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HomeMy WebLinkAbout220-007DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-65-00Well Name/No. KUPARUK RIV UNIT 1E-20L1-01Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200070Operator ConocoPhillips Alaska, Inc.MD10913TVD6150Current 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-20L1-01 EOW - NAD83.pdf32052EDDigital DataC2/24/2020 Electronic File: 1E-20L1-01 EOW - NAD83.txt32052EDDigital DataC2/24/2020 Electronic File: 1E-20L1-01 MD NAD27.pdf32052EDDigital DataC2/24/2020 Electronic File: 1E-20L1-01 MD NAD27.txt32052EDDigital Data0 0 2200070 KUPARUK RIV UNIT 1E-20L1-01 LOG HEADERS32052LogLog Header ScansC2/28/20207799 10913 Electronic Data Set, Filename: 1E-20L1-01 GAMMA RES.las32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 2MD Final.cgm32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5MD Final.cgm32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5TVDSS Final.cgm32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 2MD Final.pdf32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5MD Final.pdf32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5TVDSS Final.pdf32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 EOW - NAD83.pdf32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 EOW - NAD83.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 MD NAD27.pdf32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 MD NAD27.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 Survey Listing.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 Surveys.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01_awp_Final Surveys Confirmed 10913.csv32106EDDigital DataTuesday, April 14, 2020AOGCCPage 1 of 31E-20L1-01 GAMMA RES.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-65-00Well Name/No. KUPARUK RIV UNIT 1E-20L1-01Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200070Operator ConocoPhillips Alaska, Inc.MD10913TVD6150Current 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-20L1-01_25_tapescan_BHI_CTK.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01_5_tapescan_BHI_CTK.txt32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01_output.tap32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 2MD Final.tif32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5MD Final.tif32106EDDigital DataC2/28/2020 Electronic File: 1E-20L1-01 5TVDSS Final.tif32106EDDigital Data0 0 2200070 KUPARUK RIV UNIT 1E-20L1-01 LOG HEADERS32106LogLog Header ScansTuesday, April 14, 2020AOGCCPage 2 of 3
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20895-65-00Well Name/No. KUPARUK RIV UNIT 1E-20L1-01Completion Status1-OILCompletion Date2/4/2020Permit to Drill2200070Operator ConocoPhillips Alaska, Inc.MD10913TVD6150Current Status1-OIL4/14/2020UICNoCompliance Reviewed By:Date:Tuesday, April 14, 2020AOGCCPage 3 of 3M. Guhl4/14/2020
DLB 04/09/2020 DSR-4/9/2020
VTL 4/14/20
Baker 5�1 PRINT
Hughes
COMPANY ConocoPhillips Alaska, Inc.
WELL NAME
1E -20L1-01
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT
Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick. Ride rQbakerhughes.com
220007
32 10 6
DISTRIBUTION LIST
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 February 2, 2020
TODAYS DATE February 27, 2020
Revision
STATUS Final Replacement: No Details:
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
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 ConocoPhillips Alaska Inc.
Rev. Requested by:
FIELD /
FINAL
CD/DVD
FINAL
ATO 708
PRELIM
LOGS
las, dlis, PDF, META,
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(Compass)
Attn: Lynda M. Yaskell and/or Leonardo Elias
# OF PRINTS
3201 C Street, Suite 505
# OF COPIES
# OF COPIES
# OF COPIES
V
Attn: Ricky Elgarico
ATO 708
700 G Street
Anchorage, AK 99510
3 ExxonMobil, Alaska
IV rXN-11
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4 State of Alaska - AOGCC 1 1
Attn: Natural Resources Technician 11
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR -Division of Oil & Gas *** 1
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
*** Stamp "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
TOTALS FOR THIS PAGE:
0 1 2 0 0
x
Baker Hughes � f Date:
Abby Bell
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska 99501
February 21, 2020
220007
3205
Letter of Transmittal
Harvey Finch
Baker Hughes
795 East 94th Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
1E -20L1
1E -20U-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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THE STATE
ALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 E -20L 1 -0 1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 220-007
Surface Location: 4869' FNL, 224' FEL, SEC. 16, TI IN, RIOE, UM
Bottomhole Location: 910' FNL, 1201' FEL, SEC. 22, TI IN, RIDE, 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 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, y
Vessie L. Chmielowski
Commissioner
DATED this )::� day of January, 2020.
STATE OF ALASKA JAN
1
ALASKA OIL AND GAS CONSERVATION COMMISSION 4 2020
PERMIT TO DRILL �/�
20 AAC 25.005 A 0 -z r . r
1 a. Type of Work:
1 b. Proposed Well Class: Exploratory -Gas ❑ Service - WAG ❑ Service - Disp ❑
1 c. Specify if well is propo d for:
Drill ❑ Lateral 0
Stratigraphic Test ❑ Development -Oil ❑✓ Service - Winj ❑ Single Zone 0
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket Q Single Well ❑
11. Well Name and Number:
ConocoPhillips Alaska, Inc.
