Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout222-028T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Aug 05, 2022
AOGCC
Attention: Kayla Junke
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
1F-06L1
Kuparuk River
API #: 50-029-20820-60-00
Permit No: 222-028
Rig: CDR3
The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well.
Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files.
Thank you.
Signature of receiver & date received:
Please return transmittal letter to:
Jenny Jones
Jenny.E.Jones@conocophillips.com
Luis G Arismendi
Luis.arismendi@bakerhughes.com
PTD:222-028
T36851
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.08.05 09:04:31
-08'00'
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37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Owner/Contractor: Rig No.:CDR3AC DATE: 7/13/22
Rig Rep.: Rig Phone: 907-670-6082
Operator: Op. Phone:907-670-6050
Rep.: E-Mail
Well Name: PTD #22220280 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2747
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result Test Result Quantity Test Result
Location Gen.P Well Sign P Upper Kelly 0NA
Housekeeping P Rig P Lower Kelly 0NA
PTD On Location P Hazard Sec.P Ball Type 2P
Standing Order Posted P Misc.NA Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 2''P Trip Tank NA NA
Annular Preventer 1 7 1/16''P Pit Level Indicators PP
#1 Rams 1 Blind Shear P Flow Indicator PP
#2 Rams 1 2'' Combi P Meth Gas Detector PP
#3 Rams 1 2 3/8'' Combi P H2S Gas Detector PP
#4 Rams 1 2'' Combi P MS Misc 0NA
#5 Rams 0NA
#6 Rams 0NA Quantity Test Result
Choke Ln. Valves 1 2 1/16''P Inside Reel valves 1P
HCR Valves 2 2 1/16''FP
Kill Line Valves 5 2 1/16''FP
Check Valve 0NAACCUMULATOR SYSTEM:
BOP Misc 3 3 1/8'' / swab P Time/Pressure Test Result
System Pressure (psi)3050 P
CHOKE MANIFOLD:Pressure After Closure (psi)2350 P
Quantity Test Result 200 psi Attained (sec)23 P
No. Valves 12 FP Full Pressure Attained (sec)48 P
Manual Chokes 1P Blind Switch Covers: All stations Yes
Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 4 @ 1850 P
CH Misc 0NA ACC Misc 0NA
Test Results
Number of Failures:4 Test Time:7.5 Hours
Repair or replacement of equipment will be made within Same days.
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 7/11/22 @ 12:38
Waived By
Test Start Date/Time:7/12/2022 22:30:00 PM
(date) (time)Witness
Test Finish Date/Time:7/13/2022 6:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Nabors
Pit level alarms tested, LEL and H2S alarms tested. Verified flow through Micromotion. Bravo 5 failed, greased, re-
tested, passed. Bravo 8 failed, greased, re-tested, passed. Romeo 1 failed, greased, re-tested, passed. C-2 failed,
greased, re-tested, passed.
C. Coyne / R. Beard
Conoco Phillips Alaska
C. Erdman / L. Imm
KRU 1F-06L1
Test Pressure (psi):
cdr3.companyman@conocophillips.com
Form 10-424 (Revised 02/2022) 2022-0713_BOP_Nabors_CDR3AC_KRU_1F-06L1
9 9
9
9
999 9
9
9
9
-5HJJ
FP
FP
FP
Bravo 5 failed,
Bravo 8 failed, Romeo 1 failed, C-2 failed,
TIME STATE
°'ALASKA
GOVERNORMICHAEL J. DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK, 99510
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 IF-06L1
ConocoPhillips Alaska, Inc
Permit to Drill Number: 222-028
Surface Location: 1213' FNL, 7' FWL, Sec. 20, T11N, R10E, Umiat
Bottomhole Location: 3227' FNL, 913' FEL, Sec. 17, T11N, R10E, Umiat
Dear Mr. Ohlinger:
Enclosed is the approved application for the permit to drill the above referenced well.
The permit is for a new wellbore segment of existing well Permit No. 182-145, API No. 50-029-
20820-00-00. 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,
Jeremy Digitally signed by
Y Jeremy Price
Price Date: 2022.03.11
13:56:06-09'00'
Jeremy M. Price
Chair
DATED this 1 I day of March, 2022.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
RECEIVED
By Meredith Guhl at 2:18 pm, Mar 07, 2022
1a. Type of Work:
1b. Proposed Well Class: Exploratory -Gas ❑
Service - WAG ❑ Service - Disp ❑
1c. Specify if well is proposed for:
Drill ❑ Lateral❑
Stratigraphic Test ❑ Development - Oil U
Service - Winj ❑ Single Zone ❑
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑
Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket 0 Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180
KRU 1 F-06L1
3. Address: P.O. Box 100360
6. Proposed Depth: TVD: 6139' TVD
12. Field/Pool(s):
Anchorage, AK 99510
MD: 12100' MD TVD: 6024' TVD SS
Kuparuk River Field
Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
Surface: 1213' FNL, 7' FEL, Sec. 20, T11 N, R10E, UM
7. Property Designation: DLB
ADL0025652
Top of Productive Horizon:FWL DLB
8. DNR Approval Number:
13. Approximate Spud Date:
1452' FNL, 1807' FEL, Sec. 17, T11 N, R10E, UM
8-179/ ALK 2578
3/15/2022
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
3227' FNL, 913' FEL, Sec. 17, T11 N, R10E, UM
2480
29650'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 115'
15. Distance to Nearest Well Open
Surface: x- 539987 y- 5958314 Zone-4
GL / BF Elevation above MSL (ft): 0.0'
to Same Pool: 118'
16. Deviated wells: Kickoff depth: 9030' feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 101.25 degrees
Downhole: 3361 psi Surface: 2747 psi
18. Casing Program:
Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole
Casing
Weight
Grade
Coupling
Length
MD
TVD
MD
TVD
(including stage data)
3"
2-3/8"
4.7#
L-80
ST-L
3070'
9030'
6029'
12100'
6024'
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
9837'
6563'
9271'
9271'
6269'
9449', 9582'
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
45'
16"
252 sx AS II
80'
80'
Surface
2653'
10-3/4"
1100 sx Fondu, 250 sx Permafrost C
2687'
2317'
Intermediate
Production
9757'
7"
1725 sx Class G, 250 sx Permafrost C
9789'
6538'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
9010-9097', 9344-9430'
6134-6180', 6307-6352'
Hydraulic Fracture planned? Yes ❑ No U
20. Attachments: Property Plat ❑ BOP Sketch
Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch
Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name: James Ohlinger
Authorized Name: James Ohlinger
Contact Email: lames.i.ohlinper(a)conocophillips.com
Authorized Title: Staff CTD Engineer
Contact Phone: (907) 265-1102
James Jr.Ohlin e,gaa,eeeroo-mems:,>T°s"..
Authorized Signature: g
Date: 3/7/2022
Commission Use Only
Permit to Drill
API Number:
Permit Approval 3/11/22
See cover letter for other
Number:222-028
Date:
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:
BOPE test to 3500 psig
Samples req'd: Yes❑ Nok] Mud log req'd: Yes ❑ No�Xj
Annular preventer test to 2500 psig H2S measures: Yesk] No[_] Directional svy req'd: Yes ® No[_]
Spacing exception req'd: Yes[—] No�d Inclination -only svy req'd: Yes ❑ No�j
Post initial injection MIT req'd: Yes ❑ Nok
A variance to 20 AAC 25.015(b) is granted to allow the kickoff
point to be any point along the parent lateral.
