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By
Reviewed :
OIL AND GAS CONSERVATION COMMISSION ReRe awedSuprZtiZa3
BOPS Test Report for: MILNE PT UNIT I-39 P.IComm
Contractor/Rig No.: Hilcorp Innovation - PTD#: 2200600 ' DATE: 8/22/2020 ' Inspector Guy Cook - Insp Source
Operator: Hilcorp Alaska, LLC Operator Rep: S BarberIC Monteque Rig Rep: M Vanhoose/E Evans Inspector
Type Operation: DRILL Sundry No:
Type Test: INIT
Test Pressures:
Rams: Annular: Valves: MASP:
250/3000 250/3000 - 250/3000 - 1338
TEST DATA
Inspection No: bopGDC200821095604
Related Insp No:
MISC. INSPECTIONS:
MUD SYSTEM:
ACCUMULATOR SYSTEM:
CHOKE MANIFOLD:
P/F
P/F
Visual
Alarm
Time/Pressure P/F
Location Gen.:
P
Trip Tank
P
P
System Pressure 3100
P
Housekeeping:
P
Pit Level Indicators
- P_
P
Pressure After Closure 1450
P "
PTD On Location
P
Flow Indicator
P
P
200 PSI Attained 26
P
Standing Order Posted
P
Meth Gas Detector
P
P
Full Pressure Attained _-_98
P "
Well Sign
- P
H2S Gas Detector
P
P
Blind Switch Covers: All Stations
- P
Drl. Rig
P
MS Misc
NA
-NA
Nitgn. Bottles (avg): 62358--_
P_
Hazard Sec.
P
P -
ACC Misc 0
NA
Misc
NA
0
NA
FLOOR SAFTY VALVES:
BOP STACK:
CHOKE MANIFOLD:
Quantity
P/F
Quantity
Size
P/F
Quantity
P/F
Upper Kelly
-1
-P-
Stripper
0
-
NA
No. Valves 15
P
Lower Kelly
1
FP ✓
Annular Preventer
1
13 5/8" 5000-
_P
Manual Chokes -I _ _
P
Ball Type
2 "
P
#1 Rams
1
2 7/8" x 5.5" -
P
Hydraulic Chokes I -
P
Inside BOP
1
P
#2 Rams
1
Blinds
P
CH Misc 0
NA
FSV Misc
0
NA
#3 Rams
1
2 7/8" x 5.5"
P -
#4 Rams
0
NA
#5 Rams
-
0
--_
NA
INSIDE REEL VALVES:
#6 Rams
0
NA
(Valid for Coil Rigs Only)
Choke Ln. Valves
1 "
3 1/8" 5000 •
P
Quantity
P/F
HCR Valves
2
3 1/8115000
FP
Inside Reel Valves 0
NA
Kill Line Valves
2
3 1/8" 5000 -
P
Check Valve
_0
_
NA
BOP Misc
0
NA
Number of Failures: 2 ✓ Test Results Test Time 15
Remarks: 3.5 and 5" test joints used for testing. Lower IBOP failed. Changed out and tested for a pass. HCR choke failed. Serviced
valve and retested for a pass. Superchoke was Tested by flowing through it with the rig pumps at 3bbls/minute and V
closing/opening the choke. The manual choke was not tested by flowing through it, but by pressuring up on the closed choke
and slowly letting it bleed down by working the choke.
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-64-00Well Name/No. KUPARUK RIV UNIT 1E-20L1Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200060Operator ConocoPhillips Alaska, Inc.MD11337TVD6186Current Status1-OIL4/14/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC2/24/2020 Electronic File: 1E-20L1 EOW - NAD83.pdf32051EDDigital DataC2/24/2020 Electronic File: 1E-20L1 EOW - NAD83.txt32051EDDigital DataC2/24/2020 Electronic File: 1E-20L1 MD NAD27.pdf32051EDDigital DataC2/24/2020 Electronic File: 1E-20L1 MD NAD27.txt32051EDDigital Data0 0 2200060 KUPARUK RIV UNIT 1E-20L1 LOG HEADERS32051LogLog Header ScansC2/28/20207799 11337 Electronic Data Set, Filename: 1E-20L1 GAMMA RES.las32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 2MD Final.cgm32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5MD Final.cgm32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5TVDSS Final.cgm32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 2MD Final.pdf32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5MD Final.pdf32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5TVDSS Final.pdf32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 EOW - NAD83.pdf32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 EOW - NAD83.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 MD NAD27.pdf32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 MD NAD27.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 Survey Listing.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 Surveys.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1_Final Surveys.csv32105EDDigital DataTuesday, April 14, 2020AOGCCPage 1 of 31E-20L1 GAMMA RES.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-64-00Well Name/No. KUPARUK RIV UNIT 1E-20L1Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200060Operator ConocoPhillips Alaska, Inc.MD11337TVD6186Current Status1-OIL4/14/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:2/4/2020Release Date:1/17/2020C2/28/2020 Electronic File: 1E-20L1_25_tapescan_BHI_CTK.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1_5_tapescan_BHI_CTK.txt32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1_output.tap32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 2MD Final.tif32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5MD Final.tif32105EDDigital DataC2/28/2020 Electronic File: 1E-20L1 5TVDSS Final.tif32105EDDigital Data0 0 2200060 KUPARUK RIV UNIT 1E-20L1 LOG HEADERS32105LogLog Header ScansTuesday, April 14, 2020AOGCCPage 2 of 3
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-64-00Well Name/No. KUPARUK RIV UNIT 1E-20L1Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200060Operator ConocoPhillips Alaska, Inc.MD11337TVD6186Current Status1-OIL4/14/2020UICNoCompliance Reviewed By:Date:Tuesday, April 14, 2020AOGCCPage 3 of 3M. Guhl 4/14/2020
DLB 04/09/2020
DSR-4/9/2020
VTL 4/14/20
Baker 2�1 PRINT DISTRIBUTION LIST
Hughes
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME 1E -20L1
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick. Ride rCa)_bakerhughes. com
STATUS Final Replacement:
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
1 BP North Slope.
EOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 lConocoPhillips Alaska Inc.
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage, AK 99510
3 ExxonMobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4I State of Alaska - AOGCC
Attn: Natural Resources Technician If
1333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR -Division of Oil & Gas ***
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
*** Stamp "confidential" on all material deliver to DNR
6I BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
220005
32105
Please sign and return one copy of this transmittal form to:
ConocoPhillips Alaska, Inc.
Tom Osterkamp (WNS Petroleum Technician)
700 G Street.
Anchorage, Alaska 99510
to acknowledge receipt of this data.
LOG TYPE GR - RES
LOG DATE January 29, 2020
TODAYS DATE February 27, 2020
Revision
No Details:
Rev. Requested by: ---
FIELD /
FINAL
CD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
I
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(Compass)
_F07 PRINTS
# OF COPIES
# OF COPIES
1# OF COPIES
TOTALS FOR THIS PAGE: 0 1 2 0 0
32 05 1
Letter of Transmittal
Baker Hughes V Date:
February 21, 2020
From:
Abby Bell Harvey Finch
AOGCC Baker Hughes
333 West 7th Ave, Suite 100 795 East 94th Avenue
Anchorage, Alaska 99501 Anchorage, Alaska 99515
3lease find enclosed the directional survey data for the following well(s):
1E -20L1
1E -20L1-01
RECEIVED
FEB 2 4 2020
AOGCC
(2) Total prints
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Harvey Finch
Baker Hughes
Wellplanner
Harvey.Finch@bakerhughes.com
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A
THE STAT,
V I I a
I W wal
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E -20L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 220-006
Alaska Oil and Gas
Conservation Commission
Surface Location: 4869' FNL, 224' FEL, SEC. 16, TI IN, RI OE, UM
Bottomhole Location: 912' FNL, 1167' FEL, SEC. 22, TI IN, R1 OE, UM
Dear Mr. Ohlinger:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Enclosed is the approved application for the permit to redrill the above referenced service well.
