5,937.78
3,670.22
-6,896.42
-7,807.58
0.00
0.00
5,949,424.08
551,749.18
TIPIKOP
10,441.00
59.11
290.29
5,948.96
3,676.63
-6,913.00
-7,825.14
14.00
-30.00
5,949,430.36
551,732.55
End 14 dis, Start 45 dis
10,500.00
82.70
277.27
5,968.20
3,689.34
-6,966.73
-7,878.03
45.00
-30.00
5,949,442.65
551,678.72
10,517.97
90.00
273.78
5,969.34
3,691.06
-6,984.57
-7,894.34
45.00
-25.63
5,949,444.23
551,660.88
3
10,600.00
90.00
236.87
5,969.34
3,670.63
-7,062.56
-7,951.67
45.00
-90.00
5,949,423.20
551,583.06
10,700.00
90.00
191.87
5,969.34
3,590.20
-7,117.56
-7,959.09
45.00
-90.00
5,949,342.34
551,528.68
10,800.00
90.00
146.87
5,969.34
3,494.42
-7,099.58
-7,895.63
45.00
-90.00
5,949,246.72
551,547.41
End 45 dls, Start 7 dis
10,900.00
90.00
139.87
5,969.34
3,414.22
-7,039.95
-7,803.89
7.00
-90.00
5,949,167.00
551,607.66
11,000.00
90.00
132.87
5,969.34
3,341.89
-6,970.99
-7,708.00
7.00
-90.00
5,949,095.21
551.677.17
11,100.00
90.00
125.87
5,969.34
3,278.50
-6,893.73
-7,609.39
7.00
-90.00
5.949,032.43
551,754.92
11,125.00
90.00
124.12
5,969.34
3,264.16
-6,873.25
-7,584.49
7.00
-90.00
5,949,018.26
551,775.51
5
11,200.00
85.46
121.49
5,972.32
3,223.58
-6,810.28
-7,509.66
7.00
-150.00
5,948,978.17
551,838.78
11,300.00
79.41
117.92
5,985.48
3,174.47
-6,724.24
-7,410.60
7.00
-149.90
5,948,929.74
551,925.20
11,330.00
77.61
116.83
5,991.46
3,160.95
-6,698.13
-7,381.23
7.00
-149.43
5,948,916.43
551,951.40
6
11,400.00
77.65
111.81
6,006.46
3,132.81
-6,635.85
-7,313.22
7.00
-90.00
5,948,888.77
552,013.90
11,500.00
77.88
104.65
6,027.69
3,102.26
-6,543.09
-7,217.61
7.00
-88.92
5,948,858.94
552,106.88
11,530.00
77.98
102.51
6,033.96
3,095.37
-6,514.58
-7,189.47
7.00
-87.41
5,948,852.28
552,135.45
7
11,600.00
82.23
104.98
6,045.99
3,078.98
-6,447.62
-7,123.29
7.00
30.00
5,948,836.42
552,202.53
11,700.00
88.33
108.43
6,054.21
3,050.35
-6,352.22
-7,026.36
7.00
29.58
5,948,808.53
552,298.13
11,735.00
90.47
109.63
6,054.58
3,038.94
-6,319.14
-6,992.00
7.00
29.29
5,948,797.38
552,331.30
8
11,800.00
90.63
114.17
6,053.96
3,014.70
-6,258.85
-6,927.67
7.00
88.00
5,948,773.62
552,391.77
11,900.00
90.86
121.17
6,052.66
2,968.30
-6,170.35
-6,827.83
7.00
88.04
5,948,727.91
552,480.62
12,000.00
91.08
128.17
6,050.97
2,911.46
-6,088.16
-6,728.23
7.00
88.13
5,948,671.71
552,563.24
12,035.00
91.15
130.62
6,050.29
2,889.25
-6,061.12
-6,693.71
7.00
88.25
5,948,649.72
552,590.45
9
12,100.00
91.15
126.07
6,048.98
2,848.95
-6,010.16
-6,629.43
7.00
-90.00
5,948,609.82
552,641.72
12,200.00
91.13
119.06
6,046.99
2,795.17
-5,925.96
-6,529.61
7.00
-90.09
5,948,556.70
552,726.33
12,300.00
91.09
112.06
6,045.04
2,752.05
-5,835.82
-6,429.99
7.00
-90.23
5,948,514.29
552,816.80
10
12,400.00
89.16
118.79
6,044.82
2,709.14
-5,745.56
-6,330.37
7.00
106.00
5,948,472.09
552,907.38
12,500.00
87.24
125.53
6,047.96
2,655.98
-5,661.00
-6,230.56
7.00
106.01
5,948,419.59
552,992.34
12,600.00
85.36
132.28
6,054.43
2,593.35
-5,583.38
-6,132.03
7.00
105.80
5,948,357.58
553,070.44
12,700.00
83.54
139.07
6.064.11
2,522.19
-5,513.88
-6,036.26
7.00
105.37
5,948,286.97
553,140.48
11
12,800.00
85.04
132.20
6,074.08
2,451.11
-5,444.35
-5,940.50
7.00
-78.00
5,948,216.44
553,210.56
12,900.00
86.61
125.36
6,081.37
2,388.68
-5,366.65
-5,841.99
7.00
-77.32
5,948,154.62
553,288.74
13,000.00
88.22
118.54
6,085.89
2,335.85
-5,281.94
-5,742.22
7.00
-76.82
5,948,102.46
553,373.85
13,050.00
89.04
115.14
6,087.08
2,313.28
-5,237.34
-5,692.31
7.00
-76.51
5,948,080.24
553,418.61
12
13,100.00
89.17
118.64
6,087.87
2,290.68
-5,192.76
-5,642.40
7.00
88.00
5,948,057.99
553,463.37
13,200.00
89.42
125.63
6,089.10
2,237.52
-5,108.14
-5,542.54
7.00
87.95
5,948,005.50
553,548.39
13,300.00
89.69
132.63
6,089.88
2,174.45
-5,030.62
-5,443.87
7.00
87.86
5,947,943.04
553,626.39
13
13,400.00
89.81
125.63
6,090.32
2,111.38
-4,953.10
-5,345.20
7.00
-89.00
5,947,880.58
553,704.39
12/17/2018 10:42:18AM Page 4 COMPASS 5000.14 Build 85D
Conoc®Phillips
ConocoPhillips Planning Report
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Company:
_ConocoPhillips Export Company
TVD Reference:
Project:
Kuparuk River Unit
MD Reference:
Site:
Kuparuk 1J Pad
North Reference:
Well:
1J-10
Survey Calculation Method:
Wellbore:
iJ-10L1-01
Design:
1 J-10L1-01_wp02
1PR
GHES
E company
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
True
Minimum Curvature
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+Nl-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°)
(usft)
(usft)
13,500.00
89.94
118.63
6,090.54
2,058.23
-4,868.47
-5,245.33
7.00
-88.97
5,947,828.09
553,789.43
13,600.00
90.07
111.63
6,090.53
2,015.78
-4,778.00
-5,145.76
7.00
-88.95
5,947,786.36
553,880.22
13,700.00
90.19
104.63
6,090.30
1,984.68
-4,683.02
-5,047.95
7.00
-88.95
5,947,756.00
553,975.43
14
13,800.00
88.74
111.48
6,091.24
1,953.70
-4,588.01
-4,950.18
7.00
102.00
5,947,725.77
554,070.67
13,900.00
87.30
118.34
6,094.69
1,911.64
-4,497.42
-4,850.70
7.00
101.94
5,947,684.41
554,161.57
14,000.00
85.91
125.21
6,100.62
1,859.11
-4,412.61
-4,750.99
7.00
101.70
5,947,632.56
554,246.78
14,050.00
85.23
128.65
6,104.48
1,829.16
-4,372.76
-4,701.51
7.00
101.29
5,947,602.92
554,286.86
1s
14,100.00
85.85
125.20
6,108.37
1,799.22
-4,332.92
-4,652.03
7.00
-80.00
5,947,573.29
554,326.93
14,200.00
87.12
118.30
6,114.51
1,746.74
-4,248.10
-4,552.33
7.00
-79.73
5,947,521.48
554,412.15
14,300.00
88.44
111.42
6,118.39
1,704.75
-4,157.49
-4,452.87
7.00
-79.31
5,947,480.21
554,503.08
14,400.00
89.78
104.55
6,119.95
1,673.90
-4,062.44
-4,355.13
7.00
-79.04
5,947,450.10
554,598.35
14,450.00
90.45
101.11
6,119.85
1,662.80
-4,013.70
-4,307.36
7.00
-78.93
5,947,439.38
554,647.17
16
14,500.00
90.36
104.61
6,119.50
1,651.67
-3,964.96
-4,259.59
7.00
91.50
5,947,428.63
554,695.99
14,600.00
90.17
111.61
6,119.04
1,620.60
-3,869.98
-4,161.80
7.00
91.52
5,947,398.31
554,791.20
14,700.00
89.98
118.61
6,118.92
1,578.20
-3,779.48
-4,062.23
7.00
91.56
5,947,356.61
554,882.02
14,800.00
89.79
125.61
6,119.13
1,525.08
-3,694.83
-3,962.36
7.00
91.57
5,947,304.16
554,967.07
14,850.00
89.69
129.10
6,119.35
1,494.75
-3,655.09
-3,912.78
7.00
91.55
5,947,274.14
555,007.04
17
14,900.00
89.75
125.60
6,119.60
1,464.42
-3,615.35
-3,863.20
7.00
-89.00
5,947,244.12
555,047.01
15,000.00
89.88
118.61
6,119.92
1,411.30
-3,530.70
-3,763.33
7.00
-88.98
5,947,191.67
555,132.07
15,100.00
90.01
111.61
6,120.02
1,368.90
-3,440.20
-3,663.75
7.00
-88.96
5,947,149.98
555,222.88
15,200.00
90.13
104.61
6,119.89
1,337.84
-3,345.21
-3,565.96
7.00
-88.95
5,947,119.66
555,318.10
Planned TD at 15200.00
,asing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
15,200.00 6,119.89 23/8" 2.375 3.000
1211712018 10.42.18AM Page 5 COMPASS 5000.14 Build 85D
ConocoPhillips EtA tER
ConocoPhillips Planning Report I-�UGHES
a GE company
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1 J Pad
Well:
iJ-10
Wellbore:
1 J-1 OL1-01
Design:
1 J-10L1-01_wp02
Plan Annotations
Measured
Vertical
Depth
Depth
(usft)
(usft)
10,420.00
5,937.78
10,441.00
5,948.96
10,517.97
5,969.34
10.800.00
5,969.34
11,125.00
5,969.34
11,330.00
5,991.46
11,530.00
6,033.96
11,735.00
6,054.58
12,035.00
6,050.29
12.300.00
6,045.04
12,700.00
6,064.11
13,050.00
6,087.08
13,300.00
6,089.88
13,700.00
6,090.30
14,050.00
6,104.48
14.450.00
6,119.85
14,850.00
6,119.35
15,200.00
6,119.89
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Local Coordinates
+N/-S
+El-W
(usft)
(usft)
3,670.22
-6,896.42
3,676.63
-6,913.00
3,691.06
-6,984.57
3,494.42
-7,099.58
3,264.16
-6,873.25
3,160.95
-6,698.13
3,095.37
-6.514.58
3,038.94
-6,319.14
2,889.25
-6,061.12
2,752.05
-5.835.82
2,522.19
-5,513.88
2,313.28
-5,237.34
2,174.45
-5,030.62
1,984.68
-4,683.02
1,829.16
-4,372.76
1,662.80
-4,013.70
1,494.75
-3,655.09
1,337.84
-3,345.21
Comment
TIP/KO P
End 14 dls, Start 45 dls
3
End 45 dls, Start 7 dls
5
6
7
8
9
10
11
12
13
14
15
16
17
Planned TD at 15200.00
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1211712018 10:42:18AM Page 6 COMPASS 5000.14 Build 85D
ConocoPhillips
•° 1 o : •Inc.