Jeremy Price Digitally MgnedbyJeremy Price
Approved by: Date: 2022.03.11 13:55:53 -09'00'
APPROVED BY 3/11/22
COMMISSIONER THE COMMISSION Date:
Comm. dts 3/11/20221 Comm. Sr Pet EngVTL 3/11/2022 JSr Pet GeoDLB 03/09/2022 ISrResEng DSR-3/8/22
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 1, 2022
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 an application for a permit to drill a lateral out of the KRU 1 F-06
(PTD# 182-145) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in March 2022. The objective will be to drill a lateral, KRU 1 F-06L1
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 permit to drill applications are the following documents:
— Permit to Drill Application Form (10-401) for 1 F-061_1
— Detailed Summary of Operations
— Directional Plans for 1 F-06L1
— Current Wellbore Schematic
— Proposed CTD Schematic
If you have any questions or require additional information, please contact me at 907-265-1102.
Sincerely,
Digitally signetl by James J. 1h11",e1
James J . D3 me J OM1l J, Pni9 ,. O=Wells- C011ed Tubing
Reaaen: I am the author of thls document
Oh I i nger o it:2DF2030713a22-io O ,e
James Ohlinger
Coiled Tubing Staff Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Lateral
1 F-06L1
Application for Permit to Drill Document
1. Well Name and Classification......................................................................................................... 2
(Requirements of 20 AAC 25.005(t) and 20 AAC 25.005(b)).................................................................................................................. 2
2.
3.
4.
5.
6.
7.
8.
9.
LocationSummary.......................................................................................................................... 2
(Requirements of 20 AAC 25.005(c)(2))................................................................................................................................................. 2
Blowout Prevention Equipment Information.................................................................................2
(Requirements of 20 AAC 25.005 (c)(3))................................................................................................................................................ 2
Drilling Hazards Information and Reservoir Pressure.................................................................. 2
(Requirements of 20 AAC 25.005 (c)(4))................................................................................................................................................ 2
Procedure for Conducting Formation Integrity tests.................................................................... 2
(Requirements of 20 AAC 25.005(c)(5))................................................................................................................................................. 2
Casing and Cementing Program.................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(6))................................................................................................................................................. 3
DiverterSystem Information.......................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(7))................................................................................................................................................. 3
DrillingFluids Program................................................................................................................... 3
(Requirements of 20 AAC 25.005(c)(8))................................................................................................................................................. 3
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 CTD Operations.......................................................................................................................................... 4
LinerRunning.................................................................................................................................................................. 5
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.
Attachment 1:
Attachment 2:
Attachment 3:
................................................................................................................................. 6
Directional Plans for the 1 F-061-1 lateral...................................................................................................
Current Well Schematic for 1 F-06 and 1 F-061-1........................................................................................
Proposed Well Schematic for the 1 F-06L1 lateral.....................................................................................
Page 1 of 6 February 23, 2022
PTD Application: 1 F-06L1
1. Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed lateral described in this document is 1 F-061-1. The lateral will be classified as "Development'
well.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
The lateral will target the C-Sand package in the Kuparuk reservoir. See attached 10-401 form for surface and
subsurface coordinates of the 1 F-061-1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the
maximum formation pressure in the area of 3361 psi found in 1A-11 measured 10/2011 (i.e.10.5 ppg
EMW), the maximum potential surface pressure in 1 F-06, assuming a gas gradient of 0.1 psi/ft, would
be 2747 psi. See the "Drilling Hazards Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 1 F-06 was measured at 2384 psi @ 6134' TVD (7.74 ppg) on 2104122. The
maximum downhole pressure in the 1F-06 vicinity is IA- 11 at 3361 psi @ 6156' TVD (10.5 ppg — Measured
2011).
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
The offset injection wells are reported to have MI in the past, but there is a low possibility of encountering free
gas while drilling the 1 F-06 lateral. 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 1 F-06 lateral will be formation instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 F-06 lateral 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 March 1, 2022
PTD Application: 1 F-061_1
6. Casing and Cementing Program
(Requirements of 20 AA 25.005(c)(6))
New Completion Details
Liner Top
Liner Btm
Liner Top
Liner Btm
Lateral Name
MD
MD
TVDSS
TVDSS
Liner Details
1F-06L1
—9030'
12,100'
6029'
6024'
2-3/8", 4.7#, L-80, ST-L slotted liner,
solid liner
Existing Casing/Liner Information
Category
OD
Weight
(ppf)
Grade
Connection
Top MD
Btm MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
63
H-40
Welded
35'
80'
35'
80'
1640
670
Surface
10-3/4"
46
K-55
Butt
34'
2687'
34'
2317'
3580
2090
Production
7"
26
K-55
Butt
32'
9789'
32'
6538'
4980
4330
Tubing
3-1/2"
9.30
L-80
EUE
37'
9003'
37'
6130'
10160
10540
7. Diverter System Information
(Requirements of 20 AA 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 AA 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: Water -Based PowerVis milling fluid (8.6 ppg)
— Drilling operations: Water -based PowerVis mud (8.6 ppg). This mud weight will not hydrostatically
overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with --10.8 ppg NaBr completion fluid in order to
provide formation over -balance and well bore 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 and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud
weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled
tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3
"Blowout Prevention Equipment Information". DLB
In the 1 F-06 lateral, operations will target a constant BHP of —10.2 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
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.
Page 3 of 6 March 1, 2022
PTD Application: 1 F-06L1
Pressure at the 1 F-06 Window (9030' MD, 6144' TVD) Using MPD
Pumps On 1.9 b m
Pumps Off
A/C -sand Formation Pressure 7.47
2384 psi
2384 psi
Mud Hydrostatic 8.6
2748 psi
2748 psi
Annular friction i.e. ECD, 0.080 si/ft
722 psi
0 psi
Mud + ECD Combined
no chokepressure)
3470 psi
overbalanced -1086 psi
2478 psi
overbalanced -1086 psi
Target BHP at Window 10.8
3450 psi
3450psi'
Choke Pressure Required to Maintain
Target BHP
0 psi
703 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 CTD Operations
KRU well 1 F-06 is equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize a single
lateral to target the C-sands to the south of 1 F-06.
CDR3-AC will mill a window in the 7" casing at -9030' MD and the 1 F-061-1 lateral will be drilled to TD at 12,100'
MD, targeting the C-sands to the South. It will be completed with 2-3/8" slotted liner up to -9030' MD.
CTD Pre -Rig, Drill, and Complete 1 F-06L1 Lateral
Pre-CTD Work
• Pre-CTD diagnostics
• Slickline: dummy whipstock drift
• Eline: Set whipstock
Page 4 of 6 March 1, 2022
PTD Application: 1 F-06L1
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
Drill 1 F-061-1 Lateral (C-sand)
a. Mill 2.80" window at —9030' MD.
b. Drill 3" bi-center lateral to TD of 12,100' MD.
c. Run 2%" slotted liner up to —9030' MD
3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC.
Post -Rig Work
1. Return to production
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, deployment rams (the annular preventer will serve as a secondary barrier
during BHA pressure deployment), 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 slick -line.
— When the BHA is spaced out properly, the deployment rams are closed on the BHA to isolate reservoir
pressure via the annulus (the annular preventer will serve as a secondary barrier during BHA pressure
deployment). A closed set of double ball valves and double check valves isolate reservoir pressure
internal to the BHA. Slips on the deployment rams prevent the BHA from moving when differential
pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams.
— The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized,
and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
The 1 F-06 lateral will be displaced to an overbalancing fluid (-10.8 ppg NaBr) 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.
Page 5 of 6 March 1, 2022
PTD Application: 1 F-06L1
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. (659-7212).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plans
— Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
— MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
— Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name Distance
1 F-0611-1 29650'
— Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1F-0611-1
118'
1F-19L1-01
16.Attachments
Attachment 1: Directional Plans for 1 F-06L 1 lateral
Attachment 2: Current Well Schematic for 1 F-06
Attachment 3: Proposed Well Schematic for 1 F-06L 1 lateral
Page 6 of 6 March 1, 2022
KUP PROD WELLNAME 1F-06 WELLBORE 1F-06
ConocoPhillips
Alaska, INC.
ram.
