Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout219-014Winston, 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 1.1 Laterals: Expired Permits
Hi Ryan,
The following three permits to drill have expired under regulation 20 AAC 25.005 (g). 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-10L1-02 (issued to CPAI February 5th 2019)
• KRU 1J-101-1-03 (issued to CPAI February 5th 2019)
Please let me know if you have any questions. Thanks
Statistical Technician
Alaska Oil and Gas Conservation Commission
huffh.winston@alaska.gov
907-793-1241
1
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
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 J-1 OL 1-02
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 219-014
Surface Location: 1996' FSL, 2536' FEL, SEC. 35, T11N, RIOE, UM
Bottomhole Location: 2911' FNL, 2931' FEL, SEC. 34, Tl IN, RIOE, 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
c��
DATED this C day of February, 2019.
EIVEf .
STATE OF ALASKA
AL.,. -.,A OIL AND GAS CONSERVATION COMMI__.ON
PERMIT TO DRILL
20 AAC 25.005
JAN 7 5 2019
1 a. Type of Work:
Drill ❑ Lateral ❑✓
Redrill ❑ Reentry ❑
1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development - Oil ❑✓ Service - Winj ❑ Single Zone M
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1 c. Specify if well is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket ❑� Single Well ❑
Bond No. 5952180
11. Well Name and Number: ,
KRU 1J-101_1-02
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth: -rVD:6'(*-7,
MD: 14,775' (/ TVD 5S; 6028'
12. Field/Pool(s):
Kuparuk River Field /
Kuparuk River Oil Pool '
4a. Location of Well (Governmental Section):
Surface: 1996' FSL, 2536' FEL, Sec 35, T11 N, R10E, UM
Top of Produc oriL41
z'��L,�o48 FE(-,5+2c34,,RI�
=r�e�—rra�-3Ty'7 Grt/C�Jq;TI IP R!4E, W P- ur}
Total p : Zq 111 ` FNL Z Q31 �FEL, S-e.c. 3 4- T It
U '
7. Property Designation: �/�. 8_ vHV'sT
ADL 25660
8. DNR Approval Number: �,`,13
LONS 83-137 aka! {
13. Approximate Spud Date:
2/13/2019
9. Acres in Property:
2560
14. Distance to Nearest Property:
7620'
4b. Locatioh of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 558673 y- 5945808 Zone- 4
10. KB Elevation above MSL (ft): 114'
GL / BF Elevation above MSL (ft): 79'
15. Distance to Nearest Well Open
to Same Pool: 2706' (1 E-117)
16. Deviated wells: Kickoff depth: 12,300 feet
Maximum Hole Angle: 92 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
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
2625'
12,150'
6041'
14,775'
6028'
Slotted
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
10,845'
Total Depth TVD (ft):
6326'
Plugs (measured):
N/A
Effect. Depth MD (ft):
10,843'
Effect. Depth TVD (ft):
6324'
Junk (measured):
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
20. Attachments: Property Plat ❑ BOP Sketch
Diverter Sketch
Drilling Program
B Seabed Report
Time v. Depth Plot
e Drilling Fluid Program
Shallow Hazard Analysis
e✓ 20 AAC 25.050 requirementsB✓
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. CLaUhlln c0 .com
Authorized Title: Staff CTD gineer Contact Phone: 907-265-6218
Authorized Signature: Date: // */' /
Commission Use Only
Permit to Drill
Number: la (� ��'
API Number: Permit
50- OZ — t7 Q — 6' 01l -- 00 Date:
Approval
��
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: ,&,), tt5 f I—v 35G 0 Samples req'd: Yes ❑ No [�J' Mud log req'd: Yes ❑ No []'
✓ D Z 5-0/9 measures: Yes [Y No ❑ Directional svy req'd: Yes Y No ❑
a �� 2 G/ 6 Spacing exception req'd: Yes El No W Inclination -only svy req'd: Yes ❑ No [�
,IfI�G� ryGl y'JC'G JJ Post initial injection MIT req'd: Yes ElNo [J'
/5 Gjrcr�ftG' ccllGrc, fl�tG /��C�v tj�tr�t 7�� b� �tr�y�rJln� a/&-),7% �
APPROVED BY 2 / S�/ /7/
Approved by: COMMISSIONER THE COMMISSION Date:P ( J
ICorm 10-401 Revised 5/2017 This permit is valid for 24 months
' &RI-GiNvAel-2o
Submit Fore and
AAC 25.005(g) Attach ents in Duplicate
71,t.6. 0200)411d
ConocoPhillips
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-
10L1, 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-1OL1-02 and 1J-101_1-03
— Detailed Summary of Operations
— Directional Plans for 1J-101-1, 1J-101-1-01, 1J-10L1-02 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 CT® Laterals
1J-10L1, 1J-10L1-01, 1J-101-1-025 & 1J-101-1-03
Application for Permit to Drill Document
1.
Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(o and 20 AAC 25.005(b))...................................................................................................................
2
2.
Location Summary..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................
2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................
2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................
2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................
3
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................
3
9.
Abnormally Pressured Formation Information.............................................................................
4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................
4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................
4
11.
Seabed Condition Analysis............................................................................................................
4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4
12.
Evidence of Bonding......................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................
4
13. Proposed Drilling Program............................................................................................................. 4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................6
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6
15. Directional Plans for Intentionally Deviated Wells....................................................................... 6
(Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6
16. Attachments.................................................................................................................................... 6
Attachment 1: Directional Plans for 1J-101-1, 1J-101-1-01, 1J-10L1-02, & 1J-101-1-03 laterals.......................................6
Attachment 2: Current Well Schematic for 1J-10............................................................................................................6
Attachment 3: Proposed Well Schematic for 1J-101-1, 1J-101-1-01, 1J-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-10L1, 1J-10L1-01, 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, 1J-101-1-01, 1J-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 1J-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
PTD Application: U-101_1, U-101_1-01, U-101_1-02, & U-101_1-03
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
MD
MD
TVDSS
TVDSS
1J-101-1
10,200'
10,500'
5811'
5,982'
ORCA Liner Drilling BHA
1J-10L1-01
12,300'
15,200'
6045'
6120'
-3/8", 4.7#, L-80, ST-L slotted liner
2;
aluminum billet on to
1J-10L1-02
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
si
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 1 J-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
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 1J-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 11.8
3676 psi
3676 psi
Choke Pressure Required to Maintain
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
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: U-101_1, U-101_1-01, U-101_1-02, & 1J-101_1-03
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. 1 J-1 OL 1 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-1 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-10L1-02 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.