The permit is for a new wellbore segment of existing well Permit No. 183-005, API No. 50-029-
20895-00-00. Production should continue to be reported as a function of the original API number
stated above.
Per Statute AS 3 1.05.03 0(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, �O
Pesie L. Chmielowski
Commissioner
DATED this day of January, 2020.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAG 25.005
RECEIVED
1 4 2020
C% C
1 a. Type of Work: •
Drill ❑ Lateral Q
Redrill ❑ Reentry ❑
1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑
Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone 2 •
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
1c. Specify if well is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
5. Bond: Blanket Q . Single Well ❑
Bond No. 5952180 •
11. Well Name and Number:
KRU 1E -20L1
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth:
MD: 11300' TVD: 6200'
12. Field/Pool(s):
Kuparuk River Field /
Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
Surface: 4869' FNL, 224' FEL, Sec 16, T11 N, R1 OE, UM
Top of Productive Horizon:
3296' FNL, 1256' FEL, Sec 15, T11N, R1 OE, UM
Total Depth:
912' FNL, 1167' FEL, Sec 22, T11 N, R10E, UM
7. Property Designation:
ADL 25651
8. DNR Approval Number:
ALK 469
13. Approximate Spud Date:
1/20/2020
9. Acres in Property:
2560
14. Distance to Nearest Property:
17300'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 550300 y- 5960000 • Zone- 4
10. KB Elevation above MSL (ft): 106'
GL / BF Elevation above MSL (ft): 67'
15. Distance to Nearest Well Open
to Same Pool: 324', 1 E-03
16. Deviated wells: Kickoff depth: 7938' • feet
Maximum Hole Angle: 101 degrees
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Downhole: 3034 • Surface: 2412
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" 4.6# L-80 ST -L 1950'
9350' 6185' 11300' • 6200' Slotted Liner
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
8650' 6756' N/A 8538' 6668' 7980'
Casing Length Size Cement Volume MD TVD
Conductor 76' 16" 290 sx AS II 110' 110'
Surface 2347' 10-3/4" 1300 sx AS 111 &235 sx AS 1 2380' 2172'
Production 8591' 7" 1050 sx Class G 8622' 6734'
Perforation Depth MD (ft): 7945'- 8094', 8349' - 8362', Perforation Depth TVD (ft): 6210'- 6325', 6521'- 6532',
8382' - 8410' 6547'- 6569'
Hydraulic Fracture planned? Yes❑ No 2
20. Attachments: Property Plat ❑ BOP Sketch
Diverter Sketch
Drilling Program
B Seabed Report
Time v. Depth Plot
B Drilling Fluid Program
Shallow Hazard Analysis
B 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: James Hayes
Authorized Name: James Ohlinger Contact Email: ,James.C.Ha eS COP.COM
Authorized Title: Staff CTD Engineer Contact Phone: 265-6927
Authorized Signature r Date: ��.3/Z c
Commission Use Only
Permit to Drill �-}j���� /
Number: ��-t/-(�
API Number /
50-
Permit Approval �
hh1
Vv
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, as hydrates, or gas contained in shales:
Other: r<$f I^�SSvr� �� oo `�' Sam les re 'd: Yes ❑ No[✓� Mud log req'd: Yes[--] No Q/
q_,� YL(/lCT y� r� �rvy �7 �J rCs�v✓C 2 asure . Yes [l No L1 Directional svy req'd: Yes t/ No❑ ,
Spacing exception req'd: Yes ❑ No[o/ Inclination -only svy req'd: Yes ❑ No[f
Post initial injection MIT req'd: Yes ❑ No❑—
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
v'TL/��/a Q Submit Form and
Form 1 Revised 5/2017
This,pp
is valid for 24 months from the date of approval 2 0 ( a ments in Duplicate
x,6f R'� IN A
r ��
Conocophillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
December 19, 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 a dual lateral out of the KRU 1 E-20
(PTD# 183-005) using the coiled tubing drilling rig, Nabors CDR3-AC.
To account geological p for eolo ical uncertainties ConocoPhillips requests a variance from the requirements of 20 AAC
25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being
limited to 500' from the original point.
The CTD objective will be to drill four laterals (1 E-201_1 & 1 E-201-1-01), targeting the Kuparuk C -sand intervals.
The work is scheduled to begin Feb/Mar 2020.
Attached to this application are the following documents:
— Permit to Drill Application Forms (10-401) for 1 E-201_1 & 1 E-201-1-01
— Detailed Summary of Operations
— Directional Plans for 1 E-201_1 & 1 E-201_1-01
— Current wellbore schematic
— Proposed wellbore schematic
If you have any questions or require additional information, please contact me at 907-265-6927.
Sincerely,
James Hayes
Coiled Tubing Drilling Enginer
ConocoPhillips Alaska
Kuparuk CTD Laterals 1USORSA"MA
1E-201-1 & 1 E -20L1-01
Application for Permit to Drill Document ;R C
1.
Well Name and Classification...........................................................................................................2
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))......................................................................................................................2
2.
Location Summary.............................................................................................................................2
(Requirements of 20 AAC 25.005(c)(2))......................................................................................................................................................2
3.
Blowout Prevention Equipment Information...................................................................................2
(Requirements of 20 AAC 25.005(c)(3)).....................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure....................................................................2
(Requirements of 20 AAC 25.005(c)(4)).....................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests.....................................................................2
(Requirements of 20 AAC 25.005(c)(5))......................................................................................................................................................2
6.
Casing and Cementing Program......................................................................................................3
(Requirements of 20 AAC 25.005(c)(6)).. ....................................................................................................................................................
3
7.
Diverter System Information.............................................................................................................3
(Requirements of 20 AAC 25.005(c)(7))......................................................................................................................................................3
8.
Drilling Fluids Program.....................................................................................................................3
(Requirements of 20 AAC 25.005(c)(8))......................................................................................................................................................3
9.
Abnormally Pressured Formation Information...............................................................................4
(Requirements of 20 AAC 25.005(c)(9))......................................................................................................................................................4
10.
Seismic Analysis................................................................................................................................4
(Requirements of 20 AAC 25.005(c)(10))....................................................................................................................................................4
11.
Seabed Condition Analysis...............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))....................................................................................................................................................4
12.
Evidence of Bonding.........................................................................................................................4
(Requirements of 20 AAC 25.005(c)(12))....................................................................................................................................................4
13.
Proposed Drilling Program...............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))....................................................................................................................................................4
Summaryof Operations..................................................................................................................................................
4
LinerRunning..................................................................................................................................................................
6
14.
Disposal of Drilling Mud and Cuttings.............................................................................................6
(Requirements of 20 AAC 25.005(c)(14))....................................................................................................................................................
6
15.
Directional Plans for Intentionally Deviated Wells..........................................................................6
(Requirements of 20 AAC 25.050(b)). ..................................................... ........................... .......................................................................