Well Attributes
Max Angle & MD
TO
Field Name Wellbore API/UWI Wellbore Status
KUPARUK RIVER UNIT 500292082000 PROD
I cI (°)
8.77
MD (.KB)
9,200.00
Act Btm (ftKB)
9,837.0
Comment H28 (ppm) Date Annotation End Date
SSSV: LOCKED OUT 21 1/26/2019 Last WO: 8/24/1984
KB-Grd (ft)
40.59
Rig Release Data
10/2/1982
1F-06, 2/21/20223:14:03 PM
Last Tag
Vertical schematic (actual)
Annotation
Depth (ftKB)
End Date
Wellbore
Last Mod By
..............................................................................
3K- WELLHEAD; 25.0'
HANGER; 30.4
CONDUCTOR; 35.o-eo.o
SAFETY VLV; 1,995.9
GAS LIFT; 2,202.E
SURFACE; 34.2-2,687.4
GAS LIFT; 4,394.5
GAS LIFT; 5,819.1
GAS LIFT; 5,889.0
GAS LIFT; 6,577.E
GAS LIFT; 6,645.7
GAS LIFT; 7,052.2
GAS LIFT; 7,869.1
GAS LIFT; 8,791.2
CUT; 8,813.0
LEAK; 8,821.0
SBR; 8,827.6
PACKER; 8,853.1
PRODUCTION; 8,888.4
PRODUCTION; 8,956.0
CUT; 8,984.0
IPERF; 9,010.0-9,097.0
CUT; 9,124.0
PRODUCTION; 9,228.0
SEAL ASSY; 9,265.2
PACKER; 9,266.0
SBE: 91,268.5
9,271.0
NIPPLE; 9,282.0
sos:9.2as.1
IPERF; 9,344.0-9,420.0
RPEW 9:344.0-9,430.0
FISH; 9,449.0
FISH; 9,582.0
PRODUCTION; 31.9-9,789.0_
..........
Last Tag: SLIM
9,420.0 2/8/2015
1F-06
hip. ,
Last Rev Reason
Annotation
End Date
Wellbore
Last Mod By
Rev Reason: Three pre-RWO tubing cuts 2/20/2022
1F-06
spilch
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
35.0
Set Depth (ftKB)
80.0
Set Depth (TVD)...
80.0
Wt/Len (I... Grade
62.50 H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
103/4
ID (in)
9.95
Top (ftKB)
34.2
Set Depth (ftKB)
2,687.4
Set Depth (TVD)...
2,316.7
WtlLen (I... Grade
45.50 K-55
Top Thread
BUTT
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
31.9
Set Depth (ftKB)
9,789.0
Set Depth (TVD)...
6,537.9
WtlLen (I... Grade
26.00 K-55
Top Thread
BUTT
Tubing Strings
Tubing Description I String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt gb/ft) Grade Top Connection
TUBING 31/2 2.99 30.4 9,288.8 6,278.6 9.30 J-55 BTC IPC
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl (°)
Item Des
Nominal ID
(in)
OD
Nominal
(in)
Make
Model
Com
30.4
30.4
0.07
HANGER
3.500
8.000
FMC GEN 1 TUBING
HANGER
1,995.9
1,825.7
41.24
SAFETY VLV
2.813
5.937
OTIS OILS NON -
EQUALIZING SAFETY
VALVE -LOCKED OUT
9/6192
2,202.6
1,979.1
42.89
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
4,394.5
3,346.6
57.54
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
5,819.1
4,167.8
51.89
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
5,889.0
4,211.2
51.40
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
6,577.6
4,660.2
47.76
GAS LIFT
2.906
5.620
OTIS 3.5
x 1
6,645.7
4,706.0
47.70
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
7,052.2
4,981.3
46.99
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
7,869.1
5,510.3
56.72
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
8,791.2
6,016.5
57.34
GAS LIFT
2.860
5.620
OTIS 3.5
x 1
8,827.6
6,036.1
57.39
SBR
2.813
4.500
OTIS SBR
8,853.0
6,049.9
57.39
PACKER
4.000
6.000
OTIS RH PACKER
8,992.6
6,124.4
58.31
BLAST RINGS
2.992
4.500
BLAST RINGS (4)
9,265.2
6,266.3
58.77
SEAL ASSY
4.000
5.000
BAKER SEAL ASSEMBLY
9,266.0
6,266.8
58.77
PACKER
4.000
5.875
BAKER FB-1 PACKER
9,268.5
6,268.1
58.77
SBE
4.000
5.000
BAKER SEAL BORE
EXTENSION
9,282.0
6,275.0
58.77
NIPPLE
2.750
4.350
OTIS XNS NIPPLE NO GO
9,286.1
6,277.2
58.77
SOS
4.470
5.250
OTIS SHEAR OUT SUB,
ELMD TTL @9279' during
PPROF on 7/14/2008
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
TO
AD)
(ftKB)
Top Incl
V)
Des
Corn
Run Date
ID (in)
SIN
25.0
25.0
0.06
3K- WELLHEAD
3K WeIlHead
10/21/1982
0.000
8,813.0 6,028.3
57.38
CUT
WELLTEC MECHANICAL CUT
2/20/2022
2.992
8,821.0 6,032.6
57.38
LEAK
LDL Leak @ 8821 RKB
8/11/2016
8,984.0 6,119.9
58.22
CUT
WELLTEC MECHANICAL CUT
2/20/2022
2.992
9,124.0 6,193.1
58.66
CUT
WELLTEC MECHANICAL CUT
2/20/2022
2.992
9,271.0 6,269.3
58.77
PLUG
2.76" BOT CIBP (OAL=2.19')
3/14/2015
9,449.0 6,361.E
58.77
FISH
Baker slip stop & Lost in rathole- last tag @
9449'
6/2/1990
0.000
9,582.0 6,430.E
58.77
FISH
Vann Gun Downhole
6/2/1990
0.000
Mandrel Inserts
St
at!
on
N Top (ftKB)
Top (TVD)
(ftKB) Incl
Top
(o)
Make
Model
OD (in)
Valve
Sery Type
Latch Port
Type
Size
(in)
TRO Run
(psi)
Run Data
Com
_
1 2,202.6
1,979.1
42.89
1
GAS LIFT DMY
INT
0.000
0.0 2/10/2022
2 4,394.5
3,346.6
57.54
1
GAS LIFT GLV
BK
0.156
1,286.0 8/10/2001
FINPLUG;
Stripp
ed
3 5,819.1
4,167.8
51.89
1
GAS LIFT DMY
BK
0.000
0.0 11/10/1989
4 5,889.0
4,211.2
51.40
1
GAS LIFT DMY
BK
0.0001
0.0 9/4/1984
5 6,577.6
4,660.2
47.76
1
GAS LIFT GLV
Broke
0.188
1,327.0 8/13/2001
6 6,645.7
4,706.0
47.70
1
GAS LIFT DMY
BK
0.000
0.0 2/5/2022
7 7,052.2
4,981.3
46.99
1
GAS LIFT DMY
BK
0.000
0.0 9/4/1984
8 7,869.1
5,510.3
56.72
1
GAS LIFT DMY
BK
0.000
7/1/2018
9 8,791.2
6,016.5
57.34
1
GAS LIFT OPEN
OPEN
0.000
0.0 2710/2022
1 8,888.4
6,068.9
57.40
1
PROD OPEN
Broke
0.000
0.0 10/20/1987
Open
1 8,956.0
1
6,105.1
57.95
1
PROD OPEN
Broke
0.000
0.0 11/25/1989
1 9,228.0
2
6,247.1
58.77
1
PROD DPHF
CV
BEK
0.000
0.0 5/27/2009
KUP PROD WELLNAME 1F-06 WELLBORE 1F-06
ConocoPhillips
Alaska, Inc.