Bond No. 5952180
KRU 1E-201-1-01
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 11300' TVD: 6143'
Kuparuk River Field /
Kuparuk River Oil Pool
4a. Location of Well (Governmental Section):
Surface: 4869' FNL, 224' FEL, Sec 16, T11N, R10E, UM
7. Property Designation:
ADL 25651
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
3296' FNL, 1256' FEL, Sec 15, T11N, R10E, UM
ALK 469
1/20/2020
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property:
910' FNL, 1201' FEL, Sec 22, T11 N, R10E, UM
2560
17315'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 106'
Distance to Nearest Well Open
Surface: x- 550300 y- 5960000 Zone- 4
GL / BF Elevation above MSL (ft): 87'
115.
to Same Pool: 265', 1 E-03
16. Deviated wells: Kickoff depth: 9350 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 101 degrees
Downhole: 3034 Surface: 2412
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.6# L-80 ST -L 2555'
8745' 6294' 11300' 6143' Slotted Liner
19, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
8650' 6756' N/A 8538' 6668' 7980'
Casing Length Size Cement Volume MD TVD
Conductor 76' 16" 290 sx AS II 110' 110'
Surface 2347' 10-3/4" 1300 sx AS III & 235 sx AS 1 2380' 2172'
Production 8591' 7" 1050 sx Class G 8622' 6734'
Perforation Depth MD (ft): 7945'- 8094', 8349' - 8362', Perforation Depth TVD (ft): 6210'- 6325', 6521'- 6532',
8382' - 8410' 6547'- 6569'
Hydraulic Fracture planned? Yes L] No Q
20. Attachments: Property Plat ❑ BOP Sketch Drilling Program
Diverter Sketch B Seabed Report
Time v. Depth Plot
e Drilling Fluid Program
Shallow Hazard Analysis
e 20 AAC 25.050 requirements 8
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.Haves(a)CO P.com
Authorized Title: St Engineer Contact Phone: 265-6927
Authorized Signature: Date: 1 1.1/.1 B
Commission Use Only
Permit to Drill '
Number: M®—(�
API Number:
..-
50-Q �, q—C,5-001Date:
Permit Approval
M16
See cover letter for other
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other: L36 P f c-5 f p r�—_SS L j' -,r ¢O3 7�fj D D,5- lam^ Samples req'd: Yes ❑ No R Mud log req'd: Yes ❑ No [/
frh�vla ►-P f--.-►-<vl�c✓ Y�$51�r� �jJ S measures: Yes [�NoEl Directional svy req'd: YesF9/No❑
f� Va r/W V1 C -r- 11-0 23- 0),5 Sac g exce tion req'd: Yes ❑ No F Inclination -only svy req'd: Yes ❑ No[]/
�h Post initial injection MIT req'd: Yes ❑ NoP'
J 4 �'�►� %CIC f� �oiYr f"
b P3 y P�,,� t ��on5 >-hz ?,,i,re- 7�
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: '
/e/��1� s i Form and
Form 10- Revised 5/2017 Thi p r it is valid for 24 months from the date of approval p 2 qR� S�Vp�(a71) A a ',{eLnts in Duplicate
�c� Ifs, r.8 01/16f�,p
ConocoPhillips
philli
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 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.
�l 2
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. 'L,
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 Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals RABORSA"SKA
1E-201-1 & IE-201-1-01 C
Application for Permit to Drill Document 2RC
1.
Well Name and Classification...........................................................................................................2
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))......................................................................................................................2
2.
Location Summary.............................................................................................................................2
(Requirements of 20 AAC 25.005(c)(2))......................................................................................................................................................2
3.
Blowout Prevention Equipment Information...................................................................................2
(Requirements of 20 AAC 25.005(c)(3)).....................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure....................................................................2
(Requirements of 20 AAC 25.005(c)(4)).....................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests.....................................................................2
(Requirements of 20 AAC 25.005(c)(5))......................................................................................................................................................2
6.
Casing and Cementing Program......................................................................................................3
(Requirements of 20 AAC 25.005(c)(6))......................................................................................................................................................3
7.
Diverter System Information.............................................................................................................3
(Requirements of 20 AAC 25.005(c)(7))......................................................................................................................................................3
8.
Drilling Fluids Program.....................................................................................................................3
(Requirements of 20 AAC 25.005(c)(8))......................................................................................................................................................3
9.
Abnormally Pressured Formation Information...............................................................................4
(Requirements of 20 AAC 25.005(c)(9))......................................................................................................................................................4
10.
Seismic Analysis................................................................................................................................4
(Requirements of 20 AAC 25.005(c)(10))....................................................................................................................................................4
11.