6
16.
Attachments.......................................................................................................................................6
Attachment 1: Directional Plans for 1 E -20L1 & 1 E-201-1-01 laterals..............................................................................
6
Attachment 2: Current Well Schematic for 1 E-20...........................................................................................................
6
Attachment 3: Proposed Well Schematic for 1 E-201-1 & 1 E -20L1-01 laterals................................................................
6
Page 1 of December 31, 2019
PTD Application: 1 E-201_1 & 1 E-201_1-01
1. Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1E-201_1 & 1E-201_1-01. All laterals will be classified as
"Development -Oil" wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 1 E-201_1 & 1 E-201-1-01.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the
maximum formation pressure in the area of 3,034 psi in 1 D-03 (i.e. 9.4 ppg EMW), the maximum
potential surface pressure in 1 E-20, assuming a gas gradient of 0.1 psi/ft, would be 2,412 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 1 E-20 was measured to be 2,728 psi (8.4 ppg EMW) on 7/4/2016. The
maximum downhole pressure in the 1 E-20 vicinity is to the west in the 1 D-03 injector at 3,034 psi (9.4 ppg
EMW) from March of 2016.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Wells on 1 E pad have injected gas, so there is a chance of encountering free gas while drilling the 1 E-20
laterals. If significant gas is detected in the returns the contaminated mud can be diverted to a storage tank
away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1 E-20 laterals will be losses to the formation. Managed
pressure drilling (MPD) target pressure will be reduced in order to manage losses to the formation.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 E-20 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 December 31, 2019
PTD Application: 1 E-201_1 & 1 E-201_1-01
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
Btm MD
MD
MD
TVDSS
TVDSS
Conductor
16"
65.0
H-40
Welded
34'
2-3/8", 4.7#, L-80, ST -L slotted liner;
1 E -20L1
9350'
11300'
6079'
6094'
aluminum billet on to
45.5
K-55
BTC
33'
2380'
2-3/8", 4.7#, L-80, ST -L slotted liner;
1E -20L1-01
7745'
11300' .
6188'
6037`
SLT on to
Existing Casing/Liner Information
Category
OD
Weight
Grade
Connection
Top MD
Btm MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
65.0
H-40
Welded
34'
110'
34'
110'
1640
670
Surface
10-3/4"
45.5
K-55
BTC
33'
2380'
33'
2172'
3580
2090
Production
7"
26.0
K-55
BTC
31'
8622'
31'
6734'
4980
4320
Tubing
3-1/2"
9.3
J-55
BTC -MOD
28'
7807'
28'
6103'
6990
7400
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission
Description of Drilling Fluid System
— Window milling operations: Chloride -based FloVis mud (8.6 ppg)
— Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight will hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: BHA's will be deployed using standard pressure deployments and the well will
be loaded with 8.6 ppg FloVis completion fluid to provide formation over -balance and wellbore stability
while running completions. If higher than expected pressure is encountered while drilling the laterals,
then an overbalanced completion fluid will be utilized to provide formation over -balance. The last
lateral will be displaced to a 10.0 ppg NaCl completion fluid to allow a swell packer to be run into this
hole section.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud
weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled
tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 1 E-20 laterals we will target a constant BHP of 8.6 ppg EMW at the window. The constant BHP target will
be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if
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 December 31, 2019
PTD Application: 1 E-201_1 & 1 E-201_1-01
Pressure at the 1E-20 Window 7938' MD 6227' TVD Using MPD
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
Well KRU 1 E-20 is a Kuparuk A -sand and C -sand producer equipped with 3-1 /2" tubing and 7" production
casing. The CTD sidetrack will utilize two laterals to target the C sands to the south of the 1 E-20. The
laterals will add new resources and improve existing recovery. -
A mechanical whip -stock will be set inside the 7" production casing at the planned kick off point of 7938'
MD. The 1E -20L1 lateral will exit the 7" production casing at 7938' MD and TD at 11300' MD, targeting
the C sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 9350.' MD with an
aluminum billet for kicking off the 1E -20L1-01 lateral.
The 1E -20L1-01 lateral will drill to the south to TD at 11300' MD targeting the C sand. It will be
completed with 2-3/8" slotted liner from TD up to 7745' MD. The liner will include a swell packer, blank
2-3/8" liner, and a sealbore deployment sleeve to allow for future isolation of the 1 E-20 motherbore, but it
is not proposed at this time.
Page 4 of 6 December 31, 2019
Pumps On 1.5 bpm)
Pumps Off
A -sand Formation Pressure 8.4
2728 psi
2728 psi
Mud Hydrostatic 8.6
2784 psi
2784 psi
Annular friction i.e. ECD, 0.08psi/ft)
637 psi
0 psi
Mud + ECD Combined
no chokepressure)
3421 psi
overbalanced —693psi)
2784 psi
overbalanced —56psi)
Target BHP at Window 8.6
2784 psi
2784 psi
Choke Pressure Required to Maintain
fi ar et BHP
0 psi
0 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
Well KRU 1 E-20 is a Kuparuk A -sand and C -sand producer equipped with 3-1 /2" tubing and 7" production
casing. The CTD sidetrack will utilize two laterals to target the C sands to the south of the 1 E-20. The
laterals will add new resources and improve existing recovery. -
A mechanical whip -stock will be set inside the 7" production casing at the planned kick off point of 7938'
MD. The 1E -20L1 lateral will exit the 7" production casing at 7938' MD and TD at 11300' MD, targeting
the C sand to the south. It will be completed with 2-3/8" slotted liner from TD up to 9350.' MD with an
aluminum billet for kicking off the 1E -20L1-01 lateral.
The 1E -20L1-01 lateral will drill to the south to TD at 11300' MD targeting the C sand. It will be
completed with 2-3/8" slotted liner from TD up to 7745' MD. The liner will include a swell packer, blank
2-3/8" liner, and a sealbore deployment sleeve to allow for future isolation of the 1 E-20 motherbore, but it
is not proposed at this time.
Page 4 of 6 December 31, 2019
PTD Application: 1 E-201_1 & 1 E-201_1-01
Pre -CTD Work
1. No pre rig work is required
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPS, test.
2. Pull 2-3/8" slotted liner
3. Perform a cleanout run & tag fish top
4. 1E -20L1 Lateral (C sand -south)
a. Set top of whipstock at 7938' MD.
b. Mill 2.80" window at 7938' MD.
c. Drill 3" bi-center lateral to TD of 11300' MD.
d. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9350' MD.
1 E -20L 1 -0 1 Lateral (C sand - south)
a. Kick off of the aluminum billet at 9350' MD.
b. Drill 3" bi-center lateral to TD of 11300' MD.
c. Run 2-3/8" slotted liner from TD up to 7745' MD. Liner will include a swell packer, blank 2-
3/8" liner, and a sealbore deployment sleeve.
6. Freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Pull BPV.
2. Return to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the
BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two
barriers to reservoir pressure, both internal and external to the BHA, during the deployment process.
During BHA deployment, the following steps are observed.
— Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is
installed on the BOP riser with the BHA inside the lubricator.
— Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and
the BHA is lowered in place via slickline.
— When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off above
the deployment rams.
— The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized,
and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Page 5 of 6 December 31, 2019
PTD Application: 1 E-201_1 & 1 E-201_1-01
Liner Running
— The 1 E-20 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
— While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plans
— Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
— MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
— Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
Distance
1 E -20L1
17300' .