1F-06, 2/21/20223:14:04 PM
Perforations & Slots
Vertical schematic (acwa0
Shot
Dens
.................................................................
3K - WELLHEAD; 25.0'
..........
Top (ftKB)
Bt. (ftK13)
Top (TVD)
(ftK6)
Son (TVD)
(ftKB)
Linked Zone
Date
(shots/ft
)
Type
Com
9,010.0
9,097.0
6,133.6
6,179.0
C-4, C-3, 1F-06
9/26/1982
8.0
IPERF
90° Phasing;4" SOS
HANGER; 30.4
Hyperjet II
9,344.0
9,430.0
6,307.2
6,351.8
A-4, 1F-06
10/17/1989
4.0
RPERF
60° Phasing; 2 1/8"
Dynastrip
9,344.0
9,420.0
6,307.2
6,346.6
A-5, A-4, 1F-06
10/17/1989
12.0
IPERF
90° Phasing;4" SOS
Hyperjet II
Notes: General & Safety
CONDUCTOR; 35.0-80.0
End Dale
Annotation
10/27/2008
NOTE: MANDREL 2 - STRIPPED FN, POSSIBLE TRASH ON LATCH
SAFETY VLV; 1,995.9
8/13/2001
NOTE: MANDREL 5 - LATCH BROKE OFF
10/21/1982
NOTE: WELLHEAD IS 3,000 PSI (3K)
GAS LIFT; 2,202.E
SURFACE; 34.2-2,687.4
GAS LIFT; 4,394.5
GAS LIFT; 5,819.1
GAS LIFT; 5,889.0
GAS LIFT; 6,577.E
GAS LIFT; 6,645.7
GAS LIFT; 7,052.2
GAS LIFT; 7,869.1
GAS LIFT; 8,791.2
CUT; 8,813.0
LEAK; 8,821.0
SBR; 8,827.6
PACKER; 8,853.1
PRODUCTION; 8,888.4
PRODUCTION; 8,956.0
CUT; 8,984.0
IPERF; 9,010.0-9,097.0
CUT; 9,124.0
PRODUCTION; 9,228.0
SEAL ASSY; 9,265.2
PACKER; 9,266.0
SEE; 91268.5
PLUG; 9,271.0
NIPPLE; 9,282.0
SOS; 9,286.1
IPERF; 9,344.0-9,420.0
RPERF; 9,344.0-9,430.0
FISH; 9,449.0
FISH; 9,582.0
PRODUCTION; 31.9-9,789.0-
1 F-06 Proposed CTD Schematic
16" 62# H-
40 shoe @
10-3/4" 45.5#
K-55 shoe @
KOP @ 9030' MD
C-sand perfs
A -sand perfs
9344' - 9430' MD
7" 26# K-55
shoe @ 9789'
3-1/2" Camco IDS nipple @ XXXX' MD (2.875" min ID)
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-1/2" Camco gas lift mandrels @
Baker 3-1/2" PBR @ XXXXMD (Y ID)
Baker FHL packer @ XXXX' MD (4.0" ID)
3-1/2" Camco MMG production mandrels @
Baker FB-1 packer @ 9266' MD (4.0" ID)
Baker SBE @ 9269' MD
3-1/2" Otis XNS nipple @ 9282' MD (2.75" min ID, No -Go)
3-1/2" tubing tail @ 9289' MD
1F-06L1 wp04
TD - 12,200' MD
Top of Liner - 9030' MD
Conoa Phillips
Project: Kuparuk River Unit-1
Site: Kuparuk 1F Pad
Well: 1F-06
Wellbore: 1F-061-1
Plan: 1F-O6L1 wp04
T
G M True North: -0.30"
Magnetic North: 14.75"
Magnetic Field
Strength: 57262.1 nT
Dip Angle: 80.66"
Date: 4/1/2022
WELLBORE DETAILS: 1 F-061_1
REFERENCE INFORMATION
Coordinate Reference: Well 1F-06, Grid North
(N/E )
Vertical (TVD) Reference: Mean Sea Level
Section (VS) Reference: Slot -(O.00N, O.00E)
Measured Depth Reference: 1F-06 @ 115.00usft (1F-06)
Calculation Method: Minimum Curvature
Parent Wellbore: 1F-06
Tie on MD: 9000.00
WELL DETAILS: 1F-06
+N/-S +E/-W Northing Easting Latittude Longitude
0.00 0.00 5958314.41 539987.01 70' 17' 49.383 N 149' 40' 34.305 W
Sec MD Inc Azi
1 9000.00 58.38 32.63
2 9030.00 58.45 32.76
3 9055.00 65.95 32.76
4 9126.57 91.00 32.76
5 9196.00 101.25 34.59
6 9286.00 88.55 30.01
7 9366.00 90.95 41.77
8 9966.00 90.00 131.77
9 10246.00 91.34 173.75
10 10396.00 86.09182.85
11 10596.00 88.61 169.07
12 10846.00 89.28 186.56
13 10946.00 90.01 179.59
14 11046.00 94.02 185.34
15 11196.00 93.95174.81
16 11346.00 91.19 184.95
17 11496.00 90.81 174.46
18 11736.00 90.16 186.44
19 12100.00 89.53 168.25
2
H
SECTION DETAILS
TVDss +N/-S +E/-W
6013.31 5054.49 3435.99
6029.02 5075.99 3449.79
6040.68 5094.58 3461.75
6054.86 5153.08 3499.39
6047.46 5210.46 3537.61
6039.79 5286.10 3585.39
6040.14 5350.79 3632.20
6033.79 5381.20 4171.50
6030.37 5137.82 4296.81
6033.74 4988.13 4301.26
6043.02 4789.34 4315.33
6047.65 4540.54 4324.84
6048.27 4440.74 4319.47
6044.74 4340.96 4315.18
6034.28 4191.54 4314.99
6027.53 4041.90 4315.28
6024.91 3892.13 4316.05
6022.87 3652.59 4314.16
6023.85 3290.51 4330.93
Dleg TFace VSect
0.00 0.00-5054.49
0.44 57.74-5075.99
30.00 0.00-5094.58
35.00 0.00-5153.08
15.00 10.00-5210.46
15.00-160.00-5286.10
15.00 78.50-5350.79
15.00 90.00-5381.20
15.00 88.00-5137.82
7.00 120.00-4988.13
7.00 -80.00-4789.34
7.00 88.00-4540.54
7.00 -84.00-4440.74
7.00 55.00-4340.96
7.00 -90.00-4191.54
7.00 105.00-4041.90
7.00 -92.00-3892.13
5.00 93.00-3652.59
5.00 -92.00-3290.51
6001
5401
0
0
N 4801
i`
Z 4201
f0 3601
3001
Baker Hughes S
F-06
104
7F
T
KOP
R........'
I
I
I
TD... _
..1F-p6
Np04
A O 8� N Oo A O
0 0 0 0 0 0 0
0 0 0 0 0 0 0
West( -)/East(+) (1200 usfVin)
Vertical Section at 180.00' (400 usft/in)
Conoc6Phillips
6400-
6000-
5600-
5200—
C
w 4800—
O -
7
O
O
4400—
L
O
Z 4000—
O
fn 3600-
3200-
2800-
2400-
2000—
Project: Kuparuk River Unit-1
Site: Kuparuk 1F Pad
Well: 1F-06
Wellborn: 1F-06L1
Plan: IF-O6L1 wp04
T M Azimuths to True North
Magnetic North: 15.06"
Magnetic Field
Strength: 57261.3nT
p .