Seabed Condition Analysis...............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))....................................................................................................................................................4
12.
Evidence of Bonding.........................................................................................................................4
(Requirements of 20 AAC 25.005(c)(12))....................................................................................................................................................4
13. Proposed Drilling Program...............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))....................................................................................................................................................4
Summaryof Operations.................................................................................................................................................. 4
LinerRunning.................................................................................................................................................................. 6
14. Disposal of Drilling Mud and Cuttings.............................................................................................6
(Requirements of 20 AAC 25.005(c)(14))....................................................................................................................................................6
15. Directional Plans for Intentionally Deviated Wells..........................................................................6
(Requirements of 20 AAC 25.050(b)).......................................................................................................................................................... 6
16. Attachments.......................................................................................................................................6
Attachment 1: Directional Plans for 1 E-201-1 & 1 E -20L1-01 laterals.............................................................................. 6
Attachment 2: Current Well Schematic for 1 E-20........................................................................................................... 6
Attachment 3: Proposed Well Schematic for 1 E -20L1 & 1 E -20L1-01 laterals................................................................ 6
Page 1 of 6 December 31, 2019
PTD Application: 1 E-201_1 & 1 E -20L1-01
1. Well Name and Classification
(Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))
The proposed laterals described in this document are 1 E-201_1 & 1 E-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
1 E -20L1
9350'
11300'
6079'
6094`
2-3/8", 4.7#, L-80, ST -L slotted liner;
34'
110'
1640
670
Surface
aluminum billet on to
1E-201-1-01
7745'
11300' '
6188'
6037`
2-3/8", 4.7#, L-80, ST -L slotted liner;
2172'
3580
2090
Production
7"
SLT on to
Existing Casing/Liner Information
Category
OD
Weight
(ppf)TVD
Grade
Connection
Top MD
Btm MD
Top
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 -20L1 & 1 E-201_1-01
Pressure at the 1E-20 Window (7938' MD, 6227' TVD) Using MPD v
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 1 E -20L I 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 1 E -20L 1 -0 1 lateral.
J
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
Target 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 1 E -20L I 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 1 E -20L 1 -0 1 lateral.
J
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" BOPE, test.
2. Pull 2-3/8" slotted liner
3. Perform a cleanout run & tag fish top
4. 1 E -20L 1 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.
5. 1 E -20L1-01 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 -20L1-01
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 (1 R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plans
— Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
— MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
— Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
Distance
1 E -20L1
17300'
1 E -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 IE -20L 1& IE -20L 1-01 laterals