1 E -20L1-01
17315'
— Distance to Nearest Well within Pool
Lateral Name
Distance
Well
1 E -20L1
324'
1 E-03
1 E -20L1-01
265'
1 E-03
16. Attachments
Attachment 1: Directional Plans for 1E -20L1 & 1E -20L1-01 laterals
Attachment 2: Current Well Schematic for IE -20
Attachment 3: Proposed Well Schematic for IE -20L 1 & 1 E -20L 1-01 laterals
Page 6 of 6 December 31, 2019
k'
L
0
ro
ro
m
b
- KUP PROD WELLNAME 1E-20 "/ELLBORE 1E-20
COiIOCOr1 IIIIIpS
Alaska, Inc.
...
Well Attributes Max Angle & TD
Field Name Wellbore APyUWI Wellbore Status ncl (°J MD (ftKBAct Bum (ftKB)
KUPARUK RIVER UNIT 500292089500 PROD 8.52 4,200.0 6,650.0
MD,
CommentH2S(ppm) Date Annotation End Date KB.Gul Rig Release Date
SSSV: LOCKED OUT 90 9/4/2017 Last WO: 723/1990 39.00 2/3/1983
1 E-20 1211912019 1:25:49 PM
Last Tag
Venial schematic (actual)
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM 7,948.0 12/20/2010 1 E-20 Imosbor
CONDl1CTOR; 34.0-11 h.t1
SAFETY VLV; 1,822.0
GAS LIFT; 2,209.7
SURFACE; 33.0.2,380.0
GAS LIFT; 3,447.9
GAS LIFT; 4,314.1
GAS LIFT; 5,056.0
GAS LIFT; 5,740.1
GAS LIFT; 6,453.2
GAS LIFT; 7,114.1
GAS LIFT; 7,714.8
PACKER; 7,778.3
WINDOW; 7,949.0.7,953.0
WINDOW;7,961.0.7,965.0
Slatted Uner PB1 :7,T75.8-
7,977.0
FISH; 7,977.13
FISH; 7,979.0
(PERF; 7,945.08,094.0 -
GAS LIFT; 8,110.13
(PERF; 8,349.0-8,362.0-
IPERF;
349.0$,362.0 -(PERF; 8,382.0.8,410.0PRODUCTION; 31.2-8,621.7--
Last Rev Reason
Annotation I End Date WellboreLast Mod By
Rev Reason: Change out GLV's 6/24/2019 1E-20 Jhansen8
Casing Strings
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (... Will -en (L.. Grade Top Thread
CONDUCTOR 16 15.25 34.0 110.0 110.0 65.0() IH40 WELDED
Casing Description OD (in) ID (In) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (... Nk/Len (I... Grade Top Thread
SURFACE 103/4 9.95 33.0 2,380.0 2,172.4 45.50 K-55 BTC
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) 1••• WuLen(L.. Grade Top Thread
WINDOW 7 6.28 7,949.0 7,953.0 6,216.3
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (... VNI-en (I•.. Grade Top Thread
WINDOW 7 6.28 7,961.0 7,965.0 6,225.5
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (... WVLen (1... Grade Top Thread
PRODUCTION 7 6.28 31.2 8,621.7 6,733.7 26.00 K-55 BTC
Tubing Strings
Tubing Description Shing Max.. I ID (in) Top (ftKB) Set Depth (it Set Depth (ND) (k.. Wt (Iblft) Grade Top Connection
TUBING WO 31/2 2.99 27.6 7,807.0 6,103.2 9.20 J-55 BTC -MO)
Completion Details
Top (ND) Nominal
Top (ftKB) (ftKB) Top Incl (°) Item Des Com ID (in)
27.6 27.6 0.06 HANGER FMC GEN III TUBING HANGER 3.500
1,822.0 1,747.5 33.55 SAFETY VLV CAMCO TRDP-IA-SSA SAFETY VALVE - LOCKED OUT 6/19/2000 2.812
(FLOW TUBE ONLY)
7,764.6 6,070.2 38.81 PER BAKER PBR w/ 10' STROKE 3.000
7,778.3 6,080.9 38.89 PACKER BAKER HB RETRIEVABLE PACKER 2.890
7,794,6 6,093.6 38.99 1 NIPPLE CAMCO D NIPPLE NO GO(MILLED 3/17/2017) 2.800
7,806.3 6,102.6 39,04 SOS BAKER SHEAR OUT SUB 3.015
Tubing Description String Max.. ID (in) Top (ftKB) I Set Depth (It Set Depth (ND) (k.. Wt (Iblft) Grade Top Connection
TUBINGABANDONED 31/2 2.99 8,098.0 8,160.0 6,375.8 9.30 J-55 BTCMOD
Completion Details
Top (ND) Nominal
Top (ftKB) (ftKB) Top Incl(°) Item Des Com ID (in)
8,098.0 6,328.0 39.57 BLAST JT SHATTERED 1' OF BLAST JOINT LEFT ON TOP OF ABANDONED 2.992
TUBING COMPLETION
8,129.7 6,352.4 39.58 LOCATOR BAKER LOCATOR 4.000
8,130.3 6,352.8 39.58 PACKER BAKER FB -1 PACKER 4.000
8,132.8 6,354.8 39.58 SBE BAKER SEAL BORE EXTENSION 3.500
8,147.8 6,366.4 39.58 NIPPLE CAMCO'D' NIPPLE 2.906
8,159.3 6,375.2 39.59 SOS BAKER SHEAROUT SUB 2.938
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (TVD)
Top (ftKB) (ftKB)
Top Incl
(°) Des Co. Run Date
ID (in)
7,977.0 6,234.8
39.59 FISH 3-1/2" by 7" high328/2017
expansion wedge whipstock. Depth below 7977'
2.500
7,979.0 6,236.3
39.59 FISH 3-1/2" by 7" high 3/31/2017
expansion wedge whipstock. Depth below 7977'
2.500
Perforations & Slots
Shot
Top (ND) Btm (ND) Dens
Top (ftKB) Bt. (ftKB) (ftKB) (ftKB) Linked Zone Date (shotsJft) Type Com
7,945.0 8,094.0 6,210.1 6,324.9 C-4, C-3, C-2, 1 E 2/2/1983 4.0 (PERF 90 deg. Ph; DA 4" csg guns
-20
8,349.0 8,362.0 6,521.5 6,531.6 A-5, 1 E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns
8,382.0 8,410.0 6,547.1 6,568.8 A4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns
Mandrel Inserts
St
at!
on Top (TVD) Valve Latch Port Size TRO Run
No Top (ftKB) (ftKB) Make Model OO (in) Sery Type Type (in) (psi) Run Date Com
1 2,209.7 2,046.0 CAMCO KBUG 1 GAS LIFT GLV BK 1 0.313 1,250.0 6/24/2019
2 3,447.9 2,931.7 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,231.0 6/24/2019
4,314.1 3,526.7 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,283.0 6/23/2019
4 5,056.0 4,044.2 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 6/23/2019
5 5,740.1 4,530.6 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 3/7/2017
6 6,453.2 5,055.7 CAMCO KBUG 1 GAS LIFT DMY BK 0,000 0.0 9/26/2007
7 7,114.1 5,562.3 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 7/23/1990
8 7,714.8 6,031.3 CAMCO MMG-2 1 112 GAS LIFT DMY BK 0.000 0.0 8/2/1990
9 8,110.1 6,337.3 CAMCO GASLIFT DMY BK 0.000 0.0 2/3/1983 In
Tubing
Aband
on
Notes: General & Safety
End Datc Annotation
3/31/2017 NOTE: 2 Nonhen Solutions High Expansion Wedge Whipstock LEFT IN HOLE.