1J-IOL1-03 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
PTD Application: U-101-1, U-101-1-01, U-101-1-02, & U-101-1-03
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-10L1
11,020'
1J-10L1-01
16,913'
1J-10L1-02
7620'
1 J-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-10L1-02
2706'
1 E-117
1J-10L1-03
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
Auparuk River nit
h
r
Plans 1J-IOL1_wp01
17 December, 2018
BER
BA 0
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
Design:
1 J-10L1_wp01
ConocoPhillips
BAd(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 I 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 1J-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 Angie Field Strength
(1 (°) (nT)
BGGM2018 2/1/2019 16.77 80.84 57,424
Design iJ-101-1_wp01
Audit Notes:
Version: Phase: PLAN Tie On Depth: 10,166.00
Vertical Section: Depth From (TVD) +N/S +E/-W Direction
(usft) (usft) (usft) (°)
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)
(°)
(°)
(usft)
(usft)
(usft)
(°/100usft)
(°/100usft)
(°/100usft)
(°) 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
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
1 J-10
Wellbore:
1 J-10L1
Design:
1 J-10 L1_wp01
ConocoPhillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
BAKER
gUGHES
a GE company
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
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(_)
C)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
V)
(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
+N/-S
+E/-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 cis, Start tangent
10,500.00
5.981.87
3,695.23
-6,958.31
Planned TD at 10500.00
1211712018 10:37:55AM Page 3 COMPASS 5000.14 Build 85D
unxo_':u-'� .I ;ems
CanocaPhiMps �Aaska) Jnc.
-KupI
Kuparuk River Unit
Kuparuk IJ Pad
IJ-10
IJ-10LI
IJ-IOLI—wpOl
Travelling Cylinder Report
07 December, 2018
BA ER a
TU� GHFS
a GE COMDanv
llv_� ConocoPhillips BAd(ER
ConocoPhillips Travelling Cylinder Report UGHES
a U company
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-10L1
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 1 J-10
1J-10:114.25 @ 114.25usft (lJ-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_wp01
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
nterpolation Method: MD Interval 100.00usft Error Model: ISCWSA
3epth 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 12/712018
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
1J-03 - 1J-03L1 - 1J-03L1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-03 - 1J-03L2 - 1 J-031_2
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
11-09 - 1J-09 - 11-09
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 - 1J-09ALl
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1 J-10 - 11-10 - 1 J-10
10,499.33
10,500.00
14.99
13.99
5.31
Pass - Major Risk
1J-10 - 1J-10L1-01 - 1J-10L1-01_wp02
Out of range
1J-10 - 1J-101-1-02 - 1J-101_1-02_wp01
Out of range
1J-10 - 1J-1OLl-03 - 1 J-10L1-03_wp01
Out of range
iJ-105 - 1J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-1 05 - iJ-1051-1 - 1 J-105L1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1 J-105 - 1J-1051-2 - 1 J-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 - 1J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-107 - 1J-1071-1 - 1J-107L1
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1 J-109 - 11-109 - 1 J-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109- 1J-109P131 - 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-1151-1 - 1J-1151-1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115L1 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
1J-115 - iJ-1151-2 - 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
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
12/7/2018 9:56:40AM Page 2 COMPASS 5000.14 Build 85D
ConocoPhillips
A <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
ND Reference:
1J-10:114.25 @ 114.25usft (lJ-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
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 -1 J-115PB2 - 1J-115PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1 J-115PB3 - 1J-115PB3
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1 J-115PB4 - 1J-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 - 1 J-1181-1 - 1 J-118L1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118 - 1 J-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 - 1 J-118PB2 - 1J-118PB2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-120 - 1 J-120 - 1J-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-120Ll - 1 J-1201-1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-120L1 PBi - 1J-1201-1 PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-120L1 P132 - 1 J-1201-1 PB2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-120L1 P133 - 1 J-120L1 P83
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1 J-120L1 P134 - 1 J-120L1 P134
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-120 -1 J-1201-2 - 1 J-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 - 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
1 J-152 - 1 J-1521_2 - 1 J-1521_2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1 J-1521-213131 - 1 J-1521-21361
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1 J-152PB1 - 1J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - 1 J-152P62 - iJ-152PB2
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-154 -1 J-154 - 1J-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154 - 1 J-1541-1 - 1 J-1541-1
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
1J-156 - 1 J-156 - 1J-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-1561-1P131-1J-1561_1P131
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156 - 1J-156L2 - 1 J-1561_2
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-158 - 1 J-158 - 1J-158
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158 - 1 J-158L1 - 1 J-1581-1
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 - 1 J-159L1 - 1J-159L1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1 J-1591-1 P131 - 1 J-159L1 P81
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1 J-159L1 P82 - 1 J-1591-1 PB2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-159 - 1 J-1591_2 - 1 J-159L2
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
1 J-160 - 1 J-160 - 1 J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1 J-160L1 - 1 J-1601-1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-1601-1P81-1J-1601-1PB1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1 J-1601-2 - 1 J-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-1621_1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - 1 J-162L1 P61 - 1 J-162L1 P81
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 - 1 J-162PB2 - 1J-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 - 1 J-164L1 - 1 J-1641-1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1 J-1641-2 - 1 J-164L2
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 - 1 J-166L1 - 1J-1661-1
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
12/712018 9:56:40AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips
BTR
E
ConocoPhillips
Travelling Cylinder Report
GHES
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 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-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-166-1J-166L1PB1-1J-166L1PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1 J-166 - 1 J-166L2 - 1 J-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-iJ-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-iJ-168L1-1J-168L1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-16812-1J-1681-2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L2PB1-1J-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-170L1 - 1J-1701-1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170-1J-17012-1J-17012
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 1 J-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 1.1 Pad - 1 J-03 - 1 J-03 - 1 J-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
Tootface+
Offset Wellbore
Centre
Casing -
Centre to
No Go
Allowable
Warning
Depth
Depth
Depth
Depth
Azimuth
+NLS
+PJ-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(1
(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
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
ConocoPhillips BA_ �CER
ConocoPhillips Travelling Cylinder Report IGHES
BAT
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
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
Wset 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
+E/-W
Hole Size Centre
Distance
Deviation
(usft) (usft)
(usft) (usft)
(usft) (usft) (°)
(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
o FJaUz
E e E
p o E
3 �w��
K � �
¢¢zco
¢ zom'ao
�6>NE
Lw
6m
0
�
a
--
o
a
0
G
`
w
o
o
W
ao
o q',
�o
v�
c~
'
0
0 0 0 0
0 0
0 0
0
O
p
N
0 0
O O
(n b
00
M
0
2400
2700
3000
3300
3600
3900
t200
C
150C X
Isoc G
iloc
140C as
G
70C
a
00C
300
600
900
200
500
800
N
a
CMN
.J C-4
CO
ch
y o
m o
m o
0
� r
U)
o N
_ -o
m c
C a O
Q F— Ye w (..