DiAngle: 8066"
Date: 2022
Model: BGGM2021
WELLBORE DETAILS: 1F-06L1
REFERENCE INFORMATION
Coorrtia) Reference: Well True North
Verticcall (TVTVD) Sea Reference: Mean Sea Level
Section VS Reference: Slot - O.00N, 0.00E
Measured Depth Reference: 1F-06 @ 115.00usft (1F-06)
Calculation Method: Minimum Curvature
Parent Wellbore: 1 F-06
Tie on MD: 9000.00
West( -)/East(+) (800 usft/in)
Baker Hughes L-1
N N N W W A A A Cn Cn 0) M O v V
co N O O A c0 N CA C. A c0 N CA O A 00 N O
O O O O O O O O O O O O O O O O O O
O O O O O O O O O O O O O O O O O O
7
. 60
F-0
L1
p0
9
............ :
�s'
J
(n
6
,
m
^
AN-2a
119
1F-19
1PB1
4
f62
Oh
,0
E
3
6182
.0
1
1
TIP
.....................::.
62
80p0
60
0
0
T
m
6162
1F-19
1
1E-15A..
W
6256
Sop
Xo
00
O
0
Q
60
o°
60
LL
14600
1F-061-1 wP.......
D............................
p24
T'
000 �o
OU-
...,
A
O
M
�A
000
q
0
0
6000
o
00
0
co
4
v
h
IE-14L
LL
^
�1
4`,�_
0o O N N A A A Cn Cn T T Nk* V -Aw w
C. N CA O A Co N CA O A 00 N CA O A 00 N CA
O O O O O O O O O O O O O O O O O O
O O O O O O O O O O O O O O O O O
West( -)/East(+) (800 usft/in)
—6400
—6000
—5600
1
—5200
60p0
Cn
—4800 0
- 5
Z
4400 a
t
00
—4000 0
—3600
00
�O
—3200
—2800
—2400
—2000
ConocoPhillips
NADConversion
Kuparuk River Unit _1
Kuparuk 1 F Pad
1 F-06
1 F-06L1
Plan: 1 F-06L1 wp04
Standard Planning Report
01 March, 2022
Baker Hughes 5�1
r Baker Hughes
CbncooPhillips Planning Report Baker Hughes
Database:
EDT 15 Alaska Prod
Local Co-ordinate Reference:
Well 1 F-06
Company:
NADConversion
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit_1
MD Reference:
1 F-06 @ 115.00usft (1 F-06)
Site:
Kuparuk 1F Pad
North Reference:
Grid
Well:
1 F-06
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 F-06L1
Design:
1F-06L1 wp04
Project Kuparuk River Unit-1, 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 1F Pad
Site Position: Northing: 5,958,365.15 usft Latitude: 70° 17' 49.903 N
From: Map Easting: 539,591.86usft Longitude: 149° 40' 45.817 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence: 0.30 °
Well 1 F-06
Well Position +N/-S 0.00 usft Northing: 5,958,314.41 usft Latitude: 7' 49.383 N
+E/-W 0.00 usft Easting: 539,987.01 usft Longitude: 149° 40' 34.305 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1 F-06L1
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
A M r) M (°) A (nT) JOILMM
BGGM2021 4/1/2022 15.06 80.66 57,262.11
Design
1 F-061-1 wp04
Audit Notes:
Version:
Phase:
PROTOTYPE
Tie On Depth: 9,000.00
Vertical Section:
Depth From (TVD)
+N/-S
+E/-W Direction
(usft)
(usft)
(usft) (°)
0.00
0.00
0.00 180.00
3/1/2022 10:08:32AM Page 2 COMPASS 5000.15 Build 91E
V�- Baker Hughes
ConocoPhillips Planning Report Baker Hughes
Database:
EDT 15 Alaska Prod
Company:
NADConversion
Project:
Kuparuk River Unit
_1
Site:
Kuparuk 1 F Pad
Well:
1 F-06
Wellbore:
1 F-06L1
Design:
1F-061-1 wp04
Plan Sections
Measured
TVD Below
Depth
Inclination Azimuth
System
(usft)
(°)
(°)
(usft)
9,000.00
58.38
32.63
6,013.31
9,030.00
58.45
32.76
6,029.02
9,055.00
65.95
32.76
6,040.68
9,126.57
91.00
32.76
6,054.86
9,196.00
101.25
34.59
6,047.46
9,286.00
88.55
30.01
6,039.79
9,366.00
90.95
41.77
6,040.14
9,966.00
90.00
131.77
6,033.79
10,246.00
91.34
173.75
6,030.37
10,396.00
86.09
182.85
6,033.74
10,596.00
88.61
169.07
6,043.02
10,846.00
89.28
186.56
6,047.65
10,946.00
90.01
179.59
6,048.27
11,046.00
94.02
185.34
6,044.74
11,196.00
93.95
174.81
6,034.28
11,346.00
91.19
184.95
6,027.53
11,496.00
90.81
174.46
6,024.91
11,736.00
90.16
186.44
6,022.87
12,100.00
89.53
168.25
6,023.85
Local Co-ordinate Reference: Well 1F-06
TVD Reference: Mean Sea Level
MD Reference: 1 F-06 @ 115.00usft (1 F-06)
North Reference: Grid
Survey Calculation Method: Minimum Curvature
Dogleg
Build
Turn
+NI-S
+E/-W
Rate
Rate
Rate
TFO
(usft)
(usft)
(°/100usft)
(°/100usft)
(°I100usft)
(°)
5,054.49
3,435.99
0.00
0.00
0.00
0.00
5,075.99
3,449.79
0.44
0.23
0.43
57.74
5,094.58
3,461.75
30.00
30.00
0.00
0.00
5,153.08
3,499.39
35.00
35.00
0.00
0.00
5,210.46
3,537.61
15.00
14.77
2.64
10.00
5,286.10
3,585.39
15.00
-14.12
-5.09
-160.00
5,350.79
3,632.20
15.00
3.01
14.70
78.50
5,381.20
4,171.50
15.00
-0.16
15.00
90.00
5,137.82
4,296.81
15.00
0.48
14.99
88.00
4,988.13
4,301.26
7.00
-3.50
6.07
120.00
4,789.34
4,315.33
7.00
1.26
-6.89
-80.00
4,540.54
4,324.84
7.00
0.27
7.00
88.00
4,440.74
4,319.47
7.00
0.74
-6.96
-84.00
4,340.96
4,315.18
7.00
4.01
5.74
55.00
4,191.54
4,314.99
7.00
-0.04
-7.02
-90.00
4,041.90
4,315.28
7.00
-1.84
6.76
105.00
3,892.13
4,316.05
7.00
-0.26
-7.00
-92.00
3,652.59
4,314.16
5.00
-0.27
4.99
93.00
3,290.51
4,330.93
5.00
-0.17
-5.00
-92.00
Target
3/1/2022 10:08:32AM Page 3 COMPASS 5000.15 Build 91E
r Baker Hughes
CbncooPhillips Planning Report Baker Hughes
Database:
EDT 15 Alaska Prod
Local Co-ordinate Reference:
Well 1 F-06
Company:
NADConversion
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit_1
MD Reference:
1 F-06 @ 115.00usft (1 F-06)
Site:
Kuparuk 1F Pad
North Reference:
Grid
Well:
1 F-06
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 F-06L1
Design:
11F-061-1 wp04
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
V)
(°)
(usft)
(usft)
(usft)
(usft)
(°I100usft)
(°)
(usft)
(usft)
9,000.00
58.38
32.63
6,013.31
5,054.49
3,435.99
-5,054.49
0.00
0.00
5,963,368.40
543,422.66
TIP
9,030.00
58.45
32.76
6,029.02
5,075.99
3,449.79
-5,075.99
0.44
57.74
5,963,389.91
543,436.46
KOP
9,055.00
65.95
32.76
6,040.68
5,094.58
3,461.75
-5,094.58
30.00
0.00
5,963,408.49
543,448.42
9,100.00
81.70
32.76
6,053.17
5,130.81
3,485.06
-5,130.81
35.00
0.00
5,963,444.72
543,471.73
9,126.57
91.00
32.76
6,054.86
5,153.08
3,499.39
-5,153.08
35.00
0.00
5,963,466.99
543,486.06
9,196.00
101.25
34.59
6,047.46
5,210.46
3,537.61
-5,210.46
15.00
10.00
5,963,524.36
543,524.27
9,200.00
100.69
34.38
6,046.70
5,213.70
3,539.83
-5,213.70
15.00
-160.00
5,963,527.59
543,526.49
9,286.00
88.55
30.01
6,039.79
5,286.10
3,585.39
-5,286.10
15.00
-160.04
5,963,599.99
543,572.05
9,300.00
88.97
32.07
6,040.09
5,298.09
3,592.60
-5,298.09
15.00
78.50
5,963,611.98
543,579.26
9,366.00
90.95
41.77
6,040.14
5,350.79
3,632.20
-5,350.79
15.00
78.46
5,963,664.67
543,618.85
9,400.00
90.95
46.87
6,039.57
5,375.10
3,655.94
-5,375.10
15.00
90.00
5,963,688.99
543,642.59
9,500.00
90.89
61.87
6,037.96
5,433.18
3,736.98
-5,433.18
15.00
90.08
5,963,747.06
543,723.62
9,600.00
90.78
76.87