11/18/2010 NOTE: View Schematicw/ Alaska Schematic9.0
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ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Kuparuk 1E Pad
1 E-20
1 E -20L1
Plan: 1 E-201-1 wp03
Standard Planning Report
09 February, 2017
BAKER
HUGHES
ConocoPhillips
ConocoPhillips
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1E Pad
Well:
1 E-20
Wellbore:
1 E-201-1
Design:
1 E-20L1_wp03
ConocoPhillips
rias
Planning Report
BAKER
HUGHES
Local Co-ordinate Reference:
Well 1 E-20
TVD Reference:
Mean Sea Level
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
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 1E Pad
Site Position: Northing: 5,959,760.24 usft Latitude: 70° 18' 3.022 N
From: Map Easting: 549,889.51 usft Longitude: 149° 35'45.358 W
Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.38
Weil 1 E-20
Well Position +N/ -S 0.00 usft Northing: 5,960,000.68 usft Latitude: 700 18' 5.359 N
+E/ -W 0.00 usft Easting: 550,300.56 usft Longitude: 1490 35' 33.326 W
Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft
Wellbore 1 E-201-1
Magnetics Model Nam@, Sample Date Declination
(°)
BGGM2016 5/1/2017 17.66
Design 1E-20L1_wp03
Audit Notes:
Version: Phase: PLAN
Vertical Section: Depth From (TVD) +N/ -S
(usft) (usft)
0.00 0.00
Dip Angle Field Strength
(°) (nT)
80.93 57,541
Tie On Depth: 7,900.00
+El -W Direction
(usft) (°)
0.00 180.00
2/9/2017 3:06:54PM Page 2 COMPASS 5000.1 Build 74
ConocoPhillips MGrag
ConocoPhillips
Planning Report
HU6HE5
Database: EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1E-20
Company: ConocoPhillips (Alaska) Inc. -Kup1
ND Reference:
Mean Sea Level
Project: Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site: Kuparuk 1E Pad
North Reference:
True
Well: 1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore: 1 E -20L1
Azimuth
System
Design: 1 E-201-1_wp03
+E/ -W
Rate
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°/100ft)
(°/100ft)
(°/100ft)
(°) Target
7,900.00
39.27
64.97
6,069.61
1,555.86
4,205.66
0.00
0.00
0.00
0.00
7,967.00
39.54
64.47
6,121.38
1,574.02
4,244.12
0.62
0.40
-0.75
-49.81
7,988.00
42.48
64.47
6,137.22
1,579.96
4,256.55
14.00
14.00
0.00
0.00
8,058.00
71.88
64.47
6,174.75
1,605.03
4,309.05
42.00
42.00
0.00
0.00
8,160.00
72.81
109.53
6,207.21
1,609.86
4,403.13
42.00
0.91
44.18
96.00
8,260.00
89.94
148.49
6,222.75
1,548.49
4,477.65
42.00
17.13
38.96
70.00
8,385.00
89.96
200.99
6,222.86
1,428.33
4,488.71
42.00
0.02
42.00
90.00
8,485.00
95.32
205.50
6,218.25
1,336.60
4,449.31
7.00
5.36
4.51
40.00
8,610.00
97.52
214.03
6,204.25
1,228.87
4,387.73
7.00
1.76
6.82
75.00
8,750.00
99.10
223.80
6,183.96
1,121.21
4,300.84
7.00
1.13
6.98
80.00
8,865.00
99.71
215.66
6,165.13
1,034.04
4,228.38
7.00
0.53
-7.08
275.00
8,965.00
99.64
208.56
6,148.30
950.60
4,176.01
7.00
-0.07
-7.10
270.00
9,365.00
100.85
180.13
6,075.71
573.46
4,079.37
7.00
0.30
-7.11
275.00
9,565.00
93.25
168.27
6,051.10
376.52
4,099.55
7.00
-3.80
-5.93
238.00
9,765.00
90.75
154.48
6,044.08
187.59
4,163.24
7.00
-1.25
-6.89
260.00
9,900.00
89.11
163.79
6,044.25
61.58
4,211.27
7.00
-1.22
6.89
100.00
10,175.00
85.22
182.67
6,057.97
-209.87
4,243.57
7.00
-1.41
6.87
102.00
10,245.00
85.24
187.59
6,063.79
-279.33
4,237.33
7.00
0.02
7.02
90.00
10,445.00
90.11
174.45
6,071.93
-478.63
4,233.83
7.00
2.44
-6.57
290.00
10,600.00
90.11
163.60
6,071.63
-630.57
4,263.30
7.00
0.00
-7.00
270.00
10,800.00
88.90
177.55
6,073.37
-827.37
4,295.98
7.00
-0.61
6.97
95.00
10,975.00
86.19
165.59
6,080.90
-999.99
4,321.55
7.00
-1.55
-6.83
257.00
11,125.00
88.06
175.93
6,088.44
-1,147.65
4,345.56
7.00
1.25
6.90
80.00
11,300.00
88.11
188.19
6,094.31
-1,322.11
4,339.28
7.00
0.03
7.00
90.00
2/9/2017 3:08:54PM Page 3 COMPASS 5000.1 Build 74
Planned Survey
ConocoPhillips
F/,AI
'�
ConocoPhillips
Planning Report
BAKER
HUGHES
Database: EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company: ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Toolface
Project: Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Inclination Azimuth
Site: Kuparuk 1E Pad
North Reference:
True
Section
Well: 1 E-20
Survey Calculation Method:
Minimum Curvature
Easting
Wellbore: 1 E-201-1
(I
(I
(usft)
Design: 1 E-201-1_wp03
(usft)
(usft)
("11o0ft)
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination Azimuth
System
+Nl-S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(I
(I
(usft)
(usft)
(usft)
(usft)
("11o0ft)
(")
(usft)
(usft)
7,900.00
39.27
64.97
6,069.61
1,555.86
4,205.66
-1,555.86
0.00
0.00
5,961,584.50
554,495.30
TIP
7,967.00
39.54
64.47
6,121.38
1,574.02
4,244.12
-1,574.02
0.62
-49.81
5,961,602.92
554,533.63
KOP
7,988.00
42.48
64.47
6,137.22
1,579.96
4,256.55
-1,579.96
14.00
0.00
5,961,608.94
554,546.03
End 14 dis, Start 42 dis
8,000.00
47.52
64.47
6,145.71
1,583.61
4,264.21
-1,583.61
42.00
0.00
5,961,612.65
554,553.66
8,058.00
71.88
64.47
6,174.75
1,605.03
4,309.05
-1,605.03
42.00
0.00
5,961,634.37
554,598.35
4
8,100.00
70.94
83.06
6,188.24
1,616.12
4,347.07
-1,616.12
42.00
96.00
5,961,645.71
554,636.29
8,160.00
72.81
109.53
6,207.21
1,609.86
4,403.13
-1,609.86
42.00
90.03
5,961,639.83
554,692.39
5
8,200.00
79.13
125.59
6,216.97
1,591.92
4,437.36
-1,591.92
42.00
70.00
5,961,622.11
554,726.73
8,260.00
89.94
148.49
6,222.75
1,548.49
4,477.65
-1,548.49
42.00
66.08
5,961,578.96
554,767.31
6
8,300.00
89.94
165.29
6,222.79
1,511.83
4,493.29
-1,511.83
42.00
90.00
5,961,542.41
554,783.19
8,385.00
89.96
200.99
6,222.86
1,428.33
4,488.71
-1,428.33
42.00
89.98
5,961,458.89
554,779.17
End 42 dis, Start 7 dis
8,400.00
90.77
201.67
6,222.76
1,414.36
4,483.25
-1,414.36
7.00
40.00
5,961,444.88
554,773.81
8,485.00
95.32
205.50
6,218.25
1,336.60
4,449.31
-1,336.60
7.00
40.00
5,961,366.90