O
V V'` IlaD
C{
a)oO O)M c0
�
UJ r cO ISM
O r M 1
(U
a Z
w O
Q1Op o'p
CD,3,
0
0 0 M O O
o O 1 0 0
F- Cl)
V
OfO rOO
r
O
N o p 0 0
p
ti
l4] �c0r
�
� c p r O
m
+ CDop CO
C M
c0 c0 c0 cpp
W Ch
J
Q
(O r—
w C0
CA r`pu]M
r+ c0 c0 C11
m
C-)
ZP.- ui c`J u7
+.0M V m
w
Q
rn
1 m co co
M M M M
J
w
U)
�rncomoo
rmco>rnrrnuo
�ocoo =
C O
F-
L OO
1= O
000
z l f 7
N ap0 0 0
m
L M N N
LO
N N N N
c Cn CJ] t0 u7
Q
+,o
p o 0 0 0
O O O O
to 0
(p r M O
O O O O
O
r r r r
O
r N M V
O
rn
+
1
240
-255
-270
285
0
300
o
-315
o
-330�
-3451
-360(
-375(
-390(
-aos(
-420C
435C
-450C
-4650
41
0
-4800
0
Z�
-4950
-
O
-5100
5250
5400
-5550
-5700
5850
6000
6150
6300
-6450
-6600
-6750
_wl
o
6900
0
-7050
-7200
7350
-7500
-7650
p c
-7800
of
O
o
-7950
v
o Jo
N
-8100
w
c
9 �
N
m
�
C
�
-8250
m
a
-8400
0 0
0
0
0
0 0 0
0
0
0 0
0
0
0
0
N
Kuparuk River Unit
—ConocoPhillips Export Company
18115[17-9Qiy1
Plan: 1 J-10L1-01_wp02
LO
Tomuc=
!,
17 December, 2018
BER
T: " "
GHES
GE company
ConocoPhillip5
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk I Pad
Well:
11-10
Wellbo re:
1 J-10L1-01
Design:
1 J-10 L 1-01_wp02
ConocoPhiitlips SMER
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: 149' 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
(°) (°) (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) +N1-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
Con000P'hlll"aps
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 I Pad
North Reference:
Well:
1J-10
Survey Calculation Method:
Wellbo re:
1 J-10L1-01
Design:
1 J-10L1-01_wp02
BAt�UGHES
a GE company
Well 1J-10
Mean Sea Level
1J-10:114.25 @ 114.25usft (1 J-1 0: 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)
(°/100usft)
(°/100usft)
(°HOOusft)
{°) 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
1211712018 10:42:18AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips A (ER
ConocoPhillips Planning Report t-�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 (1J-10:114.25)
Site:
Kuparuk 1J Pad
North Reference:
True
Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Wellbore:
1J-101-1-01
Design:
1 J-10L1-01_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)
(a)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°)
(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 dls, Start 45 dls
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
12/1712018 10:42:18AM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillips 3A ER
ConocoPhillips 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:
1 J-10L1-01_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)
(°)
(1
(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
rasing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
15,200.00 6,119.89 2 3/8" 2.375 3.000
1211712018 10:42:18AM Page 5 COMPASS 5000.14 Build 85D
IV-,
ConocoPhillip5
ConocoPhillips
Planning Report
BA
I-�UGHES
(ER
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 (lJ-10:114.25)
Site: Kuparuk 1J Pad
North Reference:
True
Well: 1J-10
Survey Calculation Method:
Minimum Curvature
Wellbore: 1 J-10L1-01
Design: 1 J-10L1-01_wp02
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/-S
+E/-W
(usft)
(usft)
(usft)
(usft)
Comment
10,420.00
5,937.78
3,670.22
-6,896.42
TIP/KOP
10,441.00
5,948.96
3,676.63
-6,913.00
End 14 dls, Start 45 dls
10,517.97
5,969.34
3,691.06
-6,984.57
3
10,800.00
5,969.34
3,494.42
-7,099.58
End 45 dls, Start 7 dls
11,125.00
5,969.34
3,264.16
-6,873.25
5
11,330.00
5,991.46
3,160.95
-6,698.13
6
11,530.00
6,033.96
3,095.37
-6,514.58
7
11,735.00
6,054.58
3,038.94
-6,319.14
8
12,035.00
6,050.29
2,889.25
-6,061.12
9
12,300.00
6,045.04
2,752.05
-5,835.82
10
12,700.00
6,064.11
2,522.19
-5,513.88
11
13.050.00
6.087.08
2,313.28
-5,237.34
12
13,300.00
6,089.88
2,174.45
-5,030.62
13
13,700.00
6,090.30
1,984.68
-4,683.02
14
14,050.00
6,104.48
1,829.16
-4,372.76
15
14,450.00
6,119.85
1,662.80
-4,013.70
16
14,850.00
6,119.35
1,494.75
-3,655.09
17
15.200.00
6,119.89
1,337.84
-3,345.21
Planned TD at 15200.00
12/17/2018 10:42:18AM Page 6 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips (Alaska) Inc,
-Kupl
Kuparuk Rover Unit
Kuparuk 1J Pad
1 J-10
1J-10L1-01
1 J-10L1-01_wp02
Travelling Cylinder Report
10 December, 2018
BER
GHES
TGE company
✓ ConocoPhillips BA
R
ConocoPhillips Travelling Cylinder Report ES
GE company
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site;
Kuparuk I Pad
Site Error:
0.00 usft
Reference Well:
1 J-10
Well Error:
0.00 usft
Reference Wellbore
1J-101-1-01
Reference Design:
1 J-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
1J-10:114.25 @ 114.25usft (iJ-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
ieference 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-101_1_wp01 (1J-10L1)
MWD
MWD- Standard
10,420.00
15.200.00 1J-10L1-01_wp02(iJ-101-1-01)
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
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 I 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 1J Pad
1 J-03 - 1J-03 - 1 J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1J-03 - 1J-03L1 - 1J-03L1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-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
1 J-09 - 1J-09 - 1 J-09
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09 - 1J-09A- 1J-09A
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1J-09 - 1J-09AL1 - iJ-09ALl
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
13.37
20.96
Pass - Major Risk
1J-10- 1J-101-1 - 1J-101_1_wp01
Out of range
1J-10-1J-101-1-02-1J-10L1-02_wp01
11,100.00
11,100.00
0.00
2.43
-0.42
FAIL - Minor 1/10
1J-10-1J-101_1-03-1J-10L1-03_wp01
11,100.00
11,100.00
0.00
2.43
-0.42
FAIL - Minor 1/10
1J-105 - 1J-105 - 1J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105 - 1J-1051-1 - 1J-1051-1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105-1J-1051_2-1J-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
1 J-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 - 1J-10711
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
11-109 - 1J-109 - 1J-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
1 J-115 - 1 J-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-1151_1 PB1 - 1J-1151-1 PB1
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
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
✓
ConocoPhillips
BA@R
ConocoPhillips
Travelling Cylinder Report
UGHES
a Ucompany
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:
iJ-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-iJ-1151-2-1J-115L2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L2P131-1J-115L2P131
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115L2PB2 - 1 J-115L2PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - iJ-115PB1 - 1J-115PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115PB2 - 1 J-115P82
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
1J-115-1J-115PB4 - 1J-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-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
1 J-118 - 1J-118PB2 - iJ-118PB2
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-120 - iJ-120 - 1J-120
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - iJ-1201-1 - 1 J-1201-1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120L1P131-1J-120L1PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120-1J-120LIPB2-1J-120L113132
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - iJ-1201-1 P83 - 1 J-1201-1 PB3
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120L1 PB4 - 1 J-1201-1 P134
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-1201-2 - 1 J-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 - 1J-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 - 1J-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-1521361 - 1J-152PB1
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152PB2-iJ-152P132
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-154 - 1J-154 - iJ-154
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154 - 1J-154L1 - 1 J-154L1
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1 J-154 - 1 J-154L2 - 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-156L1 - 1J-1561-1
2,226.75
2,100.00
117.13
48.45
79.06
Pass- Major Risk
1J-156-1J-156L1PB1-1J-156L1PB1
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
1J-158-1J-158 - 1J-158
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-158-1J-158L1 - 1J-1581-1
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 - 1 J-1591-1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - iJ-159LI P131 - 1 J-1591-1 P131
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1 P82 - 1J-1591-1 P132
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-1591-2-1J-1591-2
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
iJ-159-iJ-159PB1-iJ-159P81
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
iJ-160 - 1J-160 - 1J-160
291.93
300.00
21.20
4.57
16.63
Pass- Major Risk
1J-160-1J-160L1 - 1J-160L1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160L1 P61 - lJ-160L1 PB1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1 J-160 -1 J-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-162L1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162-1J-162L1 PB1 - 1J-1621-1 PB1
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 - 1J-162PB2
491.49
500.00
40.65
8.37
32.28
Pass- Major Risk
1J-164 - 1J-164 - 1J-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-1641-1 - 1 J-1641-1
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
e•,
ConocoPhillips
Ad(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 I 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-10L1-01
Database:
EDT 14 Alaska Production
Reference Design:
iJ-101-1-01_wp02
Offset TVDReference:
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 1JPad
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-1661_1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-166LIPB1-1J-166LIP81
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - 1 J-16612 - iJ-16612
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
1 J-168 - 1J-168 - 1 J-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-168L1 - 1 J-1681-1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-1681-2-1J-16812
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- iJ-170L1 - 1J-170L1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170- 1J-1701-2 - 1J-1701-2
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-170PI32
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: 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
+E/-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
lusft)
(usft)
(usft)
(usft)
(°)
(usft)
(usft)
(rn)
(usft)
(usff)
(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
413.44
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
f
C4
wa
Lu
T
0 i g o f
3 �y�
m¢¢¢o
� Roza'
=e d
8'Nm
O
a
0
1
a,
`.l
v
G
a
FI
o
~
�
I
N
E.