-Kupl
Kuparuk River Unit
Kuparuk 1J Pad
1Jm10
IJ-IOLI-01
Travelling Cylinder Report
10 December, 2018
BER
BA 0
GE company
,. ConocoPhillips BAT
ConocoPhillips Travelling Cylinder Report UGHES
a GEcompany
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
1J-10
Well Error:
0.00 usft
Reference Wellbore
1J-101-1-01
Reference Design:
1J-10L1-01_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1J-10
1 J-10:114.25 @ 114.25usft (1 J-10:114.25)
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
teference 1J-10L1-01_wp02
ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA
)epth Range: Unlimited Scan Method: Tray. Cylinder North
tesults Limited by: Maximum center -center distance of 1,708.58 usft Error Surface: Pedal Curve
Survey Tool Program
Date 12/10/2018
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
205.18
10,166.00 1J-10(1J-10)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
10,166.00
10,420.00 1J-10L1_wp01 (1J-10L1)
MWD
MWD- Standard
10.420.00
15,200.00 1J-10L1-01_wp02(1J-101-1-01)
MWD
MWD- Standard
Casing Points
Measured
Vertical
Casing
Hale
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
6,936.54
3,991.30 9 5/8"
9.625
12.250
10,142.96
5,891.30 7"
7.000
8.500
15,200.00
6,234.14 2 3/8"
2.375
3.000
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-35 - Plan 1 E-35A - 1 E-35A (wp02)
14,800.00
14,900.00
980.15
524.29
458.57
Pass - Major Risk
Kuparuk iJ Pad
1 J-03 - 1J-03 - 1J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
iJ-03 - 1J-0311 - 1J-031-1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03 - 1J-031-2 - 1J-0312
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03 - 1J-03L2PB1 - 1J-03L2PB1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-09 - 1 J-09 - 1 J-09
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1 J-09 - 1 J-09A - 1 J-09A
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09 - 1J-09AL1 - iJ-09AL1
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-10 - 1J-10 - 1J-10
10,488.86
10,500.00
29.34
13.37
20.96
Pass - Major Risk
1 J-10 - 1 J-101-1 - 1 J-10L1_wp01
Out of range
1J-10-1J-1OL1-02-1J-1011-02_wp01
11,100.00
11,100.00
0.00
2.43
-0.42
FAIL - Minor 1/10
1J-10-1J-1011-03-1J-10L1-03_wp01
11,100.00
11,100.00
0.00
2.43
-0.42
FAIL - Minor 1/10
1 J-105 - 1 J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-10511 - 1 J-1051-1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-1051-2 - iJ-1051-2
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-105PB1 - 1J-105PB1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-107 - 1 J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-107 - 1J-1071-1 - 1 J-1071-1
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
11-109 - 1J-109 - 11-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109- 1J-109PB1 - 1J-109PB1
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-115 - 1J-115 - 1J-115
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
iJ-115 - 1J-1151-1 - 1J-115L1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151-1 PB1 - 1J-115L1 PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-11511 PB2 - 1J-1151-1 PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
121102018 4:21:10PM Page 2 COMPASS 5000.14 Build 85D
10-11
ConocoPhillips
IIA4<ER
ConocoPhillips
Travelling Cylinder Report
UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Reference Site:
Kuparuk 1J Pad
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
lJ-101-1-01
Database:
EDT 14 Alaska Production
Reference Design:
1J-10L1-01 wp02
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-115 - 1J-115L2 - 1J-1151_2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
iJ-115 - 1J-115L2PB1 - 1J-115L2PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115L2PB2 - 1J-115L2PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-1 15 - 1J-1 1 5PB1 - 1J-11 5PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115PB2 - 1 J-115PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - iJ-115PB3 - 1 J-115PB3
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115PB4 - 1J-115PB4
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
11-118 - 1J-118 - 1J-118
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-1181-1-1J-1181_1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-1181_2-1J-1181_2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-1 18 - 1J-11 8PB1 - 1 J-11 8PB1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118PB2 - 1 J-118P82
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
iJ-120 - 1J-120 - 1J-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120L1 - 1 J-120L1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-1201-1PB1-1J-120L1PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 PB2 - 1J-120L1 PB2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - iJ-120L1 PB3 - 1 J-1201-1 PB3
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-1201-1 P84 - 1J-1201_1 P84
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-1201-2-1J-1201-2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120- 1J-120L2PBi - 1J-120L2PB1
304.57
300.00
216.86
4.81
212.05
Pass- Major Risk
1 J-152 - 1 J-152 - 1 J-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152L1 - 1J-152L1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-1521-2-1J-1521_2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-iJ-152L2PB1-1J-152L2PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1J-152PB1 - 1 J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152PB2-1J-152PB2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-154 - iJ-154 - 1J-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154- 1J-154L1 - 1J-1541_1
605.44
600.00
146.13
10.47
135.67
Pass- Major Risk
1J-154 - iJ-154L2 - 1J-1541_2
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-156 - 1J-156 - 1J-156
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561-1-1J-156L1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561-1PB1-1J-1561-1PB1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561_2-1J-1561_2
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1 J-1 58 - 1J-1 58 - 1J-1 58
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158- 1J-1581-1 - 1J-158L1
392.81
400.00
60.36
6.31
54.05
Pass- Major Risk
1J-159 - iJ-159 - 1J-159
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1 J-159L1 - 1J-1591-1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-1591-1P131-1J-159LIP61
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591-1 PB2 - 1J-1591-1 PB2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-iJ-1591-2-1J-1591_2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159- iJ-159PB1 - 1J-159PB1
405.33
400.00
38.11
6.69
31.42
Pass- Major Risk
1J-160-1J-160 - 1J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-1601-1 - 1 J-160L1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-1601-1PB1-1J-160L1P131
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-1601-2 - 1 J-1601-2
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-162 - 1J-162 - 1J-162
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162L1-1J-1621-1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - iJ-162L1 P61 - 1J-162L1 PB1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - 1J-162PB1 - 1J-162PB1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162PB2-1J-162PB2
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-164 - 1J-164 - iJ-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-164L1 - 1J-164L1
796.36
800.00
77.47
13.02
64.51
Pass- Major Risk
1J-164 - 1J-164L2 - 1 J-1641_2
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:21:10PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips
98AER
ConocoPhilli
p s
Travelling Cylinder Report
t-�UGHES
U
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Reference Site:
Kuparuk 1J Pad
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-10L1-01
Database:
EDT 14 Alaska Production
Reference Design:
1J-101-1-01_w1302
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-164-1J-164L2PB1-1J-164L2PB1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-166 - 1J-166 - 1 J-166
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-166L1 - 1J-1661-1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-166L1 P131 - 1J-166L1 P81
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-1 66 - 1J-16612 - 1 J-166L2
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-166L2PB1 - 1J-166L2PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-1 68 - 1J-168 - 1J-1 68
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168- 1J-1681-1 - 1J-16811
404.72
400.00
161.98
6.61
155.38
Pass- Major Risk
1J-168 - 1J-1681-2 - 1J-1681-2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168- 1J-1681_21`131 - 1J-1681_2PB1
404.72
400.00
161.98
6.61
155.38
Pass- Major Risk
1J-170 - 1J-170 - 1J-170
5,690.17
8,300.00
247.69
159.88
140.49
Pass - Major Risk
1J-170- 1J-17OL1 - 1J-1701-1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170 - 1J-17012 - 1J-170L2
5,394.81
8,200.00
166.39
152.00
53.52
Pass - Major Risk
1J-170- 1J-170PB1 - 1J-170PB1
5,676.40
8,300.00
273.16
159.57
164.32
Pass- Major Risk
1J-170 - 1J-170PB2 - 1J-170PB2
5,690.17
8,300.00
247.69
160.14
140.23
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 - Prelim: 1J-
406.82
400.00
232.09
5.53
226.57
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L1 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L2 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-109a-1J-109PB1x-1J-109PB1x
114.25
33.25
177.64
1.02
176.62
Pass - Major Risk
W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15
487.50
500.00
209.67
9.95
199.72
Pass - Major Risk
W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2
396.03
400.00
184.70
5.72
178.98
Pass - Major Risk
W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20
810.09
800.00
83.61
17.14
66.47
Pass - Major Risk
W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3
503.17
500.00
184.73
11.21
173.52
Pass - Major Risk
W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4
491.49
500.00
196.71
7.54
189.18
Pass - Major Risk
W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5
486.33
500.00
231.04
10.16
220.89
Pass - Major Risk
Offset Design
Kuparuk 1 E Pad - 1 E-35 - Plan 1 E-35A - 1 E-35A (wp02)
offset site Error: 0.00 usft
Survey Program: 19g-GYD-CT-CMS, 6963-MWD
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
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
+EI-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
lush)
(usft)
(usft)
(°)
(usft)
lush)
(in)
(usft)
(usft)
(usft)
13,900.00
6,208.94
13,700.00
5,798.68
55.02
110.45
42.28
3,338.25
-3,668.78
5.000
1,699.37
438.66
1,266.27 Pass- Major Risk
13,950.00
6,211.60
13,800.00
5,825.46
55.52
111.94
45.20
3,253.12
-3,623.67
5.000
1,644.38
452.60
1,203.16 Pass - Major Risk
13,950.00
6.211.60
13,900.00
5,852.24
55.52
113.44
44.84
3,167.98
-3,578.56
5.000
1,592.39
456.38
1,139.51 Pass - Major Risk
14,520.69
6,233.63
14,000.00
5,879.02
61.71
114.94
29.31
3,082.85
-3,533.45
3.000
1,535.28
417.35
1,127.32 Pass - Major Risk
14,550.00
6,233.48
14,100.00
5,905.80
62.05
116.44
30.95
2,997.71
-3,488.33
3.000
1,462.60
430.15
1,043.86 Pass - Major Risk
14,570.71
6,233.39
14,200.00
5,932.58
62.29
117.95
31.92
2,912.58
-3,443.22
3.000
1,392.03
440.00
960.62 Pass - Major Risk
14,600.00
6,233.29
14,300.00
5,959.36
62.64
119.45
33.43
2,827.45
-3,398.11
3.000
1,323.86
452.37
880.39 Pass - Major Risk
14,627.13
6,233.23
14,400.00
5,986.14
62.97
120.96
34.70
2,742.31
-3,353.00
3.000
1,258.30
463.82
801.86 Pass - Major Risk
14,650.00
6,233.19
14,500.00
6,012.92
63.24
122.46
35.59
2,657.18
-3,307.89
3.000
1,195.70
473.82
725.15 Pass - Major Risk
14,700.00
6,233.17
14,600.00
6,039.71
63.85
123.97
38.27
2,572.04
-3,262.78
3.000
1,136.24
490.68
655.04 Pass - Major Risk
14,725.15
6.233.19
14,700.00
6,066.49
64.15
125.48
39.09
2,486.91
-3,217.67
3.000
1,080.17
500.53
584.43 Pass - Major Risk
14,750.00
6,233.23
14,800.00
6.093.27
64.46
127.00
39.78
2,401.77
-3,172.56
3.000
1,028.20
510.04
517.95 Pass - Major Risk
14,800.00
6,233.38
14,900.00
6,120.05
65.06
128.51
42.08
2,316.64
-3,127.45
3.000
980.15
524.29
458.57 Pass- Major Risk, CC, ES, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:21:10PM , Page 4 COMPASS 5000.14 Build 85D
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—ConocoPhillips Export Company
Kuparuk River Unit
Kuparuk IJ Pad
Plan: 1 J®1 OL1®02_wp01
17 December, 2018
BEFL
BA Do
GE company
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1J-10
Wellbore:
1 J-10L1-02
Design:
1 J-10 L 1-02_wp01
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
11A {ER
I-�UGHES
a GE company
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kuparuk 1J Pad
Site Position: Northing: 5,945,919.64 usft Latitude: 70° 15' 46.258 N
From: Map Easting: 558,789.95 usft Longitude: 149° 31' 29.007 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.45 °
Well 1 J-10
Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70° 15' 45.169 N
+E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149° 31' 32.426 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1J-101-1-02
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(I (% (nT)
BGGM2018 2/1/2019 16.77 80.84 57,424
Design iJ-101-1-02_wpol
Audit Notes:
Version: Phase: PLAN Tie On Depth: 12,300.00
Vertical Section: Depth From (TVD) +N/S +El-W Direction
(usft) (usft) (usft) (°)
0.00 0.00 0.00 180.00
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/S
+E/-W
Rate
Rate
Rate
TFp
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°/100usft)
(°/10ousft)
(°/100usft)
(°) Target
12,300.00
88.48
142.97
6,045.13
2,762.32
-5,844.45
0.00
0.00
0.00
0.00
12,425.00
80.92
147.39
6,056.67
2,660.26
-5,773.42
7.00
-6.05
3.53
150.00
12,575.00
90.03
152.61
6,068.50
2,530.92
-5,698.80
7.00
6.08
3.49
30.00
12,900.00
91.96
175.29
6,062.76
2,220.69
-5,609.53
7.00
0.59
6.98
85.00
13,225.00
91.81
198.05
6,051.92
1,900.18
-5,647.00
7.00
-0.05
7.00
90.00
13,500.00
91.71
178.79
6,043.39
1,629.56
-5,687.06
7.00
-0.04
-7.00
270.00
13,775.00
90.63
198.01
6.037.73
1,358.84
-5,727.05
7.00
-0.39
6.99
93.00
14,175.00
90.55
170.01
6,033.54
963.80
-5,754.76
7.00
-0.02
-7.00
270.00
14,375.00
90.54
184.01
6,031.63
764.58
-5,744.36
7.00
-0.01
7.00
90.00
14,775.00
90.47
156.01
6,028.04
374.57
-5,675.68
7.00
-0.02
-7.00
270.00
1211712018 10:44:13AM Page 2 COMPASS 5000.14 Build 85D
Conocophillips
8,A (ER
ConocoPhiliip5 Planning Report F UGHES
a GE company
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well iJ-10
Company:
_ConocoPhillips Export Company
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Site:
Kuparuk 1J Pad
North Reference:
True
Well:
U-10
Survey Calculation Method:
Minimum Curvature
Wellbore:
1J-10L1-02
Design:
1J-101-1-02 wp01
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
{°)
(usft)
(usft)
12,300.00
88.48
142.97
6,045.13
2,762.32
-5,844.45
-2,762.32
0.00
0.00
5,948,524.49
552,808.08
TIP/KOP
12,400.00
82.43
146.49
6,053.05
2,680.99
-5,786.92
-2,680.99
7.00
150.00
5,948,443.62
552,866.25
12,425.00
80.92
147.39
6,056.67
2,660.26
-5,773.42
-2,660.26
7.00
149.72
5,948,423.00
552,879.90
Start 7 dls
12,500.00
85.47
150.02
6,065.56
2,596.64
-5,734.76
-2,596.64
7.00
30.00
5,948,359.69
552,919.06
12,575.00
90.03
152.61
6,068.50
2,530.92
-5,698.80
-2,530.92
7.00
29.69
5,948,294.26
552,955.52
3
12,600.00
90.19
154.36
6,068.45
2,508.55
-5,687.64
-2,508.55
7.00
85.00
5,948,271.98
552,966.85
12,700.00
90.79
161.33
6,067.60
2,415.99
-5,649.95
-2,415.99
7.00
85.00
5,948,179.73
553,005.26
12,800.00
91.39
168.31
6,065.69
2,319.56
-5,623.78
-2,319.56
7.00
85.06
5,948,083.51
553,032.17
12,900.00
91.96
175.29
6,062.76
2,220.69
-5,609.53
-2,220.69
7.00
85.20
5,947,984.76
553,047.20
4
13,000.00
91.95
182.29
6,059.34
2,120.83
-5,607.42
-2,120.83
7.00
90.00
5,947,884.93
553.050.08
13,100.00
91.91
189.29
6,055.98
2,021.46
-5,617.50
-2,021.46
7.00
90.24
5,947,785.49
553,040.78
13,200.00
91.83
196.30
6,052.71
1,924.05
-5,639.62
-1,924.05
7.00
90.48
5,947,687.93
553,019.42
13,225.00
91.81
198.05
6,051.92
1,900.18
-5,647.00
-1,900.18
7.00
90.70
5,947,664.00
553,012.23
5
13,300.00
91.80
192.80
6,049.55
1,827.94
-5,666.93
-1,827.94
7.00
-90.00
5,947,591.62
552,992.86
13,400.00
91.77
185.79
6,046.43
1,729.37
-5,683.06
-1,729.37
7.00
-90.17
5,947,492.93
552,977.50
13,500.00
91.71
178.79
6,043.39
1,629.56
-5,687.06
-1,629.56
7.00
-90.38
5,947,393.10
552,974.29
6
13,600.00
91.33
185.78
6,040.73
1,529.73
-5,691.04
-1,529.73
7.00
93.00
5,947,293.26
552,971.08
13,700.00
90.93
192.77
6,038.75
1,431.12
-5,707.15
-1,431.12
7.00
93.19
5,947,194.53
552,955.74
13,775.00
90.63
198.01
6,037.73
1,358.84
-5,727.05
-1,358.84
7.00
93.32
5,947,122.11
552,936.41
7
13,800,00
90.63
196.26
6,037.46
1,334.96
-5,734.41
-1,334.96
7.00
-90.00
5,947,098.17
552,929.23
13,900.00
90.62
189.26
6,036.37
1,237.49
-5,756.49
-1,237.49
7.00
-90.02
5,947,000.54
552,907.91
14,000.00
90.60
182.26
6,035.31
1,138.07
-5,766.53
-1,138.07
7.00
-90.10
5,946,901.05
552,898.66
14,100.00
90.58
175.26
6,034.28
1,038.16
-5,764.37
-1,038.16
7.00
-90.17
5,946,801.17
552,901.59
14,175,00
90.55
170.01
6,033.54
963.80
-5,754.76
-963.80
7.00
-90.24
5,946,726.90
552,911.78
a
14,200.00
90.55
171.76
6,033.30
939.12
-5,750.80
-939.12
7.00
90.00
5,946,702.26
552,915.93
14,300.00
90.55
178.76
6,032.34
839.53
-5,742.55
-839.53
7.00
90.02
5,946,602.74
552,924.96
14,375.00
90.54
184.01
6,031.63
764.58
-5,744.36
-764.58
7.00
90.08
5,946,527.79
552,923.73
9
14,400.00
90.54
182.26
6,031.40
739.62
-5,745.73
-739.62
7.00
-90.00
5,946,502.82
552,922.55
14,500.00
90.53
175.26
6,030.47
639.71
-5,743.57
-639.71
7.00
-90.02
5,946,402.94
552,925.49
14,600.00
90.52
168.26
6,029.55
540.81
-5,729.25
-540.81
7.00
-90.08
5,946,304.16
552,940.58
14,700.00
90.49
161.26
6,028.67
444.39
-5,702.99
444.39
7.00
-90.15
5,946,207.96
552,967.59
14,775.00
90.47
156.01
6,028.04
374.57
-5,675.68
-374.57
7.00
-90.21
5,946,138.36
552,995.44
Planned TD at 14775.00
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
14,775.00 6,028.04 2 3/8" 2.375 3.000
12/17/2018 10:44.13AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips I
AKER
ConocoPhillips Planning Report 4UGHES
a GE company
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1J-10
Wellbore:
1 J-10L1-02
Design:
1 J-10L1-02_wp01
Plan Annotations
Measured
Vertical
Depth
Depth
(usft)
(usft)
12,300.00
6,045.13
12,425.00
6,056.67
12,575.00
6,068.50
12,900.00
6,062.76
13,225.00
6,051.92
13,500.00
6,043.39
13,775.00
6,037.73
14,175.00
6.033.54
14,375.00
6,031.63
14,775.00
6,028.04
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Local Coordinates
+N/-S
+El-W
(usft)
(usft)
2,762.32
-5,844.45
2,660.26
-5,773.42
2,530.92
-5,698.80
2,220.69
-5,609.53
1,900.18
-5,647.00
1,629.56
-5,687.06
1,358.84
-5,727.05
963.80
-5,754.76
764.58
-5,744.36
374.57
-5,675.68
Comment
TIP/KO P
Start 7 dls
3
4
5
6
7
8
9
Planned TD at 14775.00
Well 1J-10
Mean Sea Level
1 J-10:114.25 @ 114.25usft (1 J-10:114.25)
True
Minimum Curvature
1211712018 10:44:13AM Page 4 COMPASS 5000.14 Build 85D
onocoPhillipS
ConocoPhAsei s �iMasl a) Into
®Kup1
Kuparuk River Unit
Kuparuk 1J Pad
1J®10
1 J®10L1 m02
1J-10L1-02_wp01
`gavelling Cylinder Report
10 December, 2018
BER
T% "
GHES
GE company
ConocoPhillips BA_ �(ER
ConocoPhillips Travelling Cylinder Report BAT
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
1J-10
Well Error:
0.00 usft
Reference Wellbore
1J-10L1-02
Reference Design:
1J-10L1-02_wp01
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1J-10
1J-10:114.25 @ 114.25usft (1J-10:114.25)
iJ-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference
1J-10L1-02 wp01
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 100.00usft Error Model: ISCWSA
Depth Range:
Unlimited Scan Method: Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,666.08 usft Error Surface: Pedal Curve
Survey Tool Program
Date 12/1012018
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
205.18
10,166.00 1J-10(1J-10)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
10,166.00
10,420.00 1J-10L1_wp01 (1J-101-1)
MWD
MWD- Standard
10,420.00
12,300.00 1J-101-1-01_wp01 (iJ-10L1-01)
MWD
MWD- Standard
12,300.00
14,775.00 1J-10L1-02_wp01 (1J-101-1-02)
MWD
MWD- Standard
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
6,936.54
3,991.30 9 5/8"
9.625
12.250
10,142.96
5,891.30 7"
7.000
8.500
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 1J Pad
1 J-03 - 1 J-03 - 1 J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1 J-03 - 1J-03L1 - 1J-03L1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-03 - 1J-031_2 - 1 J-031_2
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03 - 1J-03L2PB1 - iJ-03L2PB1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-09 - 1 J-09 - 1 J-09
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1 J-09 - 1J-09A- 1 J-09A
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1 J-09 - 1J-09AL1 - 1 J-09ALl
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
11-10 - 11-10 - 11-10
10,488.86
10,500.00
29.34
13.60
20.73
Pass - Major Risk
1J-10 - iJ-10L1 - 1J-10L1_wp01
Out of range
1J-10-1J-101-1-01-1J-101-1-01_wp02
12,313.37
12,300.00
0.93
2.64
-1.78
FAI L - Minor 1 /10
1 J-10 - 1J-1 OLl-03 - 1 J-10L1-03_wp01
12,469.66
12,500.00
106.86
2.03
104.92
Pass - Minor 1/10
1 J-105-1J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105-1J-105L1-1J-105L1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1 J-105 -1J-1 051_2 - 1J-1 051_2
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1 J-105-1J-105PB1 - 1 J-105PB1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-107-1J-107 - iJ-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-107 - iJ-107L1 - 1 J-107L1
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1 J-109 - 1J-109 - 1 J-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109-1J-109PB1 - 1J-109PB1
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-115-1J-115 - 1 J-115
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1 J-115-1J-115L1 - 1 J-115L1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L1PB1-1J-115L1PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L1 PB2 - 1J-1151_1 PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L2 - 1J-1151_2
403.76
400,00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115L2PB1 - 1J-115L2PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:32:27PM . Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips
RAKER
ConocoPhillips
Travelling Cylinder Report
JUGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Reference Site:
Kuparuk 1J Pad
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-10L1-02
Database:
EDT 14 Alaska Production
Reference Design:
1J-101_1-02 wp01
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-115-1J-115L2PB2-1J-115L2PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB1-1J-115PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-11 5 - 1J-11 5PB2 - 1J-11 5PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB3 - 1J-115PB3
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
iJ-115 - 1J-115PB4 - 1 J-115PB4
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1 J-118 -1 J-118 - 1 J-118
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118L1 - 1 J-1181-1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118 - 1J-1181-2 - 1J-1181-2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118PB1-1J-118PB1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118P82 - 1J-118PB2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-120-1J-120 - iJ-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-120 - iJ-12OL1 - 1 J-120L1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
iJ-120-1J-120L1PB1 -1J-120LlPB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 PB2 - 1 J-120L1 P132
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-120 - 1J-120L1 PB3 - 1J-12OLl PB3
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-1201-1 PB4 - 1 J-1201-1 PB4
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-1201-2-1J-1201_2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L2PB1-1J-120L2PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-152 - 1J-152 - 1 J-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-1521-1-1J-152L1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1J-1521-2 - 1 J-1521-2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152L2PB1-1J-152L2PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1J-152PB1 - 1J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152PB2-1J-1521362
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1 J-154 - 1 J-154 - 1 J-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154-1J-1541-1-1J-1541-1
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154-1J-1541-2-1J-1541_2
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-156-1J-156 - 1 J-156
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-156L1-1J-1561-1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-iJ-156L1PB1 -iJ-156L1PB1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-iJ-1561_2-1J-1561_2
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-158-1J-158 - 1J-158
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158 - 1J-158L1 - 1J-158L1
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1 J-159 - 1J-159 - 1 J-159
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-159L1 - 1 J-1591-1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591-1 PB1 - 1J-159L1 PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591-1 PB2 - 1 J-1591-1 PB2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591-2 - 1 J-1591_2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159PB1-1J-159PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-160 -1 J-160 - 1 J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-1601-1-1J-16OLl
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160LIPB1 -iJ-160LiPB1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1 J-160 - iJ-1601-2 - 1 J-1601-2
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1 J-162 - 1 J-162 - 1 J-162
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - 1J-162L1 - 1 J-1621-1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-1621_1PB1-1J-162L11381
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162- 1J-162PB1 - 1J-162PB1
491.49
500.00
40.65
8.37
32.28
Pass- Major Risk
1J-162 - iJ-162PB2 - 1 J-162PB2
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-164-1J-164 - 1 J-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164-1J-164L1 - 1 J-164L1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-1641-2 - 1J-1641_2
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-1 64 - 1J-1 64L2PB1 - 1 J-1641_2PB1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-166 - 1J-166 - iJ-166
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
C(: - Min centre to center orstance or covergent point, SF - min separation factor, E5 - min ellipse separation
12/10/2018 4:32:27PM Page 3 COMPASS 5000.14 Build 85D
gy:
ConocoPhillips
I'Ad#ER
ConocoPhillips
Travelling Cylinder Report
UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupi
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
iJ-10:114.25 @ 114.25usft (1J-10:114.25)
Reference Site:
Kuparuk 1J Pad
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-10L1-02
Database:
EDT 14 Alaska Production
Reference Design:
1J-10L1-02 wp01
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-166-1J-166L1-1J-166L1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166L1 PB1 - 1 J-166L1 PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166L2 - 1J-1661-2
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166L2PB1 - 1 J-166L2PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1 J-168 -1 J-168 - 1 J-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - iJ-168L1 - 1 J-1681-1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L2 - 1 J-1681_2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L2PB1 - 1J-168L2PB1
404.72
400.00
161.98
6.61
155.38
Pass- Major Risk
1J-170 - 1J-170 - 1J-170
5,690.17
8,300.00
247.69
159.88
140.49
Pass - Major Risk
1J-170- 1J-1701-1 - 1J-1701-1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170-1J-170L2 - 1 J-1701-2
5,394.81
8,200.00
166.39
152.00
53.52
Pass - Major Risk
1J-170-iJ-170PB1-iJ-170PB1
5,676.40
8,300.00
273.16
159.57
164.32
Pass - Major Risk
1J-170 - 1J-170PB2 - 1J-170PB2
5,690.17
8,300.00
247.69
160.14
140.23
Pass - Major Risk
Plan 1 J-104 (empty) - Prelim: 1J-104 - Prelim: 1 J-
406.82
400.00
232.09
5.53
226.57
Pass - Major Risk
Plan 1 J-104 (empty) - Prelim: 1 J-104 L1 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L2 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-109a-1J-109PB1x-1J-109PB1x
114.25
33.25
177.64
1.02
176.62
Pass - Major Risk
W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15
487.50
500.00
209.67
9.95
199.72
Pass - Major Risk
W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2
396.03
400.00
184.70
5.72
178.98
Pass - Major Risk
W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20
810.09
800.00
83.61
17.14
66.47
Pass - Major Risk
W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3
503.17
500.00
184.73
11.21
173.52
Pass - Major Risk
W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4
491.49
500.00
196.71
7.54
189.18
Pass - Major Risk
W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5
486.33
500.00
231.04
10.16
220.89
Pass - Major Risk
Offset Design
Kuparuk 1 J Pad - 1J-03 - 1 J-03 - 1J-03
Offset site Error: 0,00 usft
Survey Program:
201-MWD+IFR-AK-SCC
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
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
+EI-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°)
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
114.25
114.25
116.12
116.12
0.00
0.00
46.71
110.69
117.51
8,875
161.44
0.74
160.70 Pass - Major Risk, CC, ES, SF
197.92
197.92
200.00
199.98
0.05
0.05
46.87
111.45
118.89
8.875
163.01
1.83
161.18 Pass - Major Risk
297.75
297.75
300.00
299.90
0.15
0.17
47.31
113.30
122.46
8.875
167.03
3.41
163.63 Pass - Major Risk
397.01
397.00
400.00
399.80
0.27
0.28
47.93
115.05
126.60
8.875
171.49
4.97
166.52 Pass - Major Risk
493.34
493.32
500.00
499.54
0.38
0.40
49.14
117.62
133.26
8.875
179.64
6.53
173.12 Pass - Major Risk
587.98
587.87
600.00
598.96
0.49
0.53
51.31
120.27
143.56
8.875
192.72
8.10
184.64 Pass - Major Risk
677.68
677.31
700.00
697.93
0.60
0.67
53.92
123.90
157.36
8.875
212.30
9.64
202.72 Pass - Major Risk
752.37
751.30
800.00
796.49
0.69
0.81
57.67
124.33
174.25
8.875
238.69
10.99
227.80 Pass - Major Risk
836.40
833.59
900.00
894.76
0.82
0.95
61.01
127.00
192.55
8.875
273.85
12.51
261.59 Pass - Major Risk
921.90
916.44
1,000.00
992.43
0.95
1.12
63.78
132.65
213.20
8.875
316.43
14.15
302.78 Pass - Major Risk
1,002.62
994.25
1,100.00
1,088.93
1.08
1.34
66.04
141.43
237.88
8.875
365.16
15.84
350.18 Pass - Major Risk
1,072.17
1,060.68
1,200.00
1,183.97
1.21
1.59
67.68
153.99
266.27
8.875
420.60
17.51
404.45 Pass - Major Risk
1.128.96
1,114.17
1,300.00
1,276.57
1.32
1.90
68.70
171.29
299.72
8.875
484.87
19.14
467.71 Pass - Major Risk
1,186.86
1,168.03
1,400.00
1,365.40-
1.45
2.28
69.33
193.00
340.12
8.875
557.89
21.02
539.71 Pass - Major Risk
1,236.53
1,213.77
1,500.00
1,451.11
1.57
2.72
69.75
218.16
385.04
8.875
636.46
22.91
617.42 Pass - Major Risk
1.280.95
1,254.20
1,600.00
1,533.47
1.68
3.22
70.28
245.70
434.57
8.875
719.64
24.83
699.84 Pass - Major Risk
1,316.75
1,286.41
1,700.00
1,611.71
1.76
3.77
70.68
275.94
488.99
8.875
807.16
26.73
786.71 Pass - Major Risk
1,350.74
1.316.67
1,800.00
1,686.35
1.86
4.37
70.91
308.71
546.89
8.875
897,66
28.75
876.61 Pass - Major Risk
1,377.15
1,339.96
1,900.00
1.756.58
1.93
5.02
71,00
343.98
608.70
8.875
990.96
30.74
969.42 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:32:27PM . Page 4 COMPASS 5000.14 Build 85D
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—ConecaPhNflps Carnpany
Kuparuk River Unit
Kuparuk IJ Pad
ii-10
IJ=IOLI-03
Plan: IJ-101-1-03—wp01
Standard Planning Report
17 December, 2018
ER BTGHES
I0
GE comDanv
ConocoPhillips
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1J-10
Welibore:
1 J-10L1-03
Design:
1 J-10L1-03_wp01
ConocoPhillips 11A_ <ER
Planning Report t�UGHES
a GE company
Local Co-ordinate Reference: Well 1 J-10
TVD Reference: Mean Sea Level
MD Reference: 1J-10:114.25 @ 114.25usft (1J-10:114.25)
North Reference: True
Survey Calculation Method: Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kuparuk 1J Pad
Site Position: Northing: 5,945,919.64usft Latitude: 70' 15' 46.258 N
From: Map Easting: 558,789.95 usft Longitude: 149° 31' 29.007 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.45 °
Well 1 J-10
Well Position +N/-S 0.00 usft Northing: 5,945,808.06 usft Latitude: 70' 15' 45.169 N
+E/-W 0.00 usft Easting: 558,673.32 usft Longitude: 149' 31' 32.426 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1J-101-1-03
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(I (°) (nT)
BGGM2018 2/1/2019 16.77 80.84 57,424
Design 1J-101-1-03_wp01
Audit Notes:
Version: Phase: PLAN Tie On Depth: 12,150.00
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
(usft) (usft) (usft) (I
0.00 0.00 0.00 90.00
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°/100usft)
(°/100usft)
(°/100usft)
(°) Target
12,150.00
88.46
132.46
6,041.11
2,873.09
-5,945.19
0.00
0.00
0.00
0.00
12,250.00
94.52
128.96
6,038.51
2,807.93
-5,869.47
7.00
6.06
-3.50
330.00
12,500.00
83.25
115.55
6.043.40
2,675.00
-5,658.94
7.00
-4.51
-5.37
230.00
12,800.00
84.41
94.46
6,076.01
2,598.30
-5,372.49
7.00
0.39
-7.03
272.00
13,200.00
89.72
66.92
6,096.86
2,662.53
-4,982.26
7.00
1.33
-6.88
280.00
13,600.00
89.76
94.92
6,098.71
2,725.05
-4,591.20
7.00
0.01
7.00
90.00
13,850.00
91.27
77.48
6,096.45
2,741.54
-4,342.73
7.00
0.61
-6.97
275.00
14,100.00
92.71
94.93
6,087.70
2,758.02
-4,094.40
7.00
0.58
6.98
85.00
1211712018 10:45:29AM I Page 2 . COMPASS 5000.14 Build 85D
conocophi91ops
ConocoPhillips Planning Report f UGHES
a GE mrnpany
Database:
EDT 14 Alaska Production
Local Co-ordinate Reference:
Well 1J-10
Company:
_ConocoPhillips Export Company
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Site:
Kuparuk I Pad
North Reference:
True
Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 J-10L1-03
Design:
1J-10L1-03 wp01
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(°)
(usft)
(usft)
12,150.00
88.46
132.46
6,041.11
2,873.09
-5,945.19
-5,945.19
0.00
0.00
5,948,634.47
552,706.49
TIPIKOP
12,200.00
91.49
130.71
6,041.13
2,839.91
-5,907.80
-5,907.80
7.00
-30.00
5,948,601.58
552,744.14
12,250.00
94.52
128.96
6,038.51
2,807.93
-5,869.47
-5,869.47
7.00
-30.00
5,948,569.90
552,782.71
Start 7 dls
12,300.00
92.26
126.28
6,035.56
2,777.47
-5,829.94
-5,829.94
7.00
-130.00
5,948,539.75
552,822.48
12,400.00
87.75
120.93
6,035.55
2,722.16
-5,746.70
-5,746.70
7.00
-130.16
5,948,485.10
552,906.13
12,500.00
83.25
115.55
6,043.40
2,675.00
-5,658.94
-5,658.94
7.00
-130.16
5,948,438.64
552,994.25
3
12,600.00
83.54
108.51
6,054.92
2,637.77
-5,566.91
-5,566.91
7.00
-88.00
5,948,402.13
553,086.56
12,700.00
83.93
101.48
6,065.84
2,612.08
-5,470.95
-5,470.95
7.00
-87.19
5,948,377.18
553,182.71
12,800.00
84.41
94.46
6,076.01
2,598.30
-5,372.49
-5,372.49
7.00
-86.42
5,948,364.18
553,281.26
4
12,900.00
85.67
87.54
6,084.66
2,596.57
-5,272.95
-5,272.95
7.00
-80.00
5,948,363.22
553,380.81
13,000.00
86.98
80.65
6,091.08
2,606.83
-5,173.74
-5,173.74
7.00
-79.40
5,948,374.25
553,479.92
13,100.00
88.34
73.78
6,095.17
2,628.93
-5,076.36
-5,076.36
7.00
-78.96
5,948,397.10
553,577.11
13,200.00
89.72
66.92
6,096.86
2,662.53
-4,982.26
-4,982.26
7.00
-78.68
5,948,431.44
553,670.94
5
13,300.00
89.73
73.92
6,097.34
2,696.03
-4,888.10
-4,888.10
7.00
90.00
5,948,465.66
553,764.83
13,400.00
89.73
80.92
6,097.81
2,717.80
-4,790.57
-4,790.57
7.00
89.97
5,948,488.19
553,862.18
13,500.00
89.74
87.92
6,098.27
2,727.52
-4,691.11
-4,691.11
7.00
89.93
5,948,498.68
553,961.56
13,600.00
89.76
94.92
6,098,71
2,725.05
-4,591.20
-4,591.20
7.00
89.90
5,948,496.99
554,061.47
6
13,700.00
90.37
87.94
6,098.60
2,722.55
-4,491.29
-4,491.29
7.00
-85.00
5,948,495.27
554,161.38
13,800.00
90.97
80.97
6,097.43
2,732.20
-4,391.83
-4,391.83
7.00
-85.01
5,948,505.70
554,260.76
13,850.00
91.27
77.48
6,096.45
2,741.54
-4,342.73
-4,342.73
7.00
-85.09
5,948,515.42
554,309.78
7
13,900.00
91.57
80.97
6,095.21
2,750.89
-4,293.63
-4,293.63
7.00
85.00
5,948,525.15
554,358.80
14,000.00
92.16
87.95
6,091.95
2,760.53
-4,194.21
-4,194.21
7.00
85.09
5,948,535.56
554,458.13
14,100.00
92.71
94.93
6,087.70
2,758.02
-4,094.40
-4,094.40
7.00
85.31
5,948,533.83
554,557.95
Planned TD at 14100.00
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
14,100.00 6,087.70 2 3/8" 2.375 3.000
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+Nl-S
+E/-W
(usft)
(usft)
(usft)
(usft)
Comment
12,150.00
6,041.11
2,873.09
-5,945.19
TIP/KOP
12,250.00
6,038.51
2,807.93
-5,869.47
Start 7 dIs
12,500.00
6,043.40
2,675.00
-5,658.94
3
12,800.00
6,076.01
2,598.30
-5,372.49
4
13,200.00
6,096.86
2,662.53
-4,982.26
5
13,600.00
6,098.71
2,725.05
-4,591.20
6
13,850.00
6,096.45
2,741.54
-4,342.73
7
14,100.00
6,087.70
2,758.02
-4,094.40
Planned TD at 14100.00
1211712018 10:45.29AM Page,3 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips l
p' •
Kuparuk River Unit
Kuparuk 1J Pad
IJ®10
IJ-IOLI-03_wpOl
Travelling Cylinder Report
10 December, 2018
BER
BA 0
GE company
ConocoPhillips BA, �(ER
ConocoPhillips Travelling Cylinder Report T]UGHES
a GEcompany
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
1J-10
Well Error:
0.00 usft
Reference Wellbore
1J-101-1-03
Reference Design:
1J-10L1-03_wp01
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1J-10
1J-10:114.25 @ 114.25usft (1J-10:114.25)
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference
1J-10L1-03_wp01
=ilter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
nterpolation Method:
MD Interval 100.00usft Error Model: ISCWSA
)epth Range:
Unlimited Scan Method: Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,598.58 usft Error Surface: Pedal Curve
Survey Tool Program
Date 12/10/2018
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
205.18
10,166.00 1J-10 (1J-10)
MWD+IFR-AK-CAZ-SC
MWD+IFRAK CAZ SCC
10,166.00
10,420.00 1J-10L1_wp01 (1J-101-1)
MWD
MWD- Standard
10,420.00
12,150.00 iJ-101-1-01_wp01 (1J-1011-01)
MWD
MWD- Standard
12,150.00
14,100.00 1J-10L1-03_wp01 (1J-101-1-03)
MWD
MWD- Standard
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
6,936.54
3,991.30 9 5/8"
9.625
12.250
10,142.96
5.891.30 7"
7.000
8.500
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 1E Pad
1E-35- Plan 1E-35A-1E-35A(wp02)
14,100.00
12,900.00
1,404.59
311.20
1,124.72
Pass - Major Risk
Kuparuk 1J Pad
1J-03 -I J-03 - 1J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1J-03 - 1J-031_1 - 1J-03L1
114.25
116.00
161.44
1.02
160.41
Pass- Major Risk
1J-03 - 1J-031_2 - 1J-03L2
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03 - lJ-03L2PB1 - lJ-03L2PB1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-09 - 1J-09 - 1J-09
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09 - 1J-09A - 1 J-09A
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09 - iJ-09AL1 - 1J-09AL1
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
11-10 - 1J-10 - 11-10
10,488.86
10,500.00
29.34
13.60
20.73
Pass - Major Risk
1J-10 - 1J-101_1 - 1J-10L1_wp01
Out of range
1J-10 - 1J-10L1-01 - 1J-10L1-0l_wp02
11,100.00
11,100.00
0.00
2.65
-0.45
FAIL -Minor 1/10
1J-10 - 1J-10L1-02 - 1 J-10L1-02_wp01
12,470.52
12,500.00
106.97
2.12
104.89
Pass - Minor ill
1 J-105 - 1 J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-105L1 - lJ-105L1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-105L2 - 1 J-10512
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
iJ-105 - 1J-105PB1 - 1 J-105PB1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1 J-107 - 1J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1 J-107 - 1 J-107L1 - 1 J-1071_1
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1 J-109 - 1 J-109 - 1 J-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109 - 1J-109PB1 - 1 J-109PB1
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-115 - 1J-115 - iJ-115
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151-1 - 1J-115L1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151_1 PB1 - 1J-1151_1 PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-1151-1 PB2 - 1J-1151_1 PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:38:58PM Page 2 COMPASS 5000.14 Build 85D
'W" ConocoPhillips SA_ i(ER
ConocoPhillips Travelling Cylinder Report UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (lJ-10:114.25)
Reference Site:
Kuparuk I Pad
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Site Error.
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-101-1-03
Database:
EDT 14 Alaska Production
Reference Design:
iJ-101-1-03 wp01
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-115 - 1J-1151-2 - 1J-115L2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L2P131-1J-115L2PB1
403.76
400.00
159.15
6.67
152,48
Pass - Major Risk
1J-11 5 - 1J-11 5L2PB2 - 1J-11 5L2PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115PB1 - 1 J-115PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-11 5 - 1J-11 5PB2 - 1J-11 5PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB3 - 1 J-115PB3
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115PB4 - 1 J-115PB4
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-118 - 1J-118 - 1J-118
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118-1J-118L1 - 1J-118L1
304.63
300.00
189.29
4.81
184.48
Pass- Major Risk
1J-118-1J-1181_2-1J-1181_2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118- 1J-118P131 - iJ-118PB1
304.63
300.00
189.29
4.81
184.48
Pass- Major Risk
1J-118-1J-118PB2 - 1 J-118PB2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-120-1J-120 - 1 J-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 - 1 J-1201-1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120LlPB1-1J-120L1PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 PB2 - 1J-1201-1 P132
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 P133 - 1J-120L1 PB3
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1 P64 - 1 J-1201-1 PB4
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-1201-2 - 1 J-120L2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-1 20 - 1J-120L2PB1 - 1J-1 20L2PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-152-1J-152 - 1J-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152L1 - 1 J-152L1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1J-1521-2 - 1J-152L2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152- iJ-152L2PB1 - 1J-152L2PB1
405.78
400.00
200.32
6.58
193.74
Pass- Major Risk
1J-152-1J-152PB1-1J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1 J-152-1J-152PB2 - 1 J-152PB2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1 J-154 -1 J-154 - 1 J-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154 - 1J-1541-1 - 1 J-154L1
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154 - iJA 54L2 - 1 J-1541-2
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-156-1J-156 - 1J-156
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561-1-1J-156L1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561-1PB1-1J-1561-113131
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-iJA56L2-iJ-156L2
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-158 - iJ-158 - 1J-158
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158 - 1J-158L1 - 1 J-158L1
392,81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-159-1J-159 - 1J-159
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1-1J-159L1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1 P131 - 1J-1591-1 P131
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1 P132 - 1J-159L1 PB2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L2 - 1 J-159L2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159PB1-1J-159PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-160 -1 J-160 - 1 J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160L1 - 1 J-160L1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160L1PB1-1J-160L1P131
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-160L2 - iJ-160L2
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1 J-162 -1 J-162 - 1 J-162
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162L1 - 1 J-162L1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-iJ-162LIP131-1J-162L1P131
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-iJ-162PB1-1J-162PB1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - 1J-162PB2 - 1 J-162PB2
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1 J-164 - 1 J-164 - 1 J-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-164L1 - 1 J-164L1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-164 -1 J-164L2 - 1 J-164L2
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:38:58PM Page 3 COMPASS 5000.14 Build 85D
IV-,
ConocoPhillips
BA
(ER
ConocoPhillips
Travelling Cylinder Report
UGHES
a GEcompany
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1J-10
Project:
Kuparuk River Unit
TVD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Reference Site;
Kuparuk 1J Pad
MD Reference:
1J-10:114.25 @ 114.25usft (1J-10:114.25)
Site Error:
0.00 usft
North Reference:
True
Reference Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1J-10L1-03
Database:
EDT 14 Alaska Production
Reference Design:
1J-101_1-03_wp01
Offset TVD Reference:
Offset Datum
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 1J Pad
1J-164-1J-164L2PB1-1J-164L2PB1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-166 - 1 J-166 - 1 J-166
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-1661-1-1J-166L1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-1661-1 PB1 - 1J-1661-1 PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - iJ-1661-2 - 1 J-166L2
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1J-166L2PB1 - 1J-166L2PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-168 - 1J-168 - 1J-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-1681-1 - 1J-168L1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1 J-168 - 1 J-16812 - 1 J-1681-2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L2PB1 - 1J-168L2PB1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-170 - iJ-170 - 1J-170
5,690.17
8,300.00
247.69
159.88
140.49
Pass - Major Risk
1J-170-1J-170L1-1J-170L1
5,566.22
8,300.00
182.48
156.25
55.71
Pass - Major Risk
1J-170-1J-1701-2-iJ-1701-2
5,394.81
8,200.00
166.39
152.00
53.52
Pass - Major Risk
1J-170 - iJ-170PB1 - 1J-170PB1
5,676.40
8,300.00
273.16
159.57
164.32
Pass - Major Risk
1J-170 - 1J-170PB2 - 1 J-170PB2
5,690.17
8,300.00
247.69
160.14
140.23
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 - Prelim: 1J-
406.82
400.00
232.09
5.53
226.57
Pass - Major Risk
Plan 1 J-104 (empty) - Prelim: 1 J-104 L1 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-104 (empty) - Prelim: 1J-104 L2 - Prelim:
406.82
400.00
232.07
5.53
226.54
Pass - Major Risk
Plan 1J-109a - 1J-109PB1x- 1J-109PB1x
114.25
33.25
177.64
1.02
176.62
Pass- Major Risk
W SAK PLT 15 - W SAK PLT 15 - W SAK PLT 15
487.50
500.00
209.67
9.95
199.72
Pass - Major Risk
W SAK PLT 2 - W SAK PLT 2 - W SAK PLT 2
396.03
400.00
184.70
5.72
178.98
Pass - Major Risk
W SAK PLT 20 - W SAK PLT 20 - W SAK PLT 20
810.09
800.00
83.61
17.14
66.47
Pass - Major Risk
W SAK PLT 3 - W SAK PLT 3 - W SAK PLT 3
503.17
500.00
184.73
11.21
173.52
Pass - Major Risk
W SAK PLT 4 - W SAK PLT 4 - W SAK PLT 4
491.49
500.00
196.71
7.54
189.18
Pass - Major Risk
W SAK PLT 5 - W SAK PLT 5 - W SAK PLT 5
486.33
500.00
231.04
10.16
220.89
Pass - Major Risk
Offset Design
Kuparuk 1 E Pad - 1 E-35 - Plan 1 E-35A - 1 E-35A (wp02)
Offset Site Error. 0,00 usft
Survey Program: 199-GYD-CT-CMS,
6963-MWD
Rule Assigned: Major Risk
Offset Well Error: 0.00 usft
Reference
Offset
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
+NIS
+EI-W
Hole Size
Centre
Distance
Deviation
(usft) (usft)
(usft)
(usft) (usft)
(usft)
(°I
(usft)
(usft)
(m)
(usft)
(usft)
(usft)
14,050.00 6,204.19
12,700.00
5,530.87 47.35
95.62
26.57
4,189.59
-4,119.88
7.750
1,578.47
290.32
1,310.12 Pass - Major Risk
14,074.47 6,203.12
12,800.00
5,557.65 47.51
97.09
28.71
4,104.46
.4,074.77
7.750
1,490.99
300.58
1,217.02 Pass -Major Risk
14,100.00 6.201.95
12,900.00
5,584.43 47.68
98.57
30.95
4,019.32
-4,029.66
7.750
1,404.59
311.20
IJ24.72 Pass- Major Risk, CC, ES, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
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✓ A-' KUP PROD 1J-10
ConocoPhlllips I A,
Well Attributes
Max Angle & MD TD
Alaska,hic.
Wellbore APIIUWI Field Name Weilb",Status
500292301000 KUPARUK RIVER UNIT PROD
ncl(°) MO(ftKB) Act
67.58 3,101.64
etm(ftKB)
10,845.0
Comment H2S (ppm) Date
SSSV: NIPPLE 40 9/10/2016
Annotation End Date
Last WO: 2/8/2008
KB-Grd (fry Rig Release Date
35.74 5/24/2001
1 J.10, 3W201710:46:16 AM
Vertical sc1hemalic(aclua8
Annotation Depth (ftKB) End Data
Annotation Last Mod By Entl Date
Last Tag: RKB 10,348.0 3127/2/117
Rev Reason: TAG, GLV C/O, H2S pproven 3/31/2077
HANGER; 29.6
Casing Strings
Casing Description
OD (in) ID (In)
Top (ftKB)
Set Depth (RKB)
Set Depth (ND)...
WtlLen (I...
Grade
Top Thread
CONDUCTOR
20
19.124
35.0
120.0
120.0
91.50
H-40
WELDED
Casing Description
OD (in) ID (in)
Top (PIKE)
Set Depth (ftKB)
Set Depth (TVD)...
WtlLen (1...
Grade
Top Thread
.........-..-....___._......_......_...._..............
. • ... .....,.
SURFACE
9 518
8.835
34.5
6.945.3
3,995.4
40.00
L-80
BTC
Casing Description
OD (in) ID (in)
Top (RKB)
Set Depth (RKB)
Set Depth (TVD)...
WtlLen (I...
Grade
Top Thread
PRODUCTION
7
6.276
31.7
10,230.8
5,944A
26.00
L-80
BTC-MOD
Casing Description
0o (in) ID (in)
Top (flKB)
Set Depth (RKB)
Set Depth (TVD)...
WtlLen (L..
Grade
Top Thread
LINER
41/2
3.958
9,967.2
10,843.0
6,324.7
12.60
L-80
NSCT
Liner Details
CONDUOT&; 35.0-120O
Top.(ftKe)
Top (TVD) (RKB) Top Incl
(°)
Item Des
Com
Nominal ID
(in)
9,967.2
5.787.0
53.74
TIE BACK
BAKER PACKER & TIE -BACK SLEEVE
4.438
9,985.2
5,797.E
53.67
PACKER
BAKER ZXP LINER TOP PACKER
4.438
NIPPLE; Who
9,989.2
5,800.0 53.66
HANGER
BAKER LINER HANGER
4.500
10,327.7
6,001.7 53.86
NIPPLE
CAMCO'D'NIPPLE- DRILLED OUT TO 3.87"
3.830
DURING ATTEMPT TO PULL FISH 2/8/2008
WORKOVER
10,520.7
6,118.5 51.81
NIPPLE
OTIS'XN' NIPPLE W/ No Go, 3.812" PKG BORE,
3,725
GAS LIFT; 3,723.8
3.725" profile
Tubing Strings
Tubing Description String Ma... ID (in) Top (RKB) Set Depth (ft.. Set Depth (ND) (... Wt (Ib/fq Grade Top Connection
TUBING 41/2 3.958 29.E 9,991.7 5,801.5 12.60 L-80 IBT
GAS LIFT; 6,311.7
Completion Details
Top (RKB)
Top (ND) (ftKB)
Top Intl
(°) Item Des
Com
Nominal lD
(inj
29.6
29.6
0.01
HANGER
FMC GEN V TUBING HANGER
4,500
508.0
508.0
1.97
NIPPLE
CAMCO DB-6 NIPPLE w/ 3.875 TOP NO GO PROFILE
3.875
9,933.4
5,767.0
53.86
NIPPLE
CAMCO DB NIPPLE w/ 3.812 PROFILE - DRILLED OUT
3.830
TO 3.87 DURING ATTEMPT TO PULL FISH 2/8/2008
WORKOVER
SURFACE; 34.5-6,945.3-
9978.7
5,793.8
53.70
LOCATOR
BAKER GBH-22 LOCATOR
3.958
9,979.9
6,194.5
53.69
1 SEAL ASSY
BAKER SEALASSEMBLY w/MULESHOE
3.958
GAS LIFT:8,o68.2
Other In Hole (Wire{ine-retrievable plugs, valves, pumps, fish, etc.) - -
Top TVD)
Top Intl
Top(ftKB)
(RKB)
(°) Des
Com
Run Date
ID (in)
10,400.0
6,044.8
52.94 FISH
PERF GUN PERF GUN DROPPED 7/24/01, TOP 3/17/2008
10,532', LENGTH 34.4', MAX OD 3.63"; WORKED
TO RETRIEVE THRU 8129/01. WELL SHUT IN &
GAS LIFT; 9,132.E
FREEZE PROTECTED. 36" BAT SUB LEFT ON
TOP OF E-LINE TOOL
10/25/2004: Fish Pulled up tol0,312' CTMD
6/7/2005: Tagged Fish @ 10339' RKB
1/19/2008 Tagged Fish @ 10301' SUM
2/8/2008 WORKOVER TO PULL FISH - ONLY
GAS LIFT; 9,882.2
PUSHED IT DOWNHOLE FROM 10312' TO 10400'
Perforations & Slots
Shot
Dens
NIPPLE 9,933.4
Top (RKB)
Bt. (RKB)
Top (TVD)
(RKB)
Bt. (TVD)
(RKB)
Zone
(shoWf
Date
t)
Type
Com
10,446.0
10,466.0
6,072.7
6,084.9 C-3,
1J-10
7119/2001
6.0 APERF
3
3/8" PSD PJ chgs, 60
deg
ph
10,658.0
10,678.0
6.205.0
6,217.8 A-5,
1J-10
6/12/2001
6.0 IPERF
2.5"
HSD BH & DP
Stimulations & Treatments
Proppant Designed (lb) Proppant In Formation (Ib) Data
LOCATOR; 9,978.7
6/16/2001
Stimulations & Treatments
SEAL ASSY; 9,979.9
Vol Clean Pump
Sig #
Top (ftK6)
St. (ftKBJ
Date
Stim/Treat Fluid
(b60 Vol
Slurry (bbi)
11
10,558.01
10,678.0 6/16/2001
Mandrel Inserts
St
ati
N Top (RKB)
Top(TVD)
(RKB)
Make
Model
OD (in)
Se,
Valve
Type
Latch
Type
PortSize
(in)
TRORun
(psi)
Run Data
Co.
1 3.723.8
2,558.4
CAMCO
KBG-2
1 GAS
LIFT
GLV
BK
0.188
1.149.0
3/29/2017
4:30
PRODUCTION; 31.7-10.230.8
2 6,311.7
3,723.0
CAMCO
KBG-2
1 GAS
LIFT
OV
BK
0.250
0.0
3/29/2017
7:30
3 8,068.2
4,627.0
CAMCO
KBG-2
1 GAS
LIFT
DMY
BK
0.000
0.0
3/29/2017
5:00
4 9,132.6
5,283.0
CAMCO
KBG-2
1 GAS
LIFT
DMY
BK
0.000
0.0
5/23/2001
4:15 -
5 9,882.2
51736.8
CAMCO
KBG-2
1 GAS
LIFT
DMY
BK
0.000
0-0
2/9/2014
7:00
Notes: General & Safety
End Data
Annotation
2/8/2008
NOTE: WORKOVER DONE TO PULL FISH, MILLED NIPPLES; UNSUCCESSFUL, PUSHED FISH
FISH; 10,400.0
DOWNHOLE
9/29/2010
NOTE: View Schematic w/ Alaska Schematic9.0
APERF; 10,446.0.10,466.0
IPERF; 10,658.0-10,6700, FRAC: 10,658.0
LINER; 9,967.2-10,a43.0
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From: McLaughlin Ryan
To: Boyer, David L (DOA)
Cc: Loepp, Victoria T (DOA)
Subject: RE: [EXTERNAL] Digital Survey Files for Four 11-10 Laterals
Date: Thursday, January 31, 2019 4:48:46 PM
Hello Dave,
Here is the corrected government section data:
KRU 1J-101-1:
Top of Productive Interval: 4931' FNL, 4064' FEL, Sec 27, T11N, R10E, UM
Total Depth: 4871' FNL, 4211' FEL, Sec 27, T11N, R10E, UM
KRU 1J-101-1-01:
Top of Productive Interval: 4896' FNL, 4149' FEL, Sec 27, T11N, R10E, UM
Total Depth: 1946' FNL, 600' FEL, Sec 34, T11N, R10E, UM
KRU 1J-101-1-02:
Top of Productive Interval: 523' FNL, 3098' FEL, Sec 34, T11N, R10E, UM
Total Depth: 2911' FNL, 2931' FEL, Sec 34, T11N, R10E, UM
KRU 1J-101-1-03:
Top of Productive Interval: 412' FNL, 3198' FEL, Sec 34, T11N, R10E, UM
Total Depth: 526' FNL, 1348' FEL, Sec 34, T11N, R10E, UM
Regards,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office:907-265-6218 Cell:907-444-7886
700 G St, ATO 670, Anchorage, AK 99501
From: Boyer, David L (DOA) <david.boyer2@alaska.gov>
Sent: Thursday, January 31, 2019 4:08 PM
To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals
Rya n,
In looking through the PTD's, I noticed that all four have the same Top of Productive Horizon and
Total Depth in the legal description in Part 4A on Form 10-401. Please send over the corrected
government section data, and I will make the adjustments on the forms. I assume that the legal
description is correct for the first lateral: KRU 1J-101-1 but not for the -01, -02, and -03 laterals?
Thank you,
Dave Boyer
AOGCC
From: McLaughlin, Ryan <Ryan.McLaughlin(a%conocophillics.com>
Sent: Thursday, January 31, 2019 11:53 AM
To: Boyer, David L (DOA) <david. boyer2@aIaskajoov>
Subject: RE: [EXTERNAL] Digital Survey Files for Four 1J-10 Laterals
Hello Dave,
I've attached .txt files for the 1J-10 laterals. Your assumption about our drill order is correct, we are
currently planning on drilling 1J-10 before 3M-26.
Regards,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office:907-265-6218 Cell:907-444-7886
700 G St, ATO 670, Anchorage, AK 99501
From: Boyer, David L (DOA) <david.boyer2(ci)a1asl<a.gov>
Sent: Thursday, January 31, 2019 10:13 AM
To: McLaughlin, Ryan <Ryan. AcLaughlim coconoconhiilips.com>
Subject: [EXTERNAL] Digital Survey Files for Four 11-10 Laterals
Hi Ryan,
I just began reviewing the 4 PTD's for the KRU 1J-10 laterals today. Can you please e-mail over
digital surveys for the four laterals in Excel or ASCII format so we can load them into Geographics
Wellbase program? Also, it would save splicing time if the survey files also include those from the
original mother -bore above the—10,310' KOP's.
We also received two PTD's applications from Keith Herring for 2 KRU 3-26 laterals also to be drilled
with CDR3-AC rig with the same 02/13/19 spud date.. We are assuming your 1J-10 laterals will be
drilled first since the PTD files arrived several days earlier?
Thank you,
Dave Boyer
Senior Geologist
AOGCC
TRANSMITTAL LETTER CHECKLIST
WELL NAME: l(R Ck i T- (0 i-I -C
PTD:
z
11
Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: Ku -Auto k, _- R Iyp k— POOL: k�(�u_�G ✓2i— 0 I I
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. :a C ( _ 0 �{ , API No. 50- OZ9 - k3060 - 00 - 00
V
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- -� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC .25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
-
- Well Name: KUPARUK RIV UNIT 1J-1101-1-03 _ Program DEV Well bore seg
PTD#: 2190150
Company CONOCOPHILLIPS ALASKA INC. _- - _ Initial Class/Type
DEV / PEND GeoArea 890 _ Unit _1_1160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached
NA
2
Lease number appropriate
Yes
3
Unique well -name and number
Yes
4
Well located in a -defined pool-
Yes -
5
Well located proper distance from drilling unit boundary- -
Yes
6
Well located proper distance from other wells
Yes
7
Sufficient acreage available in drilling unit - - -
Yes
8
If deviated, is wellbore plat included
No
No land plat. Directional plan view & cross-section view included.
9
Operator only affected party
Yes
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
DLB 2/4/2019
14
Well located within area and strata authorized by Injection Order # (put 10# incomments)(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 AS31.05.030(j.1.A),(j.2.A-D)
NA
18
Conductor string provided
NA
Conductor set -for -KRU- 1-J-10-
Engineering
19
Surface casing -protects all -known USDWs
NA-
Surface casing set in KRU 1J-10
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 uncemented 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 complet; no major risk failures
127
If-diverter required, does it meet regulations
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate -
Yes
Max formation pressure is 2914 psig(9.2 ppg EMW ); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD
VTL 2/5/2019
29
BOPEs,-do they meet- regulation
Yes
30
BOPE-press rating appropriate; test to -(put psig in comments)
Yes
MPSP is 2315 psig; will test BOPs to 3500 psig
31
Chokemanifoldcomplies w/API-RP-53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of 112S gas- probable
Yes
112S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA
135
Permit can be issued w/o hydrogen sulfide measures - - - -
No
Wells on-1J-Pad are H2S-bearing. 112S-measures required.
Geology
36
Data presented on potential overpressure zones -
Yes
Appr Date
37
Seismic analysis of shallow gas zones
NA
DLB 2/4/2019
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports [exploratory only] -
NA
Geologic Engineering Public
Commissioner: Date: Co missioner: Date Commissioner Date