554,740.39
8
8,500.00
95.59
206.52
6,216.82
1,323.18
4,442.76
-1,323.18
7.00
75.00
5,961,353.44
554,733.94
8,600.00
97.35
213.34
6,205.54
1,237.12
4,393.23
-1,237.12
7.00
75.10
5,961,267.06
554,684.98
8,610.00
97.52
214.03
6,204.25
1,228.87
4,387.73
-1,228.87
7.00
75.87
5,961,258.77
554,679.54
9
8,700.00
98.57
220.30
6,191.65
1,157.89
4,333.93
-1,157.89
7.00
80.00
5,961,187.44
554,626.22
8,750.00
99.10
223.80
6,183.96
1,121.21
4,300.84
-1,121.21
7.00
80.88
5,961,150.54
554,593.38
10
8,800.00
99.39
220.27
6,175.92
1,084.56
4,267.80
-1,084.56
7.00
-85.00
5,961,113.68
554,560.59
8,865.00
99.71
215.66
6,165.13
1,034.04
4,228.38
-1,034.04
7.00
-85.57
5,961,062.90
554,521.51
11
8,900.00
99.71
213.18
6,159.23
1,005.58
4,208.88
-1,005.58
7.00
-90.00
5,961,034.32
554,502.20
8,965.00
99.64
208.56
6,148.30
950.60
4,176.01
-950.60
7.00
-90.42
5,960,979.12
554,469.71
12
9,000.00
99.85
206.09
6,142.37
919.96
4,160.18
-919.96
7.00
-85.00
5,960,948.38
554,454.08
9,100.00
100.33
198.99
6,124.84
829.09
4,122.46
-829.09
7.00
-85.42
5,960,857.26
554,416.98
9,200.00
100.66
191.88
6,106.60
734.37
4,096.30
-734.37
7.00
-86.66
5,960,762.39
554,391.45
9,300.00
100.83
184.76
6,087.94
637.23
4,082.09
-637.23
7.00
-87.96
5,960,665.16
554,377.90
9,365.00
100.85
180.13
6,075.71
573.46
4,079.37
-573.46
7.00
-89.29
5,960,601.38
554,375.60
13
9,400.00
99.54
178.02
6,069.51
539.02
4,079.93
-539.02
7.00
-122.00
5,960,566.95
554,376.39
9,500.00
95.75
172.08
6,056.20
440.35
4,088.50
-440.35
7.00
-122.37
5,960,468.34
554,385.62
9,565.00
93.25
168.27
6,051.10
376.52
4,099.55
-376.52
7.00
-123.16
5,960,404.59
554,397.10
14
9,600.00
92.82
165.85
6,049.24
342.46
4,107.38
-342.46
7.00
-100.00
5,960,370.59
554,405.16
9,700.00
91.57
158.96
6,045.40
247.27
4,137.57
-247.27
7.00
-100.13
5,960,275.61
554,435.98
9,765.00
90.75
154.48
6,044.08
187.59
4,163.24
-187.59
7.00
-100.39
5,960,216.11
554,462.05
16
9,800.00
90.32
156.90
6,043.75
155.69
4,177.65
-155.69
7.00
100.00
5,960,184.32
554,476.67
9,900.00
89.11
163.79
6,044.25
61.58
4,211.27
-61.58
7.00
100.02
5,960,090.44
554,510.91
16
10,000.00
87.66
170.64
6,047.07
-35.84
4,233.38
35.84
7.00
102.00
5,959,993.18
554,533.67
219/2017 3:08:54PM Page 4 COMPASS 5000.1 Build 74
10-1 ConocoPhillips (SRI
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company:
ConocoPhillips (Alaska) Inc. -Kup1
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site:
Kuparuk 1 E Pad
North Reference:
True
Well:
1E-20
Survey Calculation Method:
Minimum Curvature
Wellbore:
IE -201-11
Depth
Inclination
Design:
1 E-20L1_wp03
+Nl-S
+El -W
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+Nl-S
+El -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(I
(o)
(usft)
(usft)
(usft)
(usft)
(.1100ft)
{`)
(usft)
(usft)
10,100.00
86.25
177.51
6,052.39
-135.10
4,243.68
135.10
7.00
101.81
5,959,894.00
554,544.64
10,175.00
85.22
182.67
6,057.97
-209.87
4,243.57
209.87
7.00
101.44
5,959,819.24
554,545.02
17
10,200.00
85.23
184.43
6,060.05
-234.73
4,242.02
234.73
7.00
90.00
5,959,794.37
554,543.65
10,245.00
85.24
187.59
6,063.79
-279.33
4,237.33
279.33
7.00
89.85
5,959,749.75
554,539.25
18
10,300.00
86.57
183.96
6,067.72
-333.90
4,231.81
333.90
7.00
-70.00
5,959,695.15
554,534.10
10,400.00
89.01
177.40
6,071.59
-433.75
4,230.63
433.75
7.00
-69.74
5,959,595.30
554,533.59
10,445.00
90.11
174.45
6,071.93
-478.63
4,233.83
478.63
7.00
-69.49
5,959,550.45
554,537.09
19
10,500.00
90.11
170.60
6,071.83
-533.15
4,240.98
533.15
7.00
-90.00
5,959,495.98
554,544.60
10,600.00
90.11
163.60
6,071.63
-630.57
4,263.30
630.57
7.00
-90.01
5,959,398.72
554,567.57
20
10,700.00
89.50
170.57
6,071.97
-727.98
4,285.63
727.98
7.00
95.00
5,959,301.48
554,590.55
10,800.00
88.90
177.55
6,073.37
-827.37
4,295.98
827.37
7.00
94.98
5,959,202.17
554,601.56
21
10,900.00
87.34
170.72
6,076.66
-926.73
4,306.18
926.73
7.00
-103.00
5,959,102.89
554,612.43
10,975.00
86.19
165.59
6,080.90
-999.99
4,321.55
999.99
7.00
-102.78
5,959,029.74
554,626.28
22
11,000.00
86.49
167.32
6,082.49
-1,024.24
4,327.39
1,024.24
7.00
80.00
5,959,005.52
554,634.29
11,100.00
87.74
174.21
6,087.53
-1,122.76
4,343.41
1,122.76
7.00
79.89
5,958,907.13
554,650.97
11,125.00
88.06
175.93
6,088.44
-1,147.65
4,345.56
1,147.65
7.00
79.54
5,958,882.25
554,653.28
23
11,200.00
88.07
181.19
6,090.97
-1,222.56
4,347.44
1,222.56
7.00
90.00
5,958,807.37
554,655.66
11,300.00
88.11
188.19
6,094.31
-1,322.11
4,339.28
1,322.11
7.00
89.82
5,958,707.78
554,648.17
Planned TD at 11300.00
2/9/2017 3:08:54PM Page 5 COMPASS 5000.1 Build 74
ConocoPhillips FGFAI
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1E-20
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site:
Kuparuk 1 E Pad
North Reference:
True
Well:
1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore:
IE -201-1
1,694,680.00
70° 2'24.915 N 140° 24'39.036 W
Design:
1 E-20L1_wp03
Point
Targets
Target Name
hitlmiss target Dip Angle Dip Dir. TVD +NI -S +E/ -W Northing
Easting
Shape V) (1) (usft) (usft) (usft) (usft)
(usft)
Latitude Longitude
1 E -201-1_T03 0.00 0.00 6,203.00 -6,660.691,144,497.66 5,961,002.00
1,694,706.00
70° 2'49.539 N 140° 24'26.829 W
plan misses target center by 1140033.66usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1 E-20L1_T10 0.00 0.00 6,094.00 -9,203.701,144,454.63 5,958,459.00
1,694,680.00
70° 2'24.915 N 140° 24'39.036 W
plan misses target center by 1140011.71 usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1 T07 0.00 0.00 6,056.00 -8,066.931,144,359.23 5,959,595.00
1,694,577.00
70° 2'36.092 N 140° 24'36.838 W
plan misses target center by 1139906.20usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1 E-20 CTD Polygon 0.00 0.00 0.00 -6,188.001,144,253.79 5,961,473.00
1,694,459.00
70° 2'54.488 N 140° 24'31.719 W
plan misses target center by 1139803.50usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Polygon
Point 1 0.00 0.00 0.00 5,961,473.00
1,694,459.00
Point 0.00 78.68 199.55 5,961,553.01
1,694,658.00
Point 0.00 57.85 325.42 5,961,533.02
1,694,783.99
Point 0.00 -69.21 482.60 5,961,407.03
1,694,942.01
Point 5 0.00 -235.45 515.50 5,961,241.03
1,694,976.01
Point 6 0.00 -525.72 400.56 5,960,950.02
1,694,863.03
Point 0.00 -921.52 212.90 5,960,553.02
1,694,678.04
Point 8 0.00 -3,001.00 397.11 5,958,475.02
1,694,876.15
Point 9 0.00 -3,311.71 349.04 5,958,164.02
1,694,830.17
Point 10 0.00 -3,289.69 45.15 5,958,184.01
1,694,526.17
Point 11 0.00 -2,985.44 13.17 5,958,488.01
1,694,492.15
Point 12 0.00 -1,368.57 -240.12 5,960,102.99
1,694,228.07
Point 13 0.00 -872.84 -190.82 5,960,598.99
1,694,274.05
Point 14 0.00 -595.74 -49.96 5,960,877.00
1,694,413.03
Point 15 0.00 -325.08 156.86 5,961,149.01
1,694,618.02
Point 16 0.00 0.00 0.00 5,961,473.00
1,694,459.00
1E -20L1 Fault2 M 0.00 0.00 0.00 -8,066.931,144,359,23 5,959,595.00
1,694,577.00
70° 2' 36.092 N 140° 24'36.838 W
plan misses target center by 1139923.17usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Rectangle (sides W1,000.00 H1.00 D0.00)
1E-20L1_T01 0.00 0.00 6,223.00 -6,333.281,144,592.86 5,961,330.00
1,694,799.00
70° 2'52.577 N 140° 24'22.708 W
plan misses target center by 1140126.56usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1 T09 0.00 0.00 6,075.00 -8,759.381,144,414.60 5,958,903.00
1,694,637.00
70° 2'29.288 N 140° 24'38.255 W
plan misses target center by 1139967.59usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1 Fault2 0.00 0.00 6,056.00 -8,066.931,144,359.23 5,959,595.00
1,694,577.00
70° 2' 36.092 N 140° 24'36.838 W
plan misses target center by 1139906.20usft at 8300.O0usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Polygon
Point 1 6,056.00 0.00 0.00 5,959,595.00
1,694,577.00
Point 6,056.00 1.00 1.00 5,959,596.01
1,694,577.99
1E-201-1 T02 0.00 0.00 6,223.00 -6,453.371,144,604.06 5,961,210.00
1,694,811.00
70° 2' 51.395 N 140° 24'22.909 W
plan misses target center by 1140138.59usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1 T05 0.00 0.00 6,062.00 -7,391.771,144,198.73 5,960,269.00
1,694,412.00
7W 2'42.883 N 140° 24'38.484 W
plan misses target center by 1139740.23usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1E-201-1 T08 0.00 0.00 6,072.00 -8,364.901,144,349.23 5,959,297.00
1,694,569.00
70° 2'33.214 N 140° 24'38.409 W
plan misses target center by 1139898.74usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
Point
1 E-201-1 Fault1 M 0.00 0.00 0.00 -6,660.691,144,497.66 5,961,002.00
1,694,706.00
70° 2'49.539 N 140° 24' 26.829 W
2/9/2017 3:08:54PM Page 6 COMPASS 5000.1 Build 74
ConocoPhillips
ConocoPhillips
Planning Report
I
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site:
Kuparuk 1 E Pad
North Reference:
True
Well:
1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 E-201-1
plan misses target center by 1139793.86usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
1,121.21
Design:
1 E-20L1_wp03
4,228.38
950.60
rr..2
BAKER
HUGHES
plan misses target center by 1140050.64usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
+N/ -S
Rectangle (sides W1,000.00 H1.00 D0.00)
(usft)
1E-20L1_Fault1 0.00 0.00 6,203.00 -6,660.691,144,497.66 5,961,002.00
1,694,706.00 70° 2'49.539 N 140° 24'26.829 W
plan misses target center by 1140033.66usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
1,574.02
Polygon
1,579.96
Point 1 6,203.00 0.00 0.00 5,961,002.00
1,694,706.00
Point 6,203.00 1.00 1.00 5,961,003.01
1,694,706.99
1E -20L1 T06 0.00 0.00 6,044.00 -7,726.441,144,292.50 5,959,935.00
1,694,508.00 70° 2'39.496 N 140° 24' 37.264 W
plan misses target center by 1139836.66usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
1,428.33
Point
1,336.60
1 E-201-1 T04 0.00 0.00 6,134.00 -7,006.101,144,255.32 5,960,655.00
1,694,466.00 70° 2'46.543 N 140° 24'35.210 W
plan misses target center by 1139793.86usft at 8300.00usft MD (6222.79 TVD, 1511.83 N, 4493.29 E)
1,121.21
Point
1,034.04
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
11,300.00 6,094.31 2 3/8" 2.375 3.000
Plan Annotations
Measured
Depth
(usft)
7,900.00
7,967.00
7,988.00
8,058.00
8,160.00
8,260.00
8,385.00
8,485.00
8,610.00
8,750.00
8,865.00
8,965.00
9,365.00
9,565.00
9,765.00
9,900.00
10,175.00
10,245.00
10,445.00
10,600.00
10,800.00
10,975.00
11,125.00
11,300.00
Vertical
Depth
(usft)
6,069.61
6,121.38
6,137.22
6,174.75
6,207.21
6,222.75
6,222.86
6,218.25
6,204.25
6,183.96
6,165.13
6,148.30
6,075.71
6,051.10
6,044.08
6,044.25
6,057.97
6,063.79
6,071.93
6,071.63
6,073.37
6,080.90
6,088.44
6,094.31
Local Coordinates
+N/ -S
+El -W
(usft)
(usft)
1,555.86
4,205.66
1,574.02
4,244.12
1,579.96
4,256.55
1,605.03
4,309.05
1,609.86
4,403.13
1,548.49
4,477.65
1,428.33
4,488.71
1,336.60
4,449.31
1,228.87
4,387.73
1,121.21
4,300.84
1,034.04
4,228.38
950.60
4,176.01
573.46
4,079.37
376.52
4,099.55
187.59
4,163.24
61.58
4,211.27
-209.87
4,243.57
-279.33
4,237.33
-478.63
4,233.83
-630.57
4,263.30
-827.37
4,295.98
-999.99
4,321.55
-1,147.65
4,345.56
-1,322.11
4,339.28
Comment
TIP
KOP
End 14 dls, Start 42 dls
4
5
6
End 42 dls, Start 7 dls
8
9
10
11
12
13
14
15
16
17
18
19
20
21
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Planned TD at 11300.00
2/9/2017 3:08:54PM Page 7 COMPASS 5000.1 Build 74
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: 2-
PTD:
_ Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD:
POOL: l� L �C ✓� ✓ �/ %
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
LATERAL,
The permit is for a new wellbore segment of exis ' well Permit
No. �
API No. 50 -CLQ'-
-LU-.