0
_
v
o%
FI
y
o
n
o
0
o
9
0
o�
n
Y
V1
O
t
v
C
w
(ul" snQOE��-)uNnoSNF_
-2400
-2700
.3000
3300
3600
3900
4200
L
450C
480C G
C
510C
540C a
570C
a
600C
5300
5600
5900
7200
7500
3800
-o
M
y o
� N O
a o0
� ^ N
m m
in In m
O r u a
m-
c
QF-W M W to Ol.-mrnrrrrrrr
U ma' V'mm M P-- rrn COr rIn CO m Co
r MCO �NaO n•rn cV M o007�M1' rn
N'n
(b Iln V N V m mmcO N C')r- INN
000 W CrnD arnD •mdM rnO,t0014 C)0m tD
I� � t; tin rNCO COp t0 ��M
-OO Z
O
'0C
w o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
0C 0 C00000000000�no
O
r
coJ r
O O O O O O O O m C 7 C O N a 0 N O r
r"--
L6
F- 2 C+M7 NN NMmN�NmN�NrnN
r
�-
rn o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
p
O o V v uj ui
r
�
mCnMm'cFNNmctNClj
V O L n t n N r t n r m m M t 0 0 1- f- O N
W c o M r m rn O t D M M M t0' )) m n `0 .mn v
+
mN
G M
mrn rn Om CO LnM Om�nNO COM O COM
CO tp CO 1 c0 CO CO CD f0 N u; V V C? M
Jco
M
u3 (D N Co to �r Lo m m c00 V
Q
LIJ W
' CV COOcfr rnM rn NO r N -d: Ca r m 1`m
Z Cl t D r O f] c O a 7 N N M Vr Vr O) N- 1
¢ ntirnrncnmrn Mm�Nrn-aON(O rnM
M NN NNNc2 crD
`M
CO+]CO+) [�')M MCO')PO]
J
pao cn 14-W comm mmOmIn�rn
LU
Nr 0�M11Myo or Cl mv, cO Mm
�c0
O
p�mai ai of-vioui ct r; aiovrnmai
MV CO co corn Min �nvcflmmrnorrr
rn rn rn rn rn rn O o O o o o r r r r
W
_
Cn N �n VJ Cn � t0 CO (O t0 C0 W CO CO CD CO (D [0 C0
O O
Z co'N
Orn a1CN MrM NtO1 MM ] r O r
�
Cl!: m m 0 7
¢ O 1� r to cCD O O r Cp t0 CO r r Cp
m
CN M6 r (DNmON cn 4mrnct
Lo
N N N r O p cM- r r O N O N O
r r
U n r O O O r a O 1- �n rn - t V- rn O c5 u] rn M
C an r 0 0 0 C0 rn la:r 0 cn O CD r N V' CO r
�o
CD pj O00 n_ I O
rnrnrr Mrn mO'o O m 0
v��nrnrnrntin•rnmmcornmrnmrn
3} 0
p oo ti o 0 000 0 o 000000 0 0
o o rn o 0 0 0 0 0 0 0 0 0 0 0 0 0 0
o tidLoc> �ri�c50000C=)c 0
N O N M M M M O O L n O O V] n l n 0
r M C n 1 O M O M n- O c f m N
O OOOr r-�N-^-- `-- - -
� O
r r r r
C J
U r, N M rC n C O n- m rn O r N M t n C O 1 m
Z O
r r r r r r r rco
0
'
qqN
a
n
901
10-I
01-f I
- -------._.
----------------
---_.
O
SOS
l0-I'I
I-f l .__
__________
_ _____
.__ _
----------
ra
O
_- .:.
0
0
-6
-6
-6
6
-6
6
w1
6
Z
IO-i
TOI-fl
'40
-7.
O
=
h
-T
51
7i
_
- _
fir: •. 3
G
W
n t
F4
O
-T
a
� O
J
-81
N
0 0
0
0
o . o
0 00
0 00
0
1-400
7-550
1700
2850
3000
3150
3300
1450
1600
1750
900
050
200
350
500
650
800
950
W)
100
0
250 p
O
00
550 �z
O
700 y
(n
M U
300
50
00
50
100
50
00
50
00
50
00
50
00
50
)0
50
)0
ConocoPhilli s
—ConocoPhillips Expoft Company
Kuparuk River Unit
Kuparuk 1J Pad
1 J-10
1J-10L1-02
Plan: `1Jm10L1-02_wp01
! • EMMM,�, •
17 December, 2018
BER
BA 0
GEcampany
ConoeoPhillips
Database:
EDT 14 Alaska Production
Company:
_ConocoPhillips Export Company
Project:
Kuparuk River Unit
Site:
Kuparuk 1J Pad
Well:
iJ-10
Wellbore:
1 J-10L 1-02
Design:
1 J-10L1-02_wp01
Conocophillips
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
BA (ER
F�UGHES
a GE company
Well iJ-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 1J-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 wpoi
Audit Notes:
Version: Phase: PLAN Tie On Depth: 12,300.00
Vertical Section: Depth From (TVD) +N1S +E/-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
TFO
(usft)
(°)
(I
(usft)
(usft)
(usft)
(°1100usft)
(°/100usft)
(°1100usft)
(°) 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
Conoc®Phillips BA�tER
ConoCOPhiIlips Planning Report FIUGHES
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-101-1-02
Design:
1J-10L1-02 wp01
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+NIS
+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
8
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 14776.00
'acing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
14,775.00 6,028.04 2 318" 2.375 3.000
12/1712018 10.44:13AM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips BA (Eli
ConocoPhillips Planning Report 1-�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:
1 J-10 L 1-02
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
+E/-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 cis
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
12/17/2018 10:44:13AM Page 4 COMPASS 5000.14 Build 85D
ConocoPhillips
ConocoPhillips (Alaska) Into
mKup1
Kuparuk River Unit
Kuparuk 1J Pad
1 J-10
1J®10L1®02
1J®10L1-02_wp01
Travelling Cylinder Report
10 December, 2018
BER
BA 0
GE company
ConocoPhillips HA4<ER
ConocoPhillips Travelling Cylinder Report UGHES
a GE company
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk iJ Pad
Site Error
0.00 usft
Reference Well:
1 J-10
Well Error.
0,00 usft
Reference Wellbore
1J-10L1-02
Reference Design:
1 J-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)
1J-10:114.25 @ 114.25usft (1J-10:114.25)
True
Minimum Curvature
1.00 sigma
EDT 14 Alaska Production
Offset Datum
Reference 1J-10L1-02 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 1,666.08 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-10L1)
MWD
MWD- Standard
10,420.00
12,300.00 1J-10L1-01_wp01 (lJ-10L1-01)
MWD
MWD- Standard
12,300.00
14,775.00 1J-10L1-02_wp01 (1J-101-1-02)
MWD
MWD- Standard
Caging 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 - 1J-03 - 1J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1 J-03 - 1J-03L1 - 1J-031_1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-03-1J-031-2-1J-031-2
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-03 - 1J-03L2PB1 - 1 J-03L2PB1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1 J-09 - 11-09 - 11-09
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-09ALI - 1 J-09ALl
299.44
300.00
160.28
3.57
156.71
Pass - Major Risk
1 J-10 - 1J-10 - 11-10
10,488.86
10,500.00
29.34
13.60
20.73
Pass - Major Risk
1J-10 - iJ-101-1 - 1J-10L1 wp01
Out of range
1J-10-1J-101-1-01-1J-10L1-01 wp02
12,313.37
12,300.00
0.93
2.64
-1.78
FAIL - Minor 1 /10
1 J-10 - 1J-1 OL1-03 - 1 J-10L1-03_wp01
12,469.66
12,500.00
106.86
2.03
104.92
Pass - Minor 1/10
1 J-105 -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-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
1 J-107 -1 J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1 J-107-1J-107L1 - 1J-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-109PB1-1J-109PB1
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1 J-115 -1 J-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
1 J-115-1J-115L1 PB1 - 1J-1151-1 PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-115L1 PB2 - 1J-115L1 PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1 J-115-1J-115L2 - 1J-115L2
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
ConocoPhiiiips
A
E
ConocoPhillips
Travelling Cylinder Report
UGHES
a GEcampany
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 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
iJ-10L1-02
Database:
EDT 14 Alaska Production
Reference Design:
iJ-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 - 1 J-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-115 - 1 J-115PB2 - 1 J-115PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115PB3 - 1 J-115P83
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - iJ-115P134 - iJ-115PB4
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
iJ-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 - 1 J-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-118PB2- 1J-118P82
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 - 1J-120L1 - iJ-1201-1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-12OL1 PB1 - 1 J-120L1 PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-1201-1 P132 - 1J-12OL1 PB2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1 J-120 - 1J-12OLl PB3 - 1J-12OLl P133
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120Ll PB4 - 1 J-120L1 PB4
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - iJ-1201-2 - 1 J-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 - iJ-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152 - iJ-152L1 - 1 J-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- 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-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 - 1J-1541_2 - 1 J-1541_2
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-156 - 1JA 56 - 1 J-156
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156-1J-1561.1 - 1J-1561-1
2,226.75
2,100.00
117.13
48.45
79.06
Pass- Major Risk
1J-156 - iJ-1561_1 P81 - 1J-156L1 PBi
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156 - 1J-1561_2 - 1 J-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
1 J-158 - 1J-1581-1 - 1 J-1581-1
392.81
400.00
60.36
6.31
54.05
Pass - Major Risk
1J-159 - iJ-159 - iJ-159
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-159L1 - 1 J-159L1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159LIPB1-1J-1591-1PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591-1 P132 - 1J-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 - iJ-160 - 1J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1 J-160 - 1J-160L1 - 1 J-1601_1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-160L1 PBi - iJ-1601-1 PB1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-160L2 - 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
1 J-162 - 1 J-1621-1 - 1 J-1621-1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-162 - 1J-162L1 P61 - 1J-1621-1 P131
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
1 J-162 - 1J-162PB2 - 1J-162PB2
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
1J-164 - 1J-164 - 1J-164
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-1641-1 - 1 J-1641_1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-164 - 1J-1641-2 - 1 J-1641_2
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1 J-1 64 - 1 J-164L2PB1 - 1 J-1 64L2PB1
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
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
12/102018 4:32:27PM Page 3 COMPASS 5000.14 Build 85D
ConocoPhillips
EA4<ER
ConocoPhillips
Travelling Cylinder Report
UGHES
a GE 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 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-101-1-02
Database:
EDT 14 Alaska Production
Reference Design:
iJ-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-166-1J-166L1-1J-1661-1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-1J-1661-1PB1-1J-166L1PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1 J-166 - 1 J-1661-2 - 1 J-1661-2
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 - iJ-168 - 1 J-168
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-168L1 - 1J-168L1
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-1681-2 - 1 J-1681_2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168 - 1J-1681_21`131 - 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-170L1 - 1J-1701-1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170-1J-1701-2-1J-1701-2
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 1 J-104 (empty) - Prelim: 1 J-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 Li - 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-MWD+IFR-AK-SCC
Rule Assigned: Major Risk
Onset 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
+E/-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(`1
(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
8875
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
i"
E�
L
(n�
uj
w= 6
uj
o FJ��z
o o E
3 �m�
8"�38
e 2Et
___��
z zola-
�� om
2: 0
Og
U �
i a0
u
^0
Y
V
o
�
0
0
0
0
YA
�
e
n
9
m1
a
0
a
0
o
-
o
o
-n
c
0
_
o-
0
n.
a
o;
0
V M M t•1 M N N N
-2400
.2700
3000
3300
3600
3900
4200
i
450C
0
480C C
C
SIOC +
r
540C °a
570C
v
C:
500C
5300
5600
5900
7200
1500
1800
N �
a
CO
C"
C
J M
M
0
v
m
O n
H
coo,
O Y N
c m
d
CA
d-
_
UN cON CA oO CO CI' 001,
�
�MN(A CO 1A OOD 1�ln
UJ C V 0 0 0 (nl C A co C ") V V
>CO OmNONt 'D tD�
N N N N� O M d) n C
N z
� rn
M
N 0 0 0 0 0 0 0 O 0 0
O
-
a
0 0 0 0 0 0 0 0 0 0 0
6 C� 6 1 o C o C o M O O C J
O I N O N
N
MCI 0c oc 0 00
m o 0 0 0 0 0 0 0 0 0
?> a0 N O M O t0 CD O a0
V' 7 a0 LO O O O n M CO
W anrnov�Nu-.4-iv1"-
O) N
oo 1- CO CO tO [O 1- ti ti co
-c M
� 1n L9 v9 19 1n 1n 1n u? In
M
Jm
ti
(nN CON CA 00 (O C' Oc01`-
W co
co
C C) Nm C --c0O �
Z N O O O O O� .6 M V V'
W
t o
+ cO OMNON to MOB
n- t O N N O O M O r- M
�
N N N N r r• a-
J
W
(n M O C O N C A M L M�
UJ Cg 10 1- O! M 1� 1A O O
tT
c CO
o
r o 0 0 0 0 0 0 0 0 0
` oo
CO t0 to O CD O O (O CO CD
O O
M
O
N 1�N 1A OOJ CI O V O
U c0 NMO� �M �l 1�
C�} CPO 0001�(O u� u�<7'
cD
eo OOm m0 mm a) CT O)
O
+
p o 0 0 0 0 0 0 c, 0 0
o 0 0 0 0 0 0 0 0 0
O1 to O 10 C)10 Uo Ln1
O N 1` O N O I n- I-- 1-
M V �0 m N IOn-
r
cn O
O
O
Ur NM V' 1.O co I'c00)O
03
+
a
o
o
o
:o
OZ ZO
tZOt-
I--------------..-------
a
a
0
r
o
Z0Z Z
-1 "I01
f 1-----
--------------_---
_1
_7
_1
_1
_1
_2
2
2
-
- -
--------
2
--------
2
-A
w
O
c
2
y
-21
_
-21
wl
21
0
-3(
-31
-3,
INI
0 0
~
J
3
0 o
m
(A
34
m
-34
35
85
170
255
340
425
510
595
580
765
350
335
020
105
190
275
360
445
530
615 0�p
0
700
0
785 00
970
O
355 N
Cn
MO
U
(25
HO
!95
180
165
i50
35
20
05
90
75
60
45
30
15
)0
35
70
—ConecaphiMps FE--,)-,Kp8rt Company
Kuparuk River Unit
Kuparuk 1J Pad
li-10
W FUM FBIQ N fflNXMr*jljL
I I 'a, a 11 1111111111111111111 11111111111111111
Mi
17 December, 2018
BTGHES
ER
0
GEcompany
,S, ConocoPhillips BA (ER
ConocoPhillips Planning Report JUGHES
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-10L1-03
Design:
1 J-10L1-03_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
2roject Kuparuk River Unit, North Slope Alaska, United States
Wap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
3eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Nap Zone: Alaska Zone 04 Using geodetic scale factor
Site
Kuparuk 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-101-1-03
Magnetics
Model Name Sample Date
Declination Dip Angle
Field Strength
(°)
(°)
(nT)
BGGM2018 2/1/2019
16.77 80.84
57,424
Design
1J-10L1-03_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)
(°)
0.00
0.00
0.00
90.00
Plan Sections
Measured
TVD Below
Dogleg Build Turn
Depth Inclination Azimuth System +N/-S
+El-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 Page 2 . COMPASS 5000.14 Build 85D
ConocoPhillips 0
ConocoPhillips Planning Report a dUGHES
a GE cornpany
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 (1J-10:114.25)
Site:
Kuparuk 1J Pad
North Reference:
True
Well:
1J-10
Survey Calculation Method:
Minimum Curvature
Wellbore:
1J-10L1-03
Design:
1 J-10L1-03_wp01
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+NI-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
(°/100usft)
(°)
(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 TO at 14100.00
-asing 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
+N/-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 dls
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 (Alaska) Inc.
-Kup1
Kuparuk River Unit
Kuparuk 1J Pad
1 J-10
1 J-10L1-03
1 J-10L1-03_wp01
Travelling Cylinder Report
10 December, 2018
BA {EFL
UGHES
a GE company
ConocoPhillips BITER
ConocoPhillips Travelling Cylinder Report IGHES
BAT
GEcompany
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1J Pad
Site Error:
0.00 usft
Reference Well:
iJ-10
Well Error:
0.00 usft
Reference Wellbore
lJ-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 (lJ-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
deference
1J-101_1-03_wp01
=ilter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
nterpolation Method:
MD Interval 100.00usft Error Model: ISCWSA
lepth Range:
Unlimited Scan Method: Tray. Cylinder North
tesults 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+IFR AK CAZ SCC
10,166.00
10,420.00 1J-101_1_wp01 (1J-101-1)
MWD
MWD- Standard
10,420.00
12,150.00 1J-10L1-01_wp01 (lJ-10L1-01)
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
1 J-03 -I J-03 - 1 J-03
114.25
116.12
161.44
0.74
160.70
Pass - Major Risk
1J-03 - 1J-031_1 - 1J-031_1
114.25
116.00
161.44
1.02
160.41
Pass - Major Risk
1J-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
1 J-09 - 1J-09A - 1 J-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 - 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-1011-01 - 1J-10L1-01_wp02
11,100.00
11,100.00
0.00
2.65
-0.45
FAIL- Minor 1/10
1J-10 - 1J-1OLl-02 - 1 J-10L1-02_wp01
12,470.52
12,500.00
106.97
2.12
104.89
Pass - Minor 1/10
iJ-105-1J-105 - 1 J-105
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105-1J-1051-1-1J-1051-1
305.08
300.00
218.10
4.82
213.29
Pass - Major Risk
1J-105-1J-105L2-1J-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
1 J-107 - 1J-107 - 1 J-107
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-107 - 1J-107L1 - 1 J-1071-1
305.01
300.00
190.36
4.92
185.44
Pass - Major Risk
1J-109-1J-109 - 1J-109
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1J-109-1J-109PB1-1J-109P61
192.21
200.00
159.58
2.72
156.86
Pass - Major Risk
1 J-115 - 1J-115 - 1 J-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-115L1 PB1
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115-1J-1151_1PB2-1J-115L1PB2
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
Conocophiiiips
Ad(ER
i
ConocoPhillips
Travelling Cylinder Report
UGHE$
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 (iJ-10:114.25)
Reference Site:
Kuparuk 1J Pad
MD Reference:
1J-10:11425 @ 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-10L1-03_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-115L2 - 1 J-115L2
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
1J-115 - 1J-115L2PB2 - 1J-115L2PB2
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-115 - 1J-115PB2 - iJ-115PB2
403.76
400.00
159.15
6.67
152.48
Pass - Major Risk
1J-115 - 1J-115P133 - 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
1J-118 - 1J-118 - iJ-118
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118 - 1J-1181_1 - 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-iJ-118PB1
304.63
300.00
189.29
4.81
184.48
Pass - Major Risk
1J-118 - 1J-118PB2 - 1J-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-120L1-1J-120L1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120L1 PB1 - 1J-120L1 PB1