6,036.49
5,468.31
3,830.29
-5,468.31
15.00
90.33
5,963,782.18
543,816.92
9,700.00
90.61
91.87
6,035.27
5,478.09
3,929.52
-5,478.09
15.00
90.55
5,963,791.96
543,916.14
9,800.00
90.40
106.87
6,034.38
5,461.85
4,027.90
-5,461.85
15.00
90.73
5,963,775.73
544,014.51
9,900.00
90.16
121.87
6,033.89
5,420.71
4,118.73
-5,420.71
15.00
90.86
5,963,734.58
544,105.33
9,966.00
90.00
131.77
6,033.79
5,381.20
4,171.50
-5,381.20
15.00
90.94
5,963,695.08
544,158.10
10,000.00
90.18
136.87
6,033.74
5,357.46
4,195.81
-5,357.46
15.00
88.00
5,963,671.34
544,182.41
10,100.00
90.69
151.86
6,032.98
5,276.42
4,253.91
-5,276.42
15.00
88.01
5,963,590.31
544,240.51
10,200.00
91.15
166.85
6,031.37
5,183.12
4,289.07
-5,183.12
15.00
88.12
5,963,497.02
544,275.66
10,246.00
91.34
173.75
6,030.37
5,137.82
4,296.81
-5,137.82
15.00
88.36
5,963,451.72
544,283.40
10,300.00
89.45
177.02
6,030.00
5,084.00
4,301.15
-5,084.00
7.00
120.00
5,963,397.92
544,287.74
10,396.00
86.09
182.85
6,033.74
4,988.13
4,301.26
-4,988.13
7.00
120.02
5,963,302.05
544,287.85
10,400.00
86.14
182.58
6,034.01
4,984.15
4,301.07
-4,984.15
7.00
-80.00
5,963,298.07
544,287.66
10,500.00
87.38
175.68
6,039.66
4,884.38
4,302.60
-4,884.38
7.00
-79.98
5,963,198.31
544,289.18
10,596.00
88.61
169.07
6,043.02
4,789.34
4,315.33
-4,789.34
7.00
-79.59
5,963,103.28
544,301.91
10,600.00
88.62
169.35
6,043.11
4,785.42
4,316.08
-4,785.42
7.00
88.00
5,963,099.36
544,302.66
10,700.00
88.88
176.34
6,045.30
4,686.28
4,328.52
-4,686.28
7.00
87.99
5,963,000.23
544,315.11
10,800.00
89.15
183.34
6,047.02
4,586.36
4,328.80
-4,586.36
7.00
87.84
5,962,900.32
544,315.39
10,846.00
89.28
186.56
6,047.65
4,540.54
4,324.84
-4,540.54
7.00
87.72
5,962,854.50
544,311.42
10,900.00
89.68
182.80
6,048.14
4,486.73
4,320.43
-4,486.73
7.00
-84.00
5,962,800.70
544,307.02
10,946.00
90.01
179.59
6,048.27
4,440.74
4,319.47
-4,440.74
7.00
-83.97
5,962,754.72
544,306.06
11,000.00
92.18
182.69
6,047.23
4,386.78
4,318.40
-4,386.78
7.00
55.00
5,962,700.76
544,304.98
11,046.00
94.02
185.34
6,044.74
4,340.96
4,315.18
-4,340.96
7.00
55.06
5,962,654.95
544,301.77
11,100.00
94.01
181.55
6,040.96
4,287.20
4,311.95
-4,287.20
7.00
-90.00
5,962,601.19
544,298.53
11,196.00
93.95
174.81
6,034.28
4,191.54
4,314.99
-4,191.54
7.00
-90.27
5,962,505.54
544,301.57
11,200.00
93.88
175.08
6,034.01
4,187.56
4,315.34
-4,187.56
7.00
105.00
5,962,501.56
544,301.92
11,300.00
92.05
181.85
6,028.83
4,087.80
4,318.00
-4,087.80
7.00
105.02
5,962,401.80
544,304.59
11,346.00
91.19
184.95
6,027.53
4,041.90
4,315.28
-4,041.90
7.00
105.37
5,962,355.91
544,301.86
11,400.00
91.06
181.18
6,026.47
3,988.00
4,312.39
-3,988.00
7.00
-92.00
5,962,302.02
544,298.98
11,496.00
90.81
174.46
6,024.91
3,892.13
4,316.05
-3,892.13
7.00
-92.07
5,962,206.16
544,302.63
11,500.00
90.79
174.66
6,024.86
3,888.15
4,316.43
-3,888.15
5.00
93.00
5,962,202.18
544,303.01
11,600.00
90.53
179.65
6,023.70
3,788.32
4,321.39
-3,788.32
5.00
93.00
5,962,102.35
544,307.97
11,700.00
90.26
184.64
6,023.01
3,688.42
4,317.64
-3,688.42
5.00
93.06
5,962,002.47
544,304.23
11,736.00
90.16
186.44
6,022.87
3,652.59
4,314.16
-3,652.59
5.00
93.10
5,961,966.64
544,300.75
11,800.00
90.05
183.24
6,022.75
3,588.83
4,308.76
-3,588.83
5.00
-92.00
5,961,902.88
544,295.35
11,900.00
89.88
178.25
6,022.81
3,488.87
4,307.46
-3,488.87
5.00
-92.01
5,961,802.93
544,294.05
12,000.00
89.70
173.25
6,023.18
3,389.17
4,314.87
-3,389.17
5.00
-92.00
5,961,703.25
544,301.46
12,100.00
89.53
168.25
6,023.85
3,290.51
4,330.93
-3,290.51
5.00
-91.98
5,961,604.60
544,317.52
TD
3/1/2022 10:08:32AM Page 4 COMPASS 5000.15 Build 91E
r Baker Hughes
CbncooPhillips Planning Report Baker Hughes
Database: EDT 15 Alaska Prod Local Co-ordinate Reference:
Well 1 F-06
Company: NADConversion TVD Reference:
Mean Sea Level
Project: Kuparuk River Unit_1 MD Reference:
1 F-06 @ 115.00usft
(1 F-06)
Site: Kuparuk 1F Pad North Reference:
Grid
Well: 1 F-06 Survey Calculation Method:
Minimum Curvature
Wellbore: 1 F-06L1
Design: 1F-06L1 wp04
Targets
Target Name
hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing
Easting
Shape (°) (°) (usft) (usft) (usft) (usft)
(usft)
Latitude Longitude
1 F-06L1 T2.8 0.00 351.03 6,025.00 3,893.69 4,329.72 5,962,207.72
544,316.30
70° 18' 27.438 N 149° 38' 27.432 W
plan misses target center by 13.78usft at 11494.96usft MD (6024.93 TVD, 3893.17 N, 4315.95 E)
Point
1F-06L1 T2.6 0.00 351.03 6,038.00 4,915.77 4,311.72 5,963,229.70
544,298.31
70° 18' 37.491 N 149° 38' 27.781 W
plan misses target center by 10.90usft at 10468.69usft MD (6038.12 TVD, 4915.60 N, 4300.83 E)
Point
1F-06L1 T2.2 0.00 351.03 6,030.00 5,050.78 4,310.72 5,963,364.69
544,297.31
70° 18' 38.819 N 149' 38' 27.787 W
plan misses target center by 8.46usft at 10333.23usft MD (6030.66 TVD, 5050.80 N, 4302.29 E)
Point
1F-06L1 T2.4 0.00 351.03 6,048.00 4,379.73 4,324.72 5,962,693.71
544,311.31
70° 18' 32.218 N 149° 38' 27.494 W
plan misses target center by 6.75usft at 11006.54usft MD (6046.97 TVD, 4380.25 N, 4318.07 E)
Point
1F-06L1 T2.5 0.00 351.03 6,048.00 4,589.75 4,324.72 5,962,903.71
544,311.31
70° 18' 34.284 N 149' 38' 27.458 W
plan misses target center by 4.39usft at 10796.61 usft MD (6046.97 TVD, 4589.74 N, 4328.99 E)
Point
1F-06L1 T2.10 0.00 351.03 6,023.00 3,365.65 4,331.71 5,961,679.73
544,318.30
70° 18' 22.245 N 149' 38' 27.464 W
plan misses target center by 28.93usft at 12000.00usft MD (6023.18 TVD, 3389.17 N, 4314.87 E)
Point
1 F-06L1 T2.1 0.00 351.03 6,031.00 5,270.80 4,297.72 5,963,584.69
544,284.31
70° 18' 40.983 N 149° 38' 28.128 W
plan misses target center by 36.90usft at 10120.80usft MD (6032.71 TVD, 5257.83 N, 4263.22 E)
Point
1F-06L1 T2.7 0.00 351.03 6,030.00 4,134.71 4,331.72 5,962,448.72
544,318.30
70° 18' 29.808 N 149° 38' 27.332 W
plan misses target center by 13.52usft at 11253.44usft MD (6030.84 TVD, 4134.31 N, 4318.23 E)
Point
1F-06L1 T2.9 0.00 351.03 6,024.00 3,654.68 4,324.72 5,961,968.73
544,311.30
70° 18' 25.088 N 149° 38' 27.619 W
plan misses target center by 10.32usft at 11732.90usft MD (6022.88 TVD, 3655.67 N, 4314.51 E)
Point
1 F-06L1 T2.3 0.00 351.03 6,044.00 4,762.76 4,317.72 5,963,076.70
544,304.31
70° 18' 35.986 N 149° 38' 27.632 W
plan misses target center by 2.29usft at 10622.71 usft MD (6043.65 TVD, 4763.04 N, 4319.97 E)
Point
1F-06L1 T2.11 0.00 351.03 6,025.00 3,204.64 4,324.71 5,961,518.74