Attachment 2: Current Well Schematic for IE -20
Attachment 3. Proposed Well Schematic for 1 E -20L 1 & 1 E -20L 1-01 laterals
Page 6 of 6 December 31, 2019
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,,r_ KUP PROD WELLNAME 1E-20 IELLBORE 1E-20
��tf�'-(1 �1��'f�as ff.
Alaska, Inc.
Well Attributes Max Angle & MD TD
Field Name Wellbore APIIUWI Wellbore Status
KUPARUK RIVER UNIT 500292089500 PROD
ncl (°) MD (ftKB) Act Btm (ftKB)
8.52 4,200.00 5,650.0
Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date
SSSV: LOCKED OUT 90 9/4/2017 Last WO: 7/23/1990 39.00 2/3/1983
1E-20, 12/19/20191:25:49 PM
Last Tag
Vertical schematic (actuap
Annotation Depth (ftKB) I End Date Wellbore Last Mod By
_
COIJDUCTOR, 34 0-110.0
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; 6,653.2
GAS LIFT; 7,114.1
GAS LIFT; 7.714.8-
PACKER; 7.778.3
WINDOW; 7,969.0.7,953.0
WINDOW; 7,96/.0.7,965.0
Slotted Liner P91 7,775.8-
7,977.0
FISH; 7,977.0
FISH; 7,979.0
(PERF; 7 945.0-B,D94.0-
GAS LIFT, 6,110.1
(PERF: 8,349.0.8,362.0-�
(PERF; 8,382.041,410.0 -
PRODUCTION', 31.2-8,621.7
I�
_
H
I
Last Tag: SLM 17,948.0 11212012010 1 E-20 Imosbor
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Change out GLV's 6/2412019 1E-20 Jhansen8
Casing Strings
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (... WVLen L... Grade Top Thread
CONDUCTOR 16 15.25 34.0 110.0 110.0 65.00 H-40 WELDED
Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) I- WULen (1... 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) (... Wt/Len (I... 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) (... Wt/Len (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 (TVD) (... WILen (I... Grade Top Thread
PRODUCTION 7 6.28 31.2 8,621.7 6,733.7 26.00 K-55 BTC
Tubing Strings
Tubing Description String Max.. ID (in) Top (ftKB) Set Depth (11 Set Depth (TVD) (ft.. Wt Owrt) Grade lop Connection
TUBING WO 3 1l2 2.99 27.6 7,80"1 6,103.2 9.20 J-55 BTC -MOD
Completion Details
Top (TVD) Nominal
Top (ftKB) (ftKB) Top Incl V) Item Des Co. 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-1ASSA SAFETY VALVE - LOCKED OUT 6/19/2000 2.812
(FLOW TUBE ONLY)
7,764.6 6,070.2 38.81 PBR BAKER PBR w/ 1 O' STROKE 3.000
7,778.3 6,080.9 38.89 PACKER BAKER HB RETRIEVABLE PACKER 2.890
71794.6 6,093.6 38.99 NIPPLE CAMCO D NIPPLE NO GO(MILLED 3117/2017) 2.800
7,806.3 6,102.6 39.04 SOS BAKER SHEAR OUT SUB 3.015
Tubing Description I String Max.. ID (in) I Top (ftKB)I set Depth (ft... set Depth (TVD) (ft.. Wt (Ib/ft) Grade Top Connection
TUBING ABANDONED 31/2 2.99 8,098.0 8,160.0 6,375.8 9.30 J-55 BTCMOD
Completion Details
Top (TVD) Nominal
Top(ftKB) (ftKB) Top Ind (°) Item Des Com ID (in)
8,098.0 6,328.0 39.57 BLAST JT SHATTERED T 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 1 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" high
expansion wedge whipstock. Depth below 7977'
3/28/2017
2.500
7,979.0 6,236.3
39.59
FISH
3-1/2" by 7" high
expansion wedge whipstock. Depth below 7977'
3/31/2017
2.500
Perforations &Slots
Shot
Top(TVD) St. (TVD) Dens
Top (ftKB) St. (ftKB) (ftKB) (ftKB) Linked Zone Date (shots/ft) Type Com
7,945.0 8,094.0 6,210.1 6,324.9 C-4, C-3, C-2, 1E 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns
-20
8,349.0 8,362.0 6,521.5 6,531.6 A-5, 1E-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 A-4, 1E-20 2/2/1983 4.0 IPERF 90 deg. Ph; DA 4" csg guns
Mandrel Inserts
St
all
on Top (TVD) Valve Latch Port Size TRO Run
No Top (ftKB) (ftKB) Make Model OD (in) sem Type Type (in) (psi) Run Date Com
1 2,209.7 2,046.0 CAMCO KBUG 1 GAS LIFT GLV BK 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
3 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 GAS LIFT DMY BK 0.000 0.0 2/3/1983 In
Tubing
Abend
on
Notes: General & Safety
End Date Annotation
3/31/2017 NOTE; 2 Northen Solutions High Expansion Wedge Whipstock LEFT IN HOLE.
11/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0
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ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Kuparuk 1 E Pad
1 E-20
IE -201-1-01
Plan: 1E -20L1-01 wp03
Standard Planning Report
09 February, 2017
VA f19 P" I
BAKER
HUGHES
ConocoPhillips
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1 E Pad