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120L1 PB2 - 1J-120Ll PB2
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - iJ-120L1 PB3 - 1 J-120L1 P133
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-1201-1 PB4 - 1J-1201-1 P134
304.57
300.00
216.86
4.81
212.05
Pass - Major Risk
1J-120 - 1J-120L2 - 1 J-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 - 1J-152
405.78
400.00
200.32
6.58
193.74
Pass - Major Risk
1J-152-1J-152L1 - 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-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 - 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-154L1 - 1 J-154L1
605.44
600.00
146.13
10.47
135.67
Pass - Major Risk
1J-154 - 1J-1541-2 - 1JA 541_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-156L1
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156 - 1J-1561-1 PBi - 1J-1561-1 PSI
2,226.75
2,100.00
117.13
48.45
79.06
Pass - Major Risk
1J-156 - 1J-1561_2 - 1 JA 561_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 - 1J-1581_1
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-1591_1 - 1 J-1591-1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159-1J-159L1PSI -1J-159L1PB1
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1J-159 - 1J-1591.1 P62 - 1J-1591-1 P132
405.33
400.00
38.11
6.69
31.42
Pass - Major Risk
1 J-159 -1 J-1591_2 - 1 J-1.591-2
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
1J-160 - 1J-160 - 1J-160
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - iJ-160L1 - 1 J-1601-1
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160 - 1J-1601-1 PB1 - 1J-1601-1 P81
291.93
300.00
21.20
4.57
16.63
Pass - Major Risk
1J-160-1J-160L2 - 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-1621_1 - 1 J-1621-1
491.49
500.00
40.65
8.37
32.28
Pass - Major Risk
iJ-162 - 1J-162L1 PB1 - 1J-162L1 PSI
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-1641_1 - 1 J-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
GG - 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
10-1
ConocoPhillips
BA�<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:
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:
1 J-10
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00 usft
Output errors are at
1.00 sigma
Reference Wellbore
1 J-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 - iJ-1641-2PB1 - 1J-164L2PB1
796.36
800.00
77.47
13.02
64.51
Pass - Major Risk
1J-166-1J-166-1J-166
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166-iJ-16611-1J-166L1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
iJ-166-1J-166L1 PB1 - 1J-1661_1 PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-1 66 - 1 J-166L2 - 1 J-166L2
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-166 - iJ-1661-2PB1 - 1J-166L2PB1
703.30
700.00
122.72
12.34
110.38
Pass - Major Risk
1J-1 68 -1J-168 - 1 J-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
1J-1 68 - 1J-1 681-2 - 1 J-1681_2
404.72
400.00
161.98
6.61
155.38
Pass - Major Risk
1J-168-1J-168L2PB1-1J-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-170L1 - 1J-17OL1
5,566.22
8,300.00
182.48
156.25
55.71
Pass- Major Risk
1J-170-1J-1701-2-1J-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-170PI32 - 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-109PI31x
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 A9
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
+E/-W
Hole Size
Centre
Distance
Deviation
(usft) (usft)
(usft) (usft) (usft) (usft)
(")
(usft)
(usft)
(in)
(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
1,124.72 Pass - Major Risk, CC, ES, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
1211012018 4:38:58PM Page 4 COMPASS 5000.14 Build 85D
Qn c
Lu a
E
V� 1O
T
42
O
�C
D a J
.0 o
o'
�
Y Y ' p
m Aoo�
a'
oN3ao1
IL
O
A
a
0�
a �
mar
c
JM
;�-
Cl)
0
a
v
c m
O a
moti
o Y a
0
Q
d
rn
r
0) N NI-cr'
fn �mco NcirN�
:v<oinroornvrn
O N (D M a) N M O
-c'z
c)
m o 0 0 0 0 0 0 0
ci000000Oo
J
�Ooo cV c:; c[i
r
�j
V
M N N N N
r
ED
r
rno 0 00 0 0 0 E
o
m o 0 0 00 0 0 0
potir-.:r r; r-:r`ti
�rnr~v rnco cD
(31 V N cV i, 1'
m
mN
i, V c0 �[] ti m � 07
a)N(D MO)�oMO
.c c')
u�cn T
J
cl)
~
w 0) M O O M u r N
Wl
�
ornc M cn no
ZM1� � mCV �rjr pp
�
w
LO
J
w
UJ r r 0
co r.nv om r`vti
cm o
p .-- a0 ri co cri a0 co
r cc;
m m o]
L o
o cn co o cD cD co cn
o co
Z Lo'
N O V 7 t o[ O N N a 0 M
V
Q d' o) N� m O V' O)
Lo
Lo
NcO �V'CO�r~ V
M NfJr a) c 0 a) r 0
U (O N o r N
C cr �oN �r�nNt•
�CD
O
eDh V
mop ao ON
M m 6i
0
+
000aoaaoo
�00000000
a00000aa
v2 �n o 0 0 0 ono
N co e0 N(O o]r
N N N N M M M V
coo
.-rrrr.-,-r
' O
z o
UrNMv�cor�oo
u)
a
0
0
3
III
0
a
00
r�
00
00
00
0
00 C)
Q
00 O
M
O
U
DO
)0 U
)0
100
700E
7300
�
L
CL
s
�a
zS
0
E
0
SCUP PROD 1J-10
CQhQcoPhi1lip7
Well Attributes
Angle
Max Angle & MD TD
Alaska Inc.Well
bore APl/UWI Field Name Wellbore Status
500292301D00 KUPARUK RIVER UNIT PROD
ncl(°) Act
67.58 3, 101.64
St. (kKB)
10,845.0
•
Comment H2S (ppm) Date
SSSV: NIPPLE 40 9/10/2016
Annotation End Date
Last WO: 2/8/2008
KB-Grd (ft) Rig Release Date
35.74 5/24/2001
iJ-10,3WQ01710:46:16AM
Verbca schematic (actual)
Annotation Depth (kKB) End Date
Annotation Last Mod ey End Date
Last Tag: RKB 10.348.0 3/27/2017
Rev Reason: TAG, GLV C/O, H2S pproven 3/31/2017
HANGER; 29.6
Casing Strings
Casing Description
OD (in) ID (in)
Top (RKB)
Set Depth (RKB)
Set Depth (NDj...
WtfLen (1...
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 (RKB)
Set Depth (RKB)
Set Depth (ND)...
Wf/Len (I...
Grade
Top Thread
.............. .... ....... ..._......................_....
... . .......
SURFACE
9 5/8
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 IWO)_
Will -en (1...
Grade
Top Thread
PRODUCTION
7
6.276
31.7
10,230.8
5,944.4
26.00
L-80
BTC-MOD
Casing Description
OD (in) ID (in)
Top (RKB)
Set Depth (RKB)
Set Depth (TVD)...
WtlLen (I...
Grade
Top Thread
LINER
4112
3.958
9,967.2
10,843.0
6,324.7
12.60
L-80
NSCT
Liner Details
CONDUCTOR; 36.0-120.0
Top (RKB)
Top (TVD) (ftKB) Top Incl
(°)
Item Des
Com
Nominal ID
(in)
9,967.2
6,787.0 53.74
TIE BACK
BAKER PACKER & TIE -BACK SLEEVE
4.438
9,985.2
5,797.6 53.67
PACKER
BAKER ZXP LINER TOP PACKER
4.438
NIPPLE; 508.0
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.E
3.725" profile
Tubing Strings
Tubing Description String Ma... ID (in) Top (RKB) Set Depth (ft.. Set Depth (ND) (... Wt pb/ft) Grade Top Connection
TUBING 4112 3.958 29.6 9,991.7 5,801.5 12.60 L-80 IBT
GAS LIFT; 6,311.7
Completion Details
Top (kKB)
Top (rvD) (tlKe)
Top Incl
(°) Item Des
Co.
Nominal 10
(in)
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-
9, 978.7
5,793.8
53.70
LOCATOR
BAKER GBH-22 LOCATOR
3.958
9,979.9
5,794.5
53.69
SEALASSY I
BAKER SEALASSEMBLY w/MULESHOE
3.958
GAS LIFT;8,068.2
Other In Hole
(Wireline retrievable plugs, valves, pumps, fish, ete.) - - - -
Top (TVD)
Top Incl
Top (RKB)
(RKB)
(°) Des
Co.
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. WELLSHUTIN&
GAS LIFT; 9,132.E
FREEZE PROTECTED. 36" BAT SUB LEFT ON
TOP OF E-LINE TOOL
10/25/2004: Fish Pulled up 1010,312' CTMD
6/712006: Tagged Fish @ 10339' RKB
1/19/2008 Tagged Fish @ 10301' SLM
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(ftKB)
Elm(ftKB)
Top (ND)
(kKB)
Btm (ND)
(kKB)
Zone
(shots/f
Date
t)
Type
Com
10,446.0
10.466.0
6,072.7
6,084.9 C-3,1J-10
7/19/2001
6.0 APERF
33/8"PSD
PJ chgs, 60
deg
ph
10,658.0
10,678D
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 (lb) Data
LOCATOR; 9,978.7
6116/2001
Stimulations & Treatments
SEAL ASSY; 9.979.9
I
Vol Clean Pump
Sig #
Top (RKB)
Ginn(kKB)
Date
Stim/Treat Fluid
(bbl) Vol
Slurry (bbl)
1
10,658.01
10,678.0 6/16/2001
Mandrel Inserts
St
at!
on
N Top (RKB)
Top(TVD)
(RKB)
Make
Model
OD (in)
S.,
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi)
Run Date
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
O.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
3/2912017
5:00
4 9,132.6
5,283.0
CAMCO
KBG-2
1 GAS
LIFT
DMY
BK
0.000
0.0
5123Y2001
4:15 -
5 9,882.2
5,736.8
CAMCO
KBG-2
1 GAS
LIFT
DMY
BK
D000
0.0
2/9/2014
7:00
Notes: General & Safety
End Date
v Annotation
2/8/2008
NOTE: WORKOVER DONE TO PULL FISH, MILLED NIPPLES; UNSUCCESSFUL, PUSHED FISH
FISH; 10,400.0
DOWNHOLE
912912010
NOTE: View Schematicw/ Alaska Schematic9.0
APERF; 10,446.0-10,466.0
IPERF; 10,658.0-10,678.0-1 e
FRAC; 10,658.0 �---i
LINER; 9,967.2-10,843.0
U
cts
L
U
Ln
0
F
U
v
a�
N
0
a
0
IL
0
❑
�i
N C
❑
g
EL �
N m
`o
a
ui
� u
o
ii
o
c
O
�
E
M
10
p
h
CV
N
2
-
m
U
a
N
C
v
ih
N g
"'
•-
p
O
m
=
N
o
°�
mCD
m m
c
N
fl.
'O
C
£
Im
a
U O���� �[ U
@
JW d
N
`:
N
U
K
c
co
W
W
-
c
(6
N A m n.
N S] N F
.--
p
C.
C
1n
T
m
h
ccm
m
= Ecl F Ol
!a\
U
•7
=
I--
m
4)G
�6 C O
U
O.
N
GD m
O
U
O
U
O
U
N
N NJ=
N
0-
O
a
N
N !A
J 3_0
O
r N U d N
Z
1
z
U
U
U
4) (U X C
vU)ilN�
p
O
@)
z
C
d
(7
=oi15 M
N
N
(V
N
Y Y Y Y
E
=
N
'C
N N 0 m a
N
A
4
4
4
.]e
f0 l0 (0 (0 (0
mmm mm
l0
U
m
lL
U
O
2
C �- 3 h
_1 C7m NM
❑ P
�5-(
oN�
3o c
O
I
J +
o �'a
ta-
I111��
��II
o
b
N
0�
1?
h
p
zo
W
O
N p
O
�
p
2
#
co O
o
p1
CL
h
N
/��
02
Oi0
O
a
u1 10
f O
O.
_ Cl
-�M
00
�O
N N
L O
(flO
Cpp
L
O
p,
o
2 p 0
� O
V o
c- O
N /7
From: McLaughlin Ryan
To: Boyer, David L (DOA)
Cc: Loeoo, Victoria T (DOA)
Subject: RE: [EXTERNAL] Digital Survey Files for Four 13-10 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-10L1-01:
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-10L1 but not for the -01, -02, and -03 laterals?
Thank you,
Dave Boyer
AOGCC
From: McLaughlin, Ryan <Ryan McLauahlinPconocophillios.com>
Sent: Thursday, January 31, 2019 11:53 AM
To: Boyer, David L (DOA) <david, boyer2@aIaska.gov>
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.boyer2C-aiasl<a.gov>
Sent: Thursday, January 31, 2019 10:13 AM
To: McLaughlin, Ryan <Ryan.McLaughlin(@conocophillips.com>
Subject: [EXTERNAL] Digital Survey Files for Four 1J-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: K R U,
PTD:
V Development _ Service Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: K(A payu !�► I Ve✓' POOL: %�ypa ry /� R 1yer- Q 1 l
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
/
LATERAL
No. `Ao l -Oj�l , API No. 50- O,;q- a3a10 - 00 -oo.
,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-101-1-02 Program DEV Well bore seg ❑�/
PTD#:2190140
Company CONOCOPHILLIPS ALASKA, INC. _ Initial Class/Type
DEV / PEND_ _GeoArea 890 _ - Unit _1_1160 _ On/Off Shore On Annular Disposal ❑
Administration
11
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 included.
9
Operator only affected party
Yes
I10
Operator has appropriate bond in force
Yes
Ill
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# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only)
NA
16
Pre -produced injector: duration of pre -production less than 3 months- (For service well only)
NA_
17
Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
NA
18
Conductor string provided
NA
Conductor set for KRU 1J-10
Engineering
19
Surface casing protects all known USDWs
NA
Surface casing set for 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 cover all knownproductivehorizons
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
I26
Adequate wellbore separation proposed
Yes
Anti -collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations-
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is 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
131
Choke manifold complies w/API RP-53 (May 84)
Yes
I32
Work will occur without operation shutdown
Yes
i33
Is presence of 112S gas probable
Yes
112S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA
35
Permit can be issued w/o hydrogen sulfide measures - -
No
Wells on 1J-Pad are H2S-bearing. 112S measures required.
Geology
36
�37
Data presented on potential overpressure zones
Yes
Appr Date
Seismic analysis of shallow gas zones
NA
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly. progress reports [exploratory only] _
NA.
Geologic Engineering Public
Commissioner: Date: om i sinner: Date Commissioner Date
__5_t cT