544,311.30
70° 18' 20.662 N 149° 38' 27.696 W
plan misses target center by 86.10usft at 12100.00usft MD (6023.85 TVD, 3290.51 N, 4330.93 E)
Point
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft)M&O Name (in) (in)
12,100.00 6,023.85 2 3/8" 2.375 3.000
Plan Annotations
T
Measured
Vertical
Local Coordinates
Depth
Depth
+N/-S +E/-W
dComment
(usft)
(usft)
(usft) (usft)
111111L Jr
9,000.00
6,013.31
5,054.49 3,435.99
TIP
9,030.00
6,029.02
5,075.99 3,449.79
KOP
12,100.00
6,023.85
3,290.51 4,330.93
TD
3/1/2022 10:08:32AM Page 5 COMPASS 5000.15 Build 91E
ConocoPh i I I i ps
ConocoPhillips Alaska
Inc _Kuparuk
Kuparuk River Unit _1
Kuparuk 1 F Pad
1 F-06
1 F-06L1
1 F-06L1 wp04
Anticollision Summary Report
01 March, 2022
Baker Hughes 5�1
Baker Hughes
ConocoPhillips Anticollision Summary Report Baker Hughes 11
Company:
ConocoPhillips Alaska Inc Kuparuk
Project:
Kuparuk River Unit-1
Reference Site:
Kuparuk 1F Pad
Site Error:
0.00 usft
Reference Well:
1F-06
Well Error:
0.00 usft
Reference Wellbore
1F-06L1
Reference Design:
1F-06L1 wp04
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 F-06
Mean Sea Level
1 F-06 @ 115.00usft (1 F-06)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Reference
1 F-061-1 wp04
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft
Error Model:
ISCWSA
Depth Range:
9,000.00 to 12,100.00usft
Scan Method:
Tray. Cylinder North
Results Limited by:
Maximum ellipse separation of 3,000.00usft
Error Surface:
Combined Pedal Curve
Warning Levels Evaluated at: 2.79 Sigma
Casing Method:
Added to Error Values
Survey Tool Program Date 3/1/2022
From To
(usft) (usft) Survey (Wellbore)
200.00 9,000.00 1 F-06 (1 F-06)
9,000.00 12,100.00 1 F-061-1 wp04 (1 F-061-1)
Tool Name
Description
FINDER -MS
SDC Finder multishot
MWD OWSG
OWSG MWD - Standard
Summary
Reference
Offset
Distance
Measured
Measured
Between
Between
Separation Warning
Site Name
Depth
Depth
Centres
Ellipses
Factor
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 1A Pad
1A-28 - 1A-28 - 1A-28
9,350.00
10,025.00
818.88
683.35
6.042 CC, ES, SF
Kuparuk 1F Pad
1 F-05 - 1 F-05 - 1 F-05
12,100.00
7,710.00
2,725.07
2,566.09
17.141 CC, ES, SF
1 F-06 - 1 F-06 - 1 F-06
9,311.26
9,350.00
155.05
152.54
61.997 CC, ES, SF
1F-19 - 1F-19L1 - 1 F-191-1
10,119.35
11,265.00
168.25
158.25
16.825 CC, ES, SF, 10 ft. DISPNSA
1 F-19 - 1 F-19L1-01 - 1 F-191-1-01
10,769.77
10,661.00
117.79
107.79
11.779 CC, ES, SF, 10 ft. DISPNSA
1F-19- 1F-19L1PB1 - 1F-19L1PB1
10,124.36
11,225.00
155.35
87.06
2.275 Normal Operations, CC
1F-19- 1F-19L1PB1 - 1F-19L1PB1
10,173.24
11,175.00
156.89
84.98
2.182 Normal Operations, ES
1F-19- 1F-19L1PB1 - 1F-19L1PB1
11,362.32
9,950.00
266.53
136.13
2.044 Normal Operations, SF
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
31112022 9:57:49AM Page 2 COMPASS 5000.15 Build 91E
VP, Baker Hughes
ConocoPhillips Anticollision Summary Report Baker Hughes
Company:
Project:
Reference Site:
Site Error:
Reference Well:
Well Error:
Reference Wellbore
Reference Design:
ConocoPhillips Alaska Inc Kuparuk
Kuparuk River Unit-1
Kuparuk 1 F Pad
0.00 usft
1 F-06
0.00 usft
1 F-06L1
11F-061-1 wp04
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 F-06
Mean Sea Level
1 F-06 @ 115.00usft (1 F-06)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Reference Depths are relative to 1 F-06 @ 115.00usft (1 F-06) Coordinates are relative to: 1 F-06
Xset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4
central Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: 0.30'
Ladder Plot
3000
-----------------------J--------------------------------
2250
2
1500
m
750
-------- - - - - ---- - - - - ---- - - - - -- - - - -
-
- ------
0
0 2000 4000 6000 8000 10000 12000
Measured Depth
LEGEND
to-2fi, 1A-2B, 1A-28 V1 x iFOB, 1FO6, 1FO6 V1 1F19, 1F19L1O1, 1F19 - VD
1 FOS-5,iP05V1 tF19,1F19L1, tF19L1 VO 1 F19, 1 F190-1, 1F19LiP91V0
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
31112022 9:57:49AM Page 3 COMPASS 5000.15 Build 91E
W, Baker Hughes
ConocoPhillips Anticollision Summary Report Baker Hughes
Company:
Project:
Reference Site:
Site Error:
Reference Well:
Well Error:
Reference Wellbore
Reference Design:
ConocoPhillips Alaska Inc Kuparuk
Kuparuk River Unit-1
Kuparuk 1 F Pad
0.00 usft
1 F-06
0.00 usft
1 F-06L1
1 F-061-1 wp04
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 F-06
Mean Sea Level
1 F-06 @ 115.00usft (1 F-06)
True
Minimum Curvature
2.00 sigma
EDT 15 Alaska Prod
Offset Datum
Reference Depths are relative to 1 F-06 @ 115.00usft (1 F-06) Coordinates are relative to: 1 F-06
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1983, Alaska Zone 4
Central Meridian is 150° 0' 0.000 W Grid Convergence at Surface is: 0.30'
Separation Factor Plot
9.00
- - - - - - - -
- - - - - - - - - - - -
- - - - - - - - - - - -
- - - - - - -
-
- -
- - - - - - - - - -
CO 6.00
it
i
i
i
i
LL
Q-
- - - - -i- - - - - -
- - - - - -i- - - - - -
- - - - - - - - - - -
- - - - - -
- - - -
- - - - - - - - -
N
Normal Operations
3.00
Caution - Monitor Cl osely
Take Immediate Action
STOP Drilling
0.00
0 2500 5000 7500 10000 12500
Measured Depth
LEGEND
9, 1F19L101, 1F19-1 VO
—04-- iP05, 1P05, 1FL5 Vt } 1F19, I-L1, 1F19L1 VO iF19, iF19LiP81, 1F190-V0
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
31112022 9:57:49AM Page 4 COMPASS 5000.15 Build 91E
TRANSMITTAL LETTER CHECKLIST
WELL NAME: KRU 1 F-061_1
PTD: 222-028
X Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: Kuparuk River
POOL: Kuparuk River Oil
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. 182-145 API No. 50-029-20820-00-00
x
(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
Pilot Hole
well 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.
Spacing
Approval to produce/inject is contingent upon issuance of
Exception
a conservation order approving a spacing exception.
( ) as 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-
well ( ) until after ( )
Conventional
has designed and implemented a water well testing program to provide
Well
baseline data on water quality and quantity.
( ) 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
X
by ( ) 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,
X
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 1 F-06L1 Program DEV Well bore seg
PTD#: 2220280 Company ConocoPhillips Alaska, Inc. Initial Class/Type
DFV / PFND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
-Perroitfeeattached ----------------------------------------------
NA,
---------------------------------------------------------------------------
2
-Leasenumberappropriate----------------------------------------
Yes---------------------------------------------------------------------------
3
-Uniquewellnameandnumber-------------------------------- - - - - --
Yes
---------------------------------------------------------------------------
4
-WellJocatedinadefinedpnol-------------------------------- - - - - --
Yes
---------------------------------------------------------------------------
5
-WellJocated proper distance from drilling unit -boundary- - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
6
-WellJocatedproperdistancefromotherweUs------------------------ - - - - --
Yes
---------------------------------------------------------------------------
7
Sufficient acreage available in drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
8
-Ifdeviated,iswepbore-pJatincluded------------------------------ - - - - --
Yes
-------Directional_pJanviewincluded,no-land plat -------------------------------------------
9
-Qperatoronlyafferted-party --------------------------------- - - - - --
Yes
---------------------------------------------------------------------------
10
-Qperator bas appropriate b-ond-in force - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
11
-Perroitcanbeissuedwifhoutconservationorder----------------------- - - - - --
Yes
---------------------------------------------------------------------------
Appr Date
12
-Perroitcan be issued without administrative approval - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
13
-Can permit be approved before 157day wait - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
DLB 3/9/2022
14
-WellJocatedwithinareaandstrata authorizedby-InjectiQnQrder#1put10#incomments)(Forserv-NA----------------------------------------------------------------------------
15
-Allwellswithin1/4mile area ofreviewidentified(For service -well only) -----------------
NA,
---------------------------------------------------------------------------
16
-Pre-produced injectQr', duration ofpre-prQd_actionLess tban3-roQnths(For serviceweporgy) -----
NA.
---------------------------------------------------------------------------
17
-hlonconven.-gascQnforrostoAS31_Q5.0300.1.A).G.2A-D)------------------------
NA,
---------------------------------------------------------------------------
18
Conductor string provided-----------------------------------------
-NA
---------------------------------------------------------------------------
Engineering
19
Surface casing -protects all known USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
-NA
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - -
20
CMT vol_adequate to circulate on -conductor & surf csg - - - - - - - - - - - - - - - - - - - - - - - - -
-NA
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
21
CMT vol_adequate to tie-in Inng_str[ng to -surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - - -
-NA
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
22
CMT will cover all known productive horizons - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
-fro-
- - - - - - - Productive -interval wip be completed with uncemented slotted production liner- - - - - - - - - - - - - - - - - - - - - - - -
23
Casing designs adequate for_C, T,_R & permafrost - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
24
Adequate -tankage -or reserve - pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - Rig has steel tanks;_aJl waste to approved disposal wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
25
-Yore-drill,has a10-403for_abandonmentbeen approved ------------------------NA---------------------------------------------------------------------------
26
Adequate-wel.lbore-separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
Yes
- - - - - -- Anti-copistionanalysis complete; no majQrrisk-failures-------------------------------------
27
_If diverfer required,-cloes it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
-NA
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Appr Date
28
-Drilling fluid -program schematic & equip listadequate- - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - Max format Qn_pressLire is 3361_psig(10 5ppg EMW); w1llddllw/8 6_ppg EMW-and maintain overbal wif IVIRD - - - -
VTL3/9/2022
29
_BOPJ=s,-do they meet -regulation --------------------------------------YQs---------------------------------------------------------------------------
30
-ROPE-press rating appropriate; testtQ(putpsigir-comments)---------------------
YQs-------MPSPis2747psig;
will test_BOPato3500psig----------------------------------------
31
Choke_manifoldcompGes_WAPI RP-53(May84)----------------------------
Yes---------------------------------------------------------------------------
32
_Work willoccur_withQutQperatiQnshutdown------------------------- - - - - --
Yes---------------------------------------------------------------------------
33
-Is presence of H2S. gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes
_ _ _ _ _ _ _ H2S measures required _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - -
34
_MecbanicalconditionofweUs_withinAORverified(For_servicewellonly)-----------------NA---------------------------------------------------------------------------
35
-Perroitcan beissuedw/o hydrQgensulfide measures---------------------------No--------Wellson1F-Pad
are H2S-bearing.Jl2S measures required.---------------------------------
Geology
36
-Data presented Qnpotential Qverpressure-zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --------------------------------------------
ApprDate
37
Seismic-analysis-ofshal.low-gas zones----------------------------------
-NA
---------------------------------------------------------------------------
DLB 3/9/2022
38
Seabedconditionsurvey(ifoff-shore)------------------------------------NA---------------------------------------------------------------------------
39
Contact name/phone for weekly progress reports [exploratory- only] - - - - - - - - - - - - - - - - - -
-NA-
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
JLC 3/11/2022 JMP 3/11/22