Well:
1 E-20
Wellbore:
1E-201-1-01
Design:
1E-20L1-01_wp03
ConocoPhillips
Planning Report
Local Co-ordinate Reference
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105 70usft (1 E-20)
True
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
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
FS k1
BAKER
HUGHES
Wellbore 1E-201-1-01
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(°) (°) (nT)
BGGM2016 5/1/2017 17.66 80.93 57,541
Design 1E-201-1-01_wp03
Audit Notes:
Version: Phase: PLAN Tie On Depth: 9,350.00
Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction
(usft) (usft) (usft) (I
0.00 0.00 0.00 180.00
Plan Sections
Site
Kuparuk 1 E Pad
Site Position:
Measured
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
+N/ -S
+E/ -W
Rate
Rate
Rate
Well
1 E-20
(°)
(I
(usft)
Well Position
+N/ -S 0.00 usft
Northing:
5,960,000.68 usft Latitude:
70° 18' 5.359 N
(°) Target
+E/ -W 0.00 usft
Easting:
550,300.56 usft Longitude:
149° 35 33.326 W
Position Uncertainty
0.00 usft
Wellhead Elevation:
usft Ground Level:
0.00 usft
0.00
9,420.00
96.60
183.66
6,067.92
Wellbore 1E-201-1-01
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(°) (°) (nT)
BGGM2016 5/1/2017 17.66 80.93 57,541
Design 1E-201-1-01_wp03
Audit Notes:
Version: Phase: PLAN Tie On Depth: 9,350.00
Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction
(usft) (usft) (usft) (I
0.00 0.00 0.00 180.00
Plan Sections
Measured
TVD Below
Dogleg
Build
Tum
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(°)
(I
(usft)
(usft)
(usft)
(°/100ft)
(°/100ft)
(°1100ft)
(°) Target
9,350.00
100.85
181.20
6,078.53
588.20
4,079.54
0.00
0.00
0.00
0.00
9,420.00
96.60
183.66
6,067.92
519.09
4,076.60
7.00
-6.07
3.52
150.00
9,490.00
95.72
188.51
6,060.40
449.91
4,069.22
7.00
-1.25
6.93
100.00
9,690.00
93.15
174.70
6,044.85
251.09
4,063.69
7.00
-1.29
-6.90
260.00
9,900.00
88.08
160.90
6,042.58
46.41
4,107.94
7.00
-2.41
-6.57
250.00
9,970.00
88.09
156.00
6,044.92
-18.64
4,133.63
7.00
0.01
-7.00
270.00
10,170.00
88.15
170.01
6,051.53
-209.33
4,191.92
7.00
0.03
7.00
90.00
10,300.00
88.17
179.11
6,055.72
-338.54
4,204.23
7.00
0.02
7.00
90.00
10,425.00
90.44
187.56
6,057.23
-463.20
4,196.96
7.00
1.82
6.76
75.00
10,550.00
91.95
178.94
6,054.61
-587.85
4,189.88
7.00
1.21
-6.90
280.00
10,850.00
95.39
158.18
6,035.18
-879.64
4,248.83
7.00
1.15
-6.92
280.00
11,000.00
90.10
167.26
6,027.98
-1,022.51
4,293.25
7.00
-3.53
6.05
120.00
11,300.00
86.52
187.96
6,036.91
-1,320.44
4,305.73
7.00
-1.19
6.90
100.00
2/9/2017 3:10:55PM Page 2 COMPASS 5000.1 Build 74
ConocoPhillips reel
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1E Pad
Well:
1 E-20
Wellbore:
1E -20L1-01
Design:
1 E-20L1-01_wp03
Planned Survey
-46.25
4,145.32
Measured
Dogleg
Toolface
Depth Inclination
Map
Azimuth
(usft)
(°)
(°)
9,350.00
100.85
181.20
TIP/KOP
(usft)
(usft)
9,400.00
97.81
182.96
9,420.00
96.60
183.66
Start 7 dls
588.20
4,079.54
9,490.00
95.72
188.51
3
554,375.68
6,070.43
9,500.00
95.60
187.82
9,600.00
94.34
180.90
9,690.00
93.15
174.70
4
-519.09
7.00
9,700.00
92.91
174.05
9,800.00
90.50
167.47
9,900.00
88.08
160.90
5
554,366.29
6,059.41
9,970.00
88.09
156.00
6
-100.00
5,960,467.91
10,000.00
88.09
158.10
10,100.00
88.11
165.10
10,170.00
88.15
170.01
7
251.09
4,063.69
10,200.00
88.15
172.11
10,300.00
88.17
179.11
8
4,064.67
-241.15
10,400.00
89.99
185.87
10,425.00
90.44
187.56
9
-142.55
7.00
10,500.00
91.35
182.39
10,550.00
91.95
178.94
10
7.00
-110.23
10,600.00
92.56
175.49
10,700.00
93.74
168.58
10,800.00
94.86
161.65
10,850.00
95.39
158.18
11
10,900.00
93.64
161.21
11,000.00
90.10
167.26
12
11,100.00
88.89
174.15
11,200.00
87.69
181.05
11,300.00
86.52
187.96
Planned TD at 11300.00
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
TVD Below
-46.25
4,145.32
Vertical
Dogleg
Toolface
Map
Map
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(usft)
(usft)
(usft)
(°/100ft)
(°)
(usft)
(usft)
6,078.53
588.20
4,079.54
-588.20
0.00
0.00
5,960,616.11
554,375.68
6,070.43
538.90
4,077.75
-538.90
7.00
150.00
5,960,566.81
554,374.21
6,067.92
519.09
4,076.60
-519.09
7.00
150.29
5,960,547.00
554,373.20
6,060.40
449.91
4,069.22
-449.91
7.00
100.00
5,960,477.77
554,366.29
6,059.41
440.06
4,067.81
-440.06
7.00
-100.00
5,960,467.91