t% (If last two digits Production should continue to be
reported 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
Pilot Hole
both well
name ( PID and API number (50-
7 _) from records, data and logs acquired for well
name on rmit .
The permit is approved subject to full compliance with 20 AAC 25.055.
Spacing Exception
Approval to produce/inject is contingent upon issuance of a conservation
order
approving a spacing exception. (Company Name) Operator
assumes the liability of any
protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30' sample intervals from below the
permafrost or from where
sam les are first canght and 10' sam le intervals throw tar et zones.
Please note the following special condition of this permit:
Non -Conventional
production or production testing of coal bed methane is not allowed for
(name of well) until
Well
after (Company Name) has designed and
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 testis program.
Regulation 20 AAC 25.071(x) 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
TzU=9nt9S1
attached application, the following well logs are
also required for this well:
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 com letion, allanangion or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
Well Name: KUPARUK RIV UNIT 1E-201_1 Program DEV Well bore seg ❑d
PTD#: 2200060 Company ConocoPhillips Alaska, Inc. Initial Class/Type
DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
NA- -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
2
Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes .
_Entire Well lies within ADL0025651._
3
Unique well -name and number --- - - - - - - - - - - - - -
Yes -
- - - - - - Previously permitted as 2170220 but that permit expired.
4
Well located in -a- defined -pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -
Yes -
- - - - - _ Kuparuk River Oil_ Pool, governed by Conservation Order No. 432D
5
Well located proper distance from drilling unit -boundary_ - - - - - -- - - - - - - - - - - -
Yes -
- - - - - - CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened in
6
Well located proper distance from other wells- - - - - - - - - - - -- - - - - - - - - - - - -
Yes -
- - - - - - a well closer-than500 feet to an external property -line where ownership or landownership changes._ - - - - - - - - -
7
Sufficient acreage available in -drilling unit- - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - As planned, well conforms with_spacing_requirements --------- - - - - - - - - - - - - - - - - - - - - - - - - - - - -
8
Ifdeviated,is_wellbore plat_induded - - _ _ - _ - - - - - - - - - - -
Yes -
- - - - - - - - - _ - - - - - - _ - -
9
Operator only affected party - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - - - - - - - - - - - - - - - - - - - - - .. - - - - - - - - - - - - - - - - - - - - - - -
10
Operator has -appropriate _bond inforce --------------------------- - -.
Yes
11
Permit can be issued without conservation order_ - - - - - -
Yes
Appr Date
12
Permit can be issued without administrative_approval - - - - _ - - - - --
Yes -
13
Can permit be approved before 15 -day wait- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
SFD 1/16/2020
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 030Q.1.A)4. .A -D) - - - - - - - - - - - - - - - - - - - - -
NA_ -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
18
Conductor string -provided - - _ - - - _ - -
NA_
Conductor set in KRU 1 E-20
Engineering
19
Surface casing -protects all -known -
llknown_ USDWs - - - - - - - - - - - - - - - - - - - - - - - - - - - -
NA- -
- - - - _ . Surface casing set in_ KRU 1 E-20 _ - - - - _ _ - - - -
20
CMT_ vol_ adequate_ to circulate -on conductor & surf_csg - - - - - - - - - - - - - - - - - - - - - - - -
NA_ -
- - - - - _ Surface casing set and fully -cemented - - - .. - - - - - - - - - -
21
CMT_vol_ adequate _totie-in -long string to -surf csg--------------- - - - _
NA- -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
22
CMT -will cover all known productive horizons_ - - - _ - - - _ - - - - - -
No
Productive interval will be completed with uncemented slotted_ liner
23
Casing designs adequate for C, T B &- permafrost _ - - - - - _ - - -
Yes
- - - - - - - - _ -
24
Adequate -tankage- or reserve pit - - - - - - - - - - - - - . _
Yes
Rig has steel tanks; all waste to approved disposal wells_
25
-If-a-re-drill, has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - -
NA- _
- - - - - - - - - - _ - - - - - _ - - - - - - - - - _ - - - - _ - - - - - - - - -
26
Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
Yes
. _ _ _ Anti -collision analysis complete; no major risk failures - - - - - - - - - - - - - - - - - - - - - - - - -
27
-if _diverter required, does it meet regulations
NA_ -
- - - - - - _ -
Appr Date
28
Drilling fluid- program schematic & equip list adequate_ - - - _ _ .---------------
--
Yes -
- - - - - _ Max formation -pressure is -3034 psig(9.4 ppg. EMW); will drill w/_8_.6 ppg_E_MW and maintain overbal w/ MPD
VTL1/17/2020
29
BOPEs,_dotheymeetregulation------------------------------------
Yes---
---------------------------------------------------------------------
30
BOPS -press rating appropriate; test to (put prig in comments) _ - - - - - .
Yes -
- _ - - _ MPSP is 2412 psig; will test SOPs_to 3500_psig- - - - -
31
Choke_manifold complies w/API_RP-53 (May 84)- - - - - - - - - - - - - - - - - -
Yes .
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
32
Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes ----------------------------------------------------------------
-
33
-is presence _ ofH2Sgas probable ------------------------------------ _
Yes__-__--H2Smeasures
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 1 E -Pad are_H2S-bearing. H2S measures required._
Geology
36
Data -presented on -potential overpressure zones - - - - - - - - - - - - - - -_ _
Yes -
- - - - - _ Max. potential_res. pressure is 9.4ppg EMW; expected res. -pressure is 8.4_ppg EMW. Well will _be drilled_
Appr Date
37
Seismic analys_is-of shallow gas zones- - - - - - - - - - - - - - - - - - - - - - - _
NA- -
- _ - - _ using 8,6-ppg mu- coiled -tubing rig, and.managed_pressure drilling technique_to control formation_
SFD 1/16/2020
38
Seabed condition survey -(if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
NA_ -
- - - - - - pressures and stabilize shale -sections -- - - - - - - _ - - -
39
Contact name/phone for weekly_p-mgress reports [exploratory only] - - - - - - - - - - _
NA- -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
�f 1 1212c)