554,364.94
6,050.74
340.78
4,060.25
-340.78
7.00
-100.07
5,960,368.60
554,358.04
6,044.85
251.09
4,063.69
-251.09
7.00
-100.67
5,960,278.94
554,362.08
6,044.32
241.15
4,064.67
-241.15
7.00
-110.00
5,960,269.01
554,363.13
6,041.34
142.55
4,080.71
-142.55
7.00
-110.03
5,960,170.53
554,379.83
6,042.58
46.41
4,107.94
-46.41
7.00
-110.23
5,960,074.58
554,407.70
6,044.92 -18.64 4,133.63 18.64 7.00 -90.00 5,960,009.71 554,433.82
6,045.92
-46.25
4,145.32
46.25
7.00
90.00
5,959,982.18
554,445.70
6,049.24
-141.03
4,176.85
141.03
7.00
89.93
5,959,887.63
554,477.85
6,051.53
-209.33
4,191.92
209.33
7.00
89.70
5,959,819.44
554,493.38
6,052.50
-238.95
4,196.58
238.95
7.00
90.00
5,959,789.85
554,498.24
6,055.72
-338.54
4,204.23
338.54
7.00
89.93
5,959,690.32
554,506.55
6,057.33
-438.37
4,199.88
438.37
7.00
75.00
5,959,590.48
554,502.88
6,057.23
-463.20
4,196.96
463.20
7.00
74.89
5,959,565.63
554,500.12
6,056.06
-537.88
4,190.46
537.88
7.00
-80.00
5,959,490.92
554,494.12
6,054.61
-587.85
4,189.88
587.85
7.00
-80.08
5,959,440.95
554,493.87
6,052.65
-637.74
4,192.30
637.74
7.00
-80.00
5,959,391.08
554,496.63
6,047.15
-736.57
4,206.13
736.57
7.00
-80.14
5,959,292.36
554,511.12
6,039.65
-832.88
4,231.73
832.88
7.00
-80.52
5,959,196.23
554,537.36
6,035.18
-879.64
4,248.83
879.64
7.00
-81.04
5,959,149.58
554,554.77
6,031.24
-926.38
4,266.12
926.38
7.00
120.00
5,959,102.96
554,572.37
6,027.98
-1,022.51
4,293.25
1,022.51
7.00
120.24
5,959,007.03
554,600.14
6,028.87
-1,121.13
4,309.39
1,121.13
7.00
100.00
5,958,908.53
554,616.94
6,031.86
-1,220.94
4,313.57
1,220.94
7.00
99.94
5,958,808.76
554,621.79
6,036.91 •
-1,320.44
4,305.73
1,320.44
7.00
99.73
5,958,709.22
554,614.61
21912017 3 10 55PM Page 3 COMPASS 5000.9 Build 74
ConocoPhillips rias
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1E Pad
Well:
1 E-20
Wellbore:
IE -201-1-01
Design:
1 E-20L1-01_wp03
Targets
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 E-20
Mean Sea Level
1 E-20 @ 105.70usft (1 E-20)
True
Minimum Curvature
Target Name
hitlmiss target Dip Angle Dip Dir. TVD +Nl-S +E/ -W Northing Easting
Shape N (I (usft) (usft) (usft) (usft) (usft)
1E-201-1-01 T03
0.00 0.00 6,028.00
-8,904.361,144,408.63
5,958,758.00
1,694,632.00
plan misses target center by 1140120.95usft at 11200.00usft
MD (6031.86 TVD, -1220.94 N, 4313.57 E)
1,694,577.00
Point
Polygon
Point 1 6,056.00 0.00 0.00 5,959,595.00
1,694,577.00
1E-20 CTD Polygon
0.00 0.00 0.00
-6,188.001,144,253.79
5,961,473.00
1,694,459.00
plan misses target center by 1139967.00usft at 11200.00usft
MD (6031.86 TVD, -1220.94 N, 4313.57 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
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 7
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-201-1_Fault2_M 0.00 0.00 0.00 -8,066.931,144,359.23 5,959,595.00
1,694,577.00
plan misses target center by 1140082.17usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Rectangle (sides W1,000.00 1-11.00 D0.00)
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
plan misses target center by 1140066.21 usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 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 -201-1-01_T02 0.00 0.00 6,057.00 -8,319.661,144,315.53 5,959,342.00
1,694,535.00
plan misses target center by 1140024.06usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Point
1E-201-1-01 T01 000 0.00 6,041.00 -7,738.801,144,196.41 5,959,922.00 1,694,412.00
plan misses target center by 1139901.47usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Point
1E-201-1_Fault1_M 0.00 0.00 0.00 -6,660.691,144,497.66 5,961,002.00 1,694,706.00
plan misses target center by 1140213.02usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Rectangle (sides W1,000.00 1-11.00 D0.00)
1E -201-1-01_T04 0.00 0.00 6,037.00 -9,202.471,144,420.63 5,958,460.00 1,694,646.00
plan misses target center by 1140135.00usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Point
1E-201-1_Faultl 0.00 0.00 6,203.00 -6,660.691,144,497.66 5,961,002.00 1,694,706.00
plan misses target center by 1140197.08usft at 11200.00usft MD (6031.86 TVD, -1220.94 N, 4313.57 E)
Polygon
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
Latitude Longitude
70° 2' 27.889 N 140° 24' 39.050 W
70° 2'54.488 N 140° 24'31.719 W
70° 2' 36.092 N 140° 24'36.838 W
70° 2' 36.092 N 140° 24'36.838 W
70° 2' 33.703 N 140° 24'39.172 W
70° 2'39.517 N 140° 24'40,049 W
70° 2'49.539 N 140° 24'26.829 W
70° 2'24.977 N 140° 24'39.996 W
70° 2'49.539 N 140° 24'26.829 W
2/9/2017 3:10 55PM Page 4 COMPASS 5000.1 Build 74
2/9/2017 3:10 55PM Page 5 COMPASS 5000.1 Build 74
ConocoPhillips
FORS
ConocoPhillips
Planning Report
BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1 E-20
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1 E-20 @ 105.70usft (1 E-20)
Site:
Kuparuk 1 E Pad
North Reference:
True
Well:
1 E-20
Survey Calculation Method:
Minimum Curvature
Wellbore:
1E-201-1-01
Design:
1 E-20 L 1-01 _wp03
r.T
Casing Points
Measured Vertical
Casing Hole
Depth Depth
Diameter Diameter
(usft) (usft)
Name
(in) (in)
11,300.00 6,036.91
23/8"
2.375 3.000
Plan Annotations
Measured Vertical
Local Coordinates
Depth Depth
+N/ -S
+E/ -W
(usft) (usft)
(usft)
(usft) Comment
9,350.00 6,078.53
588.20
4,079.54 TIP/KOP
9,420.00 6,067.92
519.09
4,076.60 Start 7 dls
9,490.00 6,060.40
449.91
4,069.22 3
9,690.00 6,044.85
251.09
4,063.69 4
9,900.00 6,042.58
46.41
4,107.94 5
9,970.00 6,044.92
-18.64
4,133.63 6
10,170.00 6,051.53
-209.33
4,191.92 7
10,300.00 6,055.72
-338.54
4,204.23 8
10,425.00 6,057.23
-463.20
4,196.96 9
10,550.00 6,054.61
-587.85
4,189.88 10
10,850.00 6,035.18
-879.64
4,248.83 11
11,000.00 6,027.98
-1,022.51
4,293.25 12
11,300.00 6,036.91
-1,320.44
4,305.73 Planned TD at 11300.00
2/9/2017 3:10 55PM Page 5 COMPASS 5000.1 Build 74
True Vertical Depth (90 usft/in)
N
C
A
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W OtOw V CT CT WN'COD
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O O O O O CO CO CD (D to
W O CD C A W CO CO CT W
OOCr Cr NODI V Om A A w
CO CO NCT
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0 0 0 0 0 0 0 0 0 0 0 0 0
o+
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South( -)/North(+) (300 usft/in)
n
0
3
0
FI
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V
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U
Boyer, David L (CED)
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Thursday, January 16, 2020 2:37 PM
To: Boyer, David L (CED)
Cc: Ohlinger, James J; Hayes, James C; Davies, Stephen F (CED)
Subject: RE: [EXTERNAL]FW: Digital Surveys for KRU 1 E Wells
Attachments: 1E-201-1_Well Plan.xlsx; 1E-20L1-01_Well Plan.xlsx ZZ
Hi Dave,
I've attached excel files of the well plans for the 1E -20L1 & 1-1-01. It's looking like Jan. 22nd could be the possible spud
date now. If it creeps up any sooner than that I can let you know.
Thanks,
Shane Germann
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>
Sent: Thursday, January 16, 2020 2:13 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Subject: FW: [EXTERNAL]FW: Digital Surveys for KRU 1E Wells
From: Boyer, David L (CED) <david.boyer2@alaska.gov>
Sent: Thursday, January 16, 2020 2:09 PM
To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>
Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>
Subject: [EXTERNAL]FW: Digital Surveys for KRU 1E Wells
Hi James,
Is the spud date for these permits on track for Monday Jan. 20th.? Can either you or James Hayes send over the digital
surveys for plotting the well on Geoatlas map in our GeoGraphix database?
Thanks,
Dave Boyer
From: Boyer, David L (CED)
Sent: Thursday, January 16, 2020 12:09 PM
To: Hayes, James C <James.C.Hayes@conocophillips.com>
Subject: Digital Surveys for KRU 1E Wells
Hi James,
I just received two PTD applications for CoP KRU 1E -20L1 & L1-01 wells. Please e-mail over the proposed survey files for
both wells ASAP. Do you really expect the wells to be spudded on Monday 01/20? That is a state holiday and the PTD's
require four levels of review including the Commissioners. The turnaround is going to be tight on these.
Thanks,
Dave Boyer
AOGCC
TRANSMITTAL L LETTER CHECKLIST
WELL NAME: B (.L
PTD:
development _ Service Exploratory _ Stratigraphic Test — Non -Conventional
FIELD:IR"I/�OOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
7VV1
OPTIONS TEXT FOR APPROVAL LETTER
MULTI The permit is for a new wellbore segment of existing well Permit
LATERAL No. l-`� 3 _ppAPI No. 50-Qp- 00 -O
6.
(If last two digits Production should continue to be reported as a functio of the original
m API number are API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole name
PIT) and API number (50-
-_) from records, data and logs acquired for well
name on rmit .
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception order approving a spacingtion.
of any exception- (C°mean Name) Operator
assumes the liability y 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
sam les are fust caught and 10' ram le intervals throu tar et zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional {rye of well) until after (Compan�Name) has designed and
Well implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance a rovai of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
l% also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(13) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
PTD#: 2200070 Company ConocoPhillips Alaska, Inc. Initial Classlfype
Well Name: KUPARUK RIV UNIT 1E-201-1-01 Program DEV Well bore seg W
DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permitfeeattached ------------------ ---------- ----------------
NA______
2
Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
3
Unique well name and number - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - -
4
Well Io c at e d i n - a -defined pool - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - -- - - - - - - - -
5
Well located proper distance from drilling unit- boundary ------------------------
Yes -
. - - - - - - _ - - - - - - - - - - - - - - - - - - - -- - - - - - -
6
Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
7
Sufficient acreage available in_drilling unit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - _ - - - - - - --------------------------------
8
-if-deviated, is wellbore plat _included _ _ _ _ _ _ - _ _ _ _ _ _ _
Yes _
- - - - - _ Directional- plan -view & wellbore profile included.
9
Operator only affected party------- ----------- ------ ------------
Yes--------------------
------
10
Operator has -appropriate_ bond in force -----------------------------
Yes ------------------------
--- -------- - -- ---- ------
11
Permitoan be issued without conservation order_ - - - - - -
Yes -
-
Appr Date
12
Permitcanbeissuedwithoutadministrative_approval- - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - -- - -- -- - - - --- - - - - - - - - - - - -- - -- - - -
13
Can permit be approved before 15 -day wait- - - - - - - - - - - - - - - - - - - - - - - - -
Yes
DLB 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_mil e area of review identified (.For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA_ -
- - _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ -
16
Pre -produced injector: duration of pre production less than 3 months- (For service well only) - -
NA_ _
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
17
Nonconven. gas conforms to AS31.05 030([.1.A),(j.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
NA_ _
_ _ - _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ -
18
Conductor string -provided _________________________________________
NA__-----_Conductorset_inKRU1E-20
Engineering
19
Surface casing_ protects all -known_ USDWs -
NA_
Surface casing set in KRU 1 E-20
20
CMT_ vol_adequate_to circulate -on jcondjjctor _& surf_csg _ _ _ _ _ - _ _
NA_
Surface casing set and fully cemented - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
21
CMT _vol _adequate -to tie-inlongstringtosurfcsg----------------------------
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-adrilL has_a 10-403 for abandonment been approved - - - - - - - - - - - - - - - - - - - - -
NA_
26
Adequate wellbore separation proposed - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - Anti -collision analysis complete; no major risk failures - - - - - - - - - - - - -
27
If diverter required, does it meet_ regulations- - - - - - - - - - - - - - - - - - - - - - - -
NA_
Appr Date
28
Drilling fluid- program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - Max formation_ pressure is 3034 psig(9.4 ppg EMW); will drill w/_8.6 ppg EMW and maintain overbal w/ MPD - - - -
VTL 1/17/2020
29
BOPEs,-do they meet regulation - - - - - - - - - - - - - - ----- - - - - --
Yes-----------------------------------------------------------
30
BOPE-press rating appropriate; test to _(put psig in comments)- - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - MPSP is 2412 psig; will test BOPs_to 3500_psig _ - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ - _ - _ _ _ - -
31
Choke- manifold complies w/API_RP-53(May 84)----------------------------
Yes ------------------------------------------------------------------
32
Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
33
Is presence of 1-12S gas_probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - H2S measures required_ - - - - - - - - - - -
34
-Mechanical condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - -
NA_ _
_ - - _ _ _ - - - - _ _ _ - - - - - _ _ _ _
35
Permit can be issued w/o hydrogen_ sulfide measures - _ -
No_ -
- - - - - - Wells_on lE-Pad are_1-12S-bearing. H2S measures required.
Geology
36
Data -presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
---------------------------
Appr Date
37
Seismic analysis_ of shallow gas -zones -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
NA_ -
- - - - - - - _ - _ - - - - _ - _ - - - - - - - - - - - - - -
DLB 1/16/2020
38
Seabed condition survey _(if off --shore)__________________________________
- NA-
39
Contact name/phone for weekly -progress reports [exploratory only] - - - - - - - - - - - - - -
NA- -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
Do -S t l ZD pl-� I IZc�
