Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout220-020 Hilcorp Alaska, LLC Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8547
September 29, 2023
Mr. Mel Rixse
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Milne Point Conductor Annulus Corrosion Inhibitor Treatments 6/9 to 9/27/2023
Dear Mr. Rixse,
Enclosed please a copy of a spreadsheet with a list of thirteen Milne Point wells that were treated
with corrosion inhibiting casing filler in the surface casing by conductor annulus. The heavier than
water “grease-like” filler displaces water to prevent external casing corrosion that could result in
a surface casing leak. The attached spreadsheets include the well names, field, API and PTD
numbers, treatment dates and volumes.
If you have any additional questions, please contact me at 907-777-8406 or
dhorner@hilcorp.com.
Sincerely,
Darci Horner
Regulatory Tech
Hilcorp Alaska, LLC
Digitally signed by Darci Horner
(c-100048)
DN: cn=Darci Horner (c-100048)
Date: 2023.09.29 09:45:20 -
08'00'
Darci Horner
(c-100048)
Well Field API PTD
Initial Top
of Cement
(ft.)
Volume of
Cement
Pumped
(bbls)
Final Top of
Cement (ft.)
Cement
Pump Date
Corrosion
Inhibitor
Fill Volume
(gal)
Final CI Top
(ft.)
Corrosion
Inhibitor
Treatment
Date
Comments
MPB-35 MPU 50029237240000 2220850 14' 0 14' N/A 50 surface 9/27/2023 Drilled Sept/Oct 2022.
MPB-39 MPU 50029237470000 2230120 1'6" 0 1'6" N/A 10 surface 6/10/2023 Drilled Mar 2023.
MPI-20 MPU 50029236790000 2200490 10' 1 1 7/2/2023 5 surface 9/27/2023 Completed Apr 8, 2021.
MPI-29 MPU 50029237080000 2220060 6' 0.5 3 7/2/2023 15 surfce 9/27/2023
Drilled in March 2022. Completeted
on 4/30/22.
MPL-60 MPU 50029236780000 2200480 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPL-62 MPU 50029236850000 2200590 1' 0 1' N/A 10 surface 6/26/2023 Drilled in 2020.
MPM-13 MPU 50029236380000 2190870 20' 3.5 2' 8/2/2023 10 surface 9/27/2023 Drilled in 2019.
MPM-27 MPU 50029237160000 2220490 2' 0 2' N/A 20 surface 6/11/2023 Monobore. Drilled June 2022.
MPM-30 MPU 50029237300000 2221180 1' 0 1' N/A 10 surface 6/11/2023 Drilled in Oct 2022.
MPM-43 MPU 50029236710000 2200200 1' 0 1' N/A 10 surface 6/11/2023 Drilled in 2020.
MPM-62 MPU 50029237440000 2230060 1' 0 1' N/A 10 surface 6/11/2023 Completed May 2023.
MPS-45 MPU 50029236930000 2210420 1' 0 1' N/A 10 surface 6/12/2023 Drilled in June 2021.
MPS-47 MPU 50029236960000 2210470 4' 0 4' N/A 20 surface 6/12/2023 Drilled in August 2021.
Notes:
The 4" conductor outlets are any where from 1 to 3' down from the top of the conductor
Surface Casing by Conductor Annulus Cement Top Job and Fill Coat Corrosion Inhibitor (CI) Applications
Cement to surface means cement is up to the 4" outlets below the wellhead. From the 4" outlets up to the top of conductor was filled with Fill Coat #7
Initial top of cement footage measurement was taken from the 4" outlet down to the TOC
RBDMS JSB 100323
MPM-43 MPU 50029236710000 2200200 1'0 1'N/A 10 surface 6/11/2023 Drilled in 2020.
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23671-00-00Well Name/No. MILNE PT UNIT M-43Completion Status1-OILCompletion Date4/28/2020Permit to Drill2200200Operator Hilcorp Alaska, LLCMD15890TVD3543Current Status1-OIL9/22/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:ROP, DGR, AGR, ABG, ADR, EWR MD & TVD PB1, PB2, PB3NoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF7/20/2020112 15890 Electronic Data Set, Filename: MPU M-43 LWD Final.las33565EDDigital DataDF7/20/20206616 15852 Electronic Data Set, Filename: MPU M-43 ADR Quadrants All Curves.las33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final MD.cgm33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final TVD.cgm33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 Definitive Survey Report.pdf33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43_DSR.txt33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43_GIS.txt33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final MD.emf33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final TVD.emf33565EDDigital DataDF7/20/2020 Electronic File: MPU_M_43_Geosteering.dlis33565EDDigital DataDF7/20/2020 Electronic File: MPU_M_43_Geosteering.ver33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final MD.pdf33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final TVD.pdf33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final MD.tif33565EDDigital DataDF7/20/2020 Electronic File: MPU M-43 LWD Final TVD.tif33565EDDigital Data0 0 2200200 MILNE PT UNIT M-43 LOG HEADERS33565LogLog Header Scans0 0 2200200 MILNE PT UNIT M-43 PB1 LOG HEADERS33566LogLog Header ScansDF7/20/2020112 13000 Electronic Data Set, Filename: MPU M-43PB1 LWD Final.las33566EDDigital DataTuesday, September 22, 2020AOGCCPage 1 of 5PB1PB2PB3MPU M-43 LWDFinal.lasMPU M-43PB1 LWD Final.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23671-00-00Well Name/No. MILNE PT UNIT M-43Completion Status1-OILCompletion Date4/28/2020Permit to Drill2200200Operator Hilcorp Alaska, LLCMD15890TVD3543Current Status1-OIL9/22/2020UICNoDF7/20/20206616 12964 Electronic Data Set, Filename: MPU M-43PB1 ADR Quadrants All Curves.las33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final MD.cgm33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final TVD.cgm33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 Definitive Survey Report.pdf33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1_DSR.txt33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1_GIS.txt33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final MD.emf33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final MD.tif33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final TVD.emf33566EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB1_Geosteering.dlis33566EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB1_Geosteering.ver33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final MD.pdf33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final TVD.pdf33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final MD.tif33566EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB1 LWD Final TVD.tif33566EDDigital DataDF7/20/2020112 15570 Electronic Data Set, Filename: MPU M-43PB2 LWD Final.las33567EDDigital DataDF7/20/20206616 15533 Electronic Data Set, Filename: MPU M-43PB2 ADR Quadrants All Curves.las33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final MD.cgm33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final TVD.cgm33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 Definitive Survey Report.pdf33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2_DSR.txt33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2_GIS.txt33567EDDigital DataTuesday, September 22, 2020AOGCCPage 2 of 5MPU M-43PB2 LWD Final.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23671-00-00Well Name/No. MILNE PT UNIT M-43Completion Status1-OILCompletion Date4/28/2020Permit to Drill2200200Operator Hilcorp Alaska, LLCMD15890TVD3543Current Status1-OIL9/22/2020UICNoDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final MD.emf33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final TVD.emf33567EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB2_Geosteering.dlis33567EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB2_Geosteering.ver33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final MD.pdf33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final TVD.pdf33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final MD.tif33567EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB2 LWD Final TVD.tif33567EDDigital Data0 0 2200200 MILNE PT UNIT M-43 PB2 LOG HEADERS33567LogLog Header Scans0 0 2200200 MILNE PT UNIT M-43 PB3 LOG HEADERS33568LogLog Header ScansDF7/20/2020112 15880 Electronic Data Set, Filename: MPU M-43PB3 LWD Final.las33568EDDigital DataDF7/20/20206616 15842 Electronic Data Set, Filename: MPU M-43PB3 ADR Quadrants All Curves.las33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final MD.cgm33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final TVD.cgm33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 Definitive Survey Report.pdf33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3_DSR.txt33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3_GIS.txt33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final MD.emf33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final TVD.emf33568EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB3_Geosteering.dlis33568EDDigital DataDF7/20/2020 Electronic File: MPU_M_43PB3_Geosteering.ver33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final MD.pdf33568EDDigital DataTuesday, September 22, 2020AOGCCPage 3 of 5MPU M-43PB3 LWD Final.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23671-00-00Well Name/No. MILNE PT UNIT M-43Completion Status1-OILCompletion Date4/28/2020Permit to Drill2200200Operator Hilcorp Alaska, LLCMD15890TVD3543Current Status1-OIL9/22/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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 / NADF7/20/2020 Electronic File: MPU M-43PB3 LWD Final TVD.pdf33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final MD.tif33568EDDigital DataDF7/20/2020 Electronic File: MPU M-43PB3 LWD Final TVD.tif33568EDDigital DataC8/31/2020 Electronic File: M-43 EOW log (redrill).emf33716EDDigital DataC8/31/2020 Electronic File: M-43 EOW log (redrill).pdf33716EDDigital DataC8/31/2020 Electronic File: M-43 EOW log (redrill).tif33716EDDigital DataC8/31/2020 Electronic File: MPU M-43 Pre Well Geosteering Report.pdf33716EDDigital DataC8/31/2020 Electronic File: MPU M-43 redrill Geosteering End of Well Report.pdf33716EDDigital DataC8/31/2020 Electronic File: MPU M-43 redrill Post-Well Geosteering X-Section Summary.pdf33716EDDigital Data0 0 2200200 MILNE PT UNIT M-43 LOG HEADERS33716LogLog Header ScansC9/2/2020 Electronic File: MPM-43PB3 Geosteering End of Well Report.pdf33729EDDigital DataC9/2/2020 Electronic File: MPM-43PB3 Geosteering Log.pdf33729EDDigital DataC9/2/2020 Electronic File: MPM-43PB3 Post-Well Geosteering X-Sec.pdf33729EDDigital Data0 0 2200200 MILNE PT UNIT M-43 PB3 LOG HEADERS33729LogLog Header ScansTuesday, September 22, 2020AOGCCPage 4 of 5
DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23671-00-00Well Name/No. MILNE PT UNIT M-43Completion Status1-OILCompletion Date4/28/2020Permit to Drill2200200Operator Hilcorp Alaska, LLCMD15890TVD3543Current Status1-OIL9/22/2020UICNoComments:Compliance Reviewed By:Date:COMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:4/28/2020Release Date:3/12/2020Tuesday, September 22, 2020AOGCCPage 5 of 5M. Guhl9/22/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 8/27/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43, MPU M-43PB3 Geosteering
Received by the AOGCC 09/02/2020
PTD: 2200200
E-Set:33729
Abby Bell 09/02/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 8/27/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43 Geosteering
PTD: 2200200
E-Set: 33716
Received by the AOGCC 08/31/2020
Abby Bell 08/31/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 7/16/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43 PB1
MPU M-43 PB2
MPU M-43 PB3
MPU M-43 / MPU M-43 PB1 / MPU M-43 PB2 / MPU M-43 PB3
Received by the AOGCC 07/20/2020
PTD: 2200200
E-Set: 33565
Abby Bell 07/20/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 7/16/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43 PB1
MPU M-43 PB2
MPU M-43 PB3
MPU M-43 / MPU M-43 PB1 / MPU M-43 PB2 / MPU M-43 PB3
Received by the AOGCC 07/20/2020
PTD: 2200200
E-Set: 33566
Abby Bell 07/20/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 7/16/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43 PB1
MPU M-43 PB2
MPU M-43 PB3
MPU M-43 / MPU M-43 PB1 / MPU M-43 PB2 / MPU M-43 PB3
Received by the AOGCC 07/20/2020
PTD: 2200200
E-Set: 33567
Abby Bell 07/20/2020
Debra Oudean Hilcorp Alaska, LLC
GeoTech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: doudean@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337
Received By: Date:
DATE 7/16/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU M-43 (220-020)
MPU M-43 PB1
MPU M-43 PB2
MPU M-43 PB3
MPU M-43 / MPU M-43 PB1 / MPU M-43 PB2 / MPU M-43 PB3
Received by the AOGCC 07/20/2020
PTD: 2200200
E-Set: 33568
Abby Bell 07/20/2020
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: 1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:9. Ref Elevations: KB 17. Field / Pool(s):
GL: 25.1' BF:25.1'
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" X-52 114'
7" L-80 3,585'
4-1/2" L-80 3,588'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9-5/8" 40# L-80 Surface 6,627' Surface
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Tieback Assy.Tieback
TUBING RECORD
Cementless Screen Liner
5,350'4-1/2"
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
14,676'
Stg 2 L - 550 sx / T - 270 sx
3,581'
Surface
3,828' 12-1/4"
42"
13.5#
Stg 1 L - 575 sx / T - 400 sx
8-1/2"
~270 ft3
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
4/28/2020
5037' FSL, 111' FEL, Sec 14, T13N, R9E, UM, AK
583' FSL, 2028' FEL, Sec 24, T13N, R9E, UM, AK
220-020
Milne Point Field / Schrader Bluff Oil Pool
59'
14,762' MD / 3,588' TVD
HOLE SIZE AMOUNT
PULLED
50-029-23671-00-00
MPU M-43
534053 6027889
731' FNL, 1702' FEL, Sec 13, T13N, R9E, UM, AK
CEMENTING RECORD
6027419
SETTING DEPTH TVD
6018172
BOTTOM TOP
146 bbls
Surface
CASING WT. PER
FT.GRADE
26#
537744
537467
TOP
SETTING DEPTH MD
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
5,350' Surface
DEPTH SET (MD)
5,326' MD / 3,572' TVD
PACKER SET (MD/TVD)
5,339'
215.5# 114'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
5/8/2020
Date of Test:
2453
5/17/2020 24
Flow Tubing
0
139
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
108139
Jet Pump
***Please see attached schematic for Solid/Screen Liner Detail***
Liner run on 4/23/2020
1282
ROP, DGR, AGR, ABG, ADR, EWR MD & TVD PB1, PB2, PB3
Sr Res EngSr Pet GeoSr Pet Eng
N/A
12.7
Oil-Bbl: Water-Bbl:
1282 0298
April 19, 2020
March 14, 2020
ADL388235, ADL025514
LONS 16-004
2,337' MD / 1,889' TVD
N/AN/A
N/A
15,890' MD / 3,543' TVD
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 12:27 pm, May 18, 2020
Completion Date
4/28/2020
HEW
RBDMS HEW 5/21/2020
DSR-5/21/2020SFD 5/22/2020MGR17SEP2020
14,767
G
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
2,337' 1,889'
Top of Productive Interval SB NB 6,627' 3,828'
1,448' 1,345'
2,416' 1,935'
4,704' 3,282'
6,203' 3,794'
6,488' 3,826'
SB NB
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Cody Dinger
Contact Email:cdinger@hilcorp.com
Authorized Contact Phone: 777-8389
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
FORMATION TESTS
Permafrost - Top
SV5
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inc lination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered):
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
SB NB
SV1
Ugnu LA3
Formation at total depth:
SB NA
Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report, OH ST Summary
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
No
NoSidewall Cores: Yes No
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2020.05.18 12:08:06 -08'00'
Monty M
Myers
_____________________________________________________________________________________
Revised By: CJD 5/18/2020
SCHEMATIC
Milne Point Unit
Well: MPU M-43
Last Completed: 4/28/2020
PTD: 220-020
+
+CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20"x34” Conductor (Insulated)215.5 / X-52 / Weld N/A Surface 107’ N/A
9-5/8" Surface 40 / L-80 / TXP 8.679” Surface 6,627’ 0.0758
7” Tieback 26/ L-80 / TXP 6.151” Surface 5,350’ 0.0383
4-1/2” Screen Liner 250ђ 13.5 / L-80 / Hydril 625 3.920” 5,339’ 14,676’ 0.0149
TUBING DETAIL
4-1/2” Tubing 12.6 / L-80 / TXP 3.958” Surface 5,350’ 0.0087
OPEN HOLE / CEMENT DETAIL
42” 50 bbls (10 Yards Pilecrete dumped down backside)
12-1/4” 1st stage L – 575 sx / T – 400 sx
12-1/4” 2nd stage L – 550 sx / T – 270 sx
8-1/2” Cementless Slotted Liner in 8-1/2” hole
WELL INCLINATION DETAIL
KOP @ 232’ MD
Max Hole Angle = 67° @ Jet Pump
Max Hole Angle = 68° @ XN profile
Max Hole Angle = 68° @ Tubing tail
Max Hole Angle = 94.9°
TREE & WELLHEAD
Tree Cameron 4 1/16" 5M
Wellhead FMC 11" 5M TC-1A w/11" x 4 1/2" TC-II Top and Bottom Tubing
Hanger with 4" CIW "H" BPV profile. 2ea 3/8" NPT control lines.
JEWELRY DETAIL
No. Top MD Item Drift ID
Upper Completion
1 28.8’ 11” x 4-1/2” Tubing Hanger 3.970”
3 5,268’ 4.5” Baker Zenith Gauge Carrier Sub 3.874”
4 5,278’ 4.5” Sliding Sleeve 3.813”
5 5,286’ 4-1/2” Zenith Ported Pressure Sub 3.889”
6 5,305’ 4.5” X Nipple (3.813” Packing Bore) 3.813”
7 5,326’ 7” x 4.5”Retrievable Packer 3.890”
8 5,339’ 4.5” XN Nipple (MIN ID = 3.725”) 3.813”
9 5,350’ 4.5” WLEG 3.958”
Lower Completion
10 5,339’ BOT SLZXP Liner Top Packer w/BD Slips 7” x 9-5/8” 6.170”
11 5,350’ 7” Tieback Assy. (8.25” OD No-Go) 6.151”
12 5,360’ 7” Hydril 563 L-80 x 4-1/2” Hydril 625 L-80 XO 5.924”
13 14,767’ Round nose float shoe -
GENERAL WELL INFO
API: 50-029-23671-00-00
Completed by Doyon 14 on 04/28/2020
4-1/2” SOLID LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
4 5,364’ 3,590’ 5,529’ 3,650’
4 7,003’ 3,823’ 7,168’ 3,821’
2 9,368’ 3,766’ 9,450’ 3,763’
10 10,824’ 3,722’ 11,235’ 3,713’
9 12,442’ 3,684’ 12,812’ 3,670’
5 13,340’ 3,650’ 13,548’ 3,643’
4-1/2” Screen LINER DETAIL
Jts Top
(MD)
Top
(TVD)
Btm
(MD)
Btm
(TVD)
35 5,529’ 3,650’ 7,003’ 3,823’
53 7,168’ 3,821’ 9,368’ 3,766’
34 9,450’ 3,763’ 10,824’ 3,722’
30 11,235’ 3,713’ 12,442’ 3,684’
13 12,812’ 3,670’ 13,340’ 3,650’
29 13,548’ 3,643’ 14,725’ 3,589’
14,767
Activity DateO Ops Summary
3/11/2020 See MPU M-25 for previous activities.;Blow down rig floor water & steam lines. Disconnect rig floor utility lines for rig move. Move rock washer with bed truck.
Skid rig floor into moving position.;PJSM, Notify DSO, jack up rig and move off M-25, align rig to back over 43, shuffle rig mats into position, spot rig over M-
43;Shim Rig. Set surface Annular preventer on Well Head. M/U first section of 20" diverter line. Skid rig floor into drilling position.
SimOps: Spot Rockwasher and service company buildings around rig.;Finish nipple up diverter system. Install landings and walkways. Spot fuel trailer.
Ready Rig floor, install 90' mousehole.
Load BHA and HWDP into pipe shed.
M/U stand of HWDP and level rig over well. Nipple up riser.
3/12/2020 C/O saver sub, inspect grabber dies, Load 580 bbls 8.8 spud mud into the pits, function annular and knife valve to make sure operating correctly. Spot, R/U
water tanks and fill same. Place diverter warning signs and containment at EOD. Work on acceptance checklist. Put rig on hi li ne power @ 10:40;Crew
change, Finish installing 90' mouse hole, Record new RKBs, house keeping on rig floor and pipe shed, function test rig evac alarm, Replace bearing on drag
chain, C/O bleeder valve on MP 2, Air pump on accumulator locked up, install new pump.;PJSM, P/U and rack 6 stands 5'' HWDP w/ jar stand in the
derrick.;Preform Diverter test. Witnessed by AOGCC rep Austin Mcleod, Knife valve opened in 17 sec, Annular closed in 25 sec. Perform accumulator
drawdown test, sys pressure 3000 psi, after closure 1800 psi. 200 psi attained in 35 sec Full pressure in 140 sec.;Nitrogen bottle average 2166 psi Tests
conducted with 5'' Drill Pipe. Closest ignition source, light plant and heater @ 134' f/ end of diverter. Test rig gas alarms. Accept rig @ 18:00.;PJSM, M/U BHA
#1: 12-1/4" Kymera KM633X bit, 8" mud motor w/ ABH set at 1.5°, bottle neck XO to 35'. RIH one stand 5" HWDP and tag bottom @ 113'. Fill lines, hole and
stack w/ H²O.;Knife valve leaking, drain stack and blow down Topdrive. Split flange at knife valve and visually inspect. Install new flange gasket and bag seal.
Flood stack, still leaking. Split open and inspect again, still leaking after flooding stack again.;Replace knife valve and flood stack. Still leaking. Drain stack and
blow down TopDrive. Phase 3 weather conditions called in field.;Phase 3 weather conditions. Shut down operations. Cease all outside work. Limit rig work to
minimal risk tasks. Inspect tools and equipment around rig and various light duty cleaning jobs. Inspect and troubleshoot knife valves in Cellar.;Daily Loss = 0
bbls, Cumulative losses = 0 bbls
Hauled 775 bbls H2O from L-Pad for total = 775 bbls
Hauled 0 bbls to MPU G&I 0 bbls cuttings/mud/cement for total = 0 bbls
3/13/2020 Milne Point at Phase 3 weather conditions, no outside work. Limit rig work to minimal risk tasks and cleaning projects.;MP reduced to phase 2, W/O G & I to
get up and running and approval f/ MP wells foreman before resuming drilling operations. Continue to troubleshoot leaking knife valve issue, grease up valve
slide and re-install and function test same, good. Clear snow drifts on pad. POOH w/ Motor and bit.;Milne Point went to Phase 3 weather conditions @ 11:30,
no outside work. Limit rig work to minimal risk tasks and cleaning projects.
3/14/2020 Milne Point in Phase 3 weather conditions, no outside work. Limit rig work to minimal risk tasks and cleaning projects. At 08:00 reduced to phase 2
conditions.;M/U stand HWDP from 90' mouse hole, Run BHA in the hole, flood lines, test stand pipe, mud lines and top drive to 3500 psi for 5 min completing
last item on checklist, BD TD and set std HW back in mouse hole, Leave MM and bit hanging.;W/O G & I to get up and running, B-Pad and access road drifts
cleared, W/O approval f/ MP wells foreman before resuming drilling operations, phase 3 conditions called at 09:30.;Milne Point in Phase 3 weather conditions,
no outside work. Limit rig work to minimal risk tasks and cleaning projects.;Weather conditions reduced to Phase 2. Continue light duty rig tasks while waiting
on road conditions to improve and cleared for travel to B-Pad. New crew double checking all equipment and prep for spud.;Weather phase conditions
downgraded to phase 1. Mobilize all drilling personnel to rig. Ensure G&I and L-Pad water source are operational. Clear pad of drifts and position trucks in
drilling positions.;Pre-Spud meeting with all parties involved. Notify MPOPS of upcoming spud.;Drill out 20" conductor f/ 113' to 114'. Drill 12-1/4" hole from
114' to 139'. 450 GPM, 620 psi. 60 RPM, 4-5k Tq. Utilize fresh water for first 10' of drilling & swap to 8.7 ppg spud mud on the fly. PU - 55k, SO - 57k, Rot -
55k.;Stand pipe clamp bolt sheared and fell to rig floor. Pull off bottom and put stand of HWDP in mousehole. Blow down topdrive and inspect Derrick.
Replace bolt. Inspect other standpipe and cement line clamp bolts for visual indication of fatigue.;Drill 12-1/4" hole from 139' to 220'. 450 GPM, 620 psi. 60
RPM, 4-5k Tq. PU - 55k, SO - 57k, Rot - 55k.;Daily Loss = 0 bbls, Cumulative losses = 0 bbls
Hauled 0 bbls H2O from L-Pad for total = 775 bbls
Hauled 0 bbls to MPU G&I 0 bbls cuttings/mud/cement for total = 0 bbls
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
MP M-43
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:2010894D MPU M-43 Drilling
Spud Date:
3/15/2020 Circulate 2x bottoms up while reaming f/ 220' t/ 128'. POOH f/ 128' t/ 32'. Blow down top drive. Inspect bit., found rock wedged on cone, remove same.;PU /
MU 12.25'' BHA#1. KM633X 12.25'' bit, 1.5 deg mud motor, DM collar, EWR-M5 collar, ILS, TM collar, UBHO, orientate UBH0 to motor. Upload and test
MWD, RIH with 3-NMFDCs, XO to 182.48', M/U Stand of HWDP and TD, tag @ 220'. Gyro on standby at rig.;Drill 12-1/4" surface hole f/ 220' t/ 401', (400’
TVD) 181' drilled, 72.4’/hr AROP. 450 GPM, 850 PSI, 60 RPM, 3K TQ, 5-7K WOB MW 9 in / 9+ out, vis 300 in / out, 9.39 ECD. 65K PU / 70K SO / 70K ROT
Kick off @ 273’, build 3 deg/100'.;Drill 12-1/4" surface hole f/ 401' t/ 1028', (1004’ TVD) 627' drilled, 104.5’/hr AROP. 550 GPM, 1500 PSI, 60 RPM, 4K TQ, 5-
15K WOB. MW 9 ppg in / 9.1 out, vis 222 in / 300 out, 9.73 ECD. 85K PU / 86K SO / 85K ROT. 80’ build 4°/100'.;Drill 12-1/4" surface hole f/ 1028' t/ 1402',
(1311’ TVD) 374' drilled, 124.7’/hr AROP. 550 GPM, 1500 PSI, 60 RPM, 4K TQ, 5-15K WOB MW 9 in / 9.1 out, vis 158 in / 251 out, 9.91 ECD. 87K PU / 88K
SO / 86K ROT Continue build 4°/100'.;High Line power went down on Rig at 21:05. On Rig Gen power at 21:10. Work string 20' with 1 BPM while 2nd Gen
warmed up and brought on line.;Drill 12-1/4" surface hole f/ 1402' t/ 1660', (1497’ TVD) 258' drilled, 103.2’/hr AROP. 550 GPM, 1610 PSI, 60 RPM, 5K TQ, 5-
15K WOB MW 9.1 in / 9.2 out, vis 231 in / 300 out, 10.12 ECD.92K PU / 88K SO / 87K ROT Max Gas - 34u
Continue build 4°/100'.;Drill 12-1/4" surface hole f/ 1660' t/ 2455', (1966’ TVD) 795' drilled, 132.5’/hr AROP. 500 GPM, 1390 PSI, 60 RPM, 3-7K TQ, 5-15K
WOB MW 9.4 in / 9.5 out, vis 95 in / 120 out, 10.19 ECD.108K PU / 88K SO / 100K ROT Max Gas - 99u EOB @ 1728’. Hold 54.11° tangent;Base of
Permafrost logged at 2355’ MD / 1900’ TVD Last survey at 2415.74' MD / 1934.62' TVD, 56.49° inc, 66.52° azm, 4.39' from plan, 4.33' high and 0.73'
right.;Daily Loss = 0 bbls, Cumulative losses = 0 bbls
Hauled 1200 bbls H2O from L-Pad for total = 1975 bbls
Hauled 0 bbls Source Water from G&I for total = 0 bbls
Hauled 1313 bbls to MPU G&I cuttings/mud/cement for total = 1313 bbls
3/16/2020 Drill 12-1/4" surface hole f/ 2455' t/ 3216', (1966’ TVD) 761' drilled, 126.8’/hr AROP.550 GPM, 1860 PSI, 80 RPM, 7K TQ, 10K WOB MW 9.3 in / 9.3+ out, vis
136 in / out, 10.19 ECD. 120K PU / 90K SO / 105K ROT Max Gas - 3052u.;hold 54 deg tangent, pump 30 bbl hi vis at 3216', sweep back on time w/ 20%
increase. Top of Ugnu (MP_UG4) logged at 2873’ MD / 2191’ TVD Phase 2 weather conditions @ 07:00 and reduced to phase 1 @ 08:30.;Drill 12-1/4"
surface hole f/ 3216' t/ 4074', (2884’ TVD) 858' drilled, 143’/hr AROP. 550 GPM, 2100 PSI, 80 RPM, 10K TQ, 5-15K WOB MW 9.3 in / 9.3 out, vis 180 in / 221
out, 10.35 ECD. 150K PU / 97K SO / 115K ROT Max Gas - 76u.;End of tangent at 3788'. Pump 30 bbl hi vis sweep @ 3693', back on time w/ 40% increase.
**Rig on High Line power @ 18:00**;Drill 12-1/4" surface hole f/ 4074' t/ 4644', (3250’ TVD) 570' drilled, 95’/hr AROP. 550 GPM, 2000 PSI, 80 RPM, 14K TQ, 5-
15K WOB MW 9.2 in / 9.2 out, vis 101 in / 168 out, 10.12 ECD. 165K PU / 100K SO / 120K ROT Max Gas - 91u.;Target 4° build and turn for landing. Pump
30 bbl hi vis sweep @ 4300', return was not recognized at surface.;Drill 12-1/4" surface hole f/ 4644' t/ 5340', (3583’ TVD) 696' drilled, 116’/hr AROP. 550
GPM, 2000 PSI, 80 RPM, 14K TQ, 5-15K WOB MW 9.4 in / 9.4 out, vis 120 in / 116 out, 10.28 ECD. 165K PU / 95K SO / 125K ROT Max Gas - 238u
Continue target 4° build and turn for landing.;Top of Ugnu-L logged at 4701’ MD / 3280’ TVD. survey at 5271.73' MD / 3555.59' TVD, 66.75° inc, 136.63° azm,
11.75' from plan, 10.1' high and 6.02' left.;Daily Loss = 0 bbls, Cumulative losses = 0 bbls
Hauled 1310 bbls H2O from L-Pad for total = 3285 bbls
Hauled 1563 bbls to MPU G&I cuttings/mud/cement for total = 2876 bbls
3/17/2020 Drill 12-1/4" surface hole f/ 5340' t/ 5715', (3710’ TVD) 379' drilled, 63.16’/hr AROP. 550 GPM, 2200 PSI, 80 RPM, 15K TQ, 12-15K WOB MW 9.3 in / 9.4 out,
vis 150 in / 180 out, 10.3 ECD. 173K PU / 90K SO / 120K ROT Max Gas - 241u.;Pump 30 bbl hi vis sweep @ 5596', back 500 stks late w/ 10% increase.
Continue target 4° build and turn for landing.;Drill 12-1/4" surface hole f/ 5715' t/ 6263' (3800’ TVD) 548' drilled, 91.3’/hr AROP. 550 GPM, 2100 PSI, 80 RPM,
17K TQ, 5-15K WOB MW 9.3 in / 9.4 out, vis 96 in / 187 out, 10.27 ECD.175K PU / 85K SO / 115K ROT Max gas = 99u
Continue 4° build & turn for landing. SB NA at 6203' MD / 3794' TVD.;Drill 12-1/4" surface hole f/ 6263' t/ 6634' (3828' TVD) 371' drilled, 61.8'/hr AROP. TD of
surface hole section. 550 GPM, 1900 PSI, 80 RPM, 15K TQ, 5-15K WOB. MW 9.3 in / 9.4 out, vis 64 in / 118 out, 10.17 ECD. 178K PU / 85K SO / 118K ROT.
Max gas = 356u.;SB NB @ 6489' MD / 3827' TVD.;Obtain final survey. Pump 30 bbl hi-vis sweep w/ nut plug marker. Sweep back 100 strokes late w/ 10%
increase. Reciprocate pipe from 6634' to 6551'. Finished mud treatment while circulating, YP at 21. Ream back to bottom, perform 5 min. flow check -
static.;BROOH f/ 6634' t/ 5884' at 5-10 min stand, slow as needed to avoid any packing off issues, continue to treat mud BROOH. 550 GPM, 1720 PSI, 80
RPM, 15 TQ, Correct displacement at this point. PU 190K, SO 90K.;Milne point lost high line power, put rig on gen power.;Continue to BROOH f/ 5884' to
5694' at 550 gpm, 1700 psi, 80 RPM, 15 TQ, slow as needed to avoid any packing off issues, continue to treat mud BROOH.;Daily losses = 0 bbls, Cumulative
losses = 0 bbls.
Hauled 2045 bbls H2O from L-Pad for total = 5330 bbls
Hauled 1736 bbls to MPU G&I cuttings/mud/cement for total = 4612 bbls
3/18/2020 BROOH f/ 5694' t/ 3409' at 5-10 min stand, slow as needed to avoid any packing off issues, continue to treat mud BROOH. 550 GPM, 1580 PSI, 80 RPM, 15
TQ, Correct displacement at this point. M Pad hi line power back online at 0900 hrs.;BROOH f/ 3409' t/ 2035' at 5-10 min stand, hole severely unloading, pull
slow @ 30 min std to 1930' until clean, 550 GPM, 1400 PSI, 60-80 RPM, 12 TQ, BROOH to 743', pulled the last two stands slow to allow thewellbore to clean
up, 550 GPM, 1250 PSI, 60 RPM, 5K TQ. Rig on hi line power at 1830 hrs.;POOH on elevators from 743', laying down excess HWDP to 431'.;Lost hi line
power at 2120 hrs. Start two rig generators and re-start rig equipment.;POOH from 431' laying down excess HWDP. Rack back stand w/ HWDP, jar & HWDP
to 179'. L/D three NMFDC to 121'. Read MWD tools. L/D remainder of BHA from 121'. Clear rig floor. Bit grade : 1-1-CT-A-E-I-SD-TD 9.2 bbls total lost on trip
out.;R/U Volant tool, 350T spiders, strap tongs. 3.5 BPH loss rate.;M/U 9-5/8" casing shoe track to 199'. Float shoe, shoe joint w/ two centralizers & 4 stop
rings, spacer joint w/ centralizer, float collar w/ bypass baffle, float joint w/ centralizer & two stop rings , baffle adapter, baffle joint w/ centralizer & two stop
rings & joint #5 w/ centralizer.;Bakerlok first 4 connections and torque to 23K ft/lbs with Doyon Volant tool. Check floats & pump through floats - good. Losing 3
BPH.;Run 9-5/8" 40# L-80 TXP-BTC SR casing f/ 199' t/ 794'. Torque connections to 21K w/ Doyon volant tool. Install 9-5/8" x 12-1/4" centralizers on each
joint #6 to #20. Losing 3 BPH.;Daily losses = 0 bbls, Cumulative losses = 0 bbls
Hauled 1210 bbls H2O from L-Pad for total = 6540 bbls
Hauled 1216 bbls to MPU G&I cuttings/mud/cement for total = 5828 bbls
Hauled 58 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/19/2020 Run 9-5/8" 40# L-80 TXP-BTC SR casing f/ 794' t/ 3166'. TQ connections to 21K ft/lbs w/ volant tool. Fill on the fly topping off every 10 jts. Install a centralizer
on ea. jt #6 to #20, then on every other jt to jt #50. 3 BPH loss rate. Rig on hi line @ 10:00.;CBU, Stage pump to 4.5 bpm, 190 psi, reciprocating pipe slow,
continue to lose 3 bph while circulating. PU 150K, SO 95K.;Run 9-5/8" casing f/ 3166' t/ 4039' at jt 102. TQ connections to 21K ft/lbs w/ volant tool. Fill on the
fly and top off every 10 jts. Note, damaged pin on jt 83, replace with jt 171, C/O collar on jt 82. Continue w/ 3 bph loss rate.;M/U ESC with pup jt above and
below @ per HES rep to 4078', verify pinned for 3300 psi, continue to run casing to 4865', Fill on the fly and top off every 10 jts. Install 1 centralizer on ea jt on
5 jts above and below ESC tool then every other jt f/ # 108 - 122.;Run 9-5/8" 40# L-80 TXP-BTC SR casing f/ 4865' t/ 6629'.TQ connections to 21K ft/lbs w/
volant tool. Fill on the fly and top off every 10 jts. Install 1 centralizer every other jt f/ #122 - 164. 58.3 bbls lost during casing run.;Total of 166 joints of casing
ran, 78 each 9.625"x12.25" centralizers and 10 stop rings ran.;Stage up pumps to 6 BPM, 270 PSI. Engage rotary w/ 20K TQ limit 1 RPM while reciprocating
pipe f/ 6629' t/ 6600'. Initial 315K PU 100K SO, cleaned up to 250K PU / 125K SO & pressure reduced to 140 PSI. Treat mud for cement job. Losing 4 BPH.
Spine road open, call cementers & extra trucks at 00:15.;Blow down top drive. Cleaned and inspected Volant dies. R/U cement lines and blow air to cementers
to verify lines clear.;Continue to circulate at 6 BPM, 240 PSI while rigging up cementers, waiting on trucks, filling cement water tank and mixing black water
pills. Rotate w/ 20K TQ limit 1 RPM while reciprocating pipe f/ 6629' t/ 6600'. Losing 4 BPH. Total of 6.7 bottoms up circulated.;Daily losses (midnight) = 62
bbls, Cumulative losses = 62 bbls
Hauled 125 bbls H2O from L-Pad for total = 6665 bbls
Hauled 694 bbls to MPU G&I cuttings/mud/cement for total = 3570 bbls
Hauled 58 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/20/2020 Continue to circulate at 6 BPM, 240 PSI, finish rigging up cementers, 360 bbls source water on location, waiting on another 125 bbls to arrive, Held PJSM with
all parties involved. Rotate w/ 20K TQ limit 1 RPM while reciprocating pipe f/ 6629' t/ 6600'. PU 300K, SO 100K 40 bbls losses circulating.;Continue to
circulate, rotate and work string -Troubleshoot HES density readings, off by .3 -10ths, reading higher on scale with water. power down and reboot same. no
change.;Shut down, swap to cementers. HES pump 5 bbl H20, Test lines to 250/4000 psi, Good. Pump 1st stage, HES pump 52 bbl 10 ppg tuned spacer w/ #4
Red Die & Poly flake in first 10 bbl. Drop bottom Bypass plug, Mix & pump 239 bbl 12 ppg Lead cmt. (575 SX) 5 bpm, 360 psi.;Mix and pump 82 bbls 15.8 tail
cmt (400 SX) 4 bpm, 420 psi. Drop shutoff plug, pump 20 bbls H20, Swap to rig, pump 268 bbls 9.4 mud 7 bpm, 260 psi. Swap to HES, pump 80 bbls 9.4
tuned spacer.;Displace with rig at 5.5 bpm 9.4 ppg mud. park w/ string in tension @ 6627', slow to 3 bpm on last 10 bbls, FCP 580 psi Bump plug @ 3830
strokes. 68 strokes early from calculated. Pressure 600 psi over FCP @ 1100 psi, hold 5 min. Good Bleed down and check floats- good. CIP @
13:35.;Pressure up to 3500 psi attempting to open ESC, Bleed off and pressure to 4000 psi shifting ES cementer tool open. Reciprocate and rotate entire job,
7 bbl losses displacing cmt. Submit 24 hr BOP test notification @ 10:34 hrs.;Stage up pumps to 6 bpm at 310 psi.Pol-E-flake back at 1173 strokes, at 1654
stks dump 57 bbls mud push and contaminated thick mud returns to rock washer. Dump total 323 bbls thick contaminated mud to rock washer then divert
back to pits. Trace cement observed.;Blow down surface equipment and flush all equipment with black water to clean up cmt. Disconnect hyd lines on knife
valve, cycle bag 2 times flushing with black water. 16:42 Phase 2 driving conditions at Milne Point.;Continue to circulate through ES cementer 6 bpm, 200 psi
while preparing for 2nd stage cement job and cement to reach 100 psi compressive strength in 9.5 hrs 6.5 bbls lost.;Continue to circulate through ES cementer
at 6 bpm, 200 psi. PJSM for cement job with all parties involved. Discussed convoy of trucks in Phase 2 conditions. Air up silos, prime cement trucks & load
spacer.;Pump 5 bbls water. Attempt pressure test, hammer union connection leaked in cement unit leaked @ 3500 PSI. Change seal & tighten. Pressure test
lines to 1000/4000 PSI - good. Mix & pump 60 bbls 10.0 ppg Tuned Spacer @ 3.5 BPM, 120 PSI.;Mix & pump 431.7 bbls 10.7 ppg Perm L lead cement (550
sks) 4.407^3/sk yield @ 4.0 BPM, 350 PSI. Spacer back @ 268 bbls lead pumped. Mix & pump 56.2 bbls 15.8 ppg Premium G tail cement (270 sks)
1.169^3/sk yield @ 2.2 BPM, 200 PSI. Drop closing plug. Pump 20 bbls of fresh water @ 5.7 BPM, 360 PSI.;Displace w/ 9.4 ppg mud with rig mud pump #2 @
4.7 BPM, 520 PSI. Slow to 3.0 BPM, 390 PSI for last 10 bbls. Bumped plug at 1760 strokes, 29 strokes late. Pressure up and close ES cementer at 1300 PSI
(910 PSI over FCP).;CIP @ 03:07. 158 bbls interface before good cement. 146.25 bbls of good cement back to surface. Open bleeder with no flow back,
verified ES cementer closed. No losses during cement job.;Drain stack. Disconnect knife valve accumulator lines. Flush stack w/ black water functioning
annular 6 times. Vacuum mud out of casing prior to cutting. Begin N/D diverter line.;Release air from air boot & hoist diverter stack. Install casing slips as per
wellhead rep and set w/ 135K on slips. Cut 9-5/8" casing and dress stump. L/D 17.48' cut joint.;Daily losses = 53.5 bbls, Cumulative losses = 115.5
bbls.;Hauled 125 bbls H2O from L-Pad for total = 6790 bbls
Hauled 585 bbls Source Water from G&I for total = 585 bbls
Hauled 857 bbls to MPU G&I cuttings/mud/cement for total = 4427 bbls
Hauled 58 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/21/2020 Set diverter stack down. N/D flow nipple, riser and diverter stack. L/D 90' mouse hole. R/D diverter line. Simops: clear rig floor, clean and load out casing
equipment, volant, clean in pits.;Install FMC slip lock head, casing and tubing spools @ per WH rep. Test seals on slip lock head to 2475 PSI (80% of 9-5/8''
collapse). Torque bottom ring and perform final pressure test of 500 psi for 5 min and 2475 PSI for 10 min. - good. Remove VR plug, install annulus valve on
tbg spool.;Set stack on tubing spool. N/U BOP stack, install kill line, turn buckles, trip nipple & accumulator lines. Remove 13-3/8" spacer spool on BOP
stack. Sim-ops: clean pits. Rig electrician test rig gas alarms.;R/U test equipment. Install test plug w/ 4-1/2" test joint. Fill stack, found leak between tubing
spool & casing spool. Tighten flange between tubing spool & casing spool.;Perform initial BOP testing as per AOGCC & PTD requirements. AOGCC inspector
Jeff Jones waived witness of testing at 9:46 on 21 March 2020. All tests performed with fresh water, to 250 PSI low / 3000 PSI high, held for 5 min. each and
charted.;1) Annular on 4.5" test joint, choke valves 1, 12, 13, 14, kill line Demco & upper IBOP. 2) Upper 4.5"x7" VBR on 4.5" test joint, choke valves 9, 11,
HCR kill & lower IBOP. 3) Choke valves 5, 8, 10, manual kill & 5" FOSV #1. 4) Choke valves 4, 6, 7 & 5" FOSV #2.;5) Lower 3.5"x6" VBR on 4.5" test joint & 5"
dart valve. 6) Upper 4.5"x7" VBR on 5" test joint, choke valve 2, 3.5" FOSV. 7) Manual choke & 3.5" dart valve. 8) HCR choke. 9 ) Lower 3.5"x6" VBR on 5" test
joint. 10) Choke valve 3 & blind rams 11) Hydraulic choke "B" 12) Manual choke "A";13) Upper 4.5"x7" VBR on 7" test joint. Accumulator test: 3000 PSI
system, 1650 PSI after closure, 200 PSI recovery in 40 sec., full recovery in 179 sec., 6 nitrogen bottle average = 2125 PSI. Sim-ops: Load 580 bbls Flo-Pro
mud in the pits.;R/D test equipment. Pull test joint. Unable to pull with tugger. Contact well head rep. M/U lift sub pull with blocks. 5, 10 & 15K no movement.
Pull 20K and rock pipe, slow movement then pulled free. Found small piece of aluminum in test plug rubber.;Suspect ES cementer piece from previous well in
blind ram cavity. Flush stack with water. Install 9-1/8" I.D. wear bushing with no difficulty. L/D running tool and test joint. Blow down choke & kill lines. Re-install
90' mousehole.;PJSM. Mobilize BHA components to the rig floor. M/U 8-1/2" NOV SK616M-J1D bit and 7600 Geo-Pilot to 25'.;Daily losses = 0 bbls,
Cumulative losses = 115.5 bbls.
Hauled 365 bbls H2O from L-Pad for total = 7155 bbls
Hauled 140 bbls Source Water from G&I for total = 725 bbls;Hauled 1166 bbls to MPU G&I cuttings/mud/cement for total = 5593 bbls
Hauled 58 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/22/2020 Continue to M/U RSS BHA 2 f/ 25', M/U MWD tools and flt sub to 86'. Initialize & test MWD tools. M/U 3 NMDCs and upper flt sub , M/U jar stand to
275'.;RIH w/ 1 std 5” DP to 370', Shallow pulse test MWD with 410 GPM, 610 PSI - good test. Pressure test Geo-Span to 3000 PSI. Blow down TD.;TIH with
stands 5'' DP from 370' to 1322', fill DP and break in geo pilot seals, BD TD.;TIH F/ 1322' to 2462' just above ESC, MU TD. PU 105K, SO 77K, ROT 90K.
Correct displacement.;Break circulation, wash and ream down 400 gpm, 840 psi, 60 rpm, 5k TQ, drill soft cement f/ 2561', Tag ESC on depth @ 2566'. Drill
plug and ES cementer f/ 2566' t/ 2569' w/ 3-14K WOB. Ream through 3 times, then Pass thru with no pump or rotary. Note plug rubber and alum. seen at
shakers. Blow TD.;TIH f/ 2569' t/ 6457'. Test MPD lines to 250 PSI low / 1300 PSI high while filling pipe at 4577'. Ran out of the derrick to 6177' then picked up
singles out of the pipe shed to 6457'. 208 PU / 70K SO.;Ream down from 6457' to firm cement at 6475' with 500 GPM, 1600 PSI, 40 RPM, 17K TQ. Observed
cement stringers f/ 6460' and firm cement at 6475'. CBU at 550 GPM, 1770 PSI, 40 RPM, 13-17K TQ.;Set stand in mousehole to 6463'. Blow down top drive &
rig up test equipment. Close upper 4-1/2"x7" VBR on 5" drill pipe. Pressure test casing to 2650 PSI for 30 min. on chart - good test. R/D test equipment & blow
down lines.;Drill cement & float equipment f/ 6475' t/ 6627', 465 GPM, 1500 PSI, 50 RPM, 17K TQ., 5-7K WOB Drilled baffle adapter on depth @ 6506', float
collar on depth @ 6546' & shoe on depth from 6625'-6627'. Clean out rat hole to 6634'. Reamed thru float equipment 3x times.;Drill 20' of 8-1/2" hole f/ 6634' t/
6654', 20' drilled, 40'/hr AROP. 460 GPM, 1420 PSI, 50 RPM, 15K TQ, 5K WOB.;Circulate a bottoms up, 460 GPM, 1420 PSI, 50 RPM, 15K TQ. Reciprocate
f/ 6627' t/ 6558'. 210K PU / 75K SO. Rack back stand to 6558' & blow down the top drive.;R/U test equipment & closed 4-1/2"x7" VBR on 5" pipe Performed
12.0 ppg EMW FIT at 6627' MD / 3828' TVD with 538 PSI applied with 9.3 ppg mud. Pump 1.8 bbls & bled back 1.8 bbls. R/D test equipment & blow down
lines.;PJSM. Remove trip nipple and install MPD RCD. Install flow line plug. PJSM for displacement. TIH f/ 6558' t/ 6654'.;0 bbls Daily Losses, 115.5 bbls
Cumulative Losses.
Hauled 230 bbls H2O from L-Pad for total = 7385 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 171 bbls to MPU G&I cuttings/mud/cement for total = 5764 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/23/2020 Pump 30 bbl 9.0 ppg high vis spacer pill. displace with 468 bbls new 8.8 flo-pro mud 6 bpm, 400 PSI, 30 RPM, 15K TQ., dump returns to rock washer until
clean 8.8 mud at returns., monitor well for pressure build, static, get new parameters. BD TD. PU 210K, SO 75K, ROT 125K.;Rack back stand parking in 9
5/8'' casing at 6553', M/U FOSV, PJSM, slip and cut 66' drlg line. Inspect saver sub and grabber dies, service rig. Re-calibrate block height, L/D FOSV.
Monitor MPD for pressure build, Simops: clean pit 4 and under shakers.;M/U stand DP, Obtain new SPRs for both pumps, wash and ream to bottom.;Drill 8
1/2'' hole f/ 6654' t0 6697' 500 gpm, 1250 psi, 80 rpm, 12k torque, ECD 9.86.;MPD chokes plugged off, shut off pumps. Rack back stand , park in 9 5/8 casing
, BD TD, clear choke and lines, remove several pieces of rubber in chokes also downstream where choke line ties into flowline. M/U TD, circulate 500 gpm to
ensure lines clear, M/U std, wash to bttm.;Drill 8-1/2" lateral f/ 6697' t/ 6746', 49' drilled, 24.5'/hr AROP. 450 GPM, 1030 PSI, 80 RPM, 12K TQ, 5K WOB. 8.7
ppg MW, 46 vis, 9.86 ECD, max gas 340u. 157K PU / 79K SO / 116K ROT. Target 91.5 deg.;MPD choke line plugged, shut off pumps, rack stand back, BD
TD, work pipe slow. Found large piece of plug rubber and several small pieces of black composite material, appears to be top hat material in #2 MPD choke
M/U TD, circulate 500 gpm, 50 rpm, to ensure lines clear, M/U std, wash to bttm.;Drill 8-1/2" lateral f/ 6746' t/ 7032', 286' drilled, 95.3'/hr AROP. 500 GPM,
1210 PSI, 120 RPM, 16K TQ, 9-11K WOB. 8.7 ppg MW, 46 vis, 9.9 ECD, max gas 404u. 183K PU / 70K SO / 115K ROT.;Drill in the NB target 91.5 deg., At
6850’ start undulating down, MPD choke fully open 50 psi line pressure & 24 psi during connections.;Drill 8-1/2" lateral f/ 7032' t/ 7697', 665' drilled , 110.8'/hr
AROP. 500 GPM, 1570 PSI, 120 RPM, 15-18K TQ, 7-15K WOB. 8.8+ ppg MW, 43 vis, 10.8 ECD, max gas 416u. 191K PU / 59K SO / 111K ROT. NB clay top
@ 7038' MD / 3826' TVD. MPD choke fully open w/46 PSI line pressure & 24 PSI on connections.;Drill 8-1/2" lateral f/ 7697' t/ 8651, 954' drilled, 159'/hr
AROP. 525 GPM, 1530 PSI, 120 RPM, 16K TQ, 3-9K WOB. 8.9 ppg MW, 39 vis, 10.58 ECD, max gas 501u. 160K PU / 75K SO / 112K ROT. NC sand top at
7755' MD / 3831' TVD, maintain 90.2°-92.4° inclination.;Oil in returns was blinding off shakers, begin holding 60 PSI (9.3 ppg EMW) w/ MPD on connections at
8270'. Increase to 100 PSI at 8555'. Add 100 bbls new mud to build volume at 8270'. Began undulation up at 8447' targeting 94.5°. Enter NB clay at 8650'.;5
concretions have been drilled for a total footage of 13’ (0.7% of the lateral). Last survey at 8581.24' MD / 3817.61' TVD, 92.61° inc, 185.56° azm, 45.19' from
plan, 45.18' low and 0.63' left.;0 bbls Daily Losses, 115.5 bbls Cumulative Losses.
Hauled 355 bbls H2O from L-Pad for total = 7740 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 827 bbls to MPU G&I cuttings/mud/cement for total = 6591 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/24/2020 Drill 8-1/2" lateral f/ 8561' t/ 9316, 755' drilled, 125.8'/hr AROP. 550 GPM, 2000 PSI, 140 RPM, 16K TQ, 10K WOB. 9 ppg MW, 43 vis, 10.99 ECD, max gas
680u. 160K PU / 65K SO / 106K ROT.;Target 93.5 undulating to NB, While undulating we hit NC top at 8,650’ then into NB at 9,080’ Pump 30 bbl hi vis sweep
@ 8861', back 100 stks early w/ 40% increase. MPD choke fully open w/ 45 PSI line pressure & 100 PSI on connections.;Drill 8-1/2" lateral f/ 9316' t/ 10000',
684' drilled, 114'/hr AROP. 500 GPM, 1800 PSI, 140 RPM, 13K TQ, 14K WOB. 8.9 ppg MW, 44 vis, 11.9 ECD, max gas 692u. 167K PU / 62K SO / 108K
ROT.;Undulate down at 9,800’ with 89° inclination exiting the bottom of NB sand at 9960’ entering clay Pump 30 bbl hi vis sweep at 9793', 100 strokes early w/
30% increase.MP in Phase 2 conditions 15:00 to 18:00.;Drill 8-1/2" lateral f/ 10000' t/ 10649', 649' drilled, 108.2'/hr AROP. 500 GPM, 1930 PSI, 140 RPM,
13K TQ, 10-15K WOB. 9.0 ppg MW, 45 vis, 11.4 ECD, max gas 381u. 162K PU / 69K SO / 107K ROT. Perform 170 bbl new 8.8 ppg Flo-Pro dilution at
10240'. NC sand top at 10560'.;Drill 8-1/2" lateral f/ 10649' t/ 11315', 666' drilled, 111'/hr AROP. 500 GPM, 1960 PSI, 120 RPM, 13K TQ, 5-10K WOB. 9.1 ppg
MW, 44 vis, 11.41 ECD, max gas 568u. 155K PU / 57K SO / 104K ROT. Drill in the NC sand, targeting 91-92.5° inclination. Sweep at 10744' back 50 strokes
early w/ 30% increase.;Increase MPD back pressure to 160 PSI at 10838' to help reduce oil at shakers. 19 concretions have been drilled so far, for a total
footage of 68’ (1.5% of the lateral). Last survey at 11150.41' MD / 3734.27' TVD, 92.42° inc., 186.40° azm, 44.40' from plan, 38.36' low and 22.35' right.;8 bbls
Daily Losses, 123.5 bbls Cumulative losses
Hauled 995bbls H2O from L-Pad for total = 8735 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1427 bbls to MPU G&I cuttings/mud/cement for total = 8018 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/25/2020 Drill 8-1/2" lateral f/ 11315' t/ 11886', 571' drilled, 95.1'/hr AROP. 475 GPM, 1960 PSI, 130 RPM, 13K TQ, 18K WOB. 9.1 ppg MW, 45 vis, 11.7 ECD, max gas
358u. 150K PU / 60K SO / 100K ROT. MPD choke wide open drlg and hold 160 psi during connections.;Drill in the NC sand 92.5 deg inc. Pump 30 bbl hi vis
sweep @ 11791'.;Drill 8-1/2" lateral f/ 11886' t/ 12267', 952' drilled, 158.7'/hr AROP. 500 GPM, 1930 PSI, 140 RPM, 15K TQ, 16-17K WOB. 8.95 ppg MW, 43
vis, 10.53 .ECD, max gas 258u. 162K PU / 50K SO / 104K ROT. MPD choke wide open drlg and hold 160 psi during connections.;Exit NC sand at 11422' and
undulate up to the NB sand target 94.5 deg. MBT 5.5 and ECD @ 11.7+ perform 580 bbl dump and dilute w/ new 8.8 flo pro mud @ 12142' Undulate up to the
NB sand target 95 deg inc, entered NB @ 11947' & exited top NB @ 12185'. Sweep back on time w/ 10% increase.;Geology evaluate logs and verify data.
Consult with town. Reciprocate f/ 12267' t/ 12255' with 505 GPM, 1880 PSI, 140 RPM, 15K TQ.;Drill 8-1/2" lateral f/ 12267' t/ 12469', 202' drilled, 44.9'/hr
AROP. 460 GPM, 1790 PSI, 140 RPM, 14K TQ, 7-12K WOB. 9.0 ppg MW, 45 vis, 11.6 ECD, max gas 312u. 167K PU / 51K SO / 105K ROT. Drop to 90°
inclination by 12313'. Consult with town, suspect drilled out the top of NB sand.;Target 88° to drop to reacquire sand. Piece of rubber and 2 pieces of aluminum
from 9-5/8" shoe track found in MPD choke at 12400'.;Drill 8-1/2" lateral f/ 12469' t/ 13000', 531' drilled, 88.5'/hr AROP. Reduce flow f/ 500 to 420 GPM due to
ECD, 1690 PSI, 140 RPM, 16K TQ, 10-20K WOB. 9.2 MW, 45 vis, 11.7 ECD, max gas 358u. 153K PU / 50K SO / 104K ROT.;Observe sand at 12596',
suspect NB but drilled further to confirm turned out to be NC. 5-10' DTN throw fault at 12220'. ND sand at 12658' and NE sand at 12787'. Drop inc to 84° @
12800' and allow to drop to 82° to cut section faster for log correlation.;Decision made to pull back & open hole sidetrack. Obtain final survey. Last survey @
12929.46' MD / 3726.80' TVD, 82.57° inc, 181.96' azm, 89.73' from plan, 85.0' low and 28.75' left. 20 concretions have been drilled so far for a total footage of
70' (1.1% of the lateral).;BROOH f/ 13000' t/ 12045', 500 GPM, 2120 PSI, 130 RPM, 13-15K TQ at 3 min/stand.;Daily Losses = 0 bbls, Cumulative Losses =
123.5 bbls
Hauled 885bbls H2O from L-Pad for total = 9620 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1851bbls to MPU G&I cuttings/mud/cement for total = 9869 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/26/2020 Sidetrack in the NB f/ 11950' to 11969', driller informed the company man DP count off, std 134 was marked as 135 on the pipe rack. Correct depth at the bit is
12064', ( sidetracked f/ 12045' instead of 11950' ) Geo was informed, drilled to 12171'.;Consequently the sidetrack did not get enough separation from the old
hole, and there was concern about running completion. It was decided to pull back to 11950’ md and perform the sidetrack. PU 150K, SO 50K, ROT
105K.;BROOH f/ 12171' to 11950', 420 gpm, 1500 psi, 100 rpm, 10k torq.;Trough 30' x3 down to 11980' MD with 400 GPM / 140 RPM, Control drill for
sidetrack, 400 GPM, 140 RPM. Vary parameters and speed without success f/11950' to 11975'. Decision to PU and begin again at 11950'.;Trough 30' x2 up to
11920' at 400 GPM, 140 RPM and control drill at 94.81 deg f/ 11950' to 11982', drill to 12077' at 500 GPM, 1890 psi, 120 rpm, 14k torque, 7k wob. 170 fph.
take Survey, 12007.92' MD 92.05 INC 182.95 AZI, 22.6' Low 5.79' Left, 1' separation at survey point and 2.7' at the bit.;BROOH to 11973' at 496 gpm, 1860
psi, 90 rpm, 13k torque, orient hi side, pass thru side track point with pumps off and no rotary with one 10k bobble, RIH to 12077'.;Drill 8-1/2" lateral f/ 12077' t/
12216', 139' drilled, 92.7'/hr AROP. 445 GPM, 1640 PSI, 140 RPM, 14K TQ, 7K WOB. 8.95 ppg MW, 41 vis, 10.84 .ECD, max gas 431u. 162K PU / 55K SO /
107K ROT. MPD choke wide open drlg and hold 160 psi during connections.;Drill 8-1/2" lateral f/ 12216' t/ 12753', 537' drilled, 89.5'/hr AROP. 490 GPM, 1990
PSI, 100 RPM, 16K TQ, 5-12K WOB. 8.95 ppg MW, 42 vis, 11.52 ECD, max gas 339u. 166K PU / 46K SO / 105K ROT.;Crossed fault at 12220' (7' DTN
throw) from NB sand to NB clay. Continue building up and entered NB sand again at 12275'. 10-99 BLUE called by Milne Security at 20:05, Stop unnecessary
work and meet with crew to take extra precautions. All clear at 20:30.;Drill 8-1/2" lateral f/ 12753' t/ 13256', 503' drilled, 83.8'/hr AROP. 500 GPM, 1910 PSI,
110 RPM, 15-17K TQ, 4-10K WOB. 9.1 ppg MW, 41 vis, 11.1 ECD, max gas 431u. 165K PU / no SO / 102K ROT. Holding 91.5° to 92.5° inclination. Lost
SOW at 12840'.;Reached plug back depth of 13,000' at 03:00. Perform 290 bbl new mud dilution at 13125' We have drilled 33 concretions for a total thickness
132' (2.0% of the lateral). Last survey @ 13150.44' MD / 3654.78' TVD, 91.49° inc, 184.59° azm, 27.94' from plan, 20.48' low and 19.00' right.;0 bbls Daily
Losses, 123.5 bbls Cumulative Losses.
Hauled 820bbls H2O from L-Pad for total = 10440 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 867bbls to MPU G&I cuttings/mud/cement for total = 10736 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/27/2020 Drill 8-1/2" lateral f/ 13256' t/ 13507', 251' drilled, 41.8'/hr AROP. 450 GPM, 1730 PSI, 80 RPM, 16-21K TQ, 7-20K WOB. 9.1 ppg MW, 45 vis, 11.25 ECD,
max gas 393u. 175K PU / no SO / 108K ROT. MPD choke wide open drlg and hold 160 psi during connections.;Hold 91.5° to 92.5° inclination, crossed fault 2
@ 13493', throw 30'-40' DTN from NB-Sand to the shale below NC-Sand. Currently targeting 93°.;Drill 8-1/2" lateral f/ 13507' t / 13764', 257' drilled, 42.8'/hr
AROP. 510 GPM, 2240 PSI, 130 RPM, 22K TQ, 20-25K WOB. 9.0 ppg MW, 43 vis, 11.5 ECD, max gas 131u. 177K PU / no SO / 102K ROT. MPD choke wide
open drlg and hold 160 psi during connections.;Target 93°-96° to re-acquire base of NC.;Drill 8-1/2" lateral f/ 13764' t/ 13924', 160' drilled, 26.7'/hr AROP. 550
GPM, 2620 PSI, 120 RPM, 21-26K TQ, 5-30K WOB. 9.05 ppg MW, 45 vis, 11.55 ECD, max gas 264u. 185K PU / no SO / 102K ROT. MPD choke wide open
drlg and hold 160 psi during connections.;Drill 8-1/2" lateral f/ 13924' t/ 13970', 46' drilled, 46'/hr AROP. 485 GPM, 2180 PSI, 130 RPM, 21-25K TQ, 15-25K
WOB. 9.15 ppg MW, 44 vis, 11.55 ECD, max gas 102u. 185K PU / no SO / 120K ROT.;Formation pushed the assembly down from 93.04° to 90.93° inclination
over 18'. Dogleg over 10' interval (13947'-13958') was 17.98°/100'.;Stop drilling. Verify dogleg w/ DD and objective with Geo. Suspect 91°-92° formation dip,
targeting 93.5°. Need to build up. Ream f/ 13918' t/ 13970' to smooth out dogleg. Reaming reduced dogleg over 10' interval to 14.6°/100'.;Time drill with 100%
deflection highside f/ 13970' t/ 13972' @ 1'/hour then 2' per hour t/ 13976'. Increase to 5'/hr f/ 13976' t/ 13977'. 450 GPM, 1720 PSI, 50 RPM, 19K TQ, 10K
WOB. 9.05 ppg MW, 40 vis, 10.8 ECD, max gas 128u.;Last survey at 13815.52' MD / 3627.87' TVD, 95.58° inc, 183.36° azm, 21.93' from plan, 15.72' low and
15.29' right.
We have drilled 46 concretions for a total thickness 253' (3.4% of the lateral).;Daily Losses = 0 bbls, Cumulative Losses = 123.5 bbls.
Hauled 1450 bbls H2O from L-Pad for total = 11890 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1818 bbls to MPU G&I cuttings/mud/cement for total = 12554 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/28/2020 Drill 8 1/2'' lateral f/ 13977' to 14365', 388' drilled, 64.6'/hr AROP. 500 GPM, 2320 PSI, 120 RPM, 24K TQ, 15K WOB. 9.1 ppg MW, 40 vis, 11.6 ECD, max
gas 314u. 175K PU / no SO / 102K ROT. MPD choke wide open drlg and hold 160 psi during connections.;Control drill to 14103', target 93 deg, inc, logged
NC sand @ 14050', tarqet 91.5 to 93 deg.;Drill 8 1/2'' lateral f/ 14365' to 14648', 283' drilled, 47.2'/hr AROP. 475 GPM, 2170 PSI, 120 RPM, 20K TQ, 5-25K
WOB. 9.0 ppg MW, 43 vis, 11.6 ECD, max gas 314u. 183K PU / no SO / 96K ROT. MPD choke wide open drlg and hold 160 psi during connections;14366'
MBT 6, Perform 290 bbl dump and dilute w/ new 8.8 mud., at 14437' add 5 drums lo-tork bring lube content f/ .5 to 1% reducing TQ f/ 27-21k Drill in NC -
Target 93 deg inclination, Cross Fault 3 @ 14420', w/ 60' DTS throw, target 84-85 deg moving down to acquire NB. Logged NA sand top @ 14595';Drill 8 1/2"
lateral f/ 14648' t/ 14939'. 291' drilled, 48.5'/hr AROP. 475 GPM, 2260 PSI, 105 RPM, 20K TQ, 15-25K WOB. 9.15 ppg MW, 45 vis, 11.8 ECD, max gas 336u.
179K PU / no SO / 95K ROT. Pump high vis sweep at 14744', not seen at shakers.;MPD choke wide open drlg and hold 160 psi during connections. Steer
down at 85°-87.5° inc. Logged NA clay top @ 14659'.;Drill 8 1/2" lateral f/ 14939' t/ 15316', 377' drilled, 62.8'/hr AROP. 400 GPM, 1700 PSI, 100 PRM, 21K
TQ, 11-20K WOB. 9.25 ppg MW, 44 vis, 11.5 ECD, max gas 311u. 175K PU / no SO / 102K ROT. Steering down at 84° inclination from 15029'.;Logged NB
sand top @ 15140'. Perform 290 bbl new mud dilution at 15255'.
Drilled 50 concretions for a total thickness 274' (3.2% of the lateral).
Last survey at 15244.13' MD / 3639.66' TVD, 84.32° inc, 182.68° azm, 41.41' from plan, 39.5' left & 12.4 low.;0 bbls Daily losses, 123.5 bbls Cumulative losses
Hauled 1105 bbls H2O from L-Pad for total = 12995 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1193bbls to MPU G&I cuttings/mud/cement for total = 13747 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/29/2020 Drill 8 1/2" lateral f/ 15316' t/ 15570', 254' drilled, 101.6'/hr AROP. 400 GPM, 1680 PSI, 100 PRM, 21K TQ, 15-20K WOB. 9.25 ppg MW, 44 vis, 11.5 ECD,
max gas 481u. 175K PU / no SO / 105K ROT. Steer down at 84° inclination.;Continue to drill down section until geology is confident of formations after
fault.;BROOH 2-3 min stand f/ 15570' to sidetrack point at 14300' (in NC sand) pumping 400 gpm, 60 rpm, 16k TQ. treat mud while BR adding dilution brine
at 30 bph lowering ECD to 10.8.;Perform OH sidetrack as per DD, Deflect 100% low side, trough down 10' f/ 14290' to 14300' x5 at 400 gpm, 1670 psi, 100
rpm, 17k TQ, control drill 1 fph f/ 14300' to 14304' target 90 deg, unproductive at this point, review options w/ Geo, decision made to continue at this
depth.;Continue to time drill at 1 fph f/ 14304' t/ 14310'. 405 GPM, 1620 PSI, 100 RPM, 19K TQ, 3-25K WOB. 9.0 ppg MW, 40 vis, 10.53 ECD, max gas 84u.
105K ROT.;Continue to time drill at 1.25 fph f/ 14310' t/ 14315'. 400 GPM, 1420 PSI, 50 RPM, 17K TQ, 15K WOB. 8.9 ppg MW, 35 vis, 10.16 ECD, max gas
31u. Observe ABI @ 14312' drop from original 93.04° to 92.43°.;MWD fail safe timer expired (pumps on too long). Cycle pumps, did not reset. Pick off bottom,
observed 10K overpull w/ torque stalls - no pack-off. Suspect minor keyseating. Slowly backream 45'. Slack off 20', P/U with no rotary - 45K drag. Pumps off
for 5 min. reset timer.;Ream f/ 14300' t/ 14260' two times, with zero deflection of Geo-Pilot. Pickup and torque while reaming reduced to normal. Still observe
45K drag P/U with no rotary.;Continue to time drill at 1.25 fph f/ 14315' t/ 14316' 400 GPM, 1420 PSI, 50 RPM, 17K TQ, 15K WOB. 8.95 ppg MW, 36 vis, 10.71
ECD, max gas 359u.
Drilled 50 concretions for a total thickness of 274' (3.1% of the lateral).;0 bbls Daily Losses, 123.5 bbls Cumulative Losses
Hauled 1000 bbls H2O from L-Pad for total = 13995 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1677 bbls to MPU G&I cuttings/mud/cement for total = 15424 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/30/2020 Continue to time drill at 1.25 fph f/ 14316' t/ 14317', increase to 2 fph to 14319', then 3.5 fph to 14323, then 6 fph to 14326', control drill to 14363' ABI @ 90.84
deg w/ 2.19 deg drop, 400 GPM, 1420 PSI, 50 RPM, 17K TQ, 5-15K WOB. 9 ppg MW, 40 vis, 10.22 ECD, max gas 70u.;BROOH f/ 14363' to above sidetrack
at 14264, 400 gpm, 1500 psi, 100 rpm, 17k TQ, slow to 40 rpm, pass thru sidetrack point w/ no issues, tag at 14363', make connection. PU 235K, no SO,
105K ROT.;Drill 8 1/2" lateral f/ 14363' t/ 14553', 190' drilled, 34.5'/hr AROP 485 GPM, 2130 PSI, 120 PRM, 24K TQ, 18K WOB. 8.9 ppg MW, 39 vis, 10.92
ECD, max gas 163u. 195K PU / no SO / 100K ROT. Target 90 deg inc.;14370' w/ MBT @ 6, perform 290 bbl dump and dilute w/ new 8.8 ppg mud. Increase
lubes f/ 1 to 1.5% adding 5 drums lo-tork, TD torque @ 27k Fault #3 @ 14422' with 37' DTS throw.;Drill 8 1/2" lateral f/ 14553' t/ 14884', 331' drilled, 55..2'/hr
AROP. 485 GPM, 2150 PSI, 120 RPM, 23K TQ, 15K WOB. 9.0 ppg MW, 40 vis, 11.18 ECD, max gas 410u. 185K PU / no SO / 95K ROT. NB sand top @
14600'. Build to 92° to 93° inclination.;Drill 8 1/2" lateral f/ 14884' t/ 15250', 366' drilled, 61'/hr AROP. 495 GPM, 2100 PSI, 125 RPM, 25K TQ, 10-20K WOB.
9.15 ppg MW, 41 vis, 11.11 ECD, max gas 164u. 185K PU / no SO / 100K ROT. Drilled NB clay f/ 14803’ t/ 15010’, Build to 95.5° then level off at 93°.;Pump
high vis sweep at 15124'. Last survey at 15054.24' MD / 3581.03' TVD, 95.52° inc, 183.90° azm, 26.05' from plan, 25.67' high and 4.45' left. Drilled 58
concretions for a total thickness of 296' (3.5% of the lateral).;8 bbls Daily Losses, 131.5 bbls Cumulative Losses
Hauled 980 bbls H2O from L-Pad for total = 14975 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1155 bbls to MPU G&I cuttings/mud/cement for total = 16579 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
3/31/2020 Drill 8 1/2" lateral f/ 15250' t/ 15695', 445' drilled, 74.1'/hr AROP. 450 GPM, 1790 PSI, 120 RPM, 22K TQ, 10-20K WOB. 9.1 ppg MW, 42 vis, 11.27 ECD, max
gas 428u. 185K PU / no SO / 104K ROT. Target 92° inclination.;15400' perform 290 bbl dump and dilute w/ 290 bbls 8.8 mud. Note: reached previous depth
on old wellbore of 15570' at 09:30.;Drill 8 1/2" lateral f/ 15695' t/ 15880', 185' drilled, 41.1'/hr AROP. TD in NB @ 15880', 3540' TVD. 450 GPM, 1790 PSI, 120
RPM, 22K TQ, 10-20K WOB. 9 ppg MW, 39 vis, 11.32 ECD, max gas 360u. 185K PU / no SO / 100K ROT. Target 89° inclination.;drilled 70 concretions for a
total thickness of 448' (4.8% of the lateral).;Last survey at 15808.80' MD / 3540.53' TVD, 90.25° inc, 185.39° azm, 39.9' from plan, 39.8' high and 2.73' left.
Extrapolated to TD at 15880' MD / 3540.22' TVD, 90.25° inc,, 185.39° azm, 48.82' from plan, 48.75' high and 2.52' left.;Pump 25 bbl hi vis sweep, 500 GPM,
2340 PSI, 120 RPM, 20K TQ. No increase observed on sweep. Circulated a total of 5.4 bottoms up. Rack back a stand each bottoms up to 15445'. 11.5 ECD,
9.0 ppg MW, 42 vis. PJSM for displacement.;Ream in the hole f/ 15445' t/ 15880' due to no slack off weight. 400 GPM, 1600 PSI, 100 RPM, 19K TQ. Blow
down Sperry Geo-Span unit.;Pump 30 bbl high vis spacer & SAPP treatment (three 30 bbls SAPP pills separated by 40 bbls seawater). Pump w/ 290 bbls SW
& 30 bbls high vis spacer followed by 8.45 ppg viscosified 2% KCl brine w/ 4% lube (2% each Lo-Torq & Lube 776). 7 BPM, 1180 PSI ICP, 860 PSI FCP, 80-
90 RPM, 24K start,18K end;1st SAPP pill was 2625 strokes (265 bbls) late, 2nd spacer was 3550 strokes (358 bbls) late and clean brine was 3675 strokes
(371 bbls) late. No losses during displacement.;Shut down & close MPD choke. Trap 103 PSI which held steady. Bleed off to 60 PSI which built to 111 PSI in 5
min. Bleed to 90 PSI which built to 107 PSI in 5 min. Change shaker screen & clean pit #3. PST test results: 4.55, 5.25 & 5.45 seconds.;30 bbls Daily Losses,
161.5 bbls Daily Losses.
Hauled 710 bbls H2O from L-Pad for total = 15685 bbls
Hauled 0 bbls Source Water from G&I for total = 725 bbls;Hauled 1442 bbls to MPU G&I cuttings/mud/cement for total = 18021 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/1/2020 Get new parameters, in mud 185k PU, no S/O, 100K ROT, in brine 210 PU, no SO, 110K ROT, torque at 90 rpm in mud 24k, in brine 18k. Obtain new SPRS
w/ both pumps.;BROOH f/ 15880' t/ 14078' at 5/10 min. stand. 470 GPM, 1490 psi, 120 RPM, 22-24K torque. L/D 5'' DP utilizing 90' mousehole while BROOH.
MPD holding 50 psi when pumps on, 180 psi during connections. 210 PU, no SO, 110 ROT.;Continue to BROOH f/ 14078' t/ 12650' at 5/10 min. stand. 500
GPM, 1640 psi, 120 RPM, 22-24K torque. L/D 5'' DP utilizing 90' mousehole while BROOH. Shakers blinding off occasionally, stop and clean same. Slight
packing off at 13910', S/O 10', work thru slow. 10k overpull @ 12900', cleanup same.;MPD holding 50 psi when pumps on, 180 psi during connections. 3.5 to 4
bph loss rate.;BROOH f/ 12650' t/ 11980' at 10/30 min. stand, slow for TQ or pressure increases. 470 GPM, 1700 PSI, 120 RPM, 22K TQ, 10.85 ECD. 113K
ROT. Max Gas: 333u. MPD holding 180 PSI on connections. 50 psi w/full open choke while reaming. 92 bbls loss. 15 BPH avg.;From 12050’ to 11980’ seeing
high torque and up to 40k overpull though no packing off. Increase MPD backpressure to 80 psi. Vary RPM f/ 120 t/40 while backreaming. Moderate difficulty
working up through tight area though pulled clean back to progress point when worked down.;BROOH f/ 11980' t/ 10746' at 10 min. stand, slow for TQ or
pressure increases. 475 GPM, 1500 PSI, 120 RPM, 18-22K TQ, 10.87 ECD. 150k PU, 75k SO, 113K ROT. Max Gas: 574u MPD holding 180 PSI on
connections. 50 psi w/full open choke while reaming. 110 bbls loss. 18 BPH avg.;Re-gained Slack off weight at 11700’. Pulling speed reduced significantly
through multiple tight areas in the NB Clay from 11947’ to 11422’.;Interval Daily (Midnight) Loss = 123 bbls, Cumulative losses = 169 bbls
Hauled 340 bbls H2O from L-Pad for total = 16025 bbls
Hauled 150 bbls Source Water from G&I for total = 875 bbls;Hauled 2,815 bbls to MPU G&I cuttings/mud/cement for total = 20,836 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/2/2020 Continue to BROOH f/ 11980' t/ 9891' at 10/60 min. stand, slow for TQ or pressure increases as needed. 430-460 GPM, 1700 PSI, 120 RPM, 22-25K TQ,
10.89 ECD. 110K ROT. Max Gas: 740u. MPD holding 180 PSI on connections. Holding 70 psi w/ choke while reaming.;Tight w/ 15k overpull and packing off f/
10524' to 10460' pulling thru NC top to NB clay, slow to 60 min stand to cleanup, continue BR 10/15 min std thru tight areas in NB clay, very tight f/ 10042' to
10035' into NB sand, work thru 1 times until clean. Loss rate avg 18-22 bph.;BROOH f/ 9891' t/8526' at 5/10 min. stand, slow for TQ or pressure increases as
needed. 470 GPM, 1450 PSI, 120 RPM, 15K TQ, 10.7 ECD. 140k PU, 85k SO, 112K ROT. Max Gas: 669u MPD holding 180 PSI on connections. Holding 70
psi w/ choke while reaming.;15k over pull and packing off observed transitioning f/ NB sand to the NB clay @ 8931', drop to 8945', hole unloading, stop and
let cleanup, continue BR slowing to 10/15 min std thru tight areas in NB clay, some wellbore breathing.;BROOH f/8526' t/7280' at 5/10 min. stand, slow for TQ
or pressure increases as needed. 470 GPM, 1220 PSI, 120 RPM, 12K TQ, 10.8 ECD. 125k PU, 95k SO, 113K ROT. Max Gas: 708u. MPD holding 180 PSI
on connections. 55 psi w/ full open choke while reaming.;Continued tight spots throughout the NB clays with slight packing off and overpulling. Noticeably
cleaning pulling through the NB sands. No excessive hole unloading. Losses continue at 10-15 BPH.;BROOH f/7280' t/6710' at 5/10 min. stand, slow for TQ or
pressure increases as needed. 500 GPM, 1480 PSI, 120 RPM, 12K TQ, 10.78 ECD. 135k PU, 98k SO, 115K ROT. Max Gas: 167u. Pump into the casing
shoe at 6627’ with no rotary.;MPD holding 180 PSI on connections. 55 psi w/ full open choke while reaming. Loss rate at 8 BPH, Total of 512 bbls loss while
BROOH.;Pump 2x hi vis sweeps and circulate 9-5/8" casing clean. 3.5x total bottoms up pumped. 555 GPM, 1650 PSI, 55 RPM, 6K TQ, 10.72 ECD. MW 9.3
ppg in/out. Recip f/ 6550' t/ 6460'. Sweeps back on time w/ 30% increase in cuttings on 1st and minimal increase with 2nd. Shakers cleaned up after second
sweep.;Shut down pumps monitor pressure build f/ 8 psi to 60 psi in 5 min, bleed off and monitor flow taper down to 7 gpm. Shut in and monitor pressure build
to 60 psi. Same results 2 more times.;Interval Daily (Midnight) Loss = 332 bbls, Cumulative losses = 501 bbls
Hauled 1260 bbls H2O from L-Pad for total = 17285 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 684 bbls to MPU G&I cuttings/mud/cement for total = 21,520 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/3/2020 Continue to monitor with MPD to verify no wellbore breathing, bleed off 50 psi, built to 48 psi in 15 min and leveled out several times. shut in MPD.;PJSM,
install FOSV, Slip and cut 79' drilling line, recalibrate block height, L/D FOSV, service Rig. SimOps: Weight up bine in pits 3 & 4 f/ 9.3 to 9.5 ppg w/ O.F.
salt.;Weight up from 9.3 ppg to 9.5 ppg from 6527', circulate around @ 8 bpm, 700 psi, 30 rpm, 5k tq. Cap well f/ shoe up. Submit 24 hr BOP test notification
to AOGCC @ 11:00.;Shut down pumps, BD TD, monitor flow, flowing 6 gpm, receding to 1/2'' stream in 45 min and not slowing. M/U TD, Increase from 9.5
ppg to 9.5+ ppg from 6627' @ 8 bpm, 700 psi, 30 rpm, 5k tq. until good 9.5+ in/out. Shut down pumps, BD TD, monitor flow, flowing 6 gpm, receding to static
in 30 min.;BD MPD line, remove RCD bearing, install trip nipple, no leaks. Well is static, pump dry job, BD TD.;TOOH L/D 5'' DP singles f/ 6527' t/ 6366'.
135k PU, 102 SO. Observe the Well swabbing.;Circulate to clean BHA of suspected clay balling. 500 GPM, 1260 psi, 40 RPM, 6k Tq. MW 9.5+ in/out. Full
circulation of 474 bbls pumped. Pull a stand and hole still swabbing. Decision made to pump out of the hole.;Pump out of the hole f/ 6336’ t/ 4590’. Lay down
drillpipe via Mousehole. 140 GPM, 220 psi. Pit straps show proper displacement. Attempted to pull on elevators at 5360'. Continued to swab.;Service
Topdrive, Drawworks and iron roughneck. C/O hydraulic hose on roughneck. Monitor well while servicing rig. Flow observed 1-2 BPH and not reducing. 1.4 bbl
gain in 30 min.;Decision made to TIH to shoe and weight up t/ 9.7 ppg. Circulate at 3 BPM, 220 psi while load and tally 62 jts drill pipe in shed.;RIH, picking up
5” drillpipe singles from 4590’ t/ 6557’. Calculated displacement = 49.6 bbls, Actual displacement = 47 bbls Weight up surface volume while TIH.;Weight up
9.5+ to 9.7+ from 6557’. Pump 215 gpm, 380 psi. No losses while weighting up.;Monitor well, Initial flow back at 4 BPH, reduced to static after 45 min. Pull 1
stand on elevators t/ 6460' and observe swab and surging. Line up pits to pump out of hole.;Pump out of the hole f/ 6460’ t/ 6080’. Lay down drillpipe via
Mousehole. 120 GPM, 200 psi. 125k PU, 100k SO. Hole taking proper displacement for first 4 stands.;Interval Daily (Midnight) Loss = 0 bbls, Cumulative
losses = 501 bbls
Hauled 210 bbls H2O from L-Pad for total = 17495 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 406 bbls to MPU G&I cuttings/mud/cement for total = 21,926 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/4/2020 Pump out of the hole f/ 6080’ t/ 5503’. Lay down drillpipe via Mousehole. 120 GPM, 200 psi. 125k PU, 100k SO. Hole taking 2.4 bbls over calc displacement
evey 5 stands.;Stop and perform flow check, slight flow going static in 25 min, Continue to Pump out of the hole f/ 5503’ t/ 4209’. Lay down total 75 jts drill pipe
via Mousehole. Drop drift on wire, continue pumping out 3 bpm, 180 psi to 3226' racking stds DP in derrick.;Flow check every 10 stds pulled, continue to
slightly flow to going static ea. time to confirm slight breathing.;Continue pumping out 3 bpm, 180 psi f/ 3226' to the HWDP @ 275' racking 41 stds DP in
derrick, stop every 10 stds to verify wellbore breathing, slight flow to static ea. time. Well took 15.6 bbls over calculated displacement pumping out.;BD TD,
Flow check before pulling BHA, static, L/D jar stand, float subs and NMFCs to 83', Recover drift on wire. Plug in and upload MWD. L/D remaining BHA. Bit
grade= 1-3-BT-T-X-1-CT-TD. Clear and clean rig floor.;The 8-3/8” ILS came out at 7-3/8”, 1” under gauge. The data from the ALD could not be read in the
rotary table or when laid down in the shed. Will be sent in to the shop to extract the data.;Make up 3.5” IF stack washer. Flush the stack and well head pumping
12.5 BPM. Drain stack and blow down topdrive. Remove split bushings and install master bushings. Pull wear ring and set test plug. Break down TIW f/ 4-
1/2” safety joint.;R/U test equipment and hold PJSM on testing BOPE. Fill stack and purge air. Perform Shell Test. SimOps: Perform Derrick
inspection.;Perform Bi-Weely BOP test as per AOGCC & PTD requirements. AOGCC inspector Austin McLeod waived witness of testing at 14:39 on 04 April
2020. All tests performed with fresh water, to 250 PSI low / 3000 PSI high, held for 5 min. each and charted.;1) Annular on 4.5" test joint, choke valves 1, 12,
13, 14, kill line Demco & upper IBOP. 2) Upper 4.5"x7" VBR on 4.5" test joint, choke valves 9, 11, HCR kill & lower IBOP. 3) Choke valves 5, 8, 10, manual kill
& 5” dart valve. 4) Choke valves 4, 6, 7 & 5" FOSV #1.;5) Lower 3.5"x6" VBR on 4.5" test joint & 5" FOSV #2. 6) Upper 4.5"x7" VBR on 5" test joint, choke
valve 2, 3.5" dart valve. 7) Choke valve 3 & 3.5" FOSV. 8) HCR choke. 9) Lower 3.5"x6" VBR on 5" test joint. 10) Blind rams 11) Hydraulic choke "B", Manual
choke "A".;12) Upper 4.5"x7" VBR on 7" test joint & Manual choke. Accumulator test: 3000 PSI system, 1650 PSI after closure, 200 PSI recovery in 40 sec.,
full recovery in 179 sec., 6 nitrogen bottle average = 2125 PSI. Sim-ops: Make up 5” TIW to safety joint and lay down in shed.;R/D test equipment. Pull test
plug and lay down. Install 9-1/8" I.D. wear bushing. L/D running tool and test joint. Blow down choke & kill lines. Sim-Ops: Test rig gas alarms.;Interval Daily
(Midnight) Loss = 27 bbls, Cumulative losses = 528 bbls
Hauled 150 bbls H2O from L-Pad for total = 17645 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 114 bbls to MPU G&I cuttings/mud/cement for total = 22,040 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/5/2020 Clear rig floor, R/U to run lower screen completion, R/U 4 1/2'' handing equipment, power tongs, ect. Monitor well, 1 bph loss rate.;PJSM with all parties
involved, P/U round nose flt shoe w/ XO jt and 1st screen to 83', P/U and test run safety jt, good, remove protective wrap from 1st row of screens in pipeshed.
250 micron screens have 1 -7.25'' straight vane centralizer pre- installed mid jt.;P/U and run 4 1/2'', 13.5#, L-80 hydril 625 lower screen completion as per tally
f/ 83' to 2034', torque to optimum @ 9600 ft/lbs. Blank jts- install 1- 4 1/2'' x 7 1/4'' centralizer w/ 1- stop ring free floating ea. jt #1-7. 1 bph loss rate at this
point.;P/U and run 4 1/2'', 13.5#, L-80 hydril 625 lower screen completion as per tally f/ 2034' to 6131', torque to optimum @ 9600 ft/lbs, Blank jts- install 1- 4
1/2'' x 7 1/4'' centralizer w/ 1- stop ring free floating ea. jt #8-46. 2.5-3 bph avg loss rate at this point.;P/U and run 4 1/2'', 13.5#, L-80 hydril 625 lower screen
completion as per tally f/ 6131' to 9393', tq to optimum @ 9600 ft/lbs. Blank jts- install 1- 4 1/2'' x 7 1/4'' centralizer w/ 1- stop ring free floating ea. jt #47-67. 1-
2 bph loss rate. At 6615’ 115k PU / 85K SO.;C/O handling equip to 5'', M/U Baker 7''x9-5/8'' LTP assy and running tool f/ 9393' t/ 9432' as per Baker rep, 8
pins in pusher tool, set at 2648 psi, packer- 9 pins set @ 44100 ft/lbs . M/U stand DP RIH to 9528'. 18.2 bbls total loss while p/u & running screen liner.;M/U
TD, set TD tq @ 10k, Pump 10 bbls at 3 bpm, 175 psi to ensure clear flow path. Obtain parameters: 10 & 20 RPM, 6k Tq. 130K PU / 72K SO / 85k ROT, BD
TD.;TIH with 4 ½” screen liner conveyed on 27 stands of drifted 5'' DP f/ 9528' to 12003'. Losing Dn Wt, string floating in hole. Single in w/ drifted 5'' HWDP to
12892'. Lost all down wt. TIH @ 30 fpm, easy in/out slips. String self filling. 4 BPH losses;Work string 60’ up, slack off and stacked out at same depth (12892’)
Kelly up Topdrive and engage rotary, 20 RPM – 10k Tq. Slack off, set 20k dn and string stall. Work string with 20 RPM, 10k Tq t/ 12896’. Small gains with
each attempt to work down.;Interval Daily (Midnight) Loss = 26 bbls, Cumulative losses = 554 bbls
Hauled 75 bbls H2O from L-Pad for total = 17720 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 57 bbls to MPU G&I cuttings/mud/cement for total = 22,097 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/6/2020 Continue to run 4 1/2'' screens conveyed on singles HWDP f/ 12896’ working tight hole, 20 RPM – 10-12k Tq. Slack off, set 30k dn until string stalls then P/U
10' and repeat making 1/2' progress each attempt working down slowly to 13050', P/U 195K, no SO, ROT 135K.;Run 4 1/2'' screens conveyed on singles
HWDP, Start making faster progress using the same parameters making 2' each time w/ progress increasing f/ 13050' to 13173'. Fill pipe as needed with
Clean 9.75 ppg Brine.;Run 4 1/2'' screens conveyed on singles HWDP using the same parameters making 1'-2' each time w/ progress slowly increasing f/
13173' to 13336', then increasing to working a jt down every 10 min f/ 13336' to 13634'. Monitor well, correct displacement.;Run 4 1/2'' screens conveyed on
singles HWDP, able to Rotate down f/ 13634' to 13880' stacking 10K, 20 rpm, 10k torque. Progress @ 5-10 min/jt Fill pipe as needed with Clean 9.75 ppg
Brine P/U 190K, no S/O, ROT 125K.;Run 4 1/2'' screens conveyed on HWDP singles f/ 13880' to 14095', work string down stacking 10K, 20 rpm, 12k torque.
working a jt down every 10-20 min, then slowing to incremental progress with each stroke next two jts. to 14146'. Fill pipe with Clean 9.75 ppg Brine. P/U
225K, no S/O, ROT 140K.;***Milne Point In Phase 2 @ 23:00***;Run 4 1/2'' screens conveyed on singles HWDP singles f/ 14146' to 14526', Work string
down stacking 10K, 20 rpm, 12k torque, 20-30 min/jt Fill pipe as needed with Clean 9.75 ppg Brine Losses at 4 BPH. P/U 210K, no S/O, ROT 160K.;Interval
Daily (Midnight) Loss = 32 bbls, Cumulative losses = 586 bbls
Hauled 40 bbls H2O from L-Pad for total = 17760 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 182 bbls to MPU G&I cuttings/mud/cement for total = 22,279 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/7/2020 Run 4 1/2'' screens conveyed on singles HWDP singles f/ 14526' to 14710'' working tight hole, 20 RPM – 12-14k Tq. Slack off, set 30-40k dn until string stalls
then P/U 10' and repeat, averaging 50-70 min a jt , PU 225K, ROT 170K. 1 bph loss rate.;Run 4 1/2'' screens conveyed on singles HWDP singles f/ 14710'
to 14787' working tight hole, 20 RPM – 12-14k Tq. Slack off, set 30-40k dn until string stalls, P/U 10' and repeat, slowing 60-90 min a jt , Fill pipe on
connections w/ clean 9.7+ brine.;14787' S/O wt went from none to 170k, torque went f/ 14k to 9k free rotation, Continue to S/O to 14832', stalling out and
taking wt, PU wt went f/ 225 to 195k, ROT wt f/ none to 173K while sitting still.;Notify Town Engineer, Discuss and Compare torque and drag modeling which
was found to be within limits , recommended to continue RIH for further indications.;Continue to working tight hole, 20 RPM – 14k Tq. S/O to 50k dn until string
stalls then P/U 10' and repeat, avg 15 fph f/ 14832' to 14855' where any progress stopped. Note: P/U seeing overpull to 225k each time P/U then dropping to
195k P/U w/ ROT wt @ 173k.;Notify Town Engineer, Relay data and observations, discuss options. Wait on orders while Engineers and Drilling management
design optimum plan forward. Decision made to POOH, perform openhole sidetrack and re-drill the lateral section. Hold PJSM on L/D HWDP trip out of
hole.;POOH f/ 14855' t/ 12004' laying down 90 jts 5" HWDP to shed. POOH f/ 12004' t/ 9432' racking 27 stands 5" DP in Derrick. L/D Baker SLZXP packer
hanger assembly. 1.3 bbls over calculated hole fill on TOH.;Rig up 4-1/2" handling equipment, Prep pipe shed for laying screens. Hold PJSM on laying down
liner.;Lay down 4-1/2” lower screen completion string f/ SLZXP packer hanger t/ parted connection on bottom of screen jt #135 top of #134, Avg 12k Tq to
break the Hydril 625 connections. Max break Tq seen = 15k one time Hole took proper fill on TOH w/ liner.;7683.36' of lower screen completion left in the hole.
134 jts of 4-1/2" 250 micron screens, 13.5#, L-80, Hydril 625 53 jts, 4-1/2" solid, 13.5#, L-80, Hydril 625 liner. TOF calculated to be 477' below the 9-5/8"
shoe.;Rig down 4-1/2" equipment, clean & clear floor. Prep pipeshed for picking up pipe.;Interval Daily (Midnight) Loss = 21 bbls, Cumulative losses = 607
bbls
Hauled 40 bbls H2O from L-Pad for total = 17,800 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 55 bbls to MPU G&I cuttings/mud/cement for total = 22,334 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/8/2020 Finish clearing the rig floor, clear out pipe shed, ready BHA 3 in shed.;PJSM, M/U 8 1/2'' BHA 3, M/U geo pilot, ADR, ILS, DGR, PWD, DM, TM and float sub
to 83', plug in and download MWD tools while W/O new NRP sleeve to arrive, pull hanging BHA. Monitor well, static.;M/U new 8 1/2'' bit and NRP sleeve, RIH,
M/U remaining components, 3 NMFCs, flt sub and HW jar stand to 280', RIH w/ 1 std 5” DP & Shallow pulse test MWD with 458 GPM, 770 PSI - good test, BD
TD. L-pad turbine went down, swap rig to gen power @ 14:40;TIH with 41 stands 5'' DP fl/ 348' to 4184' fill pipe @ 1700', break in geo pilot seals. Rig back on
high line power @ 17:30.;TIH picking up 5" drill pipe singles f/ 4184' t/ 6596'. 140k PU, 99k SO. 24 bbls loss on TIH.;Perform BOP drill. Install FOSV, Simulate
securing well 86 sec. Cut and slip 53' drilling line and C/O saver sub. Monitor well on trip tank. SimOps: Pressure test MPD lines.;Install MPD RCD. Continue
run in hole t/ 6659' picking up singles. M/U stand in 90' mousehole and Kelly up, Obtain drilling drilling parameters and ream down t/ 6680', 430 GPM, 1220
psi, 65 RPM, 7.5k Tq.;Trough 3x at a 160L HS TF f/ 6680’ t/ 6710’. 475 gpm, 1160 psi, 80 rpm, 12k Tq. Seeing 0.5° ABI difference from original wellbore
logs after 3rd trough. (91.5°-91°). 140k PU, 95k SO, 115k ROT. Displace to 8.8 ppg, 41 Vis, FLOPRO drilling mud while troughing. Max Gas: 273u.;Obtain
SPR with new 8.8 ppg fluid, trough back down and start taking wt at 6680'. Time drill at 5-10'/hr from 6680' t/ 6696'. 475 gpm, 1160 psi, 80 rpm, 12k Tq.
Maintaining 10k WOB. Seeing 1.3° (90.2° inc) ABI separation at 6696' MD , 3826' TVD.;Interval Daily (Midnight) Loss = 24 bbls, Cumulative losses = 631 bbls
Hauled 480 bbls H2O from L-Pad for total = 18,280 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 314 bbls to MPU G&I cuttings/mud/cement for total = 22,648 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/9/2020 Continue to side track, time drill at 5-10'/hr from 6696' t/ 6725'. 475 gpm, 1160 psi, 80 rpm, 12-15k Tq. 14k WOB with 2.51 deg separation @ 88.99
deg.;Control drill 50 fph f/ 6725' to 6754' at 475 gpm, 1170 psi, 100 rpm, 13k torque, WOB 16k, with 3.13 deg separation @ 88.37 deg, BR to above sidetrack
at 6654' x2, pass thru with pumps off and no rotary f/ 6654' 6754' w/ no issues, make connection. Survey. Sidetrack successful.;Drill 8-1/2'' lateral f/ 6754' t/
6810', 56' drilled. 550 GPM, 1500 PSI, 100 RPM, 10-12K TQ, 12K WOB. 8.7+ ppg MW, 41 vis, 9.8 ECD, max gas 429u. 140K PU / 80K SO / 115K ROT.
Target 91 deg.;MPD holding 70 psi drilling and 170 psi during connections.;Drill 8-1/2'' lateral f/ 6810' t/ 7087', 277' drilled, 110.8'/hr AROP. 502 GPM, 1340
PSI, 120 RPM, 11K TQ, 3-5K WOB. 8.7 ppg MW, 42 vis, 10.05 ECD, max gas 413u. 144K PU / 90K SO / 150K ROT.;Drilled 100’ just below the NB-Sand
(from 6,790’ to 6,890’ md). Currently back in good NB-Sand targeting 91°. MPD holding 70 psi drilling and 170 psi during connections.;7087' DD and MWD
troubleshooting computer data exchange issues, 450 gpm, 1150 psi, 80 rpm, 7k TQ working pipe slow up and down fast while resolving issues.;Drill 8-1/2''
lateral f/ 7087' t/ 7164', (3822' TVD) 77' drilled, 51.33'/hr AROP. 500 GPM, 1350 PSI, 100 RPM, 11K TQ, 8-10K WOB. 8.7 ppg MW, 43 vis, 9.96 ECD, max
gas 331u. 140K PU / 90K SO / 105K ROT.;MPD holding 70 psi drilling and 170 psi during connections. Drill in the NB sand targeting 91.5°.;Drill 8-1/2'' lateral
f/ 7164' t/ 7799', (3800' TVD) 635’ drilled, 105.83'/hr AROP. 450 GPM, 1220 PSI, 120 RPM, 7-8K TQ, 7K WOB. 8.8 ppg MW, 43 vis, 10.1 ECD, max gas 443u.
145K PU / 87K SO / 114K ROT.;MPD holding 70 psi drilling and 170 psi during connections. Pumped 30 bbl Hi-Vis sweep at 7539'. Back on time w/ 30%
increase in cuttings. Continue drilling in the NB-sand.;Drill 8-1/2'' lateral f/ 7799' t/ 8373', (3799' TVD) 574’ drilled, 95.67'/hr AROP. 380 GPM, 1140 PSI, 110
RPM, 7-8K TQ, 6K WOB. 8.7 ppg MW, 42 vis, 10.38 ECD, max gas 502u. 145K PU / 85K SO / 110K ROT.;At 7820’ shakers start blinding off with oil. Reduce
to 380 GPM to minimize losses over shakers. Lower flow rate and additions of screenkleen does not stop losses over shakers. Increase MPD to 125 psi
drilling and 250 psi during connections to help reduce oil.;Trajectory dropping in the NB sand . Deflect 100% @ HS TF with RSS and inc continues to drop.
The reduced flow at 380 GPM and increase ROP of 225-275’/hr does not stop the assembly from dropping inclination. Entered the NB-clay at 8136'. Target
94° to build up to sands.;14 concretions have been drilled so far, for a total footage of 85’ (5.3% of the lateral). Last survey at 8299.92' MD / 3803.57' TVD,
92.36° inc., 184.03° azm, 36.63' from plan, 11.02' low and 34.94' right.;Interval Daily (Midnight) Loss = 10 bbls, Cumulative losses = 641 bbls
Hauled 640 bbls H2O from L-Pad for total = 18,920 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 1,412 bbls to MPU G&I cuttings/mud/cement for total = 24,060 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/10/2020 Drill 8-1/2'' lateral f/ 8373' t/ 8651', 278’ drilled, 137'/hr AROP. Drill in the NB sand, Target 92 deg. 392 GPM, 1120 PSI, 100 RPM, 7K TQ, 3K WOB. 8.7 ppg
MW, 43 vis, 10.8 ECD, max gas 1107u. 149K PU / 79K SO / 109K ROT.;Shakers continue to blind off with oil and sand w/ 140 screens on all shakers ,
increase Screen Kleen content f/ .5% to 1%, still continue to dump mud to rock washer, stop drilling while cleaning shaker screens, pump mud back across
shakers f/ rock wash.;Decision made POOH to change the nozzle size and open up the TFA to reduce hydraulic impact force of the bit to prevent sand
washout and hopefully help with steering. Send tool home. MPD holding 250 psi line pressure and 360 psi back pressure to help reduce oil at shakers.;TOOH
f/ 8650', pull 1 std on elevators w/ MPD holding 300 psi, no issues, BD TD, Continue to TOOH on elevators to 8266', at 4 stds, not seeing correct
displacement, MPD holding 300 psi back pressure maintaining 10.2 ECD.;Line up MPD and Pump out of hole 200 gpm, 600 psi f/ 8266' to 6558'; just above
the 9 5/8'' shoe racking stds in derrick. MPD maintain 10 ppg ECD holding 190 psi pumping out and 250 psi at connections. 7.2 bbls over calculated
displacement to shoe. L- Pad turbine down, put rig on gen power @ 13:40.;BD TD. Monitor MPD for pressure build, Bleed off to 10 psi, flow slowed to 74 gpm,
perform 2 more times with final slowing to 21 gpm, shut in, pressure building to 48 psi and leveling out. BD geo span.;M/U TD, increase MW from 8.7 to 8.9+
adding safe carb 40 , circulate around 300 to 420 gpm, 620/1070 psi 30 rpm until a good 8.9+ in/out capping the well from shoe up. Shut down pump, BD TD,
monitor well for 30 min, flowing 4 gpm receding to 1.07 gpm. Put rig on hi line power @ 16:45.;Increase MW f/ 8.9+ t/ 9.2 ppg adding safe carb 20, circulate at
280 gpm, 630 psi, 30 RPM until a good 9.2 in/out. Shut down pump and blow down topdrive. Code 99 RED calling in the field at 18:50. Cease all but essential
rig operations until Code cleared at 20:43.;Monitor well, Initial flow of 4.3 BPH, receding 1.3 BPH after 30 min with no decrease f/1.3 after 40 min. Shut in
MPD, pressure build t/ 20 psi.;Build and weight up active surface volume to 100 bbls 9.5 ppg. Screen down front of shakers to 80 mesh to prevent stripping
weighting agent. Increase MW f/ 9.2 t/ 9.5 ppg w/ safecarb 10. Circ 250 gpm, 440 psi, 30 RPM. Recip string 30’.;Monitor well, Initial flow of 1 BPH reducing to
0.5 BPH in 10 min, 0.15 BPH in 20 min & static in 25 min. Monitor at Bell Nipple after initial 10 min & B/D MPD lines. Prejob for remove RCD while monitoring
Well.;Remove MPD RCD bearing leaving on stand of DP and racking on DS Derrick, install trip nipple, fill stack with mud, no leaks. Well static.;POOH on
elevators f/ 6558' t/ 180'. Monitor well at HWDP - Static Rack HWDP, Jars and Non Mag Collars in Derrick. Hole took correct displacement on trip out of
hole.;14 concretions have been drilled so far, for a total footage of 85’ (5.3% of the lateral).
Last survey at 8491.60' MD / 3794.20' TVD, 92.66° inc., 183.08° azm, 35.9' from plan, 7.0' low and 35.2' right.;Interval Daily (Midnight) Loss = 7 bbls,
Cumulative losses = 548 bbls
Hauled 560 bbls H2O from L-Pad for total = 19,480 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 986 bbls to MPU G&I cuttings/mud/cement for total = 25,046 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/11/2020 Plug in and upload the MWD. pull BHA 3, ILS bottom edge under cut 1'', Geo pilot anti roll cutters chipped, breakout bit, grade 1-3-BT-T-X-I-CT-BHA, L/D geo
pilot and MWD tools.;Clear and clean rig floor, Load out BHA tools, mobilize tools to rig floor.;M/U BHA 4, P/U new geo pilot, ADR with stab, C/O pulser, re-
run DM and TM collar, download MWD, M/U new 8 1/2'' bit dressed with 6-#15 nozzles, re-run NRP sleeve. Continue to M/U BHA, flex collar std w/ flt subs,
jar std to 281', run 1 std, shallow pulse test MWD 400 gpm 600 psi, BD TD.;Shakers running over at 300 gpm, Remove 140 screens on front of 2 shakers and
install 80s to keep mud on shakers. Pump 480 gpm w/ no issues.;TIH on elevators f/ 370' to 6512', fill pipe every 2000', break in GP seals, 13 bbl losses
displacement TIH.;PJSM, Install FOSV, slip and cut 25' drilling line, service rig, recalibrate block height, L/D FOSV. Monitor well with trip tank. 1/2 bph loss
rate.;PJSM. Remove trip nipple and install MPD RCD. Install flowline plug.;TIH f/ 6469’ t/ 8163’. Take 25k wt at 8163’. Note Top of NB-clay at 8136’. 155k PU,
90k SO. Kelly up and downlink RSS to “home” prior to going past sidetrack point. No issues entering sidetrack.;Wash and ream f/ 8163’ t/ 8468’. 200 GPM,
660 psi, 50 RPM, 7-10k Tq. Shakers blinding off and running wet. 155k PU, 90k SO, 116k ROT.;CBU, stage pumps up as shakers allow. Initial rate @ 215
GPM, 500 psi. Final 430 GPM, 1120 psi. Hold 75 psi with MPD, increasing t/ 125 psi when MW out @ 9.0 ppg. Blend 290 bbls new 8.8 ppg flo-pro into active
system and increase screenkleen f/ 1% t/ 1.5%.;Wash/ream bottom after BU. Max gas - 83u. 20 bbls total loss recorded during TIH. Started one Rig generator
and have idle on standby.;Drill 8-1/2" production lateral f/ 8651' t/ 8751’ (3786’ TVD), 100' drilled, 66.66/hr AROP. 310 GPM, 760 PSI, 100 RPM, 9k Tq, 1-9k
WOB. 150k PU / 76k SO / 109K ROT. MW 8.9 ppg in, 41 Vis, 10.3ECD, max gas 276u. MPD holding 220 PSI on connections. 130 psi while drilling.;Drill 8-
1/2" production lateral f/ 8751' t/ 9124’ (3776’ TVD), 373' drilled, 62.16/hr AROP. 305 GPM, 815 PSI, 100 RPM, 10k Tq, 5-15k WOB. 155k PU / 76k SO / 112K
ROT. MW 8.8 ppg in, 39 Vis, 10.3ECD, max gas 453u. MPD holding 220 PSI on connections. 130 psi while drilling.;Currently 1-2' TVD above the base of MB-
Sands. Targeting 93.5° Inclination
20 concretions have been drilled so far, for a total footage of 105’ (4.2% of the lateral).
Last survey at 8966.98' MD / 3781.69' TVD, 91.86° inc., 183.77° azm, 37.27' from plan, 7.86' low and 36.43' right.;Interval Daily (Midnight) Loss = 20 bbls,
Cumulative losses = 668 bbls
Hauled 255 bbls H2O from L-Pad for total = 19,735 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 596 bbls to MPU G&I cuttings/mud/cement for total = 25,642 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/12/2020 Drill 8-1/2" production lateral f/ 9124' t/ 9608’ (3750’ TVD), 484' drilled, 80.66/hr AROP. BR full stds. 358 GPM, 990 PSI, 110 RPM, 10k Tq, 5-13k WOB. 155k
PU / 70k SO / 210K ROT. MW 8.7+ ppg in, 42 Vis, 10.3 ECD, max gas 387u. MPD holding 220 PSI on connections. 130 psi while drilling.;Starting 9100’
efforts were made to aggressively turn left f/ PB3. At 9253.73’ we came as close as 4.3’ f/ old wellbore. By 9348.71’ managed to turn left 3.64°, started to
move left away from PB3, remaining in NB-Sand. Continue to steer left as per DD & Geo. 9513' pump 30 bbl hi vis sweep.;Drill 8-1/2" production lateral f/
9608' t/ 10160’ (3732’ TVD), 552' drilled, 92'/hr AROP. 355 GPM, 1170 PSI, 80 RPM, 13k Tq, 15k WOB. 153k PU / 73k SO / 109K ROT. MW 8.7 ppg , 43Vis,
10.3ECD, Max Gas 369u. MPD holding 220 PSI on connections. 130 psi while drilling.;Currently in the middle of the NB-Sand targeting 91.5°. Sweep back
400 stks late w/ 10% increase.;Drill 8-1/2" production lateral f/ 10160' t/ 10411’ (3740’ TVD), 251' drilled, 41.83'/hr AROP. 350 GPM, 1300 PSI, 80 RPM, 13k
Tq, 15k WOB. 155k PU / 73k SO / 109K ROT. MW 8.8 ppg , 43Vis, 10.3ECD, Max Gas 272u.;MPD holding 220 PSI on connections. 130 psi while drilling.
Backream full stds @ 400 GPM, 100 RPM. Maintain the NB-Sand.;Drill 8-1/2" production lateral f/ 10411' t/ 10797’ (3720’ TVD), 386' drilled, 106.17'/hr AROP.
350 GPM, 1230 PSI, 80 RPM, 14k Tq, 15k WOB. 160k PU / 70k SO / 108K ROT. MW 8.9 ppg , 43Vis, 10.7ECD, Max Gas 460u. MPD holding 230 PSI on
connections. 105 psi while drilling.;Backream full stands @ 400 GPM, 100 RPM. Increase flow during hard streaks when directional work is not as impacted.
10464' pump 30 bbl hi vis sweep, back 800 stks late w/ no observed increase. Exited NB-sand and entered NB-clay at 10468', build to 94° inc and re-enter the
NB-sand at 10576'.;70 concretions (and slow streaks) have been drilled so far, for a total footage of 432’ (10.5% of the lateral). Last survey at 10681.27' MD /
3728.29' TVD, 93.66° inc., 181.55° azm, 37.80' from plan, 1.84' low and 37.75' left.;Interval Daily (Midnight) Loss = 30 bbls, Cumulative losses = 705 bbls
Hauled 880 bbls H2O from L-Pad for total = 20,615 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 635 bbls to MPU G&I cuttings/mud/cement for total = 26,277 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/13/2020 Drill 8-1/2" production lateral f/ 10797' t/ 11186’ (3710’ TVD), 389' drilled, 64.8'/hr AROP. 302 GPM, 1100 PSI, 80 RPM, 13k Tq, 8-10k WOB. MW 8.9 ppg , 42
Vis, 10.6 ECD, Max Gas 480u. 165k PU / 95k SO / 106K ROT.;MPD holding 230 PSI on connections. 105 psi while drilling, Drilling in NB targeting 91-
92°.;Drill 8-1/2" production lateral f/ 11186' t/ 11595’ (3701’ TVD), 409' drilled, 68.17'/hr AROP. 410 GPM, 1620 PSI, 100 RPM, 17k Tq, 12-20k WOB. MW 8.85
ppg , 43Vis, 10.6 ECD, Max Gas 266u. 170k PU / 56k SO / 106K ROT. MPD holding 230 PSI on connections. 105 psi while drilling.;Drilling in lower NB sand
targeting 92°, Geo reports thickness about 5-6’ with quality sand at the base. Pump 30 bbl hi vis sweep at 11512', back 1200 stks late w/ 25% increase.;Drill 8-
1/2" production lateral f/ 11595' t/ 11988’ (3698’ TVD), 393' drilled, 65.5'/hr AROP. 350 GPM, 1380 PSI, 80 RPM, 15k Tq, 15-20k WOB. MW 8.9 ppg , 43Vis,
10.65 ECD, Max Gas 617u. 170k PU / 45k SO / 110K ROT.;MBT's up to 6.5. Perform 290 bbl whole mud dilution at 11898'. MBT's down to 4.5 after dilution.
MPD holding 230 PSI on connections. 90 psi while drilling, Continue to maintain the NB-sand targeting 90-92° inclination.;Drill 8-1/2" production lateral f/
11988' t/ 12136’ (3700’ TVD), 148' drilled, 24.66'/hr AROP. 350 GPM, 1300 PSI, 80 RPM, 16k Tq, 15k WOB. MW 8.9 ppg , 42Vis, 10.57 ECD, Max Gas 381u.
170k PU / 45k SO / 110K ROT.;MPD holding 230 PSI on connections. 75 psi while drilling, Exited out the top of NB Sands @ 11948’. Target 89° to drop back
to sand.;82 concretions (and slow streaks) have been drilled so far, for a total footage of 820’ (15.0% of the lateral. Last survey at 12013.86' MD / 3699.05'
TVD, 89.95° inc.,186.91° azm, 46.00' from plan, 8.69' low and 45.17' left.;Interval Daily (Midnight) Loss = 17 bbls, Cumulative losses = 722 bbls
Hauled 780 bbls H2O from L-Pad for total = 21,395 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls;Hauled 985 bbls to MPU G&I cuttings/mud/cement for total = 27,762 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/14/2020 Drill 8-1/2" production lateral f/ 12136' t/ 12290’ (3697’ TVD), 154' drilled, 25.6'/hr AROP. 370 GPM, 1390 PSI, 80 RPM, 15k Tq, 15k WOB. MW 8.9+ ppg , 43
Vis, 10.63 ECD, Max Gas 38u. 170k PU / 60k SO / 100K ROT.;Cross fault 1 at 12220' with 20' DTN throw, target 95° to re-acquire sand. MPD holding 230
PSI on connections. 70 psi while drilling, Gradually swap f/ 140s to 170 screens on shakers. At 12464' lost S/O wt.;Drill 8-1/2" production lateral f/ 12290' t/
12769’ (3675’ TVD), 479' drilled, 79.83'/hr AROP. 362 GPM, 1520 PSI, 80 RPM, 18-20k Tq, 10k WOB. MW 8.9+ ppg , 44 Vis, 10.9 ECD, Max Gas 406u. 175k
PU / No SO / 111K ROT.;12364' MBT at 7.5. Perform 290 bbl dump and dilute with new 8.8 mud lowering to 6, gradually screen up shakers to 200s. Entered
base of NB sand at 12360’ after the faulted zone, targeting 92°. MPD holding 225 PSI on connections. 60 psi while drilling.;Drill 8-1/2" production lateral f/
12769' t/ 13037’ (3663’ TVD), 268' drilled, 44.67'/hr AROP. 357 GPM, 1320 PSI, 80 RPM, 18k Tq, 18-20k WOB. MW 8.9 ppg , 43 Vis, 10.68 ECD, Max Gas
414u. 170k PU / No SO / 107K ROT. MPD holding 225 PSI on connections. 60 psi while drilling.;Drill 8-1/2" production lateral f/ 13037' t/ 13345' (3650') TVD,
308' drilled, 51.33'/hr AROP. 358 GPM, 1365 PSI, 80 RPM, 18k Tq, 15-18K WOB. MW 8.9 ppg, 42 Vis, 10.70 ECD, Max Gas 414u. 175k PU / No SO / 105K
ROT. Drill in the NB sand, continue to target 92°.;Sweep at 13037' back 600 strokes late w/ no increase observed. 13224' MBT at 7.5. Perform 290 bbl dump
and dilute with new 8.8 mud. Last Survey, 3.18' below the line, 44.95' left.;76 concretions have been drilled so far, for a total footage of 444’ (6.7% of the
lateral)
Hauled 1137 bbls to MPU G&I cuttings/mud/cement for total = 29,139 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls;Interval Daily (Midnight) Loss = 0 bbls, Cumulative losses = 722 bbls
Hauled 900 bbls H2O from L-Pad for total = 22,295 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
4/15/2020 Drill 8-1/2" production lateral f/ 13345' t/ 13556' (3645' TVD), 211' drilled, 35.16'/hr AROP. 371 GPM, 1310 PSI, 100 RPM, 19k Tq, 19K WOB. MW 8.9 ppg, 41
Vis, 10.76 ECD, Max Gas 276u. 190k PU / No SO / 101K ROT. Drill in the NB sand, continue to target 92°.;At 13430’ target 95° expecting to cross fault #2.
MPD holding 225 PSI on connections. 60 psi while drilling.;Drill 8-1/2" production lateral f/ 13556' t/ 13781' (3620' TVD), 225' drilled, 37.5'/hr AROP. 360 GPM,
1370 PSI, 100 RPM, 25-27k Tq, 17-20K WOB. MW 8.85 ppg, 43 Vis, 10.80 ECD, Max Gas 194u. 191k PU / No SO / 106K ROT.;Cross Fault #2 at 13572’ with
35' DTN throw into ND-clay, target 95° to build up to NC-Sand. 13620' MBT at 6, perform 290 bbl dump/dilute with new 8.8 mud Entered ND-sand at 13724' &
NC-clay at 13760'. MPD holding 225 PSI on connections. 65 psi while drilling.;Drill 8-1/2" production lateral f/ 13781' t/ 13854' (3615' TVD), 73' drilled,
12.17'/hr AROP. 450 GPM, 2250 PSI, 80 RPM, 23-25K TQ, 19-23K WOB. MW 8.9 ppg, vis 41, ECD 10.8, Max Gas 128u. 191K PU / no SO / 110K ROT.
Target 93.5° at 13843'. Add 0.25% Lo-Torq lube at 13845'.;Drilling in NC-clay. MPD holding 225 PSI on connections. 65 psi while drilling.;Drill 8-1/2"
production lateral f/ 13854' t/ 13946' (3614' TVD), 92' drilled, 15.33'/hr AROP. 415 GPM, 1880 PSI, 100 RPM, 21-22K TQ, 20K WOB. MW 8.9 ppg, 41 vis.
ECD 10.66, Max Gas 142u. 180K PU / no SO / 100K ROT. Lo-Torq reduced torque 3K f/ 25K to 22K. MBT @ 3am = 7#/bbl.;MPD holding 225 PSI on
connections. 65 psi while drilling. NC sand base @ 13855', targeting 93° from 13882'. Last survey at 13824.83 MD / 3620.72' TVD, 93.90° inc, 184.07° azm,
40.88' from plan, 6.51' high, 40.35' left, 96.5' left of old wellbore.;87 concretions have been drilled so far, for a total footage of 585’ (8.0% of the lateral).
0 bbls daily losses, 722.4 bbls cumulative losses.;Hauled 725 bbls H2O from L-Pad for total = 22,120 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 1,193 bbls to MPU G&I cuttings/mud/cement for total = 30,332 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/16/2020 Drill 8-1/2" production lateral f/ 13946' t/ 14358' (3594' TVD), 412' drilled, 68.6'/hr AROP. 434 GPM, 1760 PSI, 100 RPM, 20K TQ, 13K WOB. MW 8.9+ ppg, 41
vis. ECD 11, Max Gas 365u. 190K PU / no SO / 95K ROT.;At 14275' pump 30 bbl hi vis sweep w/ 40 ppb nut plug added, Sweep came back 1750 stks late,
25% increase at the shakers. MPD holding 225 PSI on connections. 65 psi while drilling. Drill in the NC sand, target 93.5°.;Drill 8-1/2" production lateral f/
14358' t/ 14561' (3587' TVD), 203' drilled, 50.75'/hr AROP. 450 GPM, 1690 PSI, 100 RPM, 26K TQ, 20-23K WOB. MW 8.9 ppg, 40 vis. ECD 10.97, Max Gas
286u. 185K PU / no SO / 105K ROT.;Drill in the NC-Sand, target 91°, crossed Fault #3 @ 14472’ with 37' DTS throw, drop to NB sand targeting 89.5° 14455'
MBT 7.5, perform 290 bbl dump/dilute w/ new 8.8 mud. MPD holding 225 PSI on connections. 65 psi while drilling.;Last survey @ 14491.81' MD / 3590.73'
TVD, 90.13° inc, 186.27° azm, 34.72' from plan, 9.95' high, 33.27' left and 94.08' from old wellbore. 104 concretions have been drilled so far, for a total footage
of 713’ (9.0% of the lateral).;Pump pressure dropped f/ 1800 psi to 1630 psi over last 2 stds drilled down, seeing flow back on the drill pipe on last 2
connections, SPRs are 30 psi less than 500' ago. MWD pulser RPM also dropped 400 RPM at 450 GPM. Notify the town team of the possible washout
situation.;Pump out of the hole looking for washout f/ 14561' t/ 12084' at 7-12'/min. depending on conditions. 125 GPM, 470 PSI, 190K PU. Pulled 40K over at
13500' in NB-clay, S/O then ream through w/ 40 RPM, 16K TQ. Pulled 15K over at 12339' in NB-clay, S/O then P/U with no problem.;Pulled 25K over at 12220'
at Fault #1, S/O then ream w/ 40 RPM 16K TQ to 11945' through NA-clay. Hold 150 PSI MPD backpressure while pumping out, trap 200 psi during
connections which bled off to 150 psi. Calculate 10.4 ppg ECD while pumping, 9.7 EMW on connections . 9 bbls lost while pumping out.;*** Provided 24 hour
BOP test notification to the AOGCC at 18:07 on 16 April 2020 ***;Pump out of the hole looking for washout f/ 12084' t 8373' at 12-30'/min. depending on
conditions. 125 GPM, 340 PSI, 175K PU. Hold 150 PSI MPD backpressure while pumping out, trap 100 psi during connections (reduced due to increased rate
of mud running over pipe) which bled off to 80 psi.;Pulled 30K over at 10635' just before NB-clay. Ream w/ 40 RPM to NB-sand at 10468'. Calculate 10.4 ppg
ECD while pumping, 9.4 EMW on connections. 2 bbls lost while pumping out, 11 bbls total at this time for pumping out. 9 bbls daily (midnight) losses, 731.4
bbls cumulative losses.;Hauled 1020 bbls H2O from L-Pad for total = 24,040 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 1,292 bbls to MPU G&I cuttings/mud/cement for total = 31,624 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/17/2020 Pump out of the hole looking for washout f/ 8373' to 7325,' at 12-30'/min. depending on conditions, top stand 74, jt # 222 washed out 11.55' down f/ the top tool
jt. L/D washed jt/replace jt. 125 GPM, 330 PSI, 175K PU. Hold 150 PSI MPD backpressure while pumping out, trap 100 psi during connections.;Continue to
pump out f/ 7325' to 6564' inside the 9 5/8'' casing, 125 gpm, pressure increase f/ 330 psi to 440 psi. Hold 150 PSI MPD backpressure while pumping out, trap
225 psi during connections. 45 bbl losses pumping out.;Circulate 464 gpm, 1300 psi, 40 rpm, 5k torque, reciprocating pipe, 200% increase all sand @ BU,
circulate until clean. MW 8.8 ppg, 41 vis. shut down pumps.;MPD monitor for pressure build, bleed off pressure to 10 psi, built to 89 psi in 5 min, perform 2
more times with final flowing 38 gpm, shut in building to 60 psi in 5 min and leveling off.;PJSM, cap well f/ shoe up, Pump 30 bbl hi vis spacer, followed with
470 bbls 9.7 ppg brine 465 gpm, 1400 psi, 40 rpm, 5k torque, reciprocating pipe. Dump interface until good 9.7 in/out, shut down pumps. Save the drilling mud
in pits 1, 2, 3 and in vac truck.;BD TD. Flow check well, initially flowing 4 gpm slowing to pencil size stream in 30 min, then static in 1 hr. PJSM, remove RCD
bearing, install trip nipple, no leaks. well is static.;Rack back 2 stands to 6275', M/U 9 5/8'' model B retrievable storm packer, RIH 1 std to 6397', set storm
packer as per BOT rep, top packer 96.68', center element 110.99', L/D running tool, rack back std. Test packer to 500 psi f/ 5 min, charted. PU 143K, SO
106K.;M/U flush tool, jet stack, R/U and pull wear bushing. Blow down top drive.;Install test plug, 4-1/2" test joint and R/U test equipment. Test plug did not
seat fully. Pull, inspect and re-install.;Perform bi-weekly test of BOP equipment as per Hilcorp, PTD & AOGCC requirements w/ AOGCC inspector Guy Cook
witnessing. All tests performed w/ fresh water, 250 PSI low / 3000 PSI high, held for 5 min. each & charted 1. Annular on 4.5" test joint, choke valves 1, 12, 13,
14, kill Demco & 5" FOSV #1;2. Upper 4.5"x7" VBR on 4.5" test joint, choke valves 9, 11, kill HCR & 5" FOSV #2 3. Choke valves 5, 8, 10, manual kill & 5"
dart valve 4. Choke valves 4, 6, 7 & 3.5" dart valve 5. Lower 3.5"x6" VBR on 4.5" test joint & 3.5" FOSV 6. Upper 4.5"x7" VBR on 7" test joint, choke valve 1 &
upper IBOP;7. HCR choke & lower IBOP 8. Manual choke 9. Lower 3.5"x6" VBR on 5" test joint 10. Choke valve 3 & blind rams 11. Hydraulic choke A 12.
Manual choke B Observed piece of annular in test plug 13. Re-test Annular on 4.5" test joint.;Accumulator: 3000 PSI system pressure, 1650 PSI after closure,
200 PSI recovery in 44 sec, full recovery in 190 sec, six nitrogen bottle avg of 2141 PSI. No failures.;R/D test equipment, L/D test joint and test plug. Install 9-
1/8" I.D. wear bushing. Blow down lines.;M/U Baker overshot and 5" pup joint. TIH w/ 5" drill pipe and install 5" FOSV in close d position. Engage storm packer
with 11-1/2 turns, open FOSV & no pressure observed. Close FOSV. M/U top drive, shear screws & M/U 11 additional turns for 22-1/2 total to relax
packer.;Close annular, P/U 1' (143K PU) , monitor choke gauge - no pressure observed. Apply 1 right turn, P/U to release packer, attempt S/O but packer not
released. Attempt to release packer 6 times w/o success. POOH to 6275', packer above rig floor. L/D FOSV & rack back stand of drill pipe.;35 bbls daily
(midnight) losses, 766.4 bbls cumulative losses.;Hauled 275 bbls H2O from L-Pad for total = 24,315 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 343 bbls to MPU G&I cuttings/mud/cement for total = 31,967 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/18/2020 L/D Baker 9-5/8" Model B retrievable storm packer. No damage observed on tool. Tool did not travel and dog into release position. Will send back to
Deadhorse and inspect tool. Monitor well on trip tank - static.;TIH 2 stands to 6457', remove the trip nipple, install the RCD bearing, well remains static.;PJSM,
Pump 30 bbl hi vise spacer, 437 bbls mud, displace 9.7 brine cap back to 8.8 mud from 6566' at 320 gpm, 900 psi, 40 rpm, 6k torque, working pipe, dump
spacer, 18 bbl losses. Send 580 bbls of 9.7 brine f/ displacing and in pit 4 to MI for storage. MPD final holding 170 circulating at 10.3 ECD;BD TD, TIH on
elevators f/ 6566' with 20k set down @ 8910', work thru easily, 9110' 20k set down, wash and ream f/ 9110' to 9143' at 250 gpm, 690 psi, 40 rpm, 10k tq, MPD
maintain 225 psi. back pressure.;RIH M/U TD for extra wt to get down f/ 9134' to 9357' with 20k set down, wash and ream f/ 9357' to 9600' at 250 gpm, 700
psi, 40 rpm, 8-10k tq, Wash down f/ 9600' at 100 gpm, 400 psi, trying to packoff at 10300' cleanup same.;Slowly loosing S/O wt, continue to wash and ream
from 10520' to 14561' at 250 gpm, 700 psi, 40 rpm, 13k tq. MPD holding 60 psi BR and 225 psi on connections 33.8 bbls lost on trip in the hole.;Stage up
pumps to 450 GPM, 1770 PSI, 80 RPM, 18K TQ. 185K PU / no SO / 100K ROT Circulate bottoms up while reciprocating 90'. Medium to light load of fine sand,
silt & clays over the shakers. Max gas 544u.;Drill 8-1/2" production lateral f/ 14561' t/ 14601' (3570' TVD), 40' drilled, 20'/hr AROP. 440 GPM, 1690 PSI, 100
RPM, 24K TQ, 15K WOB. 9.0 ppg MW, 39 vis, 11.0 ECD, 129u max gas. 185K PU / no SO / 110K ROT. Build to 90° to land in the NB-sand.;Drill 8-1/2"
production lateral f/ 14601' t/ 14995' (3550' TVD), 394' drilled, 65.67'/hr AROP. 445 GPM, 1720 PSI, 100 RPM, 23K TQ, 10-15K WOB. 9.1 ppg MW, 42 vis,
11.11 ECD. 289u max gas. NB-sand top logged at 14696', target 93.5° from 14720'. Target 92.5° from 14787'.;113 concretions have been drilled so far, for a
total footage of 769’ (9.3% of the lateral).
Last survey at 14874.44' MD / 3581.00' TVD, 93.97° inc, 189.21° azm, 12.51' from plan, 8.3' high, 9.36' left and 70.76' left of old wellbore.;60 bbls daily
(midnight) losses, 826.4 bbls cumulative losses.;Hauled 375 bbls H2O from L-Pad for total = 24,690 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 229 bbls to MPU G&I cuttings/mud/cement for total = 32,196 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/19/2020 Drill 8-1/2" production lateral f/ 14995' t/ 15435' (3534' TVD), 440' drilled, 73.3'/hr AROP. 445 GPM, 1720 PSI, 100 RPM, 23K TQ, 13K WOB. 9 ppg MW,39x
vis, 11.31 ECD. 221u max gas. PU 180k, no SO, 100k ROT.;Lost hi line power @ 06:20, put rig on gen power, back to drilling @ 06:50. At 15340' perform 290
bbl dump/dilute w/ new 8.8 mud. MPD 45 psi line pressure drlg, 150 psi @ connections. Drill NB sand, Target 92.5°.;Drill 8-1/2" production lateral f/ 15435' t/
15890' at TD in NB-sand (3542' TVD), 455' drilled, 130'/hr AROP. 445 GPM, 1690 PSI, 100 RPM, 21-22K TQ, 10-15K WOB. 9 ppg MW, 40 vis, 11.2 ECD.
529u max gas. PU 170k, no SO, 105k ROT.;Increase lubes f/ .5% to 3% adding 13 drums 776 and 13 drums lo-torq to the system before reaching TD. 118
concretions were drilled in the motherbore, with a total footage of 817’ (8.8% of the lateral). Obtain final survey= 8.44' below the line and 8.78' left, 56.54' from
plug back.;Pump 30 bbl hi vis sweep 450 GPM, 1750 PSI, 100 RPM, 22K torque. Sweep back 2000 stks late with 10% increase at sweep returns. Circulate a
total 4 BU racking a std back ea. BU to 15603', Run back to bttm. 555u max gas. No losses.;Ream in hole (no slack off weight) f/ 15603' t/ 15890', Perform
flow check w/ MPD trap 125 PSI and only built to 130 PSI in 5 min. - 9.8 ppg EMW. Obtain slow pump rates.;BROOH f/ 15890' t/ 14848' at 5-10 min/stand. 450
GPM, 1630 PSI, 100 RPM, 24K TQ, 10.55 ECD, 87u max gas. Laydown stands in the mousehole. MPD holding 150 PSI on connections, 50 PSI line pressure
while circulating.;BROOH f/ 14848' t/ 12562' at 5-10 min/stand. 450 GPM, 1400 PSI, 100 RPM, 23K TQ, 10.53 ECD, 131u max gas. Laydown stands in the
mousehole, mark joints for inspection and hardband. MPD holding 150 PSI on connections, 50 PSI line pressure while circulating. 36.4 bbls total lost for
BROOH.;18 bbls daily (midnight) losses, 844.4 bbls cumulative losses.;Hauled 1,095 bbls H2O from L-Pad for total = 25,785 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 1,254 bbls to MPU G&I cuttings/mud/cement for total = 33,450 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/20/2020 BROOH f/ 12562' t/ 10180' at 5-10 min/stand 450 GPM, 1300-1540 PSI, 100 RPM, 18-23K TQ, 10.38 ECD, 180u max gas. L/d stds in the mousehole, mark jts
for inspection and hardband. MPD holding 150 PSI on connections, 50 PSI line pressure while circulating. 50 bbl losses ( Rig on Hi Line power @ 10:28
);BROOH f/ 10180' t/ 6754' @ 5-10 min/stand. 450 GPM, 1400 PSI, 100 RPM, 23K TQ, 9.97 ECD, 171u max gas. Pump out w/ no rotary f/ 6754' t/ 6564', 450
GPM, 1100 PSI L/D stds in the mousehole, mark jts for inspection & hardband. MPD holding 150 PSI on connections, 50 PSI line pressure while
circulating.;145K PU / 95K SO at shoe. 52 bbl losses.;Pump 30 bbl high vis sweep & circulate casing clean. 450 GPM, 40 RPM, 38u max gas. Reciprocate
pipe 90'. Sweep back on time w/ 40% increase observed. PJSM for displacement to 9.7 ppg brine. No losses;Displace to 9.7 ppg lubricated 2% Na/KCl brine
250 GPM, 470PSI, 40 RPM, 5K TQ, slow to 230 GPM, 430 PSI when ECD climbed to 10.3 ppg. Pumped 469.45 bbls w/ 9.5 ppg clean brine returns. Take
returns to pits & pumped 42.93 bbls more until 9.7 ppg returns. 512.37 bbls total brine pumped. No losses.;Pumps off & chokes open, 18 GPM to no flow in 10
min. Shut chokes & built 10 PSI in 5 min. Bleed off, shut choke & built 5 PSI in 5 min. Open 2" valve on head & monitor flow. Initial 0.65 bph slowed to static in
20 min. Sim-ops: Blow down top drive, install FOSV & pup joint. Prepare to slip & cut.;Slip & cut 86' of drilling line. Remove FOSV & pump joint. Monitor MPD
casing pressure - static.;PJSM. Remove MPD RCD and install trip nipple. Fill stack, check for leaks - none. Obtain new slow pump rates.;POOH on elevators
10 stands f/ 6564' t/ 2375'. Pump 25 bbl, 11.5 ppg dry job and blow down top drive after 1st 10 stands pulled. Drop 2.44" drift w/ 100' of wire on stand #56.
140K PU / 100K SO.;167 bbls daily (midnight) losses, 1011.4 bbls cumulative losses.;Hauled 610 bbls H2O from L-Pad for total = 26,395 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 1,183 bbls to MPU G&I cuttings/mud/cement for total = 33,633 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/21/2020 POOH f/ 2375' t/ 279'. Perform flow check - static. L/D 2 jts. 5" HWDP, jars, float sub & 3 NM flex drill collars to 86'. Read MWD tools. L/D remainder of BHA
from 86'. Bit graded: 1-3-BT-T-X-I-CT-TD. 3 BPH static loss rate.;Clear rig floor & mobilize casing equipment. R/U elevators, slips & double stack tongs to run
4-1/2" screen liner. Load 4-1/2" blank liner joints into the pipe shed.;M/U 4-1/2" shoe joint w/ WIV & pack-off. Run 4-1/2" Hydril 625 13.5# L-80 Halliburton
250u screen liner w/ 7.25" O.D. 5 blade stabilizer mid-joint to 650'. Torque to 9600 ft/lbs with Doyon double stack tongs.;Run 4-1/2" Hydril 625 13.5# L-80
Halliburton 250u screen liner w/ 7.25" O.D. 5 blade stabilizer mid-joint f/ 650' t/ 9400'. Torque to 9600 ft/lbs with Doyon double stack tongs. 111K PU / 87K SO
at shoe (6627') 125K PU / 77K SO. Measured 2.8' of pipe stretch.;41 bbls lost while running liner - avg 3.25 bbl/hr.;Mobilize 2-3/8" equipment to the rig floor.
Set 4-1/2" liner in slips (compression) & install false rotary table. R/D 4-1/2" tongs & R/U 2-3/8" tongs. Reconfigure safety joint w/ 2-3/8" XO sub. Install 2-3/8"
elevators.;P/U Baker slick stick assembly to 22'. Run 2-3/8" 4.7# Hydril 503 tubing inner string f/ 22' t/ 2889', joint #94 of 306. Torque to 1,800 ft/lbs with Doyon
double stack tongs. 7.8 bbls losses, 1.56 bph avg. Sim-ops: Load 5" HWDP in the pipe shed & process.;58 bbls daily (midnight) losses, 1069.4 bbls
cumulative losses.;Hauled 140 bbls H2O from L-Pad for total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 467 bbls to MPU G&I cuttings/mud/cement for total = 34,100 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/22/2020 Run 2-3/8" 4.7# Hydril 503 tubing inner string f/ 2889' t/ 3072' (joint #100). 50K PU / 50K SO. R/D false rotary table, M/U triple connect & break string over at
140K, no overpull. 135K PU / 90K SO. R/D triple connect & R/U false rotary table.;Run 2-3/8" 4.7# Hydril 503 tubing inner string f/ 3072' t/ 6141' (joint #200).
60K PU / 50K SO. Torque to 1,800 ft/lbs with Doyon double stack tongs.;R/D false rotary table, M/U triple connect & break string over at 145K, 5K overpull.
140K PU / 95K SO. R/D triple connect & R/U false rotary table.;Run 2-3/8" 4.7# Hydril 503 tubing inner string f/ 6141' t/ 9385' (joint #306). 60K PU / 50K SO.
Torque to 1,800 ft/lbs with Doyon double stack tongs. No-go on pack-off at 9384.96', set 10K down. Measured 2.52' stretch. Calculate need 9.53' pup joint,
utilize 10.16' pup. 6.37' off no-go.;41.5 bbls lost while running inner string, 2.2 bph average losses.;R/D false rotary table, M/U triple connect & break string
over at 148K, 8K overpull. 140K PU / 90K SO. R/D triple connect & R/U false rotary table.;P/U 9-5/8" x 4-1/2" SLZXP liner top packer. M/U swivel, Hydro-trip
sub, 10.16' EUE pup joint & XO subs to inner string. M/U 4-1/2" Hydril 625 connection. RIH f/ 9400' t/ 9440' 140K PU / 90 SO. RIH w/ liner on 2 jts of 5" HWDP
to 9501'.;Obtain parameters: 2 BPM = 720 PSI, 2.5 BPM = 980, 3.0 BPM = 1280 PSI. 15 RPM, 8K TQ, 100K ROT / 140K PU / 90K SO. Blow down top
drive.;Clear rig floor of casing equipment.;Run 4-1/2" screen liner completion on 5" HWDP singles from the pipe shed f/ 9501' t/ 12737' @ 30'/min. Slack off
weight increased from 90K to 120K. Fill pipe on the fly and top off every 5 stands. 4.5 bbl/hr loss rate, 29.1 bbls lost while running HWDP.;67.5 bbls daily
(midnight) losses, 1136.9 bbls cumulative losses.;Hauled 140 bbls H2O from L-Pad for total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 57 bbls to MPU G&I cuttings/mud/cement for total = 34,157 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/23/2020 Continue to P/U 5'' Dp F/ 9625' T/ 13585'. Fault #2. Hard set down. Stage up pumps to 2 bpm at 800 psi. No over pull up. 280K/ 120K DN. Attempt to work
through with no success. ROT at 8K tq. Slight rotation. While ROT loosing dn wt and transfer. Shut down ROT. Continue working pipe through.;Work pipe
down with full set downs at 2 bpm. F/ 13600' T/ 14822'. Getting less and less movement down. Free pipe coming up. circ at 2 bpm 850 psi. ROT at 8K TQ but
not helping. Free up wt at 260K. 74.2 bbls total lost while running HWDP.;Continue to try and work pipe down. Not making hole. Work pipe up to 14775'
attempting to get down movement. Pipe wont go back down. Work pipe down to 14778'. Cant get past. Pumping 4% lube mud through liner with no help.
Decision mad from town to set liner. 3.25 bph losses.;Prep for SAP brine displacement. L/D single for space out. Continue to work pipe down with no down
movement. Free pick up wt at 260. Work pipe from 14778' to 14767', 8' of stretch observed before free up movement. Grease IBOP & swivel packing. 3.25
bph losses.;Park string at 14767' with tool joint clear of slip area. Pump at 2.5 bpm, 1420 psi. Pump 30 bbl high vis spacer & SAPP treatment (three 20 bbl
SAPP pills separated by 50 bbls seawater). Pump 30 bbl high vis spacer followed by 305 bbls seawater.;Pump 30 bbl high vis spacer followed by 9.8 ppg 2%
KCl/NaCl brine, 2.7 bpm, 1580 PSI. SAPP brought back minimal to no wall cake. 8.8 ppg @ 14700 stks, 9.0 @ 14900 stks, 9.2 @ 15100 stks, 9.3 @ 15300
stks. Losses during displacement will be on tomorrow's report after truck manifests are tallied.;Daily (midnight) losses = 64 bbls, cumulative losses = 1200.9
bbls.;Hauled 0 bbls H2O from L-Pad for total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 860 bbls to MPU G&I cuttings/mud/cement for total = 35,017 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/24/2020 Continue displacing to clean 9.8 ppg brine. Pump total of 1620 brine. 9.5+ returning to surface.;Drop 1.25 setting ball. Pump down with 35 bbl high vis sweep.
Chase with 75 bbl and bump on seat. Pressure up to 3000 psi. Saw packer set at 2100 psi. Bleed down and set down to 90K. Hold and pressure up to 4300
psi & shear off packer. Bleed down to 0. P/U to ensure free with 225 up wt.;4-1/2" lower completion screen liner set at 14,767' / TOL at 5338.73'.;Close top
rams and test annulus to 1500 psi for 10 min. Had to bleed down and pump up sensor. Got a good solid test. Pull out of pack off with 400 psi & circ 320 bbl
9.8 brine. 3 liner volumes. Good 9.6+ back. Monitor well. Static. Lost 90 bbl while displacing.;L/D 5'' HWDP F/ 17767' T/ 9410'. L/D liner running tool.
Loosing 10-15 BPH while L/D HWDP. Filling hole with 9.6 ppg Fluid. 105 bbl lost while laying down HWDP. 19 bph avg.;Monitor well - 14 BPH losses. M/U 2-
3/8" safety joint. Mobilize & R/U 2-3/8" power tongs. L/D Baker liner running tool - looks good. C/O elevators to 2-3/8". L/D Baker swivel & hydro trip to 9361'.
M/U XO to safety joint. Filling hole with 9.6 ppg fluid. 20 bph loss avg.;POOH laying down 2-3/8" inner string f/ 9361' t/ 1025'. Filling hole with 9.6 ppg fluid. 123
bbls lost while laying down pipe. 11.7 bph avg.;Daily (midnight) losses = 275 bbls, Cumulative losses = 1475.90 bbls.;Hauled 0 bbls H2O from L-Pad for
total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 1834 bbls to MPU G&I cuttings/mud/cement for total = 35,991 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
Activity Date Ops Summary
4/25/2020 Continue to L/D 2.375" Hydril 503 inner string f/ 1025' t/ 22'. L/D Baker slick stick assembly f/ 22'. L/D 2.375" handling equipment & clear rig floor.,Pull wear
bushing. Perform dummy run with 7" hanger and mark landing joint. L/D hanger and re-install wear bushing.,TIH w/ 3-1/2" perforated stringer w/ 8.25" O.D. no-go
on 5" drill pipe from the derrick to 5281'. Wash down w/ 590 GPM, 170 PSI f/ 5281' t/ 5340', tag liner top w/ 5K & observe pressure increase f/ 170 to 220
PSI.,Pump sweep to flush liner tie-back w/ 600 GPM, 200 PSI, 10 RPM, 3K TQ then circulate casing clean above liner top. Sweep 200 strokes late w/ no
increase.,Displace well to new 9.6 ppg 2% KCl/NaCl brine. 130K PU / 105K SO / 110K ROT. Monitor well, slight flow decreasing to 1 bbl in 5 min, .05 bbl in 10
min. L/D double f/ 5340' t/ 5315', B/D top drive, monitor well - level falling.,POOH laying down 5" drill pipe f/ 5315' t/ 15'. L/D 3-1/2" perforated joint w/ no-go and
XO. 46 bbls lost, 7 bph avg.,Pull split bushings, install master bushings, pull wear bushing and break down 2-3/8" safety joint. R/U 7" handling tools - slips,
elevators, double stack tongs and XO to FOSV.,PJSM. P/U Baker bullet seal assy w/ 8.26" O.D. locator to 15'. Run 7" 26# L-80 TXP-BTC liner f/ 15' t/ 5285'
Torque to 14,750 ft/lbs with Doyon double stack tongs. Perform kick while tripping drill: 75 sec. well secure, 118 sec. all res ponded. 51 bbls lost while running
liner, 8.5 bph avg.,Daily (midnight) losses = 235 bbls, production cumulative losses = 1710.9 bbls,Hauled 0 bbls H2O from L-Pad for total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 499 bbls to MPU G&I cuttings/mud/cement for total = 36,490 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/26/2020 P/U Casing F/ 5285' T/ 5351'. Tag on joint # 132. Tag no go on depth. L/D three joints and place 4 space out pups under joint # 130. M/U casing hanger, RIH &
land hanger. UP/DN 140/110. Close annular. Pressure up on annulus to 300 psi and P/U until ports open and pressure dumps.,PJSM- Pump and Spot
Corrosion inhibited brine 89 bbl 9.6 PPG, Pump 72 bbl freeze protect diesel to 2500' while reversing circulating. Final circ pressure at 330 PSI @ 4 bpm. Strip
through annular and close ports land hanger 1.33' off no-go.,Bleed off back side and flow check. Both sides went static. Blow down surface lines to cuttings tank
and pumps. Drain stack and blow down to cuttings tank also. Took 1 hr for 7'' casing to go static. Charged formation due to rev circulating. L/D 7'' landing joint,
Break all Rig floor circ equipment down. Change handling equipment to 5''.,P/U 5'' joint and M/U pack off running tool and pack off. Run pack off as per
weallhead rep with annulus open. Set down TD . Verify in place and its good. Test void to 5000 psi for 10 min. Good.,RILD. Test back side with diesel to 1000
PSI for 30 min. on chart - good. test Bleed down. Blow down all lines from pump to cuttings box.,R/U to run 4.5 jet pump completion with Baker Tec wire. Hang
sheave for wire in derrick. R/U Doyon tubing tongs. Prep pipe shed for running. 10.5 bph losses.,PJSM. M/U WLEG, Halliburton XN nipple / AHR packer
assembly, X nipple and Centrilift gauge, sliding sleeve & gauge carrier to 89'. Torque to 6170 ft/lbs with Doyon double stack tongs. 10.5 bph losses.,Install TEC
wire and gauge. Initially clamped gauge to pup joint. Verify schematic then move gauge to gauge carrier. Test gauges - good test. 10.5 bph losses.,Run 4-1/2"
12.6# L-80 TXP-BTC tubing f/ 89' t/ 5266'. Torque to 6170 ft/lbs with Doyon double stack tongs. Test TEC wire every 30 joints. Installed 72 cross coupler
Cannon clamps (2 on pup joints above gauges, 1 ea first 10 joints then every other joint). 68 bbls total losses running tubing.,P/U 5.84' & 4.84' pups for space
out and run joint #129 to 5318'. M/U FMC 11"x4.5" tubing hanger & install BPV. M/U 4.5" TC-II landing joint. Perform hanger penetration with TEC wire. Obtain
final readings: 1796.2 & 1798.14 PSI / 68.2° & 67.9°. Drain stack, blow down choke & kill lines. Land tubing on hanger - 95 PU / 72K SO, 32K on hanger. RILD &
L/D landing joint.,Clear rig floor of casing equipment and TEC wire spool.,L/D trip nipple and 90' mousehole extension. Remove kill line & N/D BOP stack.,Rig
ULSD in gallons: 0 rec'd, 857 used, 9173 on hand.
Daily (midnight) losses = 191.1 bbls, Cumulative losses for production lateral = 1902 bbls,Hauled 0 bbls H2O from L-Pad for total = 26,535 bbls
Hauled 0 bbls Source Water from G&I for total = 875 bbls
Hauled 97 bbls to MPU G&I cuttings/mud/cement for total = 36,587 bbls
Hauled 0 bbls to Kuparuk 1B cuttings/mud/cement for total = 58 bbls
4/27/2020 N/D BOP stack, remove 13-5/8"x11" adapter spool then set stack back on stump.,De-energize highline power, disconnect & remove cable to allow access
behind rig. N/U tubing head adapter flange, perform Centrilift penetrations & terminate - final readings tubing: 1175 PSI, 70.5°, annulus 1176 PSI, 70.4°. Install
test dart in BPV. N/U 5M FMC production tree.,Test tubing hanger void to 500 PSI for 5 min / 5000 PSI for 10 min - good tests. Install IA 4" wing valve. R/U test
equipment, test tree to 250/5000 PSI for 5 min each - good tests. R/D test equipment. Wellhead rep pull TWC.,R/U equipment to pump diesel freeze protection.
Fluid pack lines. Pressure test to 500 PSI - good, 1800 PSI - good, 3500 PSI - held briefly then bleeding off. Motor man immediately announced injection line
leak in generator room. Bleed off pressure & drain line to returns tank. 2 gallons diesel leaked to floor in generator room & pipe shed. Notify day DSM, Milne
security and Moose pad operator.,Wipe up leaked diesel with absorbent as per Milne ACS tech. Hold safety meeting with all parties. Reviewed incident. Good
response by motor man notification and rig crew making area safe and wiping up leak. Discussed procedural change to pressure test with fresh water when
possible. Isolate injection line from pump to pits & formulate plan to use cement line instead.,Rig up circulating lines to utilize cement line for diesel freeze
protection and injection line from cellar to mud pits for returns PJSM and verify equipment line up, communication and responsibilities.,Reverse circulate 85 bbls
of diesel freeze protection down IA with returns up the tubing to the mud pits. 2 BPM, 190 PSI initial circulating, slowed to 1.5 BPM, 480 PSI final circulating.
Shut in annulus & tubing. 46 bbls lost while circulating.,Rig up lines to u-tube annulus to the tubing. 350 PSI on IA. Begin u-tube at 23:34. At 00:30 monitor
pressure: 30 PSI differential, 150 PSI on tubing, 180 PSI on IA. At 01:00 monitor pressure: appears static, 160 PSI on tubing, 160 PSI on IA.,Mobilize lubricator
extension to rig. Bleed diesel from tree. R/U extension on the tree. Place 1-7/8" ball with 2" roller rod on top of master valve Install tree cap on lubricator
extension. Open master valve & hear ball and rod drop. Close master valve, bleed pressure and drain lubricator extension. R/D extension & install tree
cap.,Pump down tubing to set packer (pinned to set at 2200 PSI), monitor pressure on IA. Charge mud pump with diesel from vac truck. Tubing pressure
climbing slower than expected vs. volume pumped. 250 PSI built up on IA then holding steady. Shut down at 810 PSI, holding, build to 850 PSI holding, build to
880 PSI holding, built to 1060 PSI. Stroke counter showed 25 bbls,. truck showed 1-2 bbls pumped. Pumping air.,Rig up Doyon test pump to tree to pump diesel
from rig tank. Pressure up on tubing to 3600 psi. Holding for 30 min. 4.5 X 7'' annulus pressure climbed to 400 psi and holding.,Daily (midnight) losses = 52 bbls,
Cumulative production hole losses = 1954 bbls.
Contractor
AFE #:
AFE $:
Job Name:2010894C MPU M-43 Completion
Spud Date:
Well Name:
Field:
County/State:
MP M-43
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
n (LAT/LONG):
evation (RKB):
API #:
4/28/2020 Attempt to pressure test tubing at 3700 psi. Bleeding down to the IA at 100 psi in 10 min. IA climbing. bump up Twice to 3700 & the final to 3900 psi. Verify and
final pressure on IA was 950. Bleed down both sided holding 160 on tubing.,Blow down lines and flush with fresh water. R/D u tube lines and all lines to MP.
Rig up Isolation valves and no possible communication at surface from the tubing to the IA. Re test tubing and IA to 3700 with same bleed down. Bleed
tubing to 1000 psi.,Decision made from town to perform a combo test on tubing & IA. Pressure up to 3700 psi & Hold 40 min. Lost 100 psi and no loss last 25
min. Good Packer test. Bleed down and hold 200 on tubing. Blow down lines. R/D same and secure tree. Release rig at 1600.,Prep & skid rig floor. Prep rig for
move. Crew eating dinner before rig move. Swap to M-44 at 1800.,Refer to MPU M-44 for remaining activities.
20 April, 2020
Milne Point
M Pt Moose Pad
MPU M-43
500292367100
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU M-43
usft
usft
0.00
0.00
6,027,889.70
534,053.89
25.10Wellhead Elevation:25.30 usft0.50
70° 29' 13.993 N
149° 43' 17.982 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU M-43
Model NameMagnetics
IFR 3/25/2020 16.00 80.92 57,390.00000000
Phase:Version:
Audit Notes:
Design MPU M-43
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:6,676.47
184.340.000.0033.68
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 4/20/2020
Survey Date
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa232.85 6,595.01 MPU M-43PB1 MWD+IFR2+MS+Sag (1) 03/08/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,676.47 6,676.47 MPU M-43PB1 MWD+IFR2+MS+Sag (2) 03/23/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,680.00 15,821.25 MPU M-43 MWD+IFR2+MS+Sag (5) (MP 04/08/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.68 0.00 0.00 33.68 0.00 0.00-25.30 6,027,889.70 534,053.89 0.00 0.00 UNDEFINED
232.85 0.85 43.56 232.84 1.07 1.02173.86 6,027,890.78 534,054.90 0.43 -1.14 3_MWD+IFR2+MS+Sag (1)
326.51 3.44 43.75 326.43 3.60 3.44267.45 6,027,893.32 534,057.31 2.77 -3.85 3_MWD+IFR2+MS+Sag (1)
420.19 5.33 42.87 419.83 8.82 8.34360.85 6,027,898.56 534,062.19 2.02 -9.43 3_MWD+IFR2+MS+Sag (1)
514.37 7.31 44.48 513.43 16.31 15.52454.45 6,027,906.07 534,069.33 2.11 -17.43 3_MWD+IFR2+MS+Sag (1)
607.82 9.71 53.60 605.85 25.23 26.03546.87 6,027,915.04 534,079.80 2.94 -27.12 3_MWD+IFR2+MS+Sag (1)
701.31 13.23 57.16 697.46 35.71 41.37638.48 6,027,925.59 534,095.09 3.84 -38.74 3_MWD+IFR2+MS+Sag (1)
797.05 15.98 59.39 790.10 48.36 61.92731.12 6,027,938.34 534,115.58 2.93 -52.91 3_MWD+IFR2+MS+Sag (1)
892.00 20.63 59.88 880.22 63.42 87.65821.24 6,027,953.51 534,141.24 4.90 -69.87 3_MWD+IFR2+MS+Sag (1)
988.12 24.59 66.98 968.95 79.75 120.72909.97 6,027,969.99 534,174.24 5.00 -88.65 3_MWD+IFR2+MS+Sag (1)
1,083.43 28.30 68.27 1,054.28 95.87 159.98995.30 6,027,986.29 534,213.41 3.94 -107.70 3_MWD+IFR2+MS+Sag (1)
1,178.68 32.24 67.28 1,136.52 114.05 204.401,077.54 6,028,004.68 534,257.75 4.17 -129.19 3_MWD+IFR2+MS+Sag (1)
4/20/2020 2:23:12PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
1,273.73 37.93 67.55 1,214.27 135.02 254.831,155.29 6,028,025.87 534,308.07 5.99 -153.91 3_MWD+IFR2+MS+Sag (1)
1,368.47 42.46 68.24 1,286.62 158.00 311.471,227.64 6,028,049.11 534,364.60 4.80 -181.12 3_MWD+IFR2+MS+Sag (1)
1,464.34 43.40 68.95 1,356.81 181.83 372.261,297.83 6,028,073.22 534,425.28 1.10 -209.48 3_MWD+IFR2+MS+Sag (1)
1,559.24 47.80 66.04 1,423.20 207.83 434.851,364.22 6,028,099.50 534,487.74 5.13 -240.14 3_MWD+IFR2+MS+Sag (1)
1,654.40 52.05 64.16 1,484.45 238.51 500.861,425.47 6,028,130.48 534,553.61 4.71 -275.73 3_MWD+IFR2+MS+Sag (1)
1,749.72 54.47 64.11 1,541.47 271.84 569.591,482.49 6,028,164.11 534,622.17 2.54 -314.16 3_MWD+IFR2+MS+Sag (1)
1,844.32 53.34 64.50 1,597.20 304.98 638.471,538.22 6,028,197.57 534,690.89 1.24 -352.42 3_MWD+IFR2+MS+Sag (1)
1,938.79 53.23 65.49 1,653.68 336.99 707.101,594.70 6,028,229.89 534,759.37 0.85 -389.53 3_MWD+IFR2+MS+Sag (1)
2,033.72 53.60 65.20 1,710.26 368.79 776.381,651.28 6,028,262.00 534,828.49 0.46 -426.48 3_MWD+IFR2+MS+Sag (1)
2,129.44 53.83 66.12 1,766.91 400.59 846.681,707.93 6,028,294.12 534,898.64 0.81 -463.51 3_MWD+IFR2+MS+Sag (1)
2,224.78 55.21 65.60 1,822.24 432.34 917.521,763.26 6,028,326.19 534,969.33 1.51 -500.53 3_MWD+IFR2+MS+Sag (1)
2,320.25 52.02 65.68 1,878.87 464.04 987.531,819.89 6,028,358.21 535,039.18 3.34 -537.44 3_MWD+IFR2+MS+Sag (1)
2,415.74 56.49 66.52 1,934.64 495.42 1,058.371,875.66 6,028,389.91 535,109.88 4.74 -574.09 3_MWD+IFR2+MS+Sag (1)
2,510.27 55.72 66.27 1,987.35 526.83 1,130.271,928.37 6,028,421.65 535,181.62 0.84 -610.86 3_MWD+IFR2+MS+Sag (1)
2,605.92 57.05 67.73 2,040.31 557.95 1,203.591,981.33 6,028,453.10 535,254.79 1.88 -647.43 3_MWD+IFR2+MS+Sag (1)
2,701.03 56.17 67.48 2,092.65 588.20 1,277.012,033.67 6,028,483.69 535,328.07 0.95 -683.15 3_MWD+IFR2+MS+Sag (1)
2,796.38 55.05 67.68 2,146.51 618.21 1,349.752,087.53 6,028,514.02 535,400.66 1.19 -718.58 3_MWD+IFR2+MS+Sag (1)
2,892.03 54.27 68.77 2,201.83 647.16 1,422.202,142.85 6,028,543.30 535,472.97 1.24 -752.93 3_MWD+IFR2+MS+Sag (1)
2,987.70 53.63 66.24 2,258.14 676.74 1,493.662,199.16 6,028,573.21 535,544.29 2.24 -787.83 3_MWD+IFR2+MS+Sag (1)
3,082.47 52.36 66.83 2,315.18 706.88 1,563.082,256.20 6,028,603.66 535,613.56 1.43 -823.14 3_MWD+IFR2+MS+Sag (1)
3,177.58 53.49 65.14 2,372.52 737.77 1,632.382,313.54 6,028,634.86 535,682.72 1.85 -859.18 3_MWD+IFR2+MS+Sag (1)
3,272.70 53.76 65.32 2,428.93 769.86 1,701.922,369.95 6,028,667.26 535,752.10 0.32 -896.44 3_MWD+IFR2+MS+Sag (1)
3,367.88 52.94 65.93 2,485.75 801.37 1,771.482,426.77 6,028,699.10 535,821.51 1.00 -933.13 3_MWD+IFR2+MS+Sag (1)
3,463.00 52.11 65.72 2,543.62 832.29 1,840.352,484.64 6,028,730.32 535,890.22 0.89 -969.17 3_MWD+IFR2+MS+Sag (1)
3,558.38 50.98 66.66 2,602.94 862.44 1,908.682,543.96 6,028,760.79 535,958.41 1.41 -1,004.41 3_MWD+IFR2+MS+Sag (1)
3,653.55 53.74 66.98 2,661.05 892.10 1,977.952,602.07 6,028,790.76 536,027.54 2.91 -1,039.22 3_MWD+IFR2+MS+Sag (1)
3,748.64 53.98 67.07 2,717.13 922.07 2,048.652,658.15 6,028,821.05 536,098.09 0.26 -1,074.46 3_MWD+IFR2+MS+Sag (1)
3,844.18 54.22 70.77 2,773.16 949.90 2,120.842,714.18 6,028,849.21 536,170.15 3.15 -1,107.67 3_MWD+IFR2+MS+Sag (1)
3,939.54 54.33 73.40 2,828.85 973.71 2,194.492,769.87 6,028,873.35 536,243.69 2.24 -1,136.98 3_MWD+IFR2+MS+Sag (1)
4,034.50 53.37 77.78 2,884.89 992.80 2,268.722,825.91 6,028,892.78 536,317.82 3.86 -1,161.64 3_MWD+IFR2+MS+Sag (1)
4,129.52 52.42 81.67 2,942.22 1,006.33 2,343.262,883.24 6,028,906.65 536,392.29 3.41 -1,180.77 3_MWD+IFR2+MS+Sag (1)
4,225.03 52.05 85.69 3,000.73 1,014.64 2,418.282,941.75 6,028,915.30 536,467.26 3.35 -1,194.74 3_MWD+IFR2+MS+Sag (1)
4,320.20 53.10 91.90 3,058.60 1,016.20 2,493.782,999.62 6,028,917.21 536,542.74 5.30 -1,202.00 3_MWD+IFR2+MS+Sag (1)
4,415.03 52.95 98.26 3,115.68 1,009.50 2,569.173,056.70 6,028,910.86 536,618.16 5.36 -1,201.03 3_MWD+IFR2+MS+Sag (1)
4,510.35 53.78 101.25 3,172.56 996.54 2,644.543,113.58 6,028,898.23 536,693.58 2.66 -1,193.80 3_MWD+IFR2+MS+Sag (1)
4,604.91 56.08 107.45 3,226.93 977.31 2,719.443,167.95 6,028,879.36 536,768.55 5.89 -1,180.30 3_MWD+IFR2+MS+Sag (1)
4,700.43 56.62 109.49 3,279.86 952.12 2,794.853,220.88 6,028,854.51 536,844.07 1.87 -1,160.89 3_MWD+IFR2+MS+Sag (1)
4,794.99 57.40 114.03 3,331.37 922.72 2,868.473,272.39 6,028,825.45 536,917.82 4.11 -1,137.14 3_MWD+IFR2+MS+Sag (1)
4,890.38 59.03 119.90 3,381.64 885.94 2,940.673,322.66 6,028,789.01 536,990.19 5.50 -1,105.94 3_MWD+IFR2+MS+Sag (1)
4,985.54 60.14 122.23 3,429.82 843.59 3,010.953,370.84 6,028,746.99 537,060.65 2.41 -1,069.03 3_MWD+IFR2+MS+Sag (1)
4/20/2020 2:23:12PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
5,080.87 63.33 127.94 3,474.99 795.32 3,079.583,416.01 6,028,699.03 537,129.49 6.25 -1,026.08 3_MWD+IFR2+MS+Sag (1)
5,176.09 64.98 131.31 3,516.51 740.66 3,145.553,457.53 6,028,644.68 537,195.71 3.63 -976.58 3_MWD+IFR2+MS+Sag (1)
5,271.73 66.75 135.63 3,555.63 680.62 3,208.863,496.65 6,028,584.94 537,259.28 4.52 -921.50 3_MWD+IFR2+MS+Sag (1)
5,367.19 68.65 138.86 3,591.85 615.77 3,268.793,532.87 6,028,520.37 537,319.50 3.71 -861.37 3_MWD+IFR2+MS+Sag (1)
5,461.71 68.86 141.67 3,626.11 548.03 3,325.103,567.13 6,028,452.90 537,376.11 2.78 -798.09 3_MWD+IFR2+MS+Sag (1)
5,557.41 69.52 146.30 3,660.13 475.70 3,377.673,601.15 6,028,380.81 537,429.02 4.57 -729.94 3_MWD+IFR2+MS+Sag (1)
5,652.21 71.83 150.47 3,691.51 399.53 3,424.533,632.53 6,028,304.86 537,476.22 4.81 -657.53 3_MWD+IFR2+MS+Sag (1)
5,747.33 74.70 154.51 3,718.91 318.75 3,466.573,659.93 6,028,224.29 537,518.62 5.06 -580.17 3_MWD+IFR2+MS+Sag (1)
5,842.50 76.75 158.65 3,742.38 234.14 3,503.213,683.40 6,028,139.85 537,555.64 4.73 -498.57 3_MWD+IFR2+MS+Sag (1)
5,935.68 79.50 159.53 3,761.55 148.97 3,535.743,702.57 6,028,054.84 537,588.57 3.09 -416.11 3_MWD+IFR2+MS+Sag (1)
6,033.37 84.27 163.19 3,775.34 57.36 3,566.623,716.36 6,027,963.39 537,619.86 6.13 -327.10 3_MWD+IFR2+MS+Sag (1)
6,128.60 83.79 166.98 3,785.25 -34.14 3,591.003,726.27 6,027,872.00 537,644.65 3.99 -237.71 3_MWD+IFR2+MS+Sag (1)
6,223.79 82.26 167.23 3,796.81 -126.24 3,612.083,737.83 6,027,780.01 537,666.16 1.63 -147.47 3_MWD+IFR2+MS+Sag (1)
6,318.93 83.84 167.28 3,808.32 -218.35 3,632.923,749.34 6,027,688.01 537,687.41 1.66 -57.20 3_MWD+IFR2+MS+Sag (1)
6,414.13 83.03 167.54 3,819.21 -310.65 3,653.533,760.23 6,027,595.81 537,708.45 0.89 33.28 3_MWD+IFR2+MS+Sag (1)
6,508.43 86.21 169.03 3,828.05 -402.57 3,672.593,769.07 6,027,503.99 537,727.92 3.72 123.49 3_MWD+IFR2+MS+Sag (1)
6,595.01 91.66 169.71 3,829.66 -487.61 3,688.553,770.68 6,027,419.03 537,744.27 6.34 207.09 3_MWD+IFR2+MS+Sag (1)
6,676.47 91.62 168.99 3,827.33 -567.64 3,703.603,768.35 6,027,339.08 537,759.68 0.88 285.74 3_MWD+IFR2+MS+Sag (2)
6,680.00 91.62 168.97 3,827.23 -571.10 3,704.273,768.25 6,027,335.62 537,760.37 0.57 289.14 3_MWD+IFR2+MS+Sag (3)
6,778.63 88.65 168.12 3,826.99 -667.75 3,723.863,768.01 6,027,239.07 537,780.40 3.13 384.04 3_MWD+IFR2+MS+Sag (3)
6,873.79 91.31 168.29 3,827.03 -760.90 3,743.313,768.05 6,027,146.02 537,800.27 2.80 475.44 3_MWD+IFR2+MS+Sag (3)
6,968.94 91.68 168.58 3,824.54 -854.08 3,762.383,765.56 6,027,052.94 537,819.77 0.49 566.92 3_MWD+IFR2+MS+Sag (3)
7,064.03 90.69 168.22 3,822.58 -947.21 3,781.493,763.60 6,026,959.91 537,839.31 1.11 658.33 3_MWD+IFR2+MS+Sag (3)
7,159.00 90.37 166.96 3,821.70 -1,039.96 3,801.903,762.72 6,026,867.27 537,860.14 1.37 749.26 3_MWD+IFR2+MS+Sag (3)
7,252.71 89.88 167.43 3,821.49 -1,131.33 3,822.673,762.51 6,026,775.99 537,881.32 0.72 838.81 3_MWD+IFR2+MS+Sag (3)
7,349.47 91.55 169.63 3,820.29 -1,226.14 3,841.913,761.31 6,026,681.28 537,900.99 2.85 931.89 3_MWD+IFR2+MS+Sag (3)
7,442.25 92.48 171.49 3,817.02 -1,317.61 3,857.123,758.04 6,026,589.90 537,916.62 2.24 1,021.94 3_MWD+IFR2+MS+Sag (3)
7,540.10 92.05 173.05 3,813.16 -1,414.49 3,870.273,754.18 6,026,493.09 537,930.21 1.65 1,117.55 3_MWD+IFR2+MS+Sag (3)
7,634.90 92.54 176.89 3,809.36 -1,508.83 3,878.573,750.38 6,026,398.79 537,938.95 4.08 1,210.99 3_MWD+IFR2+MS+Sag (3)
7,729.79 92.17 179.67 3,805.46 -1,603.59 3,881.423,746.48 6,026,304.06 537,942.22 2.95 1,305.26 3_MWD+IFR2+MS+Sag (3)
7,825.02 91.86 182.71 3,802.11 -1,698.73 3,879.443,743.13 6,026,208.92 537,940.68 3.21 1,400.28 3_MWD+IFR2+MS+Sag (3)
7,920.70 90.07 183.57 3,800.50 -1,794.24 3,874.203,741.52 6,026,113.39 537,935.88 2.08 1,495.92 3_MWD+IFR2+MS+Sag (3)
8,015.95 88.95 183.03 3,801.31 -1,889.33 3,868.723,742.33 6,026,018.29 537,930.84 1.31 1,591.15 3_MWD+IFR2+MS+Sag (3)
8,110.99 87.54 183.28 3,804.22 -1,984.18 3,863.493,745.24 6,025,923.43 537,926.04 1.51 1,686.12 3_MWD+IFR2+MS+Sag (3)
8,206.37 90.44 184.00 3,805.91 -2,079.34 3,857.433,746.93 6,025,828.25 537,920.42 3.13 1,781.47 3_MWD+IFR2+MS+Sag (3)
8,299.92 92.36 184.03 3,803.62 -2,172.63 3,850.893,744.64 6,025,734.94 537,914.30 2.05 1,874.99 3_MWD+IFR2+MS+Sag (3)
8,396.68 93.10 183.48 3,799.01 -2,269.07 3,844.563,740.03 6,025,638.48 537,908.42 0.95 1,971.63 3_MWD+IFR2+MS+Sag (3)
8,491.60 92.66 183.08 3,794.24 -2,363.72 3,839.133,735.26 6,025,543.82 537,903.43 0.63 2,066.41 3_MWD+IFR2+MS+Sag (3)
8,586.60 91.92 183.73 3,790.45 -2,458.47 3,833.503,731.47 6,025,449.05 537,898.22 1.04 2,161.32 3_MWD+IFR2+MS+Sag (3)
8,682.32 90.50 183.45 3,788.42 -2,553.98 3,827.503,729.44 6,025,353.52 537,892.67 1.51 2,257.01 3_MWD+IFR2+MS+Sag (3)
4/20/2020 2:23:12PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,776.08 90.99 183.45 3,787.21 -2,647.56 3,821.863,728.23 6,025,259.93 537,887.46 0.52 2,350.75 3_MWD+IFR2+MS+Sag (3)
8,871.62 91.86 183.88 3,784.83 -2,742.88 3,815.763,725.85 6,025,164.59 537,881.79 1.02 2,446.25 3_MWD+IFR2+MS+Sag (3)
8,966.98 91.86 183.77 3,781.73 -2,837.97 3,809.403,722.75 6,025,069.48 537,875.87 0.12 2,541.56 3_MWD+IFR2+MS+Sag (3)
9,062.04 92.42 184.21 3,778.18 -2,932.74 3,802.793,719.20 6,024,974.70 537,869.69 0.75 2,636.55 3_MWD+IFR2+MS+Sag (3)
9,158.51 92.97 185.43 3,773.65 -3,028.76 3,794.693,714.67 6,024,878.65 537,862.04 1.39 2,732.91 3_MWD+IFR2+MS+Sag (3)
9,253.73 91.80 183.81 3,769.69 -3,123.58 3,787.033,710.71 6,024,783.80 537,854.81 2.10 2,828.04 3_MWD+IFR2+MS+Sag (3)
9,348.71 90.99 180.17 3,767.37 -3,218.46 3,783.733,708.39 6,024,688.92 537,851.95 3.92 2,922.90 3_MWD+IFR2+MS+Sag (3)
9,443.44 92.97 182.93 3,764.10 -3,313.08 3,781.173,705.12 6,024,594.29 537,849.82 3.58 3,017.44 3_MWD+IFR2+MS+Sag (3)
9,538.56 92.91 181.84 3,759.22 -3,407.99 3,777.223,700.24 6,024,499.37 537,846.30 1.15 3,112.38 3_MWD+IFR2+MS+Sag (3)
9,634.21 92.23 180.26 3,754.93 -3,503.53 3,775.473,695.95 6,024,403.84 537,844.99 1.80 3,207.77 3_MWD+IFR2+MS+Sag (3)
9,728.41 91.61 177.55 3,751.77 -3,597.65 3,777.273,692.79 6,024,309.74 537,847.22 2.95 3,301.49 3_MWD+IFR2+MS+Sag (3)
9,823.66 91.36 178.35 3,749.31 -3,692.81 3,780.683,690.33 6,024,214.61 537,851.06 0.88 3,396.11 3_MWD+IFR2+MS+Sag (3)
9,918.87 91.67 179.28 3,746.79 -3,787.96 3,782.643,687.81 6,024,119.47 537,853.47 1.03 3,490.85 3_MWD+IFR2+MS+Sag (3)
10,013.94 93.03 181.46 3,742.89 -3,882.94 3,782.033,683.91 6,024,024.50 537,853.29 2.70 3,585.60 3_MWD+IFR2+MS+Sag (3)
10,109.71 91.11 179.99 3,739.43 -3,978.63 3,780.823,680.45 6,023,928.81 537,852.52 2.52 3,681.11 3_MWD+IFR2+MS+Sag (3)
10,204.00 92.61 180.25 3,736.37 -4,072.87 3,780.623,677.39 6,023,834.58 537,852.75 1.61 3,775.09 3_MWD+IFR2+MS+Sag (3)
10,299.88 89.07 180.97 3,734.97 -4,168.72 3,779.603,675.99 6,023,738.74 537,852.17 3.77 3,870.74 3_MWD+IFR2+MS+Sag (3)
10,395.57 88.65 179.70 3,736.87 -4,264.39 3,779.043,677.89 6,023,643.08 537,852.05 1.40 3,966.18 3_MWD+IFR2+MS+Sag (3)
10,490.69 90.57 179.80 3,737.52 -4,359.50 3,779.463,678.54 6,023,547.98 537,852.90 2.02 4,060.99 3_MWD+IFR2+MS+Sag (3)
10,586.32 93.41 180.78 3,734.20 -4,455.06 3,778.983,675.22 6,023,452.43 537,852.85 3.14 4,156.31 3_MWD+IFR2+MS+Sag (3)
10,681.27 93.66 181.55 3,728.34 -4,549.81 3,777.053,669.36 6,023,357.68 537,851.36 0.85 4,250.93 3_MWD+IFR2+MS+Sag (3)
10,776.80 92.29 180.52 3,723.38 -4,645.19 3,775.333,664.40 6,023,262.30 537,850.07 1.79 4,346.17 3_MWD+IFR2+MS+Sag (3)
10,870.44 91.61 180.92 3,720.20 -4,738.77 3,774.153,661.22 6,023,168.73 537,849.33 0.84 4,439.57 3_MWD+IFR2+MS+Sag (3)
10,962.92 90.19 179.70 3,718.74 -4,831.23 3,773.653,659.76 6,023,076.27 537,849.25 2.02 4,531.81 3_MWD+IFR2+MS+Sag (3)
11,062.76 91.86 182.55 3,716.96 -4,931.02 3,771.693,657.98 6,022,976.49 537,847.75 3.31 4,631.46 3_MWD+IFR2+MS+Sag (3)
11,157.09 91.43 183.43 3,714.25 -5,025.18 3,766.773,655.27 6,022,882.31 537,843.26 1.04 4,725.72 3_MWD+IFR2+MS+Sag (3)
11,252.41 90.19 183.23 3,712.90 -5,120.33 3,761.243,653.92 6,022,787.15 537,838.16 1.32 4,821.02 3_MWD+IFR2+MS+Sag (3)
11,347.17 91.30 184.91 3,711.67 -5,214.84 3,754.513,652.69 6,022,692.62 537,831.87 2.12 4,915.76 3_MWD+IFR2+MS+Sag (3)
11,442.46 92.17 186.44 3,708.79 -5,309.61 3,745.103,649.81 6,022,597.81 537,822.89 1.85 5,010.98 3_MWD+IFR2+MS+Sag (3)
11,537.80 91.11 185.47 3,706.06 -5,404.40 3,735.213,647.08 6,022,502.99 537,813.44 1.51 5,106.24 3_MWD+IFR2+MS+Sag (3)
11,632.16 90.87 184.61 3,704.43 -5,498.38 3,726.923,645.45 6,022,408.98 537,805.58 0.95 5,200.58 3_MWD+IFR2+MS+Sag (3)
11,727.62 90.87 183.31 3,702.98 -5,593.60 3,720.333,644.00 6,022,313.75 537,799.42 1.36 5,296.02 3_MWD+IFR2+MS+Sag (3)
11,823.32 90.99 183.58 3,701.42 -5,689.11 3,714.583,642.44 6,022,218.22 537,794.11 0.31 5,391.70 3_MWD+IFR2+MS+Sag (3)
11,918.12 90.93 184.30 3,699.84 -5,783.67 3,708.073,640.86 6,022,123.63 537,788.03 0.76 5,486.48 3_MWD+IFR2+MS+Sag (3)
12,013.86 89.95 186.91 3,699.10 -5,878.94 3,698.723,640.12 6,022,028.33 537,779.12 2.91 5,582.19 3_MWD+IFR2+MS+Sag (3)
12,109.01 88.40 187.59 3,700.47 -5,973.32 3,686.713,641.49 6,021,933.91 537,767.55 1.78 5,677.20 3_MWD+IFR2+MS+Sag (3)
12,202.65 91.13 188.43 3,700.85 -6,066.04 3,673.663,641.87 6,021,841.15 537,754.93 3.05 5,770.64 3_MWD+IFR2+MS+Sag (3)
12,296.91 95.58 188.21 3,695.34 -6,159.12 3,660.053,636.36 6,021,748.01 537,741.74 4.73 5,864.49 3_MWD+IFR2+MS+Sag (3)
12,393.63 93.77 186.30 3,687.46 -6,254.74 3,647.883,628.48 6,021,652.35 537,730.01 2.72 5,960.75 3_MWD+IFR2+MS+Sag (3)
12,490.01 92.48 184.49 3,682.20 -6,350.54 3,638.833,623.22 6,021,556.51 537,721.40 2.30 6,056.97 3_MWD+IFR2+MS+Sag (3)
4/20/2020 2:23:12PM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,585.25 92.66 183.40 3,677.93 -6,445.46 3,632.293,618.95 6,021,461.57 537,715.29 1.16 6,152.11 3_MWD+IFR2+MS+Sag (3)
12,681.08 90.81 183.36 3,675.03 -6,541.08 3,626.643,616.05 6,021,365.94 537,710.08 1.93 6,247.87 3_MWD+IFR2+MS+Sag (3)
12,776.22 93.10 184.62 3,671.78 -6,635.92 3,620.023,612.80 6,021,271.08 537,703.90 2.75 6,342.95 3_MWD+IFR2+MS+Sag (3)
12,872.10 91.36 184.39 3,668.05 -6,731.43 3,612.503,609.07 6,021,175.54 537,696.82 1.83 6,438.75 3_MWD+IFR2+MS+Sag (3)
12,967.67 91.68 183.36 3,665.52 -6,826.75 3,606.043,606.54 6,021,080.21 537,690.80 1.13 6,534.28 3_MWD+IFR2+MS+Sag (3)
13,062.87 91.86 183.68 3,662.58 -6,921.72 3,600.203,603.60 6,020,985.22 537,685.39 0.39 6,629.43 3_MWD+IFR2+MS+Sag (3)
13,157.86 92.42 183.23 3,659.03 -7,016.47 3,594.483,600.05 6,020,890.45 537,680.10 0.76 6,724.34 3_MWD+IFR2+MS+Sag (3)
13,253.27 92.73 185.95 3,654.74 -7,111.47 3,586.853,595.76 6,020,795.43 537,672.91 2.87 6,819.64 3_MWD+IFR2+MS+Sag (3)
13,346.73 92.35 186.39 3,650.60 -7,204.30 3,576.823,591.62 6,020,702.56 537,663.30 0.62 6,912.96 3_MWD+IFR2+MS+Sag (3)
13,443.41 91.61 183.98 3,647.26 -7,300.52 3,568.093,588.28 6,020,606.32 537,655.01 2.61 7,009.57 3_MWD+IFR2+MS+Sag (3)
13,538.91 92.73 183.46 3,643.64 -7,395.75 3,561.903,584.66 6,020,511.07 537,649.26 1.29 7,104.99 3_MWD+IFR2+MS+Sag (3)
13,633.80 94.90 183.35 3,637.33 -7,490.25 3,556.273,578.35 6,020,416.55 537,644.07 2.29 7,199.65 3_MWD+IFR2+MS+Sag (3)
13,729.03 95.58 183.82 3,628.63 -7,584.90 3,550.343,569.65 6,020,321.88 537,638.57 0.87 7,294.48 3_MWD+IFR2+MS+Sag (3)
13,824.83 93.90 184.07 3,620.72 -7,680.14 3,543.783,561.74 6,020,226.62 537,632.44 1.77 7,389.94 3_MWD+IFR2+MS+Sag (3)
13,920.49 92.66 184.70 3,615.24 -7,775.36 3,536.473,556.26 6,020,131.38 537,625.58 1.45 7,485.44 3_MWD+IFR2+MS+Sag (3)
14,014.69 93.34 184.86 3,610.31 -7,869.11 3,528.633,551.33 6,020,037.61 537,618.17 0.74 7,579.51 3_MWD+IFR2+MS+Sag (3)
14,110.83 92.10 182.94 3,605.75 -7,964.91 3,522.103,546.77 6,019,941.79 537,612.08 2.38 7,675.53 3_MWD+IFR2+MS+Sag (3)
14,206.45 92.48 183.28 3,601.93 -8,060.31 3,516.923,542.95 6,019,846.37 537,607.33 0.53 7,771.06 3_MWD+IFR2+MS+Sag (3)
14,301.50 92.97 182.86 3,597.41 -8,155.12 3,511.843,538.43 6,019,751.55 537,602.68 0.68 7,865.97 3_MWD+IFR2+MS+Sag (3)
14,396.37 92.48 183.23 3,592.90 -8,249.75 3,506.803,533.92 6,019,656.91 537,598.08 0.65 7,960.71 3_MWD+IFR2+MS+Sag (3)
14,491.81 90.13 186.27 3,590.73 -8,344.82 3,498.903,531.75 6,019,561.82 537,590.62 4.03 8,056.11 3_MWD+IFR2+MS+Sag (3)
14,587.61 89.14 187.77 3,591.34 -8,439.89 3,487.193,532.36 6,019,466.70 537,579.35 1.88 8,151.80 3_MWD+IFR2+MS+Sag (3)
14,683.23 90.69 186.53 3,591.48 -8,534.76 3,475.293,532.50 6,019,371.78 537,567.88 2.08 8,247.30 3_MWD+IFR2+MS+Sag (3)
14,779.23 93.97 186.65 3,587.58 -8,630.04 3,464.293,528.60 6,019,276.47 537,557.31 3.42 8,343.13 3_MWD+IFR2+MS+Sag (3)
14,874.44 93.97 189.21 3,580.99 -8,724.10 3,451.183,522.01 6,019,182.35 537,544.64 2.68 8,437.92 3_MWD+IFR2+MS+Sag (3)
14,966.92 92.17 189.64 3,576.03 -8,815.20 3,436.063,517.05 6,019,091.20 537,529.94 2.00 8,529.90 3_MWD+IFR2+MS+Sag (3)
15,061.64 92.66 188.61 3,572.04 -8,908.64 3,421.053,513.06 6,018,997.70 537,515.36 1.20 8,624.20 3_MWD+IFR2+MS+Sag (3)
15,158.33 92.11 189.95 3,568.02 -9,003.97 3,405.473,509.04 6,018,902.30 537,500.22 1.50 8,720.45 3_MWD+IFR2+MS+Sag (3)
15,254.10 92.23 187.23 3,564.39 -9,098.59 3,391.183,505.41 6,018,807.63 537,486.36 2.84 8,815.88 3_MWD+IFR2+MS+Sag (3)
15,349.01 92.35 185.53 3,560.60 -9,192.84 3,380.643,501.62 6,018,713.35 537,476.25 1.79 8,910.65 3_MWD+IFR2+MS+Sag (3)
15,443.83 92.79 182.93 3,556.35 -9,287.29 3,373.663,497.37 6,018,618.87 537,469.70 2.78 9,005.36 3_MWD+IFR2+MS+Sag (3)
15,539.06 90.56 180.69 3,553.56 -9,382.42 3,370.653,494.58 6,018,523.73 537,467.13 3.32 9,100.45 3_MWD+IFR2+MS+Sag (3)
15,633.81 91.68 179.88 3,551.71 -9,477.15 3,370.183,492.73 6,018,429.01 537,467.09 1.46 9,194.94 3_MWD+IFR2+MS+Sag (3)
15,729.50 91.92 180.10 3,548.70 -9,572.80 3,370.203,489.72 6,018,333.38 537,467.55 0.34 9,290.31 3_MWD+IFR2+MS+Sag (3)
15,821.25 91.92 180.18 3,545.63 -9,664.49 3,369.973,486.65 6,018,241.69 537,467.74 0.09 9,381.76 3_MWD+IFR2+MS+Sag (3)
15,890.00 91.92 180.18 3,543.33 -9,733.21 3,369.763,484.35 6,018,172.99 537,467.84 0.00 9,450.29 PROJECTED to TD
Approved By:Checked By:Date:
4/20/2020 2:23:12PM COMPASS 5000.15 Build 91E Page 6
Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2020.04.20 11:55:07 -08'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.04.21 10:23:36 -08'00'
01 April, 2020
Milne Point
M Pt Moose Pad
MPU M-43PB1
500292367170
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB1 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB1 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU M-43
usft
usft
0.00
0.00
6,027,889.70
534,053.89
25.10Wellhead Elevation:25.30 usft0.50
70° 29' 13.993 N
149° 43' 17.982 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU M-43PB1
Model NameMagnetics
BGGM2019 3/25/2020 16.08 80.89 57,391.94198178
Phase:Version:
Audit Notes:
Design MPU M-43PB1
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:33.68
184.340.000.0033.68
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 3/26/2020
Survey Date
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa232.85 6,595.01 MPU M-43PB1 MWD+IFR2+MS+Sag (1) 03/08/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,676.47 12,929.46 MPU M-43PB1 MWD+IFR2+MS+Sag (2) 03/23/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.68 0.00 0.00 33.68 0.00 0.00-25.30 6,027,889.70 534,053.89 0.00 0.00 UNDEFINED
232.85 0.85 43.56 232.84 1.07 1.02173.86 6,027,890.78 534,054.90 0.43 -1.14 3_MWD+IFR2+MS+Sag (1)
326.51 3.44 43.75 326.43 3.60 3.44267.45 6,027,893.32 534,057.31 2.77 -3.85 3_MWD+IFR2+MS+Sag (1)
420.19 5.33 42.87 419.83 8.82 8.34360.85 6,027,898.56 534,062.19 2.02 -9.43 3_MWD+IFR2+MS+Sag (1)
514.37 7.31 44.48 513.43 16.31 15.52454.45 6,027,906.07 534,069.33 2.11 -17.43 3_MWD+IFR2+MS+Sag (1)
607.82 9.71 53.60 605.85 25.23 26.03546.87 6,027,915.04 534,079.80 2.94 -27.12 3_MWD+IFR2+MS+Sag (1)
701.31 13.23 57.16 697.46 35.71 41.37638.48 6,027,925.59 534,095.09 3.84 -38.74 3_MWD+IFR2+MS+Sag (1)
797.05 15.98 59.39 790.10 48.36 61.92731.12 6,027,938.34 534,115.58 2.93 -52.91 3_MWD+IFR2+MS+Sag (1)
892.00 20.63 59.88 880.22 63.42 87.65821.24 6,027,953.51 534,141.24 4.90 -69.87 3_MWD+IFR2+MS+Sag (1)
988.12 24.59 66.98 968.95 79.75 120.72909.97 6,027,969.99 534,174.24 5.00 -88.65 3_MWD+IFR2+MS+Sag (1)
1,083.43 28.30 68.27 1,054.28 95.87 159.98995.30 6,027,986.29 534,213.41 3.94 -107.70 3_MWD+IFR2+MS+Sag (1)
1,178.68 32.24 67.28 1,136.52 114.05 204.401,077.54 6,028,004.68 534,257.75 4.17 -129.19 3_MWD+IFR2+MS+Sag (1)
1,273.73 37.93 67.55 1,214.27 135.02 254.831,155.29 6,028,025.87 534,308.07 5.99 -153.91 3_MWD+IFR2+MS+Sag (1)
4/1/2020 1:24:49PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB1 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB1 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
1,368.47 42.46 68.24 1,286.62 158.00 311.471,227.64 6,028,049.11 534,364.60 4.80 -181.12 3_MWD+IFR2+MS+Sag (1)
1,464.34 43.40 68.95 1,356.81 181.83 372.261,297.83 6,028,073.22 534,425.28 1.10 -209.48 3_MWD+IFR2+MS+Sag (1)
1,559.24 47.80 66.04 1,423.20 207.83 434.851,364.22 6,028,099.50 534,487.74 5.13 -240.14 3_MWD+IFR2+MS+Sag (1)
1,654.40 52.05 64.16 1,484.45 238.51 500.861,425.47 6,028,130.48 534,553.61 4.71 -275.73 3_MWD+IFR2+MS+Sag (1)
1,749.72 54.47 64.11 1,541.47 271.84 569.591,482.49 6,028,164.11 534,622.17 2.54 -314.16 3_MWD+IFR2+MS+Sag (1)
1,844.32 53.34 64.50 1,597.20 304.98 638.471,538.22 6,028,197.57 534,690.89 1.24 -352.42 3_MWD+IFR2+MS+Sag (1)
1,938.79 53.23 65.49 1,653.68 336.99 707.101,594.70 6,028,229.89 534,759.37 0.85 -389.53 3_MWD+IFR2+MS+Sag (1)
2,033.72 53.60 65.20 1,710.26 368.79 776.381,651.28 6,028,262.00 534,828.49 0.46 -426.48 3_MWD+IFR2+MS+Sag (1)
2,129.44 53.83 66.12 1,766.91 400.59 846.681,707.93 6,028,294.12 534,898.64 0.81 -463.51 3_MWD+IFR2+MS+Sag (1)
2,224.78 55.21 65.60 1,822.24 432.34 917.521,763.26 6,028,326.19 534,969.33 1.51 -500.53 3_MWD+IFR2+MS+Sag (1)
2,320.25 52.02 65.68 1,878.87 464.04 987.531,819.89 6,028,358.21 535,039.18 3.34 -537.44 3_MWD+IFR2+MS+Sag (1)
2,415.74 56.49 66.52 1,934.64 495.42 1,058.371,875.66 6,028,389.91 535,109.88 4.74 -574.09 3_MWD+IFR2+MS+Sag (1)
2,510.27 55.72 66.27 1,987.35 526.83 1,130.271,928.37 6,028,421.65 535,181.62 0.84 -610.86 3_MWD+IFR2+MS+Sag (1)
2,605.92 57.05 67.73 2,040.31 557.95 1,203.591,981.33 6,028,453.10 535,254.79 1.88 -647.43 3_MWD+IFR2+MS+Sag (1)
2,701.03 56.17 67.48 2,092.65 588.20 1,277.012,033.67 6,028,483.69 535,328.07 0.95 -683.15 3_MWD+IFR2+MS+Sag (1)
2,796.38 55.05 67.68 2,146.51 618.21 1,349.752,087.53 6,028,514.02 535,400.66 1.19 -718.58 3_MWD+IFR2+MS+Sag (1)
2,892.03 54.27 68.77 2,201.83 647.16 1,422.202,142.85 6,028,543.30 535,472.97 1.24 -752.93 3_MWD+IFR2+MS+Sag (1)
2,987.70 53.63 66.24 2,258.14 676.74 1,493.662,199.16 6,028,573.21 535,544.29 2.24 -787.83 3_MWD+IFR2+MS+Sag (1)
3,082.47 52.36 66.83 2,315.18 706.88 1,563.082,256.20 6,028,603.66 535,613.56 1.43 -823.14 3_MWD+IFR2+MS+Sag (1)
3,177.58 53.49 65.14 2,372.52 737.77 1,632.382,313.54 6,028,634.86 535,682.72 1.85 -859.18 3_MWD+IFR2+MS+Sag (1)
3,272.70 53.76 65.32 2,428.93 769.86 1,701.922,369.95 6,028,667.26 535,752.10 0.32 -896.44 3_MWD+IFR2+MS+Sag (1)
3,367.88 52.94 65.93 2,485.75 801.37 1,771.482,426.77 6,028,699.10 535,821.51 1.00 -933.13 3_MWD+IFR2+MS+Sag (1)
3,463.00 52.11 65.72 2,543.62 832.29 1,840.352,484.64 6,028,730.32 535,890.22 0.89 -969.17 3_MWD+IFR2+MS+Sag (1)
3,558.38 50.98 66.66 2,602.94 862.44 1,908.682,543.96 6,028,760.79 535,958.41 1.41 -1,004.41 3_MWD+IFR2+MS+Sag (1)
3,653.55 53.74 66.98 2,661.05 892.10 1,977.952,602.07 6,028,790.76 536,027.54 2.91 -1,039.22 3_MWD+IFR2+MS+Sag (1)
3,748.64 53.98 67.07 2,717.13 922.07 2,048.652,658.15 6,028,821.05 536,098.09 0.26 -1,074.46 3_MWD+IFR2+MS+Sag (1)
3,844.18 54.22 70.77 2,773.16 949.90 2,120.842,714.18 6,028,849.21 536,170.15 3.15 -1,107.67 3_MWD+IFR2+MS+Sag (1)
3,939.54 54.33 73.40 2,828.85 973.71 2,194.492,769.87 6,028,873.35 536,243.69 2.24 -1,136.98 3_MWD+IFR2+MS+Sag (1)
4,034.50 53.37 77.78 2,884.89 992.80 2,268.722,825.91 6,028,892.78 536,317.82 3.86 -1,161.64 3_MWD+IFR2+MS+Sag (1)
4,129.52 52.42 81.67 2,942.22 1,006.33 2,343.262,883.24 6,028,906.65 536,392.29 3.41 -1,180.77 3_MWD+IFR2+MS+Sag (1)
4,225.03 52.05 85.69 3,000.73 1,014.64 2,418.282,941.75 6,028,915.30 536,467.26 3.35 -1,194.74 3_MWD+IFR2+MS+Sag (1)
4,320.20 53.10 91.90 3,058.60 1,016.20 2,493.782,999.62 6,028,917.21 536,542.74 5.30 -1,202.00 3_MWD+IFR2+MS+Sag (1)
4,415.03 52.95 98.26 3,115.68 1,009.50 2,569.173,056.70 6,028,910.86 536,618.16 5.36 -1,201.03 3_MWD+IFR2+MS+Sag (1)
4,510.35 53.78 101.25 3,172.56 996.54 2,644.543,113.58 6,028,898.23 536,693.58 2.66 -1,193.80 3_MWD+IFR2+MS+Sag (1)
4,604.91 56.08 107.45 3,226.93 977.31 2,719.443,167.95 6,028,879.36 536,768.55 5.89 -1,180.30 3_MWD+IFR2+MS+Sag (1)
4,700.43 56.62 109.49 3,279.86 952.12 2,794.853,220.88 6,028,854.51 536,844.07 1.87 -1,160.89 3_MWD+IFR2+MS+Sag (1)
4,794.99 57.40 114.03 3,331.37 922.72 2,868.473,272.39 6,028,825.45 536,917.82 4.11 -1,137.14 3_MWD+IFR2+MS+Sag (1)
4,890.38 59.03 119.90 3,381.64 885.94 2,940.673,322.66 6,028,789.01 536,990.19 5.50 -1,105.94 3_MWD+IFR2+MS+Sag (1)
4,985.54 60.14 122.23 3,429.82 843.59 3,010.953,370.84 6,028,746.99 537,060.65 2.41 -1,069.03 3_MWD+IFR2+MS+Sag (1)
5,080.87 63.33 127.94 3,474.99 795.32 3,079.583,416.01 6,028,699.03 537,129.49 6.25 -1,026.08 3_MWD+IFR2+MS+Sag (1)
4/1/2020 1:24:49PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB1 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB1 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
5,176.09 64.98 131.31 3,516.51 740.66 3,145.553,457.53 6,028,644.68 537,195.71 3.63 -976.58 3_MWD+IFR2+MS+Sag (1)
5,271.73 66.75 135.63 3,555.63 680.62 3,208.863,496.65 6,028,584.94 537,259.28 4.52 -921.50 3_MWD+IFR2+MS+Sag (1)
5,367.19 68.65 138.86 3,591.85 615.77 3,268.793,532.87 6,028,520.37 537,319.50 3.71 -861.37 3_MWD+IFR2+MS+Sag (1)
5,461.71 68.86 141.67 3,626.11 548.03 3,325.103,567.13 6,028,452.90 537,376.11 2.78 -798.09 3_MWD+IFR2+MS+Sag (1)
5,557.41 69.52 146.30 3,660.13 475.70 3,377.673,601.15 6,028,380.81 537,429.02 4.57 -729.94 3_MWD+IFR2+MS+Sag (1)
5,652.21 71.83 150.47 3,691.51 399.53 3,424.533,632.53 6,028,304.86 537,476.22 4.81 -657.53 3_MWD+IFR2+MS+Sag (1)
5,747.33 74.70 154.51 3,718.91 318.75 3,466.573,659.93 6,028,224.29 537,518.62 5.06 -580.17 3_MWD+IFR2+MS+Sag (1)
5,842.50 76.75 158.65 3,742.38 234.14 3,503.213,683.40 6,028,139.85 537,555.64 4.73 -498.57 3_MWD+IFR2+MS+Sag (1)
5,935.68 79.50 159.53 3,761.55 148.97 3,535.743,702.57 6,028,054.84 537,588.57 3.09 -416.11 3_MWD+IFR2+MS+Sag (1)
6,033.37 84.27 163.19 3,775.34 57.36 3,566.623,716.36 6,027,963.39 537,619.86 6.13 -327.10 3_MWD+IFR2+MS+Sag (1)
6,128.60 83.79 166.98 3,785.25 -34.14 3,591.003,726.27 6,027,872.00 537,644.65 3.99 -237.71 3_MWD+IFR2+MS+Sag (1)
6,223.79 82.26 167.23 3,796.81 -126.24 3,612.083,737.83 6,027,780.01 537,666.16 1.63 -147.47 3_MWD+IFR2+MS+Sag (1)
6,318.93 83.84 167.28 3,808.32 -218.35 3,632.923,749.34 6,027,688.01 537,687.41 1.66 -57.20 3_MWD+IFR2+MS+Sag (1)
6,414.13 83.03 167.54 3,819.21 -310.65 3,653.533,760.23 6,027,595.81 537,708.45 0.89 33.28 3_MWD+IFR2+MS+Sag (1)
6,508.43 86.21 169.03 3,828.05 -402.57 3,672.593,769.07 6,027,503.99 537,727.92 3.72 123.49 3_MWD+IFR2+MS+Sag (1)
6,595.01 91.66 169.71 3,829.66 -487.61 3,688.553,770.68 6,027,419.03 537,744.27 6.34 207.09 3_MWD+IFR2+MS+Sag (1)
6,676.47 91.62 168.99 3,827.33 -567.64 3,703.603,768.35 6,027,339.08 537,759.68 0.88 285.74 3_MWD+IFR2+MS+Sag (2)
6,772.52 91.56 168.46 3,824.66 -661.80 3,722.373,765.68 6,027,245.02 537,778.88 0.56 378.21 3_MWD+IFR2+MS+Sag (2)
6,867.05 90.94 169.78 3,822.60 -754.60 3,740.213,763.62 6,027,152.30 537,797.15 1.54 469.40 3_MWD+IFR2+MS+Sag (2)
6,962.65 88.03 168.00 3,823.46 -848.39 3,758.633,764.48 6,027,058.61 537,815.99 3.57 561.53 3_MWD+IFR2+MS+Sag (2)
7,057.94 88.22 169.40 3,826.58 -941.78 3,777.293,767.60 6,026,965.31 537,835.08 1.48 653.24 3_MWD+IFR2+MS+Sag (2)
7,153.21 90.32 173.99 3,827.79 -1,036.02 3,791.043,768.81 6,026,871.15 537,849.26 5.30 746.16 3_MWD+IFR2+MS+Sag (2)
7,248.24 89.89 176.42 3,827.62 -1,130.71 3,798.993,768.64 6,026,776.51 537,857.64 2.60 839.98 3_MWD+IFR2+MS+Sag (2)
7,341.79 89.45 176.08 3,828.15 -1,224.06 3,805.103,769.17 6,026,683.20 537,864.18 0.59 932.59 3_MWD+IFR2+MS+Sag (2)
7,431.30 90.38 174.54 3,828.29 -1,313.26 3,812.423,769.31 6,026,594.04 537,871.91 2.01 1,020.99 3_MWD+IFR2+MS+Sag (2)
7,530.76 89.21 174.67 3,828.64 -1,412.28 3,821.773,769.66 6,026,495.07 537,881.71 1.18 1,119.02 3_MWD+IFR2+MS+Sag (2)
7,627.01 89.58 174.55 3,829.66 -1,508.10 3,830.813,770.68 6,026,399.31 537,891.19 0.40 1,213.88 3_MWD+IFR2+MS+Sag (2)
7,716.50 89.27 174.63 3,830.56 -1,597.18 3,839.253,771.58 6,026,310.27 537,900.03 0.36 1,302.07 3_MWD+IFR2+MS+Sag (2)
7,816.00 89.45 175.42 3,831.67 -1,696.30 3,847.883,772.69 6,026,211.20 537,909.12 0.81 1,400.25 3_MWD+IFR2+MS+Sag (2)
7,914.30 90.20 177.33 3,831.97 -1,794.40 3,854.093,772.99 6,026,113.14 537,915.78 2.09 1,497.60 3_MWD+IFR2+MS+Sag (2)
8,009.71 90.81 178.73 3,831.13 -1,889.75 3,857.373,772.15 6,026,017.82 537,919.49 1.60 1,592.42 3_MWD+IFR2+MS+Sag (2)
8,105.07 90.81 179.90 3,829.78 -1,985.09 3,858.513,770.80 6,025,922.49 537,921.07 1.23 1,687.41 3_MWD+IFR2+MS+Sag (2)
8,200.56 92.24 181.15 3,827.24 -2,080.54 3,857.643,768.26 6,025,827.05 537,920.63 1.99 1,782.65 3_MWD+IFR2+MS+Sag (2)
8,295.60 91.86 181.39 3,823.84 -2,175.49 3,855.533,764.86 6,025,732.10 537,918.96 0.47 1,877.49 3_MWD+IFR2+MS+Sag (2)
8,391.16 91.00 182.35 3,821.45 -2,270.97 3,852.423,762.47 6,025,636.62 537,916.28 1.35 1,972.93 3_MWD+IFR2+MS+Sag (2)
8,486.82 90.50 183.27 3,820.20 -2,366.51 3,847.733,761.22 6,025,541.07 537,912.03 1.09 2,068.54 3_MWD+IFR2+MS+Sag (2)
8,581.24 92.61 185.56 3,817.64 -2,460.60 3,840.463,758.66 6,025,446.95 537,905.20 3.30 2,162.92 3_MWD+IFR2+MS+Sag (2)
8,676.20 94.34 186.65 3,811.88 -2,554.84 3,830.383,752.90 6,025,352.67 537,895.55 2.15 2,257.65 3_MWD+IFR2+MS+Sag (2)
8,771.80 94.40 186.22 3,804.60 -2,649.56 3,819.703,745.62 6,025,257.91 537,885.30 0.45 2,352.91 3_MWD+IFR2+MS+Sag (2)
8,867.48 94.59 185.69 3,797.10 -2,744.43 3,809.803,738.12 6,025,163.01 537,875.84 0.59 2,448.26 3_MWD+IFR2+MS+Sag (2)
4/1/2020 1:24:49PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB1 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB1 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,962.85 93.90 184.08 3,790.04 -2,839.19 3,801.713,731.06 6,025,068.22 537,868.18 1.83 2,543.36 3_MWD+IFR2+MS+Sag (2)
9,057.41 93.41 182.81 3,784.01 -2,933.39 3,796.043,725.03 6,024,974.01 537,862.94 1.44 2,637.71 3_MWD+IFR2+MS+Sag (2)
9,152.73 93.28 182.81 3,778.45 -3,028.43 3,791.373,719.47 6,024,878.96 537,858.71 0.14 2,732.84 3_MWD+IFR2+MS+Sag (2)
9,247.31 92.29 183.72 3,773.85 -3,122.74 3,785.993,714.87 6,024,784.63 537,853.77 1.42 2,827.29 3_MWD+IFR2+MS+Sag (2)
9,343.79 91.99 184.24 3,770.25 -3,218.92 3,779.303,711.27 6,024,688.43 537,847.51 0.62 2,923.70 3_MWD+IFR2+MS+Sag (2)
9,438.14 93.41 185.51 3,765.81 -3,312.82 3,771.293,706.83 6,024,594.50 537,839.94 2.02 3,017.93 3_MWD+IFR2+MS+Sag (2)
9,532.97 91.55 185.74 3,761.70 -3,407.10 3,762.003,702.72 6,024,500.19 537,831.08 1.98 3,112.65 3_MWD+IFR2+MS+Sag (2)
9,627.18 93.16 186.06 3,757.83 -3,500.73 3,752.333,698.85 6,024,406.53 537,821.84 1.74 3,206.74 3_MWD+IFR2+MS+Sag (2)
9,723.53 92.54 185.07 3,753.04 -3,596.51 3,743.003,694.06 6,024,310.72 537,812.95 1.21 3,302.95 3_MWD+IFR2+MS+Sag (2)
9,818.55 91.24 184.10 3,749.91 -3,691.17 3,735.413,690.93 6,024,216.04 537,805.79 1.71 3,397.91 3_MWD+IFR2+MS+Sag (2)
9,914.64 90.01 182.63 3,748.86 -3,787.08 3,729.773,689.88 6,024,120.11 537,800.59 1.99 3,493.98 3_MWD+IFR2+MS+Sag (2)
10,008.43 89.33 183.69 3,749.40 -3,880.73 3,724.603,690.42 6,024,026.45 537,795.85 1.34 3,587.74 3_MWD+IFR2+MS+Sag (2)
10,102.82 89.02 184.13 3,750.76 -3,974.89 3,718.163,691.78 6,023,932.27 537,789.84 0.57 3,682.12 3_MWD+IFR2+MS+Sag (2)
10,198.49 89.64 183.66 3,751.88 -4,070.33 3,711.663,692.90 6,023,836.81 537,783.78 0.81 3,777.78 3_MWD+IFR2+MS+Sag (2)
10,294.43 90.32 183.21 3,751.91 -4,166.10 3,705.923,692.93 6,023,741.03 537,778.48 0.85 3,873.71 3_MWD+IFR2+MS+Sag (2)
10,389.47 90.69 182.89 3,751.07 -4,261.00 3,700.863,692.09 6,023,646.11 537,773.85 0.51 3,968.72 3_MWD+IFR2+MS+Sag (2)
10,484.46 89.76 182.83 3,750.70 -4,355.87 3,696.123,691.72 6,023,551.23 537,769.55 0.98 4,063.67 3_MWD+IFR2+MS+Sag (2)
10,578.35 89.45 182.72 3,751.35 -4,449.65 3,691.573,692.37 6,023,457.44 537,765.43 0.35 4,157.53 3_MWD+IFR2+MS+Sag (2)
10,674.32 90.69 184.06 3,751.23 -4,545.44 3,685.903,692.25 6,023,361.63 537,760.20 1.90 4,253.48 3_MWD+IFR2+MS+Sag (2)
10,769.82 92.42 185.75 3,748.64 -4,640.55 3,677.743,689.66 6,023,266.49 537,752.47 2.53 4,348.93 3_MWD+IFR2+MS+Sag (2)
10,865.03 92.24 185.94 3,744.77 -4,735.19 3,668.053,685.79 6,023,171.82 537,743.22 0.27 4,444.03 3_MWD+IFR2+MS+Sag (2)
10,959.71 91.43 185.85 3,741.74 -4,829.32 3,658.333,682.76 6,023,077.66 537,733.93 0.86 4,538.63 3_MWD+IFR2+MS+Sag (2)
11,054.55 92.54 186.59 3,738.45 -4,923.54 3,648.063,679.47 6,022,983.40 537,724.10 1.41 4,633.36 3_MWD+IFR2+MS+Sag (2)
11,150.41 92.42 186.40 3,734.30 -5,018.70 3,637.233,675.32 6,022,888.20 537,713.70 0.23 4,729.06 3_MWD+IFR2+MS+Sag (2)
11,245.41 92.54 185.55 3,730.19 -5,113.09 3,627.353,671.21 6,022,793.77 537,704.25 0.90 4,823.93 3_MWD+IFR2+MS+Sag (2)
11,340.23 91.12 181.92 3,727.16 -5,207.64 3,621.183,668.18 6,022,699.20 537,698.52 4.11 4,918.68 3_MWD+IFR2+MS+Sag (2)
11,436.01 91.25 179.75 3,725.18 -5,303.39 3,619.783,666.20 6,022,603.46 537,697.56 2.27 5,014.25 3_MWD+IFR2+MS+Sag (2)
11,531.22 92.11 179.97 3,722.39 -5,398.56 3,620.013,663.41 6,022,508.31 537,698.23 0.93 5,109.13 3_MWD+IFR2+MS+Sag (2)
11,627.00 94.40 181.73 3,716.95 -5,494.16 3,618.603,657.97 6,022,412.71 537,697.25 3.01 5,204.57 3_MWD+IFR2+MS+Sag (2)
11,721.95 93.90 181.49 3,710.08 -5,588.82 3,615.943,651.10 6,022,318.04 537,695.02 0.58 5,299.16 3_MWD+IFR2+MS+Sag (2)
11,816.53 92.97 181.92 3,704.42 -5,683.19 3,613.133,645.44 6,022,223.67 537,692.64 1.08 5,393.47 3_MWD+IFR2+MS+Sag (2)
11,912.61 93.66 182.50 3,698.86 -5,779.04 3,609.433,639.88 6,022,127.82 537,689.38 0.94 5,489.32 3_MWD+IFR2+MS+Sag (2)
12,007.64 94.09 182.47 3,692.44 -5,873.76 3,605.323,633.46 6,022,033.09 537,685.71 0.45 5,584.09 3_MWD+IFR2+MS+Sag (2)
12,102.64 90.31 182.51 3,688.79 -5,968.58 3,601.193,629.81 6,021,938.26 537,682.02 3.98 5,678.95 3_MWD+IFR2+MS+Sag (2)
12,197.52 90.51 183.49 3,688.11 -6,063.33 3,596.233,629.13 6,021,843.50 537,677.49 1.05 5,773.80 3_MWD+IFR2+MS+Sag (2)
12,293.30 90.38 184.20 3,687.37 -6,158.89 3,589.813,628.39 6,021,747.92 537,671.50 0.75 5,869.57 3_MWD+IFR2+MS+Sag (2)
12,388.73 87.66 184.03 3,689.00 -6,254.05 3,582.963,630.02 6,021,652.73 537,665.09 2.86 5,964.98 3_MWD+IFR2+MS+Sag (2)
12,483.78 86.98 183.12 3,693.45 -6,348.81 3,577.043,634.47 6,021,557.96 537,659.61 1.19 6,059.92 3_MWD+IFR2+MS+Sag (2)
12,579.05 85.93 182.19 3,699.34 -6,443.80 3,572.643,640.36 6,021,462.97 537,655.64 1.47 6,154.96 3_MWD+IFR2+MS+Sag (2)
12,675.67 86.74 181.96 3,705.51 -6,540.15 3,569.143,646.53 6,021,366.60 537,652.59 0.87 6,251.31 3_MWD+IFR2+MS+Sag (2)
4/1/2020 1:24:49PM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB1 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB1 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,768.87 86.43 182.17 3,711.06 -6,633.13 3,565.793,652.08 6,021,273.62 537,649.66 0.40 6,344.27 3_MWD+IFR2+MS+Sag (2)
12,864.07 83.95 182.23 3,719.05 -6,727.92 3,562.153,660.07 6,021,178.83 537,646.46 2.61 6,439.06 3_MWD+IFR2+MS+Sag (2)
12,929.46 82.24 182.41 3,726.91 -6,792.78 3,559.523,667.93 6,021,113.96 537,644.13 2.63 6,503.93 3_MWD+IFR2+MS+Sag (2)
13,000.00 82.24 182.41 3,736.43 -6,862.61 3,556.583,677.45 6,021,044.13 537,641.51 0.00 6,573.79 PROJECTED to TD
Approved By:Checked By:Date:
4/1/2020 1:24:49PM COMPASS 5000.15 Build 91E Page 6
Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2020.04.01 10:26:56 -08'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.04.01 14:02:07 -08'00'
01 April, 2020
Milne Point
M Pt Moose Pad
MPU M-43PB2
500292367171
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB2 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB2 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU M-43
usft
usft
0.00
0.00
6,027,889.70
534,053.89
25.10Wellhead Elevation:25.30 usft0.50
70° 29' 13.993 N
149° 43' 17.982 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU M-43PB2
Model NameMagnetics
BGGM2019 3/25/2020 16.08 80.89 57,391.94198178
Phase:Version:
Audit Notes:
Design MPU M-43PB2
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:11,912.61
184.340.000.0033.68
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 3/30/2020
Survey Date
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa232.85 6,595.01 MPU M-43PB1 MWD+IFR2+MS+Sag (1) 03/08/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,676.47 11,912.61 MPU M-43PB1 MWD+IFR2+MS+Sag (2) 03/23/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa11,950.00 15,499.30 MPU M-43PB2 MWD+IFR2+MS+Sag (3)03/26/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.68 0.00 0.00 33.68 0.00 0.00-25.30 6,027,889.70 534,053.89 0.00 0.00 UNDEFINED
232.85 0.85 43.56 232.84 1.07 1.02173.86 6,027,890.78 534,054.90 0.43 -1.14 3_MWD+IFR2+MS+Sag (1)
326.51 3.44 43.75 326.43 3.60 3.44267.45 6,027,893.32 534,057.31 2.77 -3.85 3_MWD+IFR2+MS+Sag (1)
420.19 5.33 42.87 419.83 8.82 8.34360.85 6,027,898.56 534,062.19 2.02 -9.43 3_MWD+IFR2+MS+Sag (1)
514.37 7.31 44.48 513.43 16.31 15.52454.45 6,027,906.07 534,069.33 2.11 -17.43 3_MWD+IFR2+MS+Sag (1)
607.82 9.71 53.60 605.85 25.23 26.03546.87 6,027,915.04 534,079.80 2.94 -27.12 3_MWD+IFR2+MS+Sag (1)
701.31 13.23 57.16 697.46 35.71 41.37638.48 6,027,925.59 534,095.09 3.84 -38.74 3_MWD+IFR2+MS+Sag (1)
797.05 15.98 59.39 790.10 48.36 61.92731.12 6,027,938.34 534,115.58 2.93 -52.91 3_MWD+IFR2+MS+Sag (1)
892.00 20.63 59.88 880.22 63.42 87.65821.24 6,027,953.51 534,141.24 4.90 -69.87 3_MWD+IFR2+MS+Sag (1)
988.12 24.59 66.98 968.95 79.75 120.72909.97 6,027,969.99 534,174.24 5.00 -88.65 3_MWD+IFR2+MS+Sag (1)
1,083.43 28.30 68.27 1,054.28 95.87 159.98995.30 6,027,986.29 534,213.41 3.94 -107.70 3_MWD+IFR2+MS+Sag (1)
1,178.68 32.24 67.28 1,136.52 114.05 204.401,077.54 6,028,004.68 534,257.75 4.17 -129.19 3_MWD+IFR2+MS+Sag (1)
4/1/2020 1:25:53PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB2 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB2 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
1,273.73 37.93 67.55 1,214.27 135.02 254.831,155.29 6,028,025.87 534,308.07 5.99 -153.91 3_MWD+IFR2+MS+Sag (1)
1,368.47 42.46 68.24 1,286.62 158.00 311.471,227.64 6,028,049.11 534,364.60 4.80 -181.12 3_MWD+IFR2+MS+Sag (1)
1,464.34 43.40 68.95 1,356.81 181.83 372.261,297.83 6,028,073.22 534,425.28 1.10 -209.48 3_MWD+IFR2+MS+Sag (1)
1,559.24 47.80 66.04 1,423.20 207.83 434.851,364.22 6,028,099.50 534,487.74 5.13 -240.14 3_MWD+IFR2+MS+Sag (1)
1,654.40 52.05 64.16 1,484.45 238.51 500.861,425.47 6,028,130.48 534,553.61 4.71 -275.73 3_MWD+IFR2+MS+Sag (1)
1,749.72 54.47 64.11 1,541.47 271.84 569.591,482.49 6,028,164.11 534,622.17 2.54 -314.16 3_MWD+IFR2+MS+Sag (1)
1,844.32 53.34 64.50 1,597.20 304.98 638.471,538.22 6,028,197.57 534,690.89 1.24 -352.42 3_MWD+IFR2+MS+Sag (1)
1,938.79 53.23 65.49 1,653.68 336.99 707.101,594.70 6,028,229.89 534,759.37 0.85 -389.53 3_MWD+IFR2+MS+Sag (1)
2,033.72 53.60 65.20 1,710.26 368.79 776.381,651.28 6,028,262.00 534,828.49 0.46 -426.48 3_MWD+IFR2+MS+Sag (1)
2,129.44 53.83 66.12 1,766.91 400.59 846.681,707.93 6,028,294.12 534,898.64 0.81 -463.51 3_MWD+IFR2+MS+Sag (1)
2,224.78 55.21 65.60 1,822.24 432.34 917.521,763.26 6,028,326.19 534,969.33 1.51 -500.53 3_MWD+IFR2+MS+Sag (1)
2,320.25 52.02 65.68 1,878.87 464.04 987.531,819.89 6,028,358.21 535,039.18 3.34 -537.44 3_MWD+IFR2+MS+Sag (1)
2,415.74 56.49 66.52 1,934.64 495.42 1,058.371,875.66 6,028,389.91 535,109.88 4.74 -574.09 3_MWD+IFR2+MS+Sag (1)
2,510.27 55.72 66.27 1,987.35 526.83 1,130.271,928.37 6,028,421.65 535,181.62 0.84 -610.86 3_MWD+IFR2+MS+Sag (1)
2,605.92 57.05 67.73 2,040.31 557.95 1,203.591,981.33 6,028,453.10 535,254.79 1.88 -647.43 3_MWD+IFR2+MS+Sag (1)
2,701.03 56.17 67.48 2,092.65 588.20 1,277.012,033.67 6,028,483.69 535,328.07 0.95 -683.15 3_MWD+IFR2+MS+Sag (1)
2,796.38 55.05 67.68 2,146.51 618.21 1,349.752,087.53 6,028,514.02 535,400.66 1.19 -718.58 3_MWD+IFR2+MS+Sag (1)
2,892.03 54.27 68.77 2,201.83 647.16 1,422.202,142.85 6,028,543.30 535,472.97 1.24 -752.93 3_MWD+IFR2+MS+Sag (1)
2,987.70 53.63 66.24 2,258.14 676.74 1,493.662,199.16 6,028,573.21 535,544.29 2.24 -787.83 3_MWD+IFR2+MS+Sag (1)
3,082.47 52.36 66.83 2,315.18 706.88 1,563.082,256.20 6,028,603.66 535,613.56 1.43 -823.14 3_MWD+IFR2+MS+Sag (1)
3,177.58 53.49 65.14 2,372.52 737.77 1,632.382,313.54 6,028,634.86 535,682.72 1.85 -859.18 3_MWD+IFR2+MS+Sag (1)
3,272.70 53.76 65.32 2,428.93 769.86 1,701.922,369.95 6,028,667.26 535,752.10 0.32 -896.44 3_MWD+IFR2+MS+Sag (1)
3,367.88 52.94 65.93 2,485.75 801.37 1,771.482,426.77 6,028,699.10 535,821.51 1.00 -933.13 3_MWD+IFR2+MS+Sag (1)
3,463.00 52.11 65.72 2,543.62 832.29 1,840.352,484.64 6,028,730.32 535,890.22 0.89 -969.17 3_MWD+IFR2+MS+Sag (1)
3,558.38 50.98 66.66 2,602.94 862.44 1,908.682,543.96 6,028,760.79 535,958.41 1.41 -1,004.41 3_MWD+IFR2+MS+Sag (1)
3,653.55 53.74 66.98 2,661.05 892.10 1,977.952,602.07 6,028,790.76 536,027.54 2.91 -1,039.22 3_MWD+IFR2+MS+Sag (1)
3,748.64 53.98 67.07 2,717.13 922.07 2,048.652,658.15 6,028,821.05 536,098.09 0.26 -1,074.46 3_MWD+IFR2+MS+Sag (1)
3,844.18 54.22 70.77 2,773.16 949.90 2,120.842,714.18 6,028,849.21 536,170.15 3.15 -1,107.67 3_MWD+IFR2+MS+Sag (1)
3,939.54 54.33 73.40 2,828.85 973.71 2,194.492,769.87 6,028,873.35 536,243.69 2.24 -1,136.98 3_MWD+IFR2+MS+Sag (1)
4,034.50 53.37 77.78 2,884.89 992.80 2,268.722,825.91 6,028,892.78 536,317.82 3.86 -1,161.64 3_MWD+IFR2+MS+Sag (1)
4,129.52 52.42 81.67 2,942.22 1,006.33 2,343.262,883.24 6,028,906.65 536,392.29 3.41 -1,180.77 3_MWD+IFR2+MS+Sag (1)
4,225.03 52.05 85.69 3,000.73 1,014.64 2,418.282,941.75 6,028,915.30 536,467.26 3.35 -1,194.74 3_MWD+IFR2+MS+Sag (1)
4,320.20 53.10 91.90 3,058.60 1,016.20 2,493.782,999.62 6,028,917.21 536,542.74 5.30 -1,202.00 3_MWD+IFR2+MS+Sag (1)
4,415.03 52.95 98.26 3,115.68 1,009.50 2,569.173,056.70 6,028,910.86 536,618.16 5.36 -1,201.03 3_MWD+IFR2+MS+Sag (1)
4,510.35 53.78 101.25 3,172.56 996.54 2,644.543,113.58 6,028,898.23 536,693.58 2.66 -1,193.80 3_MWD+IFR2+MS+Sag (1)
4,604.91 56.08 107.45 3,226.93 977.31 2,719.443,167.95 6,028,879.36 536,768.55 5.89 -1,180.30 3_MWD+IFR2+MS+Sag (1)
4,700.43 56.62 109.49 3,279.86 952.12 2,794.853,220.88 6,028,854.51 536,844.07 1.87 -1,160.89 3_MWD+IFR2+MS+Sag (1)
4,794.99 57.40 114.03 3,331.37 922.72 2,868.473,272.39 6,028,825.45 536,917.82 4.11 -1,137.14 3_MWD+IFR2+MS+Sag (1)
4,890.38 59.03 119.90 3,381.64 885.94 2,940.673,322.66 6,028,789.01 536,990.19 5.50 -1,105.94 3_MWD+IFR2+MS+Sag (1)
4,985.54 60.14 122.23 3,429.82 843.59 3,010.953,370.84 6,028,746.99 537,060.65 2.41 -1,069.03 3_MWD+IFR2+MS+Sag (1)
4/1/2020 1:25:53PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB2 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB2 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
5,080.87 63.33 127.94 3,474.99 795.32 3,079.583,416.01 6,028,699.03 537,129.49 6.25 -1,026.08 3_MWD+IFR2+MS+Sag (1)
5,176.09 64.98 131.31 3,516.51 740.66 3,145.553,457.53 6,028,644.68 537,195.71 3.63 -976.58 3_MWD+IFR2+MS+Sag (1)
5,271.73 66.75 135.63 3,555.63 680.62 3,208.863,496.65 6,028,584.94 537,259.28 4.52 -921.50 3_MWD+IFR2+MS+Sag (1)
5,367.19 68.65 138.86 3,591.85 615.77 3,268.793,532.87 6,028,520.37 537,319.50 3.71 -861.37 3_MWD+IFR2+MS+Sag (1)
5,461.71 68.86 141.67 3,626.11 548.03 3,325.103,567.13 6,028,452.90 537,376.11 2.78 -798.09 3_MWD+IFR2+MS+Sag (1)
5,557.41 69.52 146.30 3,660.13 475.70 3,377.673,601.15 6,028,380.81 537,429.02 4.57 -729.94 3_MWD+IFR2+MS+Sag (1)
5,652.21 71.83 150.47 3,691.51 399.53 3,424.533,632.53 6,028,304.86 537,476.22 4.81 -657.53 3_MWD+IFR2+MS+Sag (1)
5,747.33 74.70 154.51 3,718.91 318.75 3,466.573,659.93 6,028,224.29 537,518.62 5.06 -580.17 3_MWD+IFR2+MS+Sag (1)
5,842.50 76.75 158.65 3,742.38 234.14 3,503.213,683.40 6,028,139.85 537,555.64 4.73 -498.57 3_MWD+IFR2+MS+Sag (1)
5,935.68 79.50 159.53 3,761.55 148.97 3,535.743,702.57 6,028,054.84 537,588.57 3.09 -416.11 3_MWD+IFR2+MS+Sag (1)
6,033.37 84.27 163.19 3,775.34 57.36 3,566.623,716.36 6,027,963.39 537,619.86 6.13 -327.10 3_MWD+IFR2+MS+Sag (1)
6,128.60 83.79 166.98 3,785.25 -34.14 3,591.003,726.27 6,027,872.00 537,644.65 3.99 -237.71 3_MWD+IFR2+MS+Sag (1)
6,223.79 82.26 167.23 3,796.81 -126.24 3,612.083,737.83 6,027,780.01 537,666.16 1.63 -147.47 3_MWD+IFR2+MS+Sag (1)
6,318.93 83.84 167.28 3,808.32 -218.35 3,632.923,749.34 6,027,688.01 537,687.41 1.66 -57.20 3_MWD+IFR2+MS+Sag (1)
6,414.13 83.03 167.54 3,819.21 -310.65 3,653.533,760.23 6,027,595.81 537,708.45 0.89 33.28 3_MWD+IFR2+MS+Sag (1)
6,508.43 86.21 169.03 3,828.05 -402.57 3,672.593,769.07 6,027,503.99 537,727.92 3.72 123.49 3_MWD+IFR2+MS+Sag (1)
6,595.01 91.66 169.71 3,829.66 -487.61 3,688.553,770.68 6,027,419.03 537,744.27 6.34 207.09 3_MWD+IFR2+MS+Sag (1)
6,676.47 91.62 168.99 3,827.33 -567.64 3,703.603,768.35 6,027,339.08 537,759.68 0.88 285.74 3_MWD+IFR2+MS+Sag (2)
6,772.52 91.56 168.46 3,824.66 -661.80 3,722.373,765.68 6,027,245.02 537,778.88 0.56 378.21 3_MWD+IFR2+MS+Sag (2)
6,867.05 90.94 169.78 3,822.60 -754.60 3,740.213,763.62 6,027,152.30 537,797.15 1.54 469.40 3_MWD+IFR2+MS+Sag (2)
6,962.65 88.03 168.00 3,823.46 -848.39 3,758.633,764.48 6,027,058.61 537,815.99 3.57 561.53 3_MWD+IFR2+MS+Sag (2)
7,057.94 88.22 169.40 3,826.58 -941.78 3,777.293,767.60 6,026,965.31 537,835.08 1.48 653.24 3_MWD+IFR2+MS+Sag (2)
7,153.21 90.32 173.99 3,827.79 -1,036.02 3,791.043,768.81 6,026,871.15 537,849.26 5.30 746.16 3_MWD+IFR2+MS+Sag (2)
7,248.24 89.89 176.42 3,827.62 -1,130.71 3,798.993,768.64 6,026,776.51 537,857.64 2.60 839.98 3_MWD+IFR2+MS+Sag (2)
7,341.79 89.45 176.08 3,828.15 -1,224.06 3,805.103,769.17 6,026,683.20 537,864.18 0.59 932.59 3_MWD+IFR2+MS+Sag (2)
7,431.30 90.38 174.54 3,828.29 -1,313.26 3,812.423,769.31 6,026,594.04 537,871.91 2.01 1,020.99 3_MWD+IFR2+MS+Sag (2)
7,530.76 89.21 174.67 3,828.64 -1,412.28 3,821.773,769.66 6,026,495.07 537,881.71 1.18 1,119.02 3_MWD+IFR2+MS+Sag (2)
7,627.01 89.58 174.55 3,829.66 -1,508.10 3,830.813,770.68 6,026,399.31 537,891.19 0.40 1,213.88 3_MWD+IFR2+MS+Sag (2)
7,716.50 89.27 174.63 3,830.56 -1,597.18 3,839.253,771.58 6,026,310.27 537,900.03 0.36 1,302.07 3_MWD+IFR2+MS+Sag (2)
7,816.00 89.45 175.42 3,831.67 -1,696.30 3,847.883,772.69 6,026,211.20 537,909.12 0.81 1,400.25 3_MWD+IFR2+MS+Sag (2)
7,914.30 90.20 177.33 3,831.97 -1,794.40 3,854.093,772.99 6,026,113.14 537,915.78 2.09 1,497.60 3_MWD+IFR2+MS+Sag (2)
8,009.71 90.81 178.73 3,831.13 -1,889.75 3,857.373,772.15 6,026,017.82 537,919.49 1.60 1,592.42 3_MWD+IFR2+MS+Sag (2)
8,105.07 90.81 179.90 3,829.78 -1,985.09 3,858.513,770.80 6,025,922.49 537,921.07 1.23 1,687.41 3_MWD+IFR2+MS+Sag (2)
8,200.56 92.24 181.15 3,827.24 -2,080.54 3,857.643,768.26 6,025,827.05 537,920.63 1.99 1,782.65 3_MWD+IFR2+MS+Sag (2)
8,295.60 91.86 181.39 3,823.84 -2,175.49 3,855.533,764.86 6,025,732.10 537,918.96 0.47 1,877.49 3_MWD+IFR2+MS+Sag (2)
8,391.16 91.00 182.35 3,821.45 -2,270.97 3,852.423,762.47 6,025,636.62 537,916.28 1.35 1,972.93 3_MWD+IFR2+MS+Sag (2)
8,486.82 90.50 183.27 3,820.20 -2,366.51 3,847.733,761.22 6,025,541.07 537,912.03 1.09 2,068.54 3_MWD+IFR2+MS+Sag (2)
8,581.24 92.61 185.56 3,817.64 -2,460.60 3,840.463,758.66 6,025,446.95 537,905.20 3.30 2,162.92 3_MWD+IFR2+MS+Sag (2)
8,676.20 94.34 186.65 3,811.88 -2,554.84 3,830.383,752.90 6,025,352.67 537,895.55 2.15 2,257.65 3_MWD+IFR2+MS+Sag (2)
8,771.80 94.40 186.22 3,804.60 -2,649.56 3,819.703,745.62 6,025,257.91 537,885.30 0.45 2,352.91 3_MWD+IFR2+MS+Sag (2)
4/1/2020 1:25:53PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB2 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB2 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,867.48 94.59 185.69 3,797.10 -2,744.43 3,809.803,738.12 6,025,163.01 537,875.84 0.59 2,448.26 3_MWD+IFR2+MS+Sag (2)
8,962.85 93.90 184.08 3,790.04 -2,839.19 3,801.713,731.06 6,025,068.22 537,868.18 1.83 2,543.36 3_MWD+IFR2+MS+Sag (2)
9,057.41 93.41 182.81 3,784.01 -2,933.39 3,796.043,725.03 6,024,974.01 537,862.94 1.44 2,637.71 3_MWD+IFR2+MS+Sag (2)
9,152.73 93.28 182.81 3,778.45 -3,028.43 3,791.373,719.47 6,024,878.96 537,858.71 0.14 2,732.84 3_MWD+IFR2+MS+Sag (2)
9,247.31 92.29 183.72 3,773.85 -3,122.74 3,785.993,714.87 6,024,784.63 537,853.77 1.42 2,827.29 3_MWD+IFR2+MS+Sag (2)
9,343.79 91.99 184.24 3,770.25 -3,218.92 3,779.303,711.27 6,024,688.43 537,847.51 0.62 2,923.70 3_MWD+IFR2+MS+Sag (2)
9,438.14 93.41 185.51 3,765.81 -3,312.82 3,771.293,706.83 6,024,594.50 537,839.94 2.02 3,017.93 3_MWD+IFR2+MS+Sag (2)
9,532.97 91.55 185.74 3,761.70 -3,407.10 3,762.003,702.72 6,024,500.19 537,831.08 1.98 3,112.65 3_MWD+IFR2+MS+Sag (2)
9,627.18 93.16 186.06 3,757.83 -3,500.73 3,752.333,698.85 6,024,406.53 537,821.84 1.74 3,206.74 3_MWD+IFR2+MS+Sag (2)
9,723.53 92.54 185.07 3,753.04 -3,596.51 3,743.003,694.06 6,024,310.72 537,812.95 1.21 3,302.95 3_MWD+IFR2+MS+Sag (2)
9,818.55 91.24 184.10 3,749.91 -3,691.17 3,735.413,690.93 6,024,216.04 537,805.79 1.71 3,397.91 3_MWD+IFR2+MS+Sag (2)
9,914.64 90.01 182.63 3,748.86 -3,787.08 3,729.773,689.88 6,024,120.11 537,800.59 1.99 3,493.98 3_MWD+IFR2+MS+Sag (2)
10,008.43 89.33 183.69 3,749.40 -3,880.73 3,724.603,690.42 6,024,026.45 537,795.85 1.34 3,587.74 3_MWD+IFR2+MS+Sag (2)
10,102.82 89.02 184.13 3,750.76 -3,974.89 3,718.163,691.78 6,023,932.27 537,789.84 0.57 3,682.12 3_MWD+IFR2+MS+Sag (2)
10,198.49 89.64 183.66 3,751.88 -4,070.33 3,711.663,692.90 6,023,836.81 537,783.78 0.81 3,777.78 3_MWD+IFR2+MS+Sag (2)
10,294.43 90.32 183.21 3,751.91 -4,166.10 3,705.923,692.93 6,023,741.03 537,778.48 0.85 3,873.71 3_MWD+IFR2+MS+Sag (2)
10,389.47 90.69 182.89 3,751.07 -4,261.00 3,700.863,692.09 6,023,646.11 537,773.85 0.51 3,968.72 3_MWD+IFR2+MS+Sag (2)
10,484.46 89.76 182.83 3,750.70 -4,355.87 3,696.123,691.72 6,023,551.23 537,769.55 0.98 4,063.67 3_MWD+IFR2+MS+Sag (2)
10,578.35 89.45 182.72 3,751.35 -4,449.65 3,691.573,692.37 6,023,457.44 537,765.43 0.35 4,157.53 3_MWD+IFR2+MS+Sag (2)
10,674.32 90.69 184.06 3,751.23 -4,545.44 3,685.903,692.25 6,023,361.63 537,760.20 1.90 4,253.48 3_MWD+IFR2+MS+Sag (2)
10,769.82 92.42 185.75 3,748.64 -4,640.55 3,677.743,689.66 6,023,266.49 537,752.47 2.53 4,348.93 3_MWD+IFR2+MS+Sag (2)
10,865.03 92.24 185.94 3,744.77 -4,735.19 3,668.053,685.79 6,023,171.82 537,743.22 0.27 4,444.03 3_MWD+IFR2+MS+Sag (2)
10,959.71 91.43 185.85 3,741.74 -4,829.32 3,658.333,682.76 6,023,077.66 537,733.93 0.86 4,538.63 3_MWD+IFR2+MS+Sag (2)
11,054.55 92.54 186.59 3,738.45 -4,923.54 3,648.063,679.47 6,022,983.40 537,724.10 1.41 4,633.36 3_MWD+IFR2+MS+Sag (2)
11,150.41 92.42 186.40 3,734.30 -5,018.70 3,637.233,675.32 6,022,888.20 537,713.70 0.23 4,729.06 3_MWD+IFR2+MS+Sag (2)
11,245.41 92.54 185.55 3,730.19 -5,113.09 3,627.353,671.21 6,022,793.77 537,704.25 0.90 4,823.93 3_MWD+IFR2+MS+Sag (2)
11,340.23 91.12 181.92 3,727.16 -5,207.64 3,621.183,668.18 6,022,699.20 537,698.52 4.11 4,918.68 3_MWD+IFR2+MS+Sag (2)
11,436.01 91.25 179.75 3,725.18 -5,303.39 3,619.783,666.20 6,022,603.46 537,697.56 2.27 5,014.25 3_MWD+IFR2+MS+Sag (2)
11,531.22 92.11 179.97 3,722.39 -5,398.56 3,620.013,663.41 6,022,508.31 537,698.23 0.93 5,109.13 3_MWD+IFR2+MS+Sag (2)
11,627.00 94.40 181.73 3,716.95 -5,494.16 3,618.603,657.97 6,022,412.71 537,697.25 3.01 5,204.57 3_MWD+IFR2+MS+Sag (2)
11,721.95 93.90 181.49 3,710.08 -5,588.82 3,615.943,651.10 6,022,318.04 537,695.02 0.58 5,299.16 3_MWD+IFR2+MS+Sag (2)
11,816.53 92.97 181.92 3,704.42 -5,683.19 3,613.133,645.44 6,022,223.67 537,692.64 1.08 5,393.47 3_MWD+IFR2+MS+Sag (2)
11,912.61 93.66 182.50 3,698.86 -5,779.04 3,609.433,639.88 6,022,127.82 537,689.38 0.94 5,489.32 3_MWD+IFR2+MS+Sag (2)
11,950.00 93.83 182.49 3,696.42 -5,816.31 3,607.813,637.44 6,022,090.54 537,687.93 0.46 5,526.61 3_MWD+IFR2+MS+Sag (3)
12,007.92 92.05 182.95 3,693.45 -5,874.09 3,605.063,634.47 6,022,032.76 537,685.45 3.17 5,584.43 3_MWD+IFR2+MS+Sag (3)
12,102.92 91.24 185.43 3,690.72 -5,968.79 3,598.123,631.74 6,021,938.04 537,678.95 2.75 5,679.38 3_MWD+IFR2+MS+Sag (3)
12,197.87 91.43 187.63 3,688.51 -6,063.09 3,587.333,629.53 6,021,843.70 537,668.59 2.33 5,774.23 3_MWD+IFR2+MS+Sag (3)
12,293.01 92.54 187.87 3,685.21 -6,157.30 3,574.513,626.23 6,021,749.44 537,656.20 1.19 5,869.15 3_MWD+IFR2+MS+Sag (3)
12,388.63 92.36 187.07 3,681.12 -6,252.02 3,562.093,622.14 6,021,654.67 537,644.21 0.86 5,964.54 3_MWD+IFR2+MS+Sag (3)
12,482.93 91.43 186.05 3,678.01 -6,345.65 3,551.323,619.03 6,021,561.00 537,633.88 1.46 6,058.71 3_MWD+IFR2+MS+Sag (3)
4/1/2020 1:25:53PM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB2 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB2 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,578.44 92.61 185.05 3,674.64 -6,440.65 3,542.093,615.66 6,021,465.97 537,625.08 1.62 6,154.14 3_MWD+IFR2+MS+Sag (3)
12,673.94 91.98 184.17 3,670.81 -6,535.77 3,534.423,611.83 6,021,370.83 537,617.85 1.13 6,249.56 3_MWD+IFR2+MS+Sag (3)
12,769.35 91.93 183.99 3,667.56 -6,630.88 3,527.633,608.58 6,021,275.70 537,611.50 0.20 6,344.91 3_MWD+IFR2+MS+Sag (3)
12,864.21 92.17 185.02 3,664.17 -6,725.38 3,520.193,605.19 6,021,181.17 537,604.49 1.11 6,439.71 3_MWD+IFR2+MS+Sag (3)
12,959.65 91.86 185.36 3,660.81 -6,820.37 3,511.563,601.83 6,021,086.15 537,596.29 0.48 6,535.08 3_MWD+IFR2+MS+Sag (3)
13,054.55 91.92 184.90 3,657.68 -6,914.84 3,503.083,598.70 6,020,991.65 537,588.25 0.49 6,629.92 3_MWD+IFR2+MS+Sag (3)
13,150.44 91.49 184.59 3,654.83 -7,010.36 3,495.153,595.85 6,020,896.11 537,580.76 0.55 6,725.76 3_MWD+IFR2+MS+Sag (3)
13,244.60 92.61 184.37 3,651.46 -7,104.17 3,487.803,592.48 6,020,802.27 537,573.84 1.21 6,819.86 3_MWD+IFR2+MS+Sag (3)
13,340.28 90.81 184.67 3,648.60 -7,199.51 3,480.263,589.62 6,020,706.91 537,566.74 1.91 6,915.49 3_MWD+IFR2+MS+Sag (3)
13,435.10 92.30 184.48 3,646.03 -7,293.99 3,472.703,587.05 6,020,612.41 537,559.61 1.58 7,010.28 3_MWD+IFR2+MS+Sag (3)
13,530.58 91.43 184.66 3,642.92 -7,389.11 3,465.103,583.94 6,020,517.26 537,552.44 0.93 7,105.70 3_MWD+IFR2+MS+Sag (3)
13,625.36 93.10 183.16 3,639.18 -7,483.59 3,458.643,580.20 6,020,422.76 537,546.42 2.37 7,200.40 3_MWD+IFR2+MS+Sag (3)
13,720.38 92.48 183.30 3,634.55 -7,578.35 3,453.293,575.57 6,020,327.99 537,541.51 0.67 7,295.29 3_MWD+IFR2+MS+Sag (3)
13,815.52 95.58 183.36 3,627.87 -7,673.08 3,447.783,568.89 6,020,233.24 537,536.43 3.26 7,390.17 3_MWD+IFR2+MS+Sag (3)
13,911.81 93.53 184.09 3,620.22 -7,768.86 3,441.553,561.24 6,020,137.45 537,530.63 2.26 7,486.14 3_MWD+IFR2+MS+Sag (3)
14,007.19 92.04 184.79 3,615.59 -7,863.84 3,434.173,556.61 6,020,042.44 537,523.69 1.73 7,581.41 3_MWD+IFR2+MS+Sag (3)
14,102.13 93.72 184.68 3,610.82 -7,958.33 3,426.343,551.84 6,019,947.93 537,516.30 1.77 7,676.22 3_MWD+IFR2+MS+Sag (3)
14,198.07 90.99 184.64 3,606.87 -8,053.86 3,418.563,547.89 6,019,852.37 537,508.95 2.85 7,772.07 3_MWD+IFR2+MS+Sag (3)
14,292.69 92.79 183.66 3,603.75 -8,148.18 3,411.713,544.77 6,019,758.03 537,502.54 2.17 7,866.63 3_MWD+IFR2+MS+Sag (3)
14,386.67 92.91 181.82 3,599.08 -8,241.93 3,407.233,540.10 6,019,664.27 537,498.48 1.96 7,960.46 3_MWD+IFR2+MS+Sag (3)
14,483.72 90.07 180.72 3,596.56 -8,338.91 3,405.083,537.58 6,019,567.29 537,496.77 3.14 8,057.32 3_MWD+IFR2+MS+Sag (3)
14,579.08 85.43 181.25 3,600.30 -8,434.16 3,403.443,541.32 6,019,472.04 537,495.57 4.90 8,152.42 3_MWD+IFR2+MS+Sag (3)
14,674.01 84.19 182.28 3,608.89 -8,528.65 3,400.533,549.91 6,019,377.55 537,493.10 1.70 8,246.86 3_MWD+IFR2+MS+Sag (3)
14,769.85 85.56 183.51 3,617.45 -8,623.98 3,395.713,558.47 6,019,282.21 537,488.71 1.92 8,342.28 3_MWD+IFR2+MS+Sag (3)
14,864.36 88.16 184.59 3,622.63 -8,718.11 3,389.043,563.65 6,019,188.06 537,482.48 2.98 8,436.64 3_MWD+IFR2+MS+Sag (3)
14,960.13 89.09 184.42 3,624.92 -8,813.55 3,381.523,565.94 6,019,092.59 537,475.40 0.99 8,532.38 3_MWD+IFR2+MS+Sag (3)
15,054.83 88.78 183.38 3,626.68 -8,908.01 3,375.083,567.70 6,018,998.11 537,469.39 1.15 8,627.06 3_MWD+IFR2+MS+Sag (3)
15,149.08 85.55 182.37 3,631.35 -9,002.02 3,370.363,572.37 6,018,904.10 537,465.10 3.59 8,721.15 3_MWD+IFR2+MS+Sag (3)
15,244.13 84.32 182.68 3,639.74 -9,096.60 3,366.193,580.76 6,018,809.50 537,461.36 1.33 8,815.78 3_MWD+IFR2+MS+Sag (3)
15,340.15 85.63 183.09 3,648.15 -9,192.13 3,361.373,589.17 6,018,713.96 537,456.98 1.43 8,911.40 3_MWD+IFR2+MS+Sag (3)
15,435.68 84.26 183.03 3,656.56 -9,287.15 3,356.293,597.58 6,018,618.93 537,452.34 1.44 9,006.53 3_MWD+IFR2+MS+Sag (3)
15,499.30 84.20 182.34 3,662.96 -9,350.38 3,353.333,603.98 6,018,555.70 537,449.66 1.08 9,069.80 3_MWD+IFR2+MS+Sag (3)
15,570.00 84.20 182.34 3,670.10 -9,420.66 3,350.463,611.12 6,018,485.41 537,447.11 0.00 9,140.10 PROJECTED to TD
Approved By:Checked By:Date:
4/1/2020 1:25:53PM COMPASS 5000.15 Build 91E Page 6
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2020.04.01 10:28:48 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.04.01 13:57:49 -08'00'
20 April, 2020
Milne Point
M Pt Moose Pad
MPU M-43PB3
500292367172
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Milne Point, ACT, MILNE POINT
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
usft
+E/-W
+N/-S
Position Uncertainty
usft
usft
usftGround Level:
MPU M-43
usft
usft
0.00
0.00
6,027,889.70
534,053.89
25.10Wellhead Elevation:25.30 usft0.50
70° 29' 13.993 N
149° 43' 17.982 W
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MPU M-43PB3
Model NameMagnetics
BGGM2019 3/30/2020 16.07 80.89 57,391.23244398
Phase:Version:
Audit Notes:
Design MPU M-43PB3
1.0 ACTUAL
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:14,292.69
184.340.000.0033.68
From
(usft)
Survey Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 4/8/2020
Survey Date
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa232.85 6,595.01 MPU M-43PB1 MWD+IFR2+MS+Sag (1) 03/08/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa6,676.47 11,912.61 MPU M-43PB1 MWD+IFR2+MS+Sag (2) 03/23/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa11,950.00 14,292.69 MPU M-43PB2 MWD+IFR2+MS+Sag (3)03/26/2020
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sa14,300.00 15,808.80 MPU M-43PB3 MWD+IFR2+MS+Sag (4)03/30/2020
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
33.68 0.00 0.00 33.68 0.00 0.00-25.30 6,027,889.70 534,053.89 0.00 0.00 UNDEFINED
232.85 0.85 43.56 232.84 1.07 1.02173.86 6,027,890.78 534,054.90 0.43 -1.14 3_MWD+IFR2+MS+Sag (1)
326.51 3.44 43.75 326.43 3.60 3.44267.45 6,027,893.32 534,057.31 2.77 -3.85 3_MWD+IFR2+MS+Sag (1)
420.19 5.33 42.87 419.83 8.82 8.34360.85 6,027,898.56 534,062.19 2.02 -9.43 3_MWD+IFR2+MS+Sag (1)
514.37 7.31 44.48 513.43 16.31 15.52454.45 6,027,906.07 534,069.33 2.11 -17.43 3_MWD+IFR2+MS+Sag (1)
607.82 9.71 53.60 605.85 25.23 26.03546.87 6,027,915.04 534,079.80 2.94 -27.12 3_MWD+IFR2+MS+Sag (1)
701.31 13.23 57.16 697.46 35.71 41.37638.48 6,027,925.59 534,095.09 3.84 -38.74 3_MWD+IFR2+MS+Sag (1)
797.05 15.98 59.39 790.10 48.36 61.92731.12 6,027,938.34 534,115.58 2.93 -52.91 3_MWD+IFR2+MS+Sag (1)
892.00 20.63 59.88 880.22 63.42 87.65821.24 6,027,953.51 534,141.24 4.90 -69.87 3_MWD+IFR2+MS+Sag (1)
988.12 24.59 66.98 968.95 79.75 120.72909.97 6,027,969.99 534,174.24 5.00 -88.65 3_MWD+IFR2+MS+Sag (1)
1,083.43 28.30 68.27 1,054.28 95.87 159.98995.30 6,027,986.29 534,213.41 3.94 -107.70 3_MWD+IFR2+MS+Sag (1)
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 2
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
1,178.68 32.24 67.28 1,136.52 114.05 204.401,077.54 6,028,004.68 534,257.75 4.17 -129.19 3_MWD+IFR2+MS+Sag (1)
1,273.73 37.93 67.55 1,214.27 135.02 254.831,155.29 6,028,025.87 534,308.07 5.99 -153.91 3_MWD+IFR2+MS+Sag (1)
1,368.47 42.46 68.24 1,286.62 158.00 311.471,227.64 6,028,049.11 534,364.60 4.80 -181.12 3_MWD+IFR2+MS+Sag (1)
1,464.34 43.40 68.95 1,356.81 181.83 372.261,297.83 6,028,073.22 534,425.28 1.10 -209.48 3_MWD+IFR2+MS+Sag (1)
1,559.24 47.80 66.04 1,423.20 207.83 434.851,364.22 6,028,099.50 534,487.74 5.13 -240.14 3_MWD+IFR2+MS+Sag (1)
1,654.40 52.05 64.16 1,484.45 238.51 500.861,425.47 6,028,130.48 534,553.61 4.71 -275.73 3_MWD+IFR2+MS+Sag (1)
1,749.72 54.47 64.11 1,541.47 271.84 569.591,482.49 6,028,164.11 534,622.17 2.54 -314.16 3_MWD+IFR2+MS+Sag (1)
1,844.32 53.34 64.50 1,597.20 304.98 638.471,538.22 6,028,197.57 534,690.89 1.24 -352.42 3_MWD+IFR2+MS+Sag (1)
1,938.79 53.23 65.49 1,653.68 336.99 707.101,594.70 6,028,229.89 534,759.37 0.85 -389.53 3_MWD+IFR2+MS+Sag (1)
2,033.72 53.60 65.20 1,710.26 368.79 776.381,651.28 6,028,262.00 534,828.49 0.46 -426.48 3_MWD+IFR2+MS+Sag (1)
2,129.44 53.83 66.12 1,766.91 400.59 846.681,707.93 6,028,294.12 534,898.64 0.81 -463.51 3_MWD+IFR2+MS+Sag (1)
2,224.78 55.21 65.60 1,822.24 432.34 917.521,763.26 6,028,326.19 534,969.33 1.51 -500.53 3_MWD+IFR2+MS+Sag (1)
2,320.25 52.02 65.68 1,878.87 464.04 987.531,819.89 6,028,358.21 535,039.18 3.34 -537.44 3_MWD+IFR2+MS+Sag (1)
2,415.74 56.49 66.52 1,934.64 495.42 1,058.371,875.66 6,028,389.91 535,109.88 4.74 -574.09 3_MWD+IFR2+MS+Sag (1)
2,510.27 55.72 66.27 1,987.35 526.83 1,130.271,928.37 6,028,421.65 535,181.62 0.84 -610.86 3_MWD+IFR2+MS+Sag (1)
2,605.92 57.05 67.73 2,040.31 557.95 1,203.591,981.33 6,028,453.10 535,254.79 1.88 -647.43 3_MWD+IFR2+MS+Sag (1)
2,701.03 56.17 67.48 2,092.65 588.20 1,277.012,033.67 6,028,483.69 535,328.07 0.95 -683.15 3_MWD+IFR2+MS+Sag (1)
2,796.38 55.05 67.68 2,146.51 618.21 1,349.752,087.53 6,028,514.02 535,400.66 1.19 -718.58 3_MWD+IFR2+MS+Sag (1)
2,892.03 54.27 68.77 2,201.83 647.16 1,422.202,142.85 6,028,543.30 535,472.97 1.24 -752.93 3_MWD+IFR2+MS+Sag (1)
2,987.70 53.63 66.24 2,258.14 676.74 1,493.662,199.16 6,028,573.21 535,544.29 2.24 -787.83 3_MWD+IFR2+MS+Sag (1)
3,082.47 52.36 66.83 2,315.18 706.88 1,563.082,256.20 6,028,603.66 535,613.56 1.43 -823.14 3_MWD+IFR2+MS+Sag (1)
3,177.58 53.49 65.14 2,372.52 737.77 1,632.382,313.54 6,028,634.86 535,682.72 1.85 -859.18 3_MWD+IFR2+MS+Sag (1)
3,272.70 53.76 65.32 2,428.93 769.86 1,701.922,369.95 6,028,667.26 535,752.10 0.32 -896.44 3_MWD+IFR2+MS+Sag (1)
3,367.88 52.94 65.93 2,485.75 801.37 1,771.482,426.77 6,028,699.10 535,821.51 1.00 -933.13 3_MWD+IFR2+MS+Sag (1)
3,463.00 52.11 65.72 2,543.62 832.29 1,840.352,484.64 6,028,730.32 535,890.22 0.89 -969.17 3_MWD+IFR2+MS+Sag (1)
3,558.38 50.98 66.66 2,602.94 862.44 1,908.682,543.96 6,028,760.79 535,958.41 1.41 -1,004.41 3_MWD+IFR2+MS+Sag (1)
3,653.55 53.74 66.98 2,661.05 892.10 1,977.952,602.07 6,028,790.76 536,027.54 2.91 -1,039.22 3_MWD+IFR2+MS+Sag (1)
3,748.64 53.98 67.07 2,717.13 922.07 2,048.652,658.15 6,028,821.05 536,098.09 0.26 -1,074.46 3_MWD+IFR2+MS+Sag (1)
3,844.18 54.22 70.77 2,773.16 949.90 2,120.842,714.18 6,028,849.21 536,170.15 3.15 -1,107.67 3_MWD+IFR2+MS+Sag (1)
3,939.54 54.33 73.40 2,828.85 973.71 2,194.492,769.87 6,028,873.35 536,243.69 2.24 -1,136.98 3_MWD+IFR2+MS+Sag (1)
4,034.50 53.37 77.78 2,884.89 992.80 2,268.722,825.91 6,028,892.78 536,317.82 3.86 -1,161.64 3_MWD+IFR2+MS+Sag (1)
4,129.52 52.42 81.67 2,942.22 1,006.33 2,343.262,883.24 6,028,906.65 536,392.29 3.41 -1,180.77 3_MWD+IFR2+MS+Sag (1)
4,225.03 52.05 85.69 3,000.73 1,014.64 2,418.282,941.75 6,028,915.30 536,467.26 3.35 -1,194.74 3_MWD+IFR2+MS+Sag (1)
4,320.20 53.10 91.90 3,058.60 1,016.20 2,493.782,999.62 6,028,917.21 536,542.74 5.30 -1,202.00 3_MWD+IFR2+MS+Sag (1)
4,415.03 52.95 98.26 3,115.68 1,009.50 2,569.173,056.70 6,028,910.86 536,618.16 5.36 -1,201.03 3_MWD+IFR2+MS+Sag (1)
4,510.35 53.78 101.25 3,172.56 996.54 2,644.543,113.58 6,028,898.23 536,693.58 2.66 -1,193.80 3_MWD+IFR2+MS+Sag (1)
4,604.91 56.08 107.45 3,226.93 977.31 2,719.443,167.95 6,028,879.36 536,768.55 5.89 -1,180.30 3_MWD+IFR2+MS+Sag (1)
4,700.43 56.62 109.49 3,279.86 952.12 2,794.853,220.88 6,028,854.51 536,844.07 1.87 -1,160.89 3_MWD+IFR2+MS+Sag (1)
4,794.99 57.40 114.03 3,331.37 922.72 2,868.473,272.39 6,028,825.45 536,917.82 4.11 -1,137.14 3_MWD+IFR2+MS+Sag (1)
4,890.38 59.03 119.90 3,381.64 885.94 2,940.673,322.66 6,028,789.01 536,990.19 5.50 -1,105.94 3_MWD+IFR2+MS+Sag (1)
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 3
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
4,985.54 60.14 122.23 3,429.82 843.59 3,010.953,370.84 6,028,746.99 537,060.65 2.41 -1,069.03 3_MWD+IFR2+MS+Sag (1)
5,080.87 63.33 127.94 3,474.99 795.32 3,079.583,416.01 6,028,699.03 537,129.49 6.25 -1,026.08 3_MWD+IFR2+MS+Sag (1)
5,176.09 64.98 131.31 3,516.51 740.66 3,145.553,457.53 6,028,644.68 537,195.71 3.63 -976.58 3_MWD+IFR2+MS+Sag (1)
5,271.73 66.75 135.63 3,555.63 680.62 3,208.863,496.65 6,028,584.94 537,259.28 4.52 -921.50 3_MWD+IFR2+MS+Sag (1)
5,367.19 68.65 138.86 3,591.85 615.77 3,268.793,532.87 6,028,520.37 537,319.50 3.71 -861.37 3_MWD+IFR2+MS+Sag (1)
5,461.71 68.86 141.67 3,626.11 548.03 3,325.103,567.13 6,028,452.90 537,376.11 2.78 -798.09 3_MWD+IFR2+MS+Sag (1)
5,557.41 69.52 146.30 3,660.13 475.70 3,377.673,601.15 6,028,380.81 537,429.02 4.57 -729.94 3_MWD+IFR2+MS+Sag (1)
5,652.21 71.83 150.47 3,691.51 399.53 3,424.533,632.53 6,028,304.86 537,476.22 4.81 -657.53 3_MWD+IFR2+MS+Sag (1)
5,747.33 74.70 154.51 3,718.91 318.75 3,466.573,659.93 6,028,224.29 537,518.62 5.06 -580.17 3_MWD+IFR2+MS+Sag (1)
5,842.50 76.75 158.65 3,742.38 234.14 3,503.213,683.40 6,028,139.85 537,555.64 4.73 -498.57 3_MWD+IFR2+MS+Sag (1)
5,935.68 79.50 159.53 3,761.55 148.97 3,535.743,702.57 6,028,054.84 537,588.57 3.09 -416.11 3_MWD+IFR2+MS+Sag (1)
6,033.37 84.27 163.19 3,775.34 57.36 3,566.623,716.36 6,027,963.39 537,619.86 6.13 -327.10 3_MWD+IFR2+MS+Sag (1)
6,128.60 83.79 166.98 3,785.25 -34.14 3,591.003,726.27 6,027,872.00 537,644.65 3.99 -237.71 3_MWD+IFR2+MS+Sag (1)
6,223.79 82.26 167.23 3,796.81 -126.24 3,612.083,737.83 6,027,780.01 537,666.16 1.63 -147.47 3_MWD+IFR2+MS+Sag (1)
6,318.93 83.84 167.28 3,808.32 -218.35 3,632.923,749.34 6,027,688.01 537,687.41 1.66 -57.20 3_MWD+IFR2+MS+Sag (1)
6,414.13 83.03 167.54 3,819.21 -310.65 3,653.533,760.23 6,027,595.81 537,708.45 0.89 33.28 3_MWD+IFR2+MS+Sag (1)
6,508.43 86.21 169.03 3,828.05 -402.57 3,672.593,769.07 6,027,503.99 537,727.92 3.72 123.49 3_MWD+IFR2+MS+Sag (1)
6,595.01 91.66 169.71 3,829.66 -487.61 3,688.553,770.68 6,027,419.03 537,744.27 6.34 207.09 3_MWD+IFR2+MS+Sag (1)
6,676.47 91.62 168.99 3,827.33 -567.64 3,703.603,768.35 6,027,339.08 537,759.68 0.88 285.74 3_MWD+IFR2+MS+Sag (2)
6,772.52 91.56 168.46 3,824.66 -661.80 3,722.373,765.68 6,027,245.02 537,778.88 0.56 378.21 3_MWD+IFR2+MS+Sag (2)
6,867.05 90.94 169.78 3,822.60 -754.60 3,740.213,763.62 6,027,152.30 537,797.15 1.54 469.40 3_MWD+IFR2+MS+Sag (2)
6,962.65 88.03 168.00 3,823.46 -848.39 3,758.633,764.48 6,027,058.61 537,815.99 3.57 561.53 3_MWD+IFR2+MS+Sag (2)
7,057.94 88.22 169.40 3,826.58 -941.78 3,777.293,767.60 6,026,965.31 537,835.08 1.48 653.24 3_MWD+IFR2+MS+Sag (2)
7,153.21 90.32 173.99 3,827.79 -1,036.02 3,791.043,768.81 6,026,871.15 537,849.26 5.30 746.16 3_MWD+IFR2+MS+Sag (2)
7,248.24 89.89 176.42 3,827.62 -1,130.71 3,798.993,768.64 6,026,776.51 537,857.64 2.60 839.98 3_MWD+IFR2+MS+Sag (2)
7,341.79 89.45 176.08 3,828.15 -1,224.06 3,805.103,769.17 6,026,683.20 537,864.18 0.59 932.59 3_MWD+IFR2+MS+Sag (2)
7,431.30 90.38 174.54 3,828.29 -1,313.26 3,812.423,769.31 6,026,594.04 537,871.91 2.01 1,020.99 3_MWD+IFR2+MS+Sag (2)
7,530.76 89.21 174.67 3,828.64 -1,412.28 3,821.773,769.66 6,026,495.07 537,881.71 1.18 1,119.02 3_MWD+IFR2+MS+Sag (2)
7,627.01 89.58 174.55 3,829.66 -1,508.10 3,830.813,770.68 6,026,399.31 537,891.19 0.40 1,213.88 3_MWD+IFR2+MS+Sag (2)
7,716.50 89.27 174.63 3,830.56 -1,597.18 3,839.253,771.58 6,026,310.27 537,900.03 0.36 1,302.07 3_MWD+IFR2+MS+Sag (2)
7,816.00 89.45 175.42 3,831.67 -1,696.30 3,847.883,772.69 6,026,211.20 537,909.12 0.81 1,400.25 3_MWD+IFR2+MS+Sag (2)
7,914.30 90.20 177.33 3,831.97 -1,794.40 3,854.093,772.99 6,026,113.14 537,915.78 2.09 1,497.60 3_MWD+IFR2+MS+Sag (2)
8,009.71 90.81 178.73 3,831.13 -1,889.75 3,857.373,772.15 6,026,017.82 537,919.49 1.60 1,592.42 3_MWD+IFR2+MS+Sag (2)
8,105.07 90.81 179.90 3,829.78 -1,985.09 3,858.513,770.80 6,025,922.49 537,921.07 1.23 1,687.41 3_MWD+IFR2+MS+Sag (2)
8,200.56 92.24 181.15 3,827.24 -2,080.54 3,857.643,768.26 6,025,827.05 537,920.63 1.99 1,782.65 3_MWD+IFR2+MS+Sag (2)
8,295.60 91.86 181.39 3,823.84 -2,175.49 3,855.533,764.86 6,025,732.10 537,918.96 0.47 1,877.49 3_MWD+IFR2+MS+Sag (2)
8,391.16 91.00 182.35 3,821.45 -2,270.97 3,852.423,762.47 6,025,636.62 537,916.28 1.35 1,972.93 3_MWD+IFR2+MS+Sag (2)
8,486.82 90.50 183.27 3,820.20 -2,366.51 3,847.733,761.22 6,025,541.07 537,912.03 1.09 2,068.54 3_MWD+IFR2+MS+Sag (2)
8,581.24 92.61 185.56 3,817.64 -2,460.60 3,840.463,758.66 6,025,446.95 537,905.20 3.30 2,162.92 3_MWD+IFR2+MS+Sag (2)
8,676.20 94.34 186.65 3,811.88 -2,554.84 3,830.383,752.90 6,025,352.67 537,895.55 2.15 2,257.65 3_MWD+IFR2+MS+Sag (2)
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 4
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
8,771.80 94.40 186.22 3,804.60 -2,649.56 3,819.703,745.62 6,025,257.91 537,885.30 0.45 2,352.91 3_MWD+IFR2+MS+Sag (2)
8,867.48 94.59 185.69 3,797.10 -2,744.43 3,809.803,738.12 6,025,163.01 537,875.84 0.59 2,448.26 3_MWD+IFR2+MS+Sag (2)
8,962.85 93.90 184.08 3,790.04 -2,839.19 3,801.713,731.06 6,025,068.22 537,868.18 1.83 2,543.36 3_MWD+IFR2+MS+Sag (2)
9,057.41 93.41 182.81 3,784.01 -2,933.39 3,796.043,725.03 6,024,974.01 537,862.94 1.44 2,637.71 3_MWD+IFR2+MS+Sag (2)
9,152.73 93.28 182.81 3,778.45 -3,028.43 3,791.373,719.47 6,024,878.96 537,858.71 0.14 2,732.84 3_MWD+IFR2+MS+Sag (2)
9,247.31 92.29 183.72 3,773.85 -3,122.74 3,785.993,714.87 6,024,784.63 537,853.77 1.42 2,827.29 3_MWD+IFR2+MS+Sag (2)
9,343.79 91.99 184.24 3,770.25 -3,218.92 3,779.303,711.27 6,024,688.43 537,847.51 0.62 2,923.70 3_MWD+IFR2+MS+Sag (2)
9,438.14 93.41 185.51 3,765.81 -3,312.82 3,771.293,706.83 6,024,594.50 537,839.94 2.02 3,017.93 3_MWD+IFR2+MS+Sag (2)
9,532.97 91.55 185.74 3,761.70 -3,407.10 3,762.003,702.72 6,024,500.19 537,831.08 1.98 3,112.65 3_MWD+IFR2+MS+Sag (2)
9,627.18 93.16 186.06 3,757.83 -3,500.73 3,752.333,698.85 6,024,406.53 537,821.84 1.74 3,206.74 3_MWD+IFR2+MS+Sag (2)
9,723.53 92.54 185.07 3,753.04 -3,596.51 3,743.003,694.06 6,024,310.72 537,812.95 1.21 3,302.95 3_MWD+IFR2+MS+Sag (2)
9,818.55 91.24 184.10 3,749.91 -3,691.17 3,735.413,690.93 6,024,216.04 537,805.79 1.71 3,397.91 3_MWD+IFR2+MS+Sag (2)
9,914.64 90.01 182.63 3,748.86 -3,787.08 3,729.773,689.88 6,024,120.11 537,800.59 1.99 3,493.98 3_MWD+IFR2+MS+Sag (2)
10,008.43 89.33 183.69 3,749.40 -3,880.73 3,724.603,690.42 6,024,026.45 537,795.85 1.34 3,587.74 3_MWD+IFR2+MS+Sag (2)
10,102.82 89.02 184.13 3,750.76 -3,974.89 3,718.163,691.78 6,023,932.27 537,789.84 0.57 3,682.12 3_MWD+IFR2+MS+Sag (2)
10,198.49 89.64 183.66 3,751.88 -4,070.33 3,711.663,692.90 6,023,836.81 537,783.78 0.81 3,777.78 3_MWD+IFR2+MS+Sag (2)
10,294.43 90.32 183.21 3,751.91 -4,166.10 3,705.923,692.93 6,023,741.03 537,778.48 0.85 3,873.71 3_MWD+IFR2+MS+Sag (2)
10,389.47 90.69 182.89 3,751.07 -4,261.00 3,700.863,692.09 6,023,646.11 537,773.85 0.51 3,968.72 3_MWD+IFR2+MS+Sag (2)
10,484.46 89.76 182.83 3,750.70 -4,355.87 3,696.123,691.72 6,023,551.23 537,769.55 0.98 4,063.67 3_MWD+IFR2+MS+Sag (2)
10,578.35 89.45 182.72 3,751.35 -4,449.65 3,691.573,692.37 6,023,457.44 537,765.43 0.35 4,157.53 3_MWD+IFR2+MS+Sag (2)
10,674.32 90.69 184.06 3,751.23 -4,545.44 3,685.903,692.25 6,023,361.63 537,760.20 1.90 4,253.48 3_MWD+IFR2+MS+Sag (2)
10,769.82 92.42 185.75 3,748.64 -4,640.55 3,677.743,689.66 6,023,266.49 537,752.47 2.53 4,348.93 3_MWD+IFR2+MS+Sag (2)
10,865.03 92.24 185.94 3,744.77 -4,735.19 3,668.053,685.79 6,023,171.82 537,743.22 0.27 4,444.03 3_MWD+IFR2+MS+Sag (2)
10,959.71 91.43 185.85 3,741.74 -4,829.32 3,658.333,682.76 6,023,077.66 537,733.93 0.86 4,538.63 3_MWD+IFR2+MS+Sag (2)
11,054.55 92.54 186.59 3,738.45 -4,923.54 3,648.063,679.47 6,022,983.40 537,724.10 1.41 4,633.36 3_MWD+IFR2+MS+Sag (2)
11,150.41 92.42 186.40 3,734.30 -5,018.70 3,637.233,675.32 6,022,888.20 537,713.70 0.23 4,729.06 3_MWD+IFR2+MS+Sag (2)
11,245.41 92.54 185.55 3,730.19 -5,113.09 3,627.353,671.21 6,022,793.77 537,704.25 0.90 4,823.93 3_MWD+IFR2+MS+Sag (2)
11,340.23 91.12 181.92 3,727.16 -5,207.64 3,621.183,668.18 6,022,699.20 537,698.52 4.11 4,918.68 3_MWD+IFR2+MS+Sag (2)
11,436.01 91.25 179.75 3,725.18 -5,303.39 3,619.783,666.20 6,022,603.46 537,697.56 2.27 5,014.25 3_MWD+IFR2+MS+Sag (2)
11,531.22 92.11 179.97 3,722.39 -5,398.56 3,620.013,663.41 6,022,508.31 537,698.23 0.93 5,109.13 3_MWD+IFR2+MS+Sag (2)
11,627.00 94.40 181.73 3,716.95 -5,494.16 3,618.603,657.97 6,022,412.71 537,697.25 3.01 5,204.57 3_MWD+IFR2+MS+Sag (2)
11,721.95 93.90 181.49 3,710.08 -5,588.82 3,615.943,651.10 6,022,318.04 537,695.02 0.58 5,299.16 3_MWD+IFR2+MS+Sag (2)
11,816.53 92.97 181.92 3,704.42 -5,683.19 3,613.133,645.44 6,022,223.67 537,692.64 1.08 5,393.47 3_MWD+IFR2+MS+Sag (2)
11,912.61 93.66 182.50 3,698.86 -5,779.04 3,609.433,639.88 6,022,127.82 537,689.38 0.94 5,489.32 3_MWD+IFR2+MS+Sag (2)
11,950.00 93.83 182.49 3,696.42 -5,816.31 3,607.813,637.44 6,022,090.54 537,687.93 0.46 5,526.61 3_MWD+IFR2+MS+Sag (3)
12,007.92 92.05 182.95 3,693.45 -5,874.09 3,605.063,634.47 6,022,032.76 537,685.45 3.17 5,584.43 3_MWD+IFR2+MS+Sag (3)
12,102.92 91.24 185.43 3,690.72 -5,968.79 3,598.123,631.74 6,021,938.04 537,678.95 2.75 5,679.38 3_MWD+IFR2+MS+Sag (3)
12,197.87 91.43 187.63 3,688.51 -6,063.09 3,587.333,629.53 6,021,843.70 537,668.59 2.33 5,774.23 3_MWD+IFR2+MS+Sag (3)
12,293.01 92.54 187.87 3,685.21 -6,157.30 3,574.513,626.23 6,021,749.44 537,656.20 1.19 5,869.15 3_MWD+IFR2+MS+Sag (3)
12,388.63 92.36 187.07 3,681.12 -6,252.02 3,562.093,622.14 6,021,654.67 537,644.21 0.86 5,964.54 3_MWD+IFR2+MS+Sag (3)
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 5
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
MD
(usft)
Inc
(°)
Azi
(°)
+E/-W
(usft)
+N/-S
(usft)
Survey
TVD
(usft)
TVDSS
(usft)
Map
Northing
(ft)
Map
Easting
(ft)
Vertical
Section
(ft)
DLS
(°/100')Survey Tool Name
12,482.93 91.43 186.05 3,678.01 -6,345.65 3,551.323,619.03 6,021,561.00 537,633.88 1.46 6,058.71 3_MWD+IFR2+MS+Sag (3)
12,578.44 92.61 185.05 3,674.64 -6,440.65 3,542.093,615.66 6,021,465.97 537,625.08 1.62 6,154.14 3_MWD+IFR2+MS+Sag (3)
12,673.94 91.98 184.17 3,670.81 -6,535.77 3,534.423,611.83 6,021,370.83 537,617.85 1.13 6,249.56 3_MWD+IFR2+MS+Sag (3)
12,769.35 91.93 183.99 3,667.56 -6,630.88 3,527.633,608.58 6,021,275.70 537,611.50 0.20 6,344.91 3_MWD+IFR2+MS+Sag (3)
12,864.21 92.17 185.02 3,664.17 -6,725.38 3,520.193,605.19 6,021,181.17 537,604.49 1.11 6,439.71 3_MWD+IFR2+MS+Sag (3)
12,959.65 91.86 185.36 3,660.81 -6,820.37 3,511.563,601.83 6,021,086.15 537,596.29 0.48 6,535.08 3_MWD+IFR2+MS+Sag (3)
13,054.55 91.92 184.90 3,657.68 -6,914.84 3,503.083,598.70 6,020,991.65 537,588.25 0.49 6,629.92 3_MWD+IFR2+MS+Sag (3)
13,150.44 91.49 184.59 3,654.83 -7,010.36 3,495.153,595.85 6,020,896.11 537,580.76 0.55 6,725.76 3_MWD+IFR2+MS+Sag (3)
13,244.60 92.61 184.37 3,651.46 -7,104.17 3,487.803,592.48 6,020,802.27 537,573.84 1.21 6,819.86 3_MWD+IFR2+MS+Sag (3)
13,340.28 90.81 184.67 3,648.60 -7,199.51 3,480.263,589.62 6,020,706.91 537,566.74 1.91 6,915.49 3_MWD+IFR2+MS+Sag (3)
13,435.10 92.30 184.48 3,646.03 -7,293.99 3,472.703,587.05 6,020,612.41 537,559.61 1.58 7,010.28 3_MWD+IFR2+MS+Sag (3)
13,530.58 91.43 184.66 3,642.92 -7,389.11 3,465.103,583.94 6,020,517.26 537,552.44 0.93 7,105.70 3_MWD+IFR2+MS+Sag (3)
13,625.36 93.10 183.16 3,639.18 -7,483.59 3,458.643,580.20 6,020,422.76 537,546.42 2.37 7,200.40 3_MWD+IFR2+MS+Sag (3)
13,720.38 92.48 183.30 3,634.55 -7,578.35 3,453.293,575.57 6,020,327.99 537,541.51 0.67 7,295.29 3_MWD+IFR2+MS+Sag (3)
13,815.52 95.58 183.36 3,627.87 -7,673.08 3,447.783,568.89 6,020,233.24 537,536.43 3.26 7,390.17 3_MWD+IFR2+MS+Sag (3)
13,911.81 93.53 184.09 3,620.22 -7,768.86 3,441.553,561.24 6,020,137.45 537,530.63 2.26 7,486.14 3_MWD+IFR2+MS+Sag (3)
14,007.19 92.04 184.79 3,615.59 -7,863.84 3,434.173,556.61 6,020,042.44 537,523.69 1.73 7,581.41 3_MWD+IFR2+MS+Sag (3)
14,102.13 93.72 184.68 3,610.82 -7,958.33 3,426.343,551.84 6,019,947.93 537,516.30 1.77 7,676.22 3_MWD+IFR2+MS+Sag (3)
14,198.07 90.99 184.64 3,606.87 -8,053.86 3,418.563,547.89 6,019,852.37 537,508.95 2.85 7,772.07 3_MWD+IFR2+MS+Sag (3)
14,292.69 92.79 183.66 3,603.75 -8,148.18 3,411.713,544.77 6,019,758.03 537,502.54 2.17 7,866.63 3_MWD+IFR2+MS+Sag (3)
14,300.00 92.80 183.52 3,603.40 -8,155.47 3,411.263,544.42 6,019,750.74 537,502.11 1.92 7,873.93 3_MWD+IFR2+MS+Sag (4)
14,387.51 90.50 184.21 3,600.88 -8,242.73 3,405.363,541.90 6,019,663.46 537,496.62 2.74 7,961.40 3_MWD+IFR2+MS+Sag (4)
14,483.86 89.89 184.26 3,600.55 -8,338.82 3,398.243,541.57 6,019,567.35 537,489.94 0.64 8,057.75 3_MWD+IFR2+MS+Sag (4)
14,577.07 89.89 182.60 3,600.73 -8,431.86 3,392.673,541.75 6,019,474.29 537,484.79 1.78 8,150.94 3_MWD+IFR2+MS+Sag (4)
14,674.18 90.50 181.78 3,600.40 -8,528.90 3,388.963,541.42 6,019,377.25 537,481.53 1.05 8,247.98 3_MWD+IFR2+MS+Sag (4)
14,768.87 90.81 181.97 3,599.32 -8,623.53 3,385.863,540.34 6,019,282.61 537,478.86 0.38 8,342.58 3_MWD+IFR2+MS+Sag (4)
14,863.37 93.04 182.44 3,596.14 -8,717.90 3,382.233,537.16 6,019,188.24 537,475.66 2.41 8,436.95 3_MWD+IFR2+MS+Sag (4)
14,959.37 94.77 182.65 3,589.60 -8,813.58 3,377.973,530.62 6,019,092.55 537,471.85 1.82 8,532.68 3_MWD+IFR2+MS+Sag (4)
15,054.24 95.52 183.90 3,581.10 -8,907.91 3,372.583,522.12 6,018,998.20 537,466.88 1.53 8,627.15 3_MWD+IFR2+MS+Sag (4)
15,149.21 94.59 185.04 3,572.73 -9,002.22 3,365.203,513.75 6,018,903.87 537,459.94 1.55 8,721.75 3_MWD+IFR2+MS+Sag (4)
15,245.05 92.10 185.33 3,567.14 -9,097.50 3,356.563,508.16 6,018,808.56 537,451.73 2.62 8,817.40 3_MWD+IFR2+MS+Sag (4)
15,339.68 93.66 185.98 3,562.38 -9,191.54 3,347.243,503.40 6,018,714.48 537,442.85 1.79 8,911.89 3_MWD+IFR2+MS+Sag (4)
15,435.45 93.72 185.90 3,556.22 -9,286.60 3,337.353,497.24 6,018,619.39 537,433.40 0.10 9,007.42 3_MWD+IFR2+MS+Sag (4)
15,531.02 92.85 183.05 3,550.74 -9,381.71 3,329.913,491.76 6,018,524.26 537,426.39 3.11 9,102.82 3_MWD+IFR2+MS+Sag (4)
15,625.60 92.97 182.24 3,545.94 -9,476.07 3,325.553,486.96 6,018,429.89 537,422.47 0.86 9,197.24 3_MWD+IFR2+MS+Sag (4)
15,720.46 91.68 183.51 3,542.09 -9,570.73 3,320.803,483.11 6,018,335.22 537,418.15 1.91 9,291.99 3_MWD+IFR2+MS+Sag (4)
15,808.80 90.25 185.39 3,540.60 -9,658.78 3,313.953,481.62 6,018,247.14 537,411.70 2.67 9,380.31 3_MWD+IFR2+MS+Sag (4)
15,880.00 90.25 185.39 3,540.29 -9,729.67 3,307.263,481.31 6,018,176.24 537,405.33 0.00 9,451.49 PROJECTED to TD
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 6
Project:
Company: Local Co-ordinate Reference:
TVD Reference:
Site:
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Halliburton
Definitive Survey Report
Well:
Wellbore:
MPU M-43
MPU M-43PB3 Survey Calculation Method:Minimum Curvature
MPU M-43 Actual RKB @ 58.98usft
Design:MPU M-43PB3 Database:NORTH US + CANADA
MD Reference:MPU M-43 Actual RKB @ 58.98usft
North Reference:
Well MPU M-43
True
Approved By:Checked By:Date:
4/20/2020 2:04:32PM COMPASS 5000.15 Build 91E Page 7
Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2020.04.20 11:52:17 -08'00'
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2020.04.21 10:19:10 -08'00'
TD Shoe Depth: PBTD:
Jts.
1
2
1
1
1
99
1
1
1
63
1
X Yes No X Yes No 20
Fluid Description:
Liner hanger Info (Make/Model):Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg)Rate (bpm):Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg)Rate (bpm):Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns? Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
1.17
3/21/2020 36
Spud Mud
Lead Cement 575 2.35
Tail Cement 400 1.16
4
2,547.95
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 2,493.76 2,547.95 54.19
2,568.80 2,566.01
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 18.06 2,566.01
18.25 2,587.05 2,568.80
ES Cementer 10 3/4 TXP BTC-SR HES 2.79
Pup Joint 9 5/8 40.0 L-80 TXP BTC-SR Tenaris
6,506.39
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 3,919.34 6,506.39 2,587.05
6,546.13 6,507.86
Baffle Adapter 10 3/4 50.0 TXP BTC-SR HES 1.47 6,507.86
1.31 6,547.44 6,546.13
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 38.27
Float Collar 10 3/4 50.0 TXP BTC-SR Innovex
78 total 9-5/8"x12-1/4" bowspring centralizers ran.
2 on joint #1 with 4 stop rings. 1 free floating on joint #2. 1 each mid-joint on #3&4 wit 4 stop rings.
1 each free floating on joints #6 to 26.
1 each free floating every other joint #28 to 50.
1 each free floating on joint #99 to 106.
1 each on pup joint above and below ES cementer w/ 2 stop rings.
1 each free floating on joint #108 to 164.
Casing 9 5/8 40.0 L-80 TXP BTC-SR Tenaris 77.98 6,625.42 6,547.44
www.wellez.net WellEz Information Management LLC ver_04818br
4
Type of Shoe:Innovex Casing Crew:Doyon
12 239
ES Cementer Closure OK
56.2
Perm L lead
Type
Premium G Tail 270
Tuned Spacer
550 4.41
Stage Collar @
60
Bump press
100
146.25
6,627.006,634.00
CEMENTING REPORT
Csg Wt. On Slips:135,000
Spud Mud
13:35 3/20/2020 2,566
2566.01
15.8 82
Bump press
Returns to surface
Bump Plug?
Y
2.2
9.4 5.7 197.76/174.83
486.83/493.7
1100
0.1
RigFIRST STAGE10Tuned Spacer 52
15.8
390
9.4 5.5
1300
10
10.7 431.7 4
99
580
Bump Plug?
Csg Wt. On Hook:175,000 Type Float Collar:Innovex No. Hrs to Run:19
9 5/8 40.0 L-80 TXP BTC-SR Tenaris
TXP BTC-SR Innovex 1.58 6,627.00 6,625.42
22.68 54.19 34.19
Setting Depths
Component Size Wt.Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP M-43 Date Run 18-Mar-20
CASING RECORD
County State Alaska Supv.D. Yessak / C. Demoski
6,546.13
Floats Held
403.3 808.9
146.25 662.65
Spud Mud
Rotate Csg Recip Csg Ft. Min.PPG9.4
Shoe @ 6627 FC @ Top of Liner
SECOND STAGERig
3:07
Returns to surface
363.42 769.02 211.6
Casing (Or Liner) Detail
Shoe
Cut Joint of Casing
10 3/4 50.0
PB1 PB2 PB3
TD 13,000' MD / 3,736' TVD 15,570' MD / 3,670' TVD 15,880' MD / 3,540' TVD
KOP 11,950' MD / 3,695' TVD 14,290' MD / 3,603' TVD 6,680' MD / 3,827' TVD
Date 3/25/2020 3/29/2020 4/8/2020
PTD: 220-020 / API: 50-029-23671-00-00
MPU M-43 OH Sidetrack Summary
STATE OF ALASKA
Reviewed By:.���'""
OIL AND GAS CONSERVATION COMMISSION P.I. supry Z-7 ZLt�
BOPE Test Report for: MILNE PT UNIT M-43 Comm
Contractor/Rig No.: Doyon 14 PTD#: 2200200 ` DATE: 4/18/2020 " Inspector Guy Cook - Insp Source
Operator: Hilcorp Alaska, LLC Operator Rep: Claude Demoski Rig Rep: Randy Jordan Inspector
Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopGDC200418120630
Rams: Annular: Valves: MASP:
Type Test: BIWKLY 250/3000 " 250/3000 250/3000 1336 • Related Insp No:
TEST DATA
MISC. INSPECTIONS:
MUD SYSTEM:
ACCUMULATOR SYSTEM:
Upper Kelly
1
P/F
Lower Kelly
Visual
Alarm
Time/Pressure P/F
Location Gen.:
P
Trip Tank
P
P
System Pressure 3000
P
Housekeeping:
P
Pit Level Indicators
P
P
Pressure After Closure 1.650
P _
PTD On Location
P
Flow Indicator
P
P
200 PSI Attained 44
P "
Standing Order Posted
P _
Meth Gas Detector
P
P
Full Pressure Attained 190
P ---
"Well
Well Sign
_P
H2S Gas Detector
P
P
Blind Switch Covers: All Stations
_ P -
Drl. Rig
- P
MS Misc
-NA
NA-
Nitgn. Bottles (avg): 6(u)2141
P_-_
Hazard Sec.
P
P
Inside Reel Valves 0
NA
ACC Misc 0
NA
Misc
NA
Check Valve
0
NA
FLOOR SAFTY VALVES:
BOP STACK:
Quantity
P/F
Upper Kelly
1
P
Lower Kelly
1--_
P_-'
Ball Type
3
P -
Inside BOP
_ 2_
P
FSV Misc
0
NA
BOP STACK:
CHOKE MANIFOLD:
Quantity Size
P/F
Quantity
P/F
Stripper
0
NA
No. Valves 14
P -
Annular Preventer
1 13 5/8 5000
P
Manual Chokes 1
P "
#1 Rams
1 4.5 x 7 V_B_ R '
P- -
Hydraulic Chokes 1
P
#2 Rams
1 Blinds
P
CH Misc 0
NA
#3 Rams
1 3.5 X 6 VBR
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 1/8 5000
P
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: 0 - Test Results Test Time 9
Remarks: 4.5", 5" and 7" test joints used for testing. During the high pressure portion of Test #1, a test equipment needle valve started
leaking at the handle stem packing. We bled off and tightened the packing and continued on with testing.
PATE OF ALASKA
By:
OIL AND GAS CONSERVATION COMMISSION P.I. Reviewed awed
Supry
DIVERTER Test Report for: MILNE PT UNIT M-43 Comm
Contractor/Rig No.: Doyon 14 PTD#: 2200200 DATE: 3/12/2020 ' Inspector Austin McLeod " Insp Source
Operator: Hilcorp Alaska LLC Operator Rep: Doug Yessak Rig Rep: Eric Rodland Inspector
Well Class: DEV Inspection No: divSAM200313084722
Related Insp No:
MISC. INSPECTIONS:
GAS DETECTORS:
Visual Alarm
Methane: P P
Hydrogen Sulfide: P ' P
Gas Detectors Mise: NA NA
TEST DATA
MUD SYSTEM:
Visual Alarm
Trip Tank:
P/F
Location Gen.:
P
Housekeeping:
P_-
Warning Sign
_P_
24 hr Notice:
P
Well Sign:
- P '
Drlg. Rig.
P
Mise:
NA
GAS DETECTORS:
Visual Alarm
Methane: P P
Hydrogen Sulfide: P ' P
Gas Detectors Mise: NA NA
TEST DATA
MUD SYSTEM:
Visual Alarm
Trip Tank:
P
P
Mud Pits:
_ P
_P -
Flow Monitor:
P
_ P
Mud System Mise:
NA_
NA_
ACCUMULATOR SYSTEM:
P/F
Time/Pressure
P/F
Systems Pressure:_ 3000_ "
P _
Pressure After Closure: 1800
P
200 psi Recharge Time: 35
P
Full Recharge Time: 140
P
Nitrogen Bottles (Number of): 6
P
Avg. Pressure: 2166
P '
Accumulator Misc: I
FP
DIVERTER SYSTEM:
Size
P/F
Designed to Avoid Freeze-up?
P
Remote Operated Diverter?
P
No Threaded Connections?
P
Vent line Below Diverter?
P "
Diverter Size: 21.25
- P '
Hole Size: 12.25
P
Vent Line(s) Size: 16
P
Vent Line(s) Length: 255
P
Closest Ignition Source: 134
P
Outlet from Rig Substructure: 230
P
Vent Line(s) Anchored:
P
Turns Targeted / Long Radius:
P '
Divert Valve(s) Full Opening:
P "
Valve(s) Auto & Simultaneous:
P
Annular Closed Time: 25
P
Knife Valve Open Time: 17
P
Diverter Misc: 0
NA
Number of Failures: 1 x Test Time: 2
Remarks: 5" DP. Accumulator air pump locked up. Replaced for a pass.
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Monty Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.o ogcc.alaska.gov
Re: Milne Point Field, Schrader Bluff Oil Pool, MPU M-43
Hilcorp Alaska, LLC
Permit to Drill Number: 220-020
Surface Location: 5037' FSL, 111' FEL, SEC. 14, T13N, R9E, UM, AK
Bottomhole Location: 617' FSL, 2089' FEL, SEC. 24, T13N, R9E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced development 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 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, yy �v%�
nLCielowski
Commissioner
DATED this 12— day of March, 2020.
RECEIVED
I STATE OF ALASKA
Al OIL AND GAS CONSERVATION COMMI_. ION FEB 2 7 2020
PERMIT TO DRILL
20 AAC 25.005 . �.......
1a. Type of Work:
I 1b. Proposed Well Class: Exploratory - Gas ❑
Service - WAG ❑ Service - Disp ❑
1 c. SAkj&a kVkped for:
Drill ❑� ' Lateral Ell
Stratigraphic Test ❑ Development -Oil ❑✓
•Service - Winj ❑ Single Zone Q
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑
Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket Single Well ❑
11. Well Name and Number:
Hilcorp Alaska, LLC
Bond No. 022224484
MPU M-43 -
3. Address:
6. Proposed Depth:
12. Field/Pcol(s):
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
MD: 15,860' . TVD: 3,579'
Milne Point Unit
Schrader Bluff Oil Pool -
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 5037' FSL, 111' FEL, Sec 14, T13N, R9E, UM, AK •
ADL025514, ADL388235
f4 B Pfi. 5.gN0
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
635' FNL, 1716' FEL, Sec 13, T13N, R9E, UM, AK
LONS 16-004
3/15/2020
9. Acres in Property:
14. Distance to Nearest Property:
Total Depth:
617' FSL, 2089' FEL, Sec 24, TI 3N, l UM, AK
4480
617' to nearest unit boundary
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 58.8'
15. Distance to Nearest Well Open
Surface: x-534053 y- 6027889 Zone -4
GL / BE Elevation above MSL (ft): 25.3'
to Same Pool: 120' to M-11
16. Deviated wells: Kickoff depth: 280 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 92 degrees -
Downhole: 1681 Surface:
1336 -
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)
Cond
20" -
X52
Weld
113'
Surface
Surface
113'
113'
-270113
Stg 1 -L-1225 ft3/T-458 ft3
12-1/4"
9-5/8" 40#
L-80
TXP
6,508'
Surface
Surface
6,508'
3,819'
Sig 2 - L - 1937 ft3 / T - 314 ft3
8-1/2"
4-1/2" 13.5#
L-80
Hyd 625
9,502'
6,358'
3,808'
15,860'
3,579'
Cementless Screen Liner
Tieback
7" 26#
L-80
TXP
6,358'
Surface
Surface
6,358'
3,808'
Tieback
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
UEr purhp c,,.%pL
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):
Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
Casing Length Size
Cement Volume MD TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes ❑ No ❑✓
20. Attachments: Property Plat O BOP Sketch
e
Drilling Programs
Time v. Depth Plot
B e
Shallow Hazard Analysis
8
Diverter Sketch
Seabed
Report
Drilling Fluid Program
20 AAC 25.050 requirements
21. Verbal Approval: Commission Representative:
Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name:
Joe Engel
Authorized Name: Monty Myers
Contact Email:en
el hIICOr .COm
Authorized Title: Drilling Manager
Contact Phone:
777-8395
fol M0
2 7-o -00
Authorized Signature:
Date: Z�
ommission Use Only
Permit to Drill ��,Rc
�C.ti"b��
API Number: --7
��
Permit Approv
See cover letter for other
requirements.
Number:
50-�%Z- ( �"(�-�
Date:
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: * 3 oali p5 � �a P ��S �—
/
Samples req'd: Yes ❑ No /
Mud log req'd: Yes ❑ o t}�
VNo,❑�,/
HzS measures: Yes ❑ No,[�v�,/ Directional svy req'd: Yes
Spacing
exception req'd: Yes ❑ No I1� Inclination
-only svy req'd: Yes ❑ No (_J✓
Post initial
injection MIT req'd: Yes ❑ No ❑
•
n
APPROVED BY
9J
Approved by: IAAeuCOMMISSIONER
THE COMMISSION
Date:
Form 10 1 Revise 5/2 1. n
��IRY
This permit Is valid for
,�(
submit Form and
n f e a proval per 20 AAC 25.005() Attachm s in Duplicate
R'1 BHT L Z QF,-
,03r�-2�
.
Hilcorp Alaska, LLC
Milne Point Unit
(MPU) M-43
Drilling Program
Version 1
2/26/2020
Table of Contents
1.0
Well Summary.................................................................................................................................2
2.0
Management of Change Information............................................................................................3
3.0
Tubular Program: ...........................................................................................................................
4
4.0
Drill Pipe Information: ...................................................................................................................
4
5.0
Internal Reporting Requirements..................................................................................................5
6.0
Planned Wellbore Schematic..........................................................................................................6
7.0
Drilling / Completion Summary.....................................................................................................7
8.0
Mandatory Regulatory Compliance / Notifications
.....................................................................8
9.0
RU and Preparatory Work...........................................................................................................10
10.0
NU 21-1/4" 2M Diverter System..................................................................................................11
11.0
Drill 12-1/4" Hole Section.............................................................................................................13
12.0
Run 9-5/8" Surface Casing...........................................................................................................16
13.0 Cement 9-5/8" Surface Casing.....................................................................................................21
14.0 ND Diverter, NU BOPS, & Test...................................................................................................26
15.0 Drill 8-1/2" Hole Section...............................................................................................................27
16.0 Run 4-1/2" Screen Liner...............................................................................................................32
17.0 Run 7" Tieback..............................................................................................................................36
18.0 Run Upper Completion.................................................................................................................39
19.0Doyon 14 Diverter Schematic.......................................................................................................41
20.0 Doyon 14 BOP Schematic.............................................................................................................42
21.0 Wellhead Schematic......................................................................................................................43
22.0 Days Vs Depth................................................................................................................................44
23.0 Formation Tops & Information...................................................................................................45
24.0 Anticipated Drilling Hazards.......................................................................................................46
25.0 Doyon 14 Layout............................................................................................................................49
26.0 FIT Procedure................................................................................................................................50
27.0 Doyon 14 Choke Manifold Schematic..........................................................................................51
28.0 Casing Design.................................................................................................................................52
29.0 8-1/2" Hole Section MASP............................................................................................................53
30.0 Spider Plot (NAD 27) (Governmental Sections).........................................................................54
31.0 Surface Plat (As Staked) (NAD 27)..............................................................................................55
32.0 Schrader Bluff Nb Sand Offset MW vs TVD Chart...................................................................56
H
Hilcorp
Ene`gy C22
1.0 Well Summary
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Well
MPU M-43
Pad
Milne Point "M" Pad
Planned Completion Type
Jet Pump on 4-1/2 tubing
Target Reservoir(s)
Schrader Bluff NB/NC Sand
Planned Well TD, MD / TVD
15,860' MD / 3,578' TVD
PBTD, MD / TVD
15,850' MD / 3,578' TVD
Surface Location (Governmental)
5037' FSL, 111' FEL, Sec 14, T13N, R9E, UM, AK
Surface Location AD 27)
X= 534053, Y= 6027889 -
Top of Productive Horizon
(Governmental)
635' FNL, 1716' FEL, Sec 13, TON, R9E, UM, AK
TPH Location AD 27)
X= 537730 Y= 6027515
BHL Governmental
617' FSL, 2089' FEL, Sec 24, T13N, R9E, UM, AK
BHL (NAD 27)
X= 537406, Y= 6018206
AFE Number
2010894
AFE Drilling Das
20
AFE Completion Das
4
AFE Drilling Amount
$4,155,051
AFE Completion Amount
$2,625,628
AFE Facility Amount
$391,000
Maximum Anticipated Pressure
(Surface)
1,336 psig
Maximum Anticipated Pressure
(Downhole/Reservoir)
1,681 psig
Work String
5" 19.5# S-135 NC 50
D14 KB Elevation above MSL:
33.7 ft +25.1 ft = 58.8 ft
GL Elevation above MSL:
25.1 ft
BOP Equipment
13-5/8" x 5M Annular, (3) ea 13-5/8" x 5M Rams
Page 2
2.0 Management of Change Information
11
Hilcorp Alaska, LLC Hilcorp
Fmp fail
Changes to Approved Permit to Drill
Date: 2126120201
Subject: Changes to Approved Permit to Drill for MPU M-43
File #: MPU M-43 Drilling and Completion Program
Any modifications to MPU M-43 Drilling & Completion Program will be documented and approved below.
Changes to an approved APD will be approved in advance to the AGGCC
Approval:
Drilling Manager Date
Prepared:
Drilling Engineer
Page 3
Date
Milne Point unit
M-43 SB Producer
Hilco
E,
Drilling Procedure
2.0 Management of Change Information
11
Hilcorp Alaska, LLC Hilcorp
Fmp fail
Changes to Approved Permit to Drill
Date: 2126120201
Subject: Changes to Approved Permit to Drill for MPU M-43
File #: MPU M-43 Drilling and Completion Program
Any modifications to MPU M-43 Drilling & Completion Program will be documented and approved below.
Changes to an approved APD will be approved in advance to the AGGCC
Approval:
Drilling Manager Date
Prepared:
Drilling Engineer
Page 3
Date
3.0 Tubular Program:
4.0 Drill Pipe Information:
_
"Conn
"Surface&
Milne Point Unit
5" 3.250"
6.625" 19.5 S-135
M-43 SB Producer
36,100 43,100 560klb
Hilco+}/��
E,a Cmpmy
Drilling Procedure
3.0 Tubular Program:
4.0 Drill Pipe Information:
_
"Conn
"Surface&
5" 3.250"
6.625" 19.5 S-135
DS50
36,100 43,100 560klb
Production
I=
5" 4.276" 3.250"
6.625" 19.5 S-135
NC50
30,730 34,136 560klb
All casing will be new, PSL 1 (100% mill inspected, 10% inspection upon delivery).
Page 4
5.0 Internal Reporting Requirements
Milne Point Unit
M-43 SB Producer
Drilling Procedure
5.1 Fill out daily drilling report and cost report on WellEz.
• Report covers operations from 6am to 6am
• Click on one of the tabs at the top to save data entered. If you click on one of the tabs to the left
of the data entry area — this will not save the data entered, and will navigate to another data entry.
• Ensure time entry adds up to 24 hours total.
• Try to capture any out of scope work as NPT. This helps later on when we pull end of well
reports.
• Enter the MD and TVD depths EVERY DAY whether you are making hole or not.
5.2 Afternoon Updates
• Submit a short operations update each work day to pmazzolini@a hilcorp.com, mmyers e hilcorp,
ieneel@hilcorp.com and cdinger@hilcoM.com
5.3 Intranet Home Page Morning Update
• Submit a short operations update each morning by lam on the company intranet homepage. On
weekend and holidays, ensure to have this update in before 5am.
5.4 EHS Incident Reporting
• Health and Safety: Notify EHS field coordinator.
• Environmental: Drilling Environmental Coordinator
• Notify Drilling Manager & Drilling Engineer on all incidents
• Submit Hilcorp Incident report to contacts above within 24 hrs
5.5 Casing Tally
• Send final "As -Run" Casing tally to mmyers@hilcorp,com ieneel@hilcorp.com and
cdinizer@hilc=.com
5.6 Casing and Cement report
• Send casing and cement report for each string of casing to mmyers@hilcorp.com
hilcorp.com
icnizel@hilcorp.com and cdinger(d)hilcorp.com
5.7 Hilcorp Milne Point Contact List:
Title
Name
Work Phone
Cell Phone
Email
Drilling Manager
Monty Myers
907.777.8431
907.538.1168
mmyers@hilcorp.com
Drilling Engineer
Joe Engel
907.777.8395
805.235.6265
leneel@hilcorp.com
Completion Engineer
Ian Toomey
907.777.8434
907.903.3987
itoomey@hilcorp.com
Geologist
Kevin Eastham
907.777.8316
907.360.5087
keastham@hilcoro.com
Reservoir Engineer
Reid Edwards
907.777.8421
907.250.5081
reedwards@hilcorp.com
Drilling Env. Coordinator
Keegan Fleming
907.777.8477
907.350.9439
kfleming@hilcorp.com
EHS Manager
Carl Jones
907.777.8327
907.382.4336
caiones@hilcorp.com
Drilling Tech
Cody Dinger
907.777.8389
509.768.8196
cdinger@hilcorp.com
Page 5
n
MCorp
Bl C.mryvy
6.0 Planned Wellbore Schematic i q —
Milne Point Unit
M-43 SB Producer
Drilling Procedure
KOP Q
Max 006 A,16 TW ka Jet Pum
Mex flak Angle =T80p IN prahkv
Max lle6 Anµle=TOO @TpN ISI
Max Ilok Angle =TBO
OPEN HOLE/ CEMENT DETAIL
62'
Milne Point Unit
12.1/YlstsMge
I L-122583/T-458ft1
U-V4'2M sup
Well: MPU M-43
&112"
(plpppVrP Shllad over in &1/2' hxde
N rtpm lotion
Proposed SCHEMATIC Last Completed: Future
1
TBD
11'xd 2"TWixilan
PTD: TBD
l
TBD
IBEche: SEK/ GL E6V.:25.Y
--------------------------- _______-__-_____--_-_-
TREE & WELLHEAD
4
Trey
Cameron 6l/I5' 51.1
t
5
J
1 4.5'G ewl V NSm llntakc@sa )
3.8P.P'
VielNrad
FMC1I"5MTGIAw111'x41,12'TC-IITUPxnd Batt.Tering
I 4.5"%Nipp1e 13813-Packln Bare)
3813"
]
no
1 7'x0.5'Pxerie ahle Pa er
3890'
Ila rwitli3"OW"'ll'BPV mfik.2ea3/8'N mM aline.
KOP Q
Max 006 A,16 TW ka Jet Pum
Mex flak Angle =T80p IN prahkv
Max lle6 Anµle=TOO @TpN ISI
Max Ilok Angle =TBO
OPEN HOLE/ CEMENT DETAIL
62'
I 501Pp{s(1OVw&ejlty141Cdxmpcddawnbaksirk{
12.1/YlstsMge
I L-122583/T-458ft1
U-V4'2M sup
L -1937@3/7-314R3
&112"
(plpppVrP Shllad over in &1/2' hxde
KOP Q
Max 006 A,16 TW ka Jet Pum
Mex flak Angle =T80p IN prahkv
Max lle6 Anµle=TOO @TpN ISI
Max Ilok Angle =TBO
---------------------GENERAL__________WE____LL__ INF___O
TD=iS,.�Y{MU{/Tp=gK)9'IT5'�l API: TBD
PBrD=15,B<D IMDJ/TD=sS>9'[rvDl
R—ld E, COD 2. 2E, 20
Page 6
1
IEWELRYDETAIL
Np
T.P MD
I
5MID
N rtpm lotion
1
TBD
11'xd 2"TWixilan
39]0'
l
TBD
4.5"Di.:haree Frnseee Gaage MandreHOucharge Caugel
38]4"
4
TBD
4.5'ShdmxSk .
3.813"
5
TBD
1 4.5'G ewl V NSm llntakc@sa )
3.8P.P'
6
TBD
I 4.5"%Nipp1e 13813-Packln Bare)
3813"
]
no
1 7'x0.5'Pxerie ahle Pa er
3890'
8
no
I 4.5" M Nipple IMIN 10=3725
3.813"
4
TBD
I 4.V WIDG
Saw,
W., C.Mixtim
10
6
1 BQTSIDIPLim Tcp PacharwMD51im7-x45/8"
6,170'
I1
6,168'
YTeNck Asa .1825"CO No W)
6,151"
12 1
6.1111'
5.925'
13 1
15,8K+
I P ... d ,, ll—Lstce
---------------------GENERAL__________WE____LL__ INF___O
TD=iS,.�Y{MU{/Tp=gK)9'IT5'�l API: TBD
PBrD=15,B<D IMDJ/TD=sS>9'[rvDl
R—ld E, COD 2. 2E, 20
Page 6
H
Hilcorp
U .2
7.0 Drilling / Completion Summary
Milne Point Unit
M-43 SB Producer
Drilling Procedure
MPU M-43 is a grassroots jet pump producer planned to be drilled in the Schrader Bluff NB/NC sand. M-43
is part of a multi well program targeting the Schrader Bluff sand on M -Pad.
The directional plan is a catenary well path build, 12-1/4" hole with 9-5/8" surface casing set into the top of
the Schrader Bluff NB sand. An 8-1/2" lateral section will then be drilled. A 4-1/2" screen liner will be run
in the open hole section and the well produced with a jet pump assembly.
The Doyon 14 will be used to drill and complete the wellbore
Drilling operations are expected to commence approximately March 15, 2020, pending rig schedule.
Surface casing will be run to 6,508' MD / 3,818' TVD and cemented to surface via a 2 stage primary cement
job. Cement returns to surface will confirm TOC at surface. If cement returns to surface are not observed,
necessary remedial action will then be discussed with AOGCC authorities.
All cuttings & mud generated during drilling operations will be hauled to the Milne Point `B" pad G&I facility.
General sequence of operations:
1. MIRU Doyon 14 to well site
2. NU & Test 21-1/4" Diverter and 16" diverter line
3. Drill 12-1/4" hole to TD of surface hole section. Run and cement 9-5/8" surface casing
4. ND diverter, NU wellhead, NU 13-5/8" 5M BOP & Test
5. Drill 8-1/2" lateral to well TD. .
6. Run 6-5/8" production liner
7. Run 7" tieback
8. Run Upper Completion
9. ND BOP, NU Tree, RDMO
Reservoir Evaluation Plan:
1. Surface hole: No mud logging. On Site geologist. LWD: GR + Res
2. Production Hole: No mud logging. On site geologist. LWD: GR + ADR (For geo-steering)
Page 7
Milne Point Unit
M-43 SB Producer
Drilling Procedure
8.0 Mandatory Regulatory Compliance / Notifications
Regulatory Compliance
Ensure that our drilling and completion operations comply with the all applicable AOGCC regulations,
specific regulations are listed below. If additional clarity or guidance is required on how to comply with
a specific regulation, do not hesitate to contact the Anchorage Drilling Team.
• BOPs shall be tested at (2) week intervals during the drilling and completion of MPU M-43. Ensure
to provide AOGCC 24 hrs notice prior to testing BOPs.
• The initial test of BOP equipment will be to 250/3,000 psi & subsequent tests of the BOP equipment
will be to 250/3,000 psi for 5/5 min (annular to 50% rated WP, 2,500 psi on the high test for initial
and subsequent tests). Confirm that these test pressures match those specified on the APD.
• If the BOP is used to shut in on the well in a well control situation or control fluid flow from the
well bore, AOGCC is to be notified and we must test all BOP components utilized for well control
prior to the next trip into the wellbore. This pressure test will be charted same as the 14 day BOP
test.
• All AOGCC regulations within 20 AAC 25.033 "Primary well control for drilling: drilling fluid program
and drilling fluid system".
• All AOGCC regulations within 20 AAC 25.035 "Secondary well control for primary drilling and
completion: blowout prevention equipment and diverter requirements".
o Ensure the diverter vent line is at least 75' away from potential ignition sources
• Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
AOGCC Regulation Variance Requests:
No variances are requested at this time. i
Page 8
Summary of Doyon 14 BOP Equipment & Test Requirements
Hole Section
Equipment
Test Pressure(psi)
12 1/4"
• 21-1/4" 2M Diverter w/ 16" Diverter Line
Function Test Only
Milne Point unit
• 13-5/8" x 5M Hydril "GK" Annular BOP
M-43 SB Producer
N/A
HilcoTfyf
Energy Compmy
Drilling Procedure
Summary of Doyon 14 BOP Equipment & Test Requirements
Hole Section
Equipment
Test Pressure(psi)
12 1/4"
• 21-1/4" 2M Diverter w/ 16" Diverter Line
Function Test Only
• 13-5/8" x 5M Hydril "GK" Annular BOP
• 13-5/8" x 5M Hydril MPL Double Gate
N/A
o Blind ram in bum cavity
• Mud cross w/ 3" x 5M side outlets
For Reference
13-5/8" x 5M Hydril WL Single ram
• 3-1/8" x 5M Choke Line
N/A
• 3-1/8" x 5M Kill line
• 3-1/8" x 5M Choke manifold
• Standpipe, floor valves, etc
Primary closing unit: NL Shaffer, 6 station, 3,000 psi, 180 gallon accumulator unit.
Primary closing hydraulics is provided by an electrically driven triplex pump. Secondary back-up is a 30:1 air
pump, and emergency pressure is provided by bottled nitrogen.
The remote closing operator panels are located in the doghouse and on accumulator unit.
Required AOGCC Notifications:
• Well control event (BOPS utilized to shut in the well to control influx of formation fluids).
• 24 hours notice prior to spud.
• 24 hours notice prior to testing BOPs.
• 24 hours notice prior to casing running & cement operations.
• Any other notifications required in APD.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (0): 907-793-1236 / Email: iim.regg@alaska.gov
Guy Schwartz / Petroleum Engineer / (0): 907-793-1226 / (C): 907-301-4533 / Email: guy.schwartz(c�r�alaska.gov
Victoria Loepp / Petroleum Engineer / (0): 907-793-1247 / Email: Victoria. loeppnalaska.gov
Mel Rixse / Petroleum Engineer / (0): 907-793-1231 / (C): 907-223-3605 / Email: melvin.rixse@alaska.eov
Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format: hfp://doa.alaska.gov/ogc/forms/TestWitnessNotif.html
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
1/
Page 9
H
Hilcorp
�.�Prq
9.0 RU and Preparatory Work
Milne Point Unit
M-43 SB Producer
Drilling Procedure
9.1 M-24 will utilize a newly set 20" conductor on M -Pad. Ensure to review attached surface plat
and make sure rig is over appropriate conductor.
9.2 Ensure PTD and drilling program are posted in the rig office and on the rig floor.
9.3 Install landing ring.
9.4 Insure (2) 4" nipples are installed on opposite sides of the conductor with ball valves on each.
9.5 Level pad and ensure enough room for layout of rig footprint and RU.
9.6 Rig mat footprint of rig.
9.7 MIRU Doyon 14. Ensure rig is centered over conductor to prevent any wear to BOPE or
wellhead.
9.8 Mud loggers WILL NOT be used on either hole section.
9.9 Mix spud mud for 12-1/4" surface hole section. Ensure mud temperatures are cool (<807).
9.10 Ensure 6" liners in mud pumps.
• Continental EMSCO FB -1600 mud pumps are rated at 4,665 psi, 462 GPM @ 110 SPM @
95% volumetric efficiency.
Page 10
H
OIC-Oarp
10.0 NU 21-1/4" 2M Diverter System
Milne Point Unit
M-43 SB Producer
Drilling Procedure
10.1 NU 21-1/4" Hydril MSP 2M Diverter System (Diverter Schematic attached to program).
• NU 16-3/4" 3M x 21-1/4" 2M DSA on 16-3/4" 3M wellhead.
• NU 21-1/4" diverter "T".
• Knife gate, 16" diverter line.
• Ensure diverter RU complies with AOGCC reg 20.AAC.25.035(C).
• Diverter line must be 75 feet from nearest ignition source
• Place drip berm at the end of diverter line.
10.2 Notify AOGCC. Function test diverter. Ensure that the knife gate and annular are operated on
the same circuit so that knife gate opens prior to annular closure.
10.3 Ensure to set up a clearly marked "warning zone" is established on each side and ahead of the
vent line tip. "Warning Zone" must include:
• A prohibition on vehicle parking
• A prohibition on ignition sources or running equipment
• A prohibition on staged equipment or materials
• Restriction of traffic to essential foot or vehicle traffic only.
J
Page 11
Milne Point Unit
M-43 SB Producer
Drilling Procedure
10.4 Rig & Diverter Orientation: C
• May change on location �� " �d Ju�jC 71V
� I
M-44 -(P- �l
� M -+o • �� Imo+
M-43 ■ I
■ MAL J �
M—+7 ■
■ M -u
M-10 ■
M-57 • ■ M-15
M-21 ■
75' Radius Clear of lenition Sources
Diverter Line
Drawing Not To Scale
MPU M -Pad Diverter Line May Be Oriented
Different On Location
Page 12
J
11.0
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Drill 12-1/4" Hole Section
PU 12-1/4" directional drilling assembly:
• Ensure BHA components have been inspected previously.
• Drift and caliper all components before MU. Visually verify no debris inside components
that cannot be drifted.
• Ensure TF offset is measured accurately and entered correctly into the MWD software.
• Be sure to run a UBHO sub for wireline gyro
• Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
• Drill string will be 5", 19.54, 5-135, NC50.
• Run a solid float in the surface hole section.
11.2 Begin drilling out from 20" conductor at reduced flow rates to avoid broaching the conductor.
• Consider using a trash bit to clean out conductor to mitigate potential damage from debris in
conductor.
11.3 Drill 12-1/4" hole section to section TD, in the Schrader NB sand. Confirm this setting depth
with the Geologist and Drilling Engineer while drilling the well.
• Monitor the area around the conductor for any signs of broaching. If broaching is observed,
Stop drilling (or circulating) immediately notify Drilling Engineer.
• Efforts should be made to minimize dog legs in the surface hole. Keep DLS < 6°/ 100.
• Hold a safety meeting with rig crews to discuss:
• Conductor broaching ops and mitigation procedures.
Well control procedures and rig evacuation
Flow rates, hole cleaning, mud cooling, etc.
• Pump sweeps and maintain mud rheology to ensure effective hole cleaning.
• Keep mud as cool as possible to keep from washing out permafrost. .
• Pump at 400-600 GPM. Monitor shakers closely to ensure shaker screens and return lines
can handle the flow rate.
• Ensure to not out drill hole cleaning capacity, perform clean up cycles or reduce ROP if
packoffs, increase in pump pressure or changes in hookload are seen
• Slow in/out of slips and while tripping to keep swab and surge pressures low
• Ensure shakers are functioning properly. Check for holes in screens on connections.
• Have the flowline jets hooked up and be ready to jet the flowline at the first sign of pea
gravel, clay balling or packing off.
• Adjust MW and viscosity as necessary to maintain hole stability, ensure MW is at a 9.2 ppg
minimum at TD (pending MW increase due to hydrates).
• Perform wireline gyros until clean MWD surveys are seen. Take MWD surveys every stand
drilled.
• Gas hydrates have not been seen on M -Pad. However, be prepared for them. In MPU they
have been encountered typically around 2,100-2,400' TVD (just below permafrost). Be
prepared for hydrates:
Page 13
l
Milne Point Unit
M-43 SB Producer
Drilling Procedure
• Gas hydrates can be identified by the gas detector and a decrease in MW or ECD
• Monitor returns for hydrates, checking pressurized & non -pressurized scales
• Do not stop to circulate out gas hydrates — this will only exacerbate the problem by washing
out additional permafrost. Attempt to control drill (150 FPH MAX) through the zone
completely and efficiently to mitigate the hydrate issue. Flowrates can also be reduced to
prevent mud from belching over the bell nipple. Consider adding Lecithin to allow the gas to
break out.
• Gas hydrates are not a gas sand, once a hydrate is disturbed the gas will come out of the well.
MW will not control gas hydrates, but will affect how gas breaks out at surface.
• Surface Hole AC:
• There are no wells with a clearance factor of <1.0
11.4 12-1/4" hole mud program summary:
• Density: Weighting material to be used for the hole section will be barite. Additional barite
or spike fluid will be on location to weight up the active system (1) ppg above highest
anticipated MW. We will start with a simple gel + FW spud mud at 8.8 ppg and TD with -
9.2+ pp .
Depth Interval MW )
Surface — Base Permafrost 8.9+
Base Permafrost - TD 9.2+ For Hydrates if need based on offset wells
MW can be cut once —500' below hydrate zone
• PVT System: MD Totco PVT will be used throughout the drilling and completion phase.
Remote monitoring stations will be available at the driller's console, Co Man office,
Toolpusher office, and mud loggers office.
• Rheology: Aquagel and Barazan D+ should be used to maintain rheology. Begin system
with a 75 YP but reduce this once clays are encountered. Maintain a minimum 25 YP at all
times while drilling. Be prepared to increase the YP if hole cleaning becomes an issue.
• Fluid Loss: DEXTRID and/or PAC L should be used for filtrate control. Background LCM
(10 ppb total) BARACARBs/BAROFIBRE/STEELSEALs can be used in the system while
drilling the surface interval to prevent losses and strengthen the wellbore.
• Wellbore and mud stability: Additions of CON DET PRE-MIX/DRIL N SLIDE are
recommended to reduce the incidence of bit balling and shaker blinding when penetrating the
high -clay content sections of the Sagavanirktok and the heavy oil sections of the UGNU 4A.
Maintain the pH in the 8.5 — 9.0 range with caustic soda. Daily additions of ALDACIDE G /
X -GIDE 207 MUST be made to control bacterial action.
• Casing Running: Reduce system YP with DESCO as required for running casing as allowed
(do not jeopardize hole conditions). Run casing carefully to minimize surge and swab
pressures. Reduce the system rheology once the casing is landed to a YP < 20 (check with
the cementers to see what YP value they have targeted).
Page 14
n
Hilcorp
U ami,
System Type: 8.8 — 9.2 ppg Pre -Hydrated Aquagel/freshwater spud mud
Properties:
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Section
nsi Viscosity
Plastic Viscosity
Yield Point
API FL
pH
:ii
Surface
.8 — 9.8 75-175
20-40
25-45
<10
8.5-9.0
System Formulation: Gel + FW spud mud
Product- Surface hole
Size
Pkg
ppb or (% liquids)
M -I Gel
50
lb sx
25
Soda Ash
50
lb sx
0.25
Pol Pac Supreme UL
50
lb sx
0.08
Caustic Soda
50
lb sx
0.1
SCREENCLEEN
55
gal dm
0.5
11.5 At TD; PU 2-3 stands off bottom, CBU, pump tandem sweeps and drop viscosity.
11.6 RIH to bottom, proceed to BROOH to HWDP
• Pump at full drill rate (400-600 GPM), and maximize rotation.
• Pull slowly, 5 — 10 ft/minute, adjust as dictated by hole conditions
• Monitor well for any signs of packing off or losses.
• Have the flowline jets hooked up and be ready to jet the flowline at the first sign of clay
balling.
• If flow rates are reduced to combat overloaded shakers/flowline, stop back reaming until
parameters are restored.
11.7 TOOH and LD BHA
11.8 No open hole logging program planned.
Page 15
./
H
Hile
a.orp
� �2x
12.0
12.1
Run 9-5/8" Surface Casing
RU and pull wearbushing.
Milne Point Unit
M-43 SB Producer
Drilling Procedure
12.2 RU Weatherford 9-5/8" casing running equipment (CRT & Tongs)
• Ensure 9-5/8" TXP x DS50 XO on rig floor and M/U to FOSV.
• Use BOL 2000 thread compound. Dope pin end only w/ paint brush.
• RU of CRT if hole conditions require.
• RU a fill up tool to fill casing while running if the CRT is not used.
• Ensure all casing has been drifted to 8.750" on the location prior to running.
• Be sure to count the total # of joints on the location before running.
• Keep hole covered while RU casing tools.
• Record OD's, ID's, lengths, SN's of all components with vendor & model info.
12.3 PU shoe joint, visually verify no debris inside joint.
12.4 Continue MU & thread locking 120' shoe track assembly consisting of:
9-5/8"
Float Shoe
1 joint
— 9-5/8" TXP, 2 Centralizers 10' from each end w/ stop rings
1 joint
— 9-5/8" TXP, 1 Centralizer mid joint w/ stop ring
9-5/8"
Float Collar with Stage Cementer Bypass Baffle 'Top Hat'
1 joint
— 9-5/8" TXP, 1 Centralizer mid joint with stop ring
9-5/8"
HES Baffle Adaptor
• Ensure bypass baffle is correctly installed on top of float collar.
This end up.
Bypass Baffle
IN
• Ensure proper operation of float equipment while picking up.
• Ensure to record SN's of all float equipment and stage tool components.
Page 16
12.5 Float equipment and Stage tool equipment drawings:
Type H ES Cementer
Part No.
SO No.
Closing Sleeve
No. Shear Pins
Dpening Sleeve
No. Shear Pins
ES Cementerap
Depth
— Baffle Adapter (if used)
ID
Depth
— Bypass or Shut-off Baffle
ID
Depth
— Float Collar
Depth
Float Shoe
AT Depth
Hole TD
"Reference Casing
Sales Manual
Section 5
Page 17
"A
Rikorp 1 S11 Running aCer
6rerall Length
B
Milne Point unit
AUn. ID Ager Drillout
C
M-43 SB Producer
Max. Tcbl OD
Hilco
Drilling Procedure
12.5 Float equipment and Stage tool equipment drawings:
Type H ES Cementer
Part No.
SO No.
Closing Sleeve
No. Shear Pins
Dpening Sleeve
No. Shear Pins
ES Cementerap
Depth
— Baffle Adapter (if used)
ID
Depth
— Bypass or Shut-off Baffle
ID
Depth
— Float Collar
Depth
Float Shoe
AT Depth
Hole TD
"Reference Casing
Sales Manual
Section 5
Page 17
"A
Rikorp 1 S11 Running aCer
6rerall Length
B
AUn. ID Ager Drillout
C
Max. Tcbl OD
D
Open+g Seal ID
E
Closing Seat ID
Plug Set
Part No.
SO No.
Closing Plug
OD
Opening Plug
OD
OD
Shut -oft Plug
OD
Bypass Plug
(if used)
oD
Rikorp 1 S11 Running aCer
Eill Cementer,
:
sheat off Rrrg
Baine Atlapser
Byhss Rug
I
By pass Raft
Float Cellar
Fort Shue
12.6 Continue running 9-5/8" surface casing
• Fill casing while running using fill up line on rig floor.
• Use BOL 2000 thread compound. Dope pin end only with paint brush.
• Centralization:
• 1 centralizer every joint to 1,000' MD from shoe
• 1 centralizer every 2 joints to 2,000' above shoe (Ton of Lowest Ugnu)
• Verify depth of lowest Ugnu water sand for isolation with Geologist
• Utilize a collar clamp until weight is sufficient to keep slips set properly.
• Break circulation prior to reaching the base of the permafrost if casing run indicates poor
hole conditions.
• Any packing off while running casing should be treated as a major problem. It is preferable
to POH with casing and condition hole than to risk not getting cement returns to surface.
12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below
the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used).
�S • Install centralizers over couplings on 5 joints below and 5 joints above stage tool.
• Do not place tongs on ES cementer, this can cause damaged to the tool.
• Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3,300
psi.
• ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2,080 psi, and the tool
to open at — 3,000 psi. Reference ESIPC Procedure.
9-5/8" 40# L-80 TXP Make Up Torques:
Casing OD
Minimum
Optimum
Maximum
9-5/8"
18,860 ft -lbs
Milne Point Unit
23,060 ft -lbs
M-43 SB Producer
Hilco
E ��
Drilling Procedure
12.6 Continue running 9-5/8" surface casing
• Fill casing while running using fill up line on rig floor.
• Use BOL 2000 thread compound. Dope pin end only with paint brush.
• Centralization:
• 1 centralizer every joint to 1,000' MD from shoe
• 1 centralizer every 2 joints to 2,000' above shoe (Ton of Lowest Ugnu)
• Verify depth of lowest Ugnu water sand for isolation with Geologist
• Utilize a collar clamp until weight is sufficient to keep slips set properly.
• Break circulation prior to reaching the base of the permafrost if casing run indicates poor
hole conditions.
• Any packing off while running casing should be treated as a major problem. It is preferable
to POH with casing and condition hole than to risk not getting cement returns to surface.
12.7 Install the Halliburton Type H ES -II Stage tool so that it is positioned at least 100' TVD below
the permafrost (— 2,500' MD). (Halliburton ESIPC with packer element may be used).
�S • Install centralizers over couplings on 5 joints below and 5 joints above stage tool.
• Do not place tongs on ES cementer, this can cause damaged to the tool.
• Ensure tool is pinned with 6 opening shear pins. This will allow the tool to open at 3,300
psi.
• ESIPC: Ensure tool is pinned properly. ESIPC packer to inflate at — 2,080 psi, and the tool
to open at — 3,000 psi. Reference ESIPC Procedure.
9-5/8" 40# L-80 TXP Make Up Torques:
Casing OD
Minimum
Optimum
Maximum
9-5/8"
18,860 ft -lbs
20,960 ft -lbs
23,060 ft -lbs
Ar
Page 18
H
Hilcorp
Eev®' Compmy
TXPC BTC
Outside Diameter
9.525 in.
Min. Wall
ST5%
COUPLING
PIPE BODY
Thickness
istsand: Rae
Wall Thickness
B395m_
Connection OD
REGULAR
31 Band: -
3I. Bard: -
Option
4fi Ban.: -
Graee
LSO Type V
Drift
API Standard!
Campresaion Ef ienry 100'x:
Compression SRengih
Type
Casirer
Page 19
Milne Point Unit
M-43 SB Producer
Drilling Procedure
11108/2018
I1 Grade LBO
j
Type 1
[enaction DD Option REGULAR
COUPLING
PIPE BODY
Eody: Rea
istsand: Rae
lot Bari: armor
tri Sand:
2nd Bard: -
Brown
31 Band: -
3I. Bard: -
916000x1000
4fi Ban.: -
GEOMETRY
Ti per.
5
[enaction DD Option REGULAR
I
riominal OD
Nominal lC
9.625 in
8.835 in.
Nominal liVegi
VWThicknEss
40 11,01
0.395 m.
Doe
Plain End y'Right
8.679in.
3697 lbsR
OD Tak ante API
PERFORMANCE
Body veld strength 916 x1000 1tr nuaru YieU 5750 psi smys SDODD psi
Ccfli 3090 psi
GEOMETRY
Coarw+etun OD 10.625 in. Coupling Length 10.825 m. Connection ID 9,823 in.
Maki Lass 6.891 in.
Ti per.
5
[enaction DD Option REGULAR
PERFORMANCE
Tension Effeiency 100.0%
rim Vied spiIi
916000x1000
Internal Pressure Capacity In 5750.000 psi
lips
Campresaion Ef ienry 100'x:
Compression SRengih
91S 000 x1000
Max. NlOii fientling 38'100 ft
lbs
Eiaemal Presscre Capacity 3090.005 psi
MAKE-UP TORQUES
Mimi 18860 M -lbs Optimum 20860 Rads Maximum 23060 ftJhs
OPERATION LIMIT TORQUES
Operating Torque 35600 ft -lbs Yield Torque 43400 No.
Notes
This connection is fully interchangeable with:
TXM BTC -9.625 in.- 36 i 43.5147153.5158.411
[1] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section 10.3 API
5C3 I ISO 10400 - 2007.
Datasheet is also valid for Special Bevel option when applicable - except for Coupling Face Load, which will be reduced
Please contact a local Tennis technical sales representative.
H
Hilcorp
En�W'Compnny
Milne Point Unit
M-43 SB Producer
Drilling Procedure
12.8 Continue running 9-5/8" surface casing
• Fill casing while running using fill up line on rig floor.
• Use BOL 2000 thread compound. Dope pin end only with paint brush.
• Centralization:
• 1 centralizer every 2 joints to base of conductor
12.9 Watch displacement carefully and avoid surging the hole. Slow down running speed if
necessary.
12.10 Slow in and out of slips.
12.11 PU landing joint and MU to casing string. Position the casing shoe ±10' from TD. Strap the
landing joint prior to the casing job and mark the joint at (1) ft intervals to use as a reference
when getting the casing on depth.
12.12 Lower casing to setting depth. Confirm measurements.
12.13 Have slips staged in cellar, along with necessary equipment for the operation.
12.14 Circulate and condition mud through CRT. Reduce YP to < 20 to help ensure success of cement
job. Ensure adequate amounts of cold MU water are available to achieve this. If possible
reciprocate casing string while conditioning mud.
l
Page 20
n
Hilo
Eu Co T
13.0 Cement 9-5/8" Surface Casing
Milne Point Unit
M-43 SB Producer
Drilling Procedure
13.1 Hold a pre job safety meeting over the upcoming cement operations. Make room in pits for
volume gained during cement job. Ensure adequate cement displacement volume available as
well. Ensure mud & water can be delivered to the cementing unit at acceptable rates.
• How to handle cement returns at surface. Ensure vac trucks are on standby and ready to
assist.
• Which pumps will be utilized for displacement, and how fluid will be fed to displacement
PUMP.
• Ensure adequate amounts of water for mix fluid is heated and available in the water tanks.
• Positions and expectations of personnel involved with the cementing operation.
i. Extra hands in the pits to strap during the cement job to identify any losses
• Review test reports and ensure pump times are acceptable.
• Conduct visual inspection of all hard lines and connections used to route slurry to rig floor.
13.2 Document efficiency of all possible displacement pumps prior to cement job.
13.3 Flush through cement pump and treating iron from pump to rig floor to the shakers. This will
help ensure any debris left in the cement pump or treating iron will not be pumped downhole.
13.4 RU cement line (if not already done so). Company Rep to witness loading of the top and bottom
plugs to ensure done in correct order.
13.5 Fill surface cement lines with water and pressure test.
13.6 Pump remaining 60 bbls 10.5 ppg tuned spacer.
13.7 Drop bottom plug (flexible bypass plug) — HEC rep to witness. Mix and pump cement per below
calculations for the 1St stage, confirm actual cement volumes with cementer after TD is reached.
13.8 Cement volume based on annular volume + 30% open hole excess. Job will consist of lead &
tail, TOC brought to stage tool.
tis G 2 5
S� Estimated 11' Stage Total Cement Volume:
Page 21
(Sr')
S3Zy,'
3 � L� -3x
Section
Calculation
Vol (bbl)
Vol (ft3)
12-1/4' OH x 9-5/8"
�
(5,508'- 2,500') x .0558 bpf x 1.3 =
218.2
1225
J
Casing
Total Lead
218.2
1225
12-1/4" OH x 9-5/8"
(6,508' - 5,508') x .0558 bpf x 1.3 =
72.5
407
—
Casing
~
9-5/8" Shoe Track
120'x .0758 bpf =
9.1
51.09
Total Tail
81.6
458
Page 21
(Sr')
S3Zy,'
3 � L� -3x
Cement Slurry Design (111 Stage Cement Job):
Lead Slurry
Tail Slurry
Density
12.0 lb/gal
15.8 lb/gal
Milne Point Unit
2.35 ft3/sk ✓
1.16 ft3/sk
Mixed Water
M-43 SB Producer
4.98 gal/sk
Hilcorp
Eo W c=Wy
Drilling Procedure
Cement Slurry Design (111 Stage Cement Job):
13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch
reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue
with the cement job.
13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of
mud pits, spotting water across the HEC stage cementer.
• Ensure volumes pumped and volumes returned are documented and constant communication
between mud pits, HEC Rep and HES Cementers during the entire job.
13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very
accurate using 0.0625 BPS (5" liners) for the Quattro pump output. To operate the stage tool
hydraulically, the plug must be bumped.
13.11 Displacement calculation: d 1`
6,388' x.0758 BPF = 484.2 bbls
80 bbls of tuned spacer to be left behind stage tool
13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any
point during the job. Be prepared to pump out fluid from cellar. Have black water available to
contaminate any cement seen at surface.
13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over
displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling
Engineer.
13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening
plug is available if needed. This is the back-up option to open the stage tool if the plugs are not
bumped.
13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats
are holding. If floats do not hold, pressure up string to final circulating pressure and hold until
cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating
pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened.
Page 22
Lead Slurry
Tail Slurry
Density
12.0 lb/gal
15.8 lb/gal
Yield
2.35 ft3/sk ✓
1.16 ft3/sk
Mixed Water
13.92 gal/sk
4.98 gal/sk
13.8 Attempt to reciprocate casing during cement pumping if hole conditions allow. Watch
reciprocation PU and SO weights, if the hole gets "sticky", cease pipe reciprocation and continue
with the cement job.
13.9 After pumping cement, drop top plug (Shutoff plug) and displace cement with spud mud out of
mud pits, spotting water across the HEC stage cementer.
• Ensure volumes pumped and volumes returned are documented and constant communication
between mud pits, HEC Rep and HES Cementers during the entire job.
13.10 Ensure rig pump is used to displace cement. Displacement calculations have proven to be very
accurate using 0.0625 BPS (5" liners) for the Quattro pump output. To operate the stage tool
hydraulically, the plug must be bumped.
13.11 Displacement calculation: d 1`
6,388' x.0758 BPF = 484.2 bbls
80 bbls of tuned spacer to be left behind stage tool
13.12 Monitor returns closely while displacing cement. Adjust pump rate if losses are seen at any
point during the job. Be prepared to pump out fluid from cellar. Have black water available to
contaminate any cement seen at surface.
13.13 If plug is not bumped at calculated strokes, double check volumes and calculations. Over
displace by no more than 50% of shoe track volume, t4.5 bbls before consulting with Drilling
Engineer.
13.14 If plug is not bumped, consult with Drilling Engineer. Ensure the free fall stage tool opening
plug is available if needed. This is the back-up option to open the stage tool if the plugs are not
bumped.
13.15 Bump the plug with 500 psi over displacement pressure. Bleed off pressure and confirm floats
are holding. If floats do not hold, pressure up string to final circulating pressure and hold until
cement is set. Monitor pressure build up and do not let it exceed 500 psi above final circulating
pressure if pressure must be held, this is to ensure the stage tool is not prematurely opened.
Page 22
13.16 Increase pressure to 3.300 psi to
in stage collar. Slightly higher pressure
may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns
to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation
for the 2"d stage of the cement job.
13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker
bypass line to the cuttings tank. Have black water available and vac trucks ready to assist.
Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact
with the cement.
Page 23
Milne Point unit
M-43 SB Producer
HilcolTy
Erc T2
Drilling Procedure
13.16 Increase pressure to 3.300 psi to
in stage collar. Slightly higher pressure
may be necessary if TOC is above the stage tool. CBU and record any spacer or cement returns
to surface and volume pumped to see the returns. Circulate until YP < 20 again in preparation
for the 2"d stage of the cement job.
13.17 Be prepared for cement returns to surface. Dump cement returns in the cellar or open the shaker
bypass line to the cuttings tank. Have black water available and vac trucks ready to assist.
Ensure to flush out any rig components, hard lines and BOP stack that may have come in contact
with the cement.
Page 23
H
Hilcorp
E� Cumpmy
Second Stage Surface Cement Job:
Milne Point Unit
M-43 SB Producer
Drilling Procedure
13.18 Prepare for the 2"d stage as necessary. Circulate until first stage reaches sufficient compressive
strength. Try to maintain flow rate through stage tool until 2"d stage is ready. Hold pre job safety
meeting.
• Past wells have seen pressure increase while circulating through stage tool after reduced rate
13.19 HEC representative to witness the loading of the ES cementer closing plug in the cementing
head.
13.20 Fill surface lines with water and pressure test.
13.21 Pump remaining 60 bbls of 10.5 ppg tuned spacer.
13.22 Mix and pump cement per below recipe for the 2"d stage.
13.23 Cement volume based on annular volume + open hole excess (2001/o for lead and 100% for tail).
Job will consist of lead & tail, TOC brought to surface. However cement will continue to be
pumped until clean spacer is observed at surface.
.2,o 3 K
Estimated 2"d Stage Total Cement Volume:
Cement Slurry Design (2nd stage cement job):
Section
Calculation
Vol (bbl)
Vol (ft3)
20" Conductor x 9-5/8" Casing
110') x.26 bpf x 1 =
28.6
161
J
12-1/4" OH x 9-5/8" Casing
(2000' - 110') x .0558 b f x 3 =
316.4
1776.3
Total Lead
345
1937
12-1/4" OH x 9-5/8" Casing
(2500' - 2000') x .0558 b f x 2 =
55.8
314
Total Tail
55.8
314
Cement Slurry Design (2nd stage cement job):
Page 24
Lead Slurry
Tail Slurry
System
Permafrost L
Density
10.7 lb/gal
15.8 lb/gal
Yield
4.41 ft3lsV
1.17 ft3/sk
Mixed Water
22.02 gal/sk
5.08 gal/sk
Page 24
H
Hilcorp
Milne Point Unit
M-43 SB Producer
Drilling Procedure
13.24 Continue pumping lead until uncontaminated spacer is seen at surface, then switch to tail.
13.25 After pumping cement, drop ES Cementer closing plug and displace cement with spud mud out
of mud pits.
13.26 Displacement calculation:
2,500' x .0758 BPF = 190 bbls mud
13.27 Monitor returns closely while displacing cement. Adjust pump rate if necessary. Wellhead side
outlet valve in cellar can be opened to take returns to cellar if required. Be prepared to pump out
fluid from cellar. Have black water available to retard setting of cement.
13.28 Decide ahead of time what will be done with cement returns once they are at surface. We should
circulate approximately 100 - 150 bbls of cement slurry to surface. '
13.29 Land closing plug on stage collar and pressure up to 1,000 — 1,500 psi to ensure stage tool closes.
Follow instructions of Halliburton personnel. Bleed off pressure and check to ensure stage tool
has closed. Slips will be set as per plan to allow frill annulus for returns during surface cement
job. Set slips
13.30 Make initial cut on 9-5/8" final joint. LD cut joint. Make final cut on 9-5/8". Dress off stump.
Install 9-5/8" wellhead. If transition nipple is welded on, allow to cool as per schedule.
Ensure to report the following on wellez:
• Pre flush type, volume (bbls) & weight (ppg)
• Cement slurry type, lead or tail, volume & weight
• Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration
a. Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight
& type of displacing fluid
b. Note if casing is reciprocated or rotated during the job
c. Calculated volume of displacement, actual displacement volume, whether plug bumped &
bump pressure, do floats hold
d. Percent mud returns during job, if intermittent note timing during pumping of job. Final
circulating pressure
e. Note if pre flush or cement returns at surface & volume
f. Note time cement in place
g. Note calculated top of cement
h. Add any continents which would describe the success or problems during the cement job
Send final ",4s -Run " casing tally & casing and cement report to iennelna hilcorp. com and
cdineerna hilcorn. com This will be included with the EOW documentation that izoes to the AOGCC
Page 25
H
HilmTE.� ��,
14.0 ND Diverter, NU BOPE, & Test
Milne Point Unit
M-43 SB Producer
Drilling Procedure
14.1 ND the diverter T, knife gate, diverter line & NU 11" x 13-5/8" 5M casing spool.
14.2 NU 13-5/8" x 5M BOP as follows:
• BOP configuration from top down: 13-5/8" x 5M annular / 13-5/8" x 5M double gate / 13-
5/8" x 5M mud cross / 13-5/8" x 5M single gate 31j, x ( -;i, b. N-- -- s; yC eA A,,
• Double gate ram should be dressed with x " VBRs in top cavity, blind ram in
bottom cavity.
• Single ram can be dressed with 4-1/2" x 7" VBRs /vim G
• NU bell nipple, install flowline. 6
• Install (1) manual valve & HCR valve on kill side of mud cross. (Manual valve closest to
mud cross).
• Install (1) manual valve on choke side of mud cross. Install an HRC outside of the manual
valve
14.3 RU MPD RCD and related equipment.
14.4 Run 5" BOP test plug.
14.5 Test BOP to 250/3,000 psi for 5/5 min. Test annular to 250/2,500 psi for 5/5 min.
• Test with 5" test joint
• Confirm test pressures with PTD
• Ensure to monitor side outlet valves and annulus valve pressure gauges to ensure no pressure
is trapped underneath test plug
• Once BOPE test is complete, send a copy of the test report to town engineer and drilling tech
14.6 RD BOP test equipment
14.7 Dump and clean mud pits, send spud mud to G&I pad for injection.
14.8 Mix 8.9 ppg F1oPro fluid for production hole.
14.9 Set wearbushing in wellhead.
14.10 If needed, rack back as much 5" DP in derrick as possible to be used while drilling the hole
section.
14.11 Ensure 6" liners in mud pumps.
Page 26
15.0 Drill 8-1/2" Hole Section
15.1 MU 8-1/2" Cleanout BHA (Milltooth Bit & 1.22° PDM).
Milne Point Unit
M-43 SB Producer
Drilling Procedure
15.2 TIH with 8-1/2" cleanout BHA to stage tool. Note depth TOC tagged on AM report. Drill out
stage tool.
15.3 TIH to TOC above the �baffle adapter. Note depth TOC tagged on morning report.
15.4 RU and PT casing to 2,500 psi for 30 minutes charted. Ensure to record volume / pressure
(every '/4 bbl) and plot on FIT graph. AOGCC reg is 50% of burst = 5,750 / 2 = —2,875 psi, but
max test pressure on the well is 2,500 psi as per AOGCC. Document incremental volume
pumped (and subsequent pressure) and volume returned. Ensure rams are used to test casing as
per AOGCC Industry Guidance Bulletin 17-001.
15.5 Drill out shoe track and 20' of new formation.
15.6 CBU and condition mud for FIT.
15.7 Conduct FIT to 12.0 ppg EMW. Chart Test. Ensure test is recorded on same chart as FIT.
Document incremental volume pumped (and subsequent pressure) and volume returned.
15.8 POOH and LD Cleanout BHA.
15.9 PU 8-1/2" directional BHA.
• Ensure BHA components have been inspected previously.
• Drift and caliper all components before MU. Visually verify no debris inside components
that cannot be drifted.
• Ensure TF offset is measured accurately and entered correctly into the MWD software.
• Ensure MWD is RU and operational.
• Have DD run hydraulics calculations on site to ensure optimum nozzle sizing. Hydraulics
calculations and recommended TFA is attached below.
• Drill string will be 5", 19.5#, 5-135, DS50 & NC50.
• Run a ported float in the production hole section.
15.10 8-1/2" hole section mud program summary:
• Density: Weighting material to be used for the hole section will be calcium carbonate.
Additional calcium carbonate will be on location to weight up the active system (1) ppg
above highest anticipated MW.
Solids Concentration: It is imperative that the solids concentration be kept low while
drilling the production hole section. Keep the shaker screen size optimized and fluid running
Page 27
Milne Point Unit
M-43 SB Producer
Drilling Procedure
to near the end of the shakers. It is okay if the shakers run slightly wet to ensure we are
running the finest screens possible.
• Rheology: Keep viscosifier additions to an absolute minimum (N -VIS). Data suggests
excessive viscosifier concentrations can decrease return permeability. Do not pump high vis
sweeps, instead use tandem sweeps. Ensure 6 rpm is > 8-1/2" (hole diameter) for sufficient
hole cleaning
• Run the centrifuge continuously while drilling the production hole, this will help with solids
removal.
• Dump and dilute as necessary to keep drilled solids to an absolute minimum.
• MD Totco PVT will be used throughout the drilling and completion phase. Remote
monitoring stations will be available at the driller's console, Co Man office, & Toolpusher
office.
System Type: 8.9 — 9.5 ppg F1oPro drilling fluid
Properties:
Interval
Size
I PV
I YP
I LSYP
Total Solids
MBT
HPHT
Hardness
Production
8.9-9.5
15-25 - ALAP
1 15 - 30
1 4-6
<10%
<8
<11.0
<100
System Fornl ation:
Product- production
Size
Pkg
ppb or (% liquids)
Busan 1060
55
gal dm
0.095
FLOTROL
55
lb sx
6
CONQOR 404 WH (8.5 gal/100 bbls)
55
gal dm
0.2
FLO-VIS PLUS
25
lb sx
0.7
KCI
50
lb sx
10.7
SMB
50
lb sx
0.45
LOTORQ
55
gal dm
1.0
SAFE-CARB 10 (verify)
50
lb sx
10
SAFE-CARB 20 (verify)
50
lb sx
10
Soda Ash
50
lb sx
0.5
Page 28
N
Hileorp
p . Mrlp
15.11 TIH with 8-1/2" directional assembly to bottom.
15.12 Install MPD RCD.
15.13 Displace wellbore to 8.9 ppg Flo Pro drilling fluid
Milne Point Unit
M-43 SB Producer
Drilling Procedure
15.14 Begin drilling 8-1/2" hole section, on -bottom staging technique:
• Tag bottom and begin drilling with 100 - 120 RPMs at bit. Allow WOB to stabilize at 5-8K.
• Slowly begin bringing up rpms, monitoring stick slip and BHA vibrations
• If BHA begins to show excessive vibrations / whirl / stick slip, it may be necessary to PU
off bottom and restart on bottom staging technique. If stick slip continues, consider adding
0.5% lubes
15.14 Drill 8-1/2" hole section to section TD ner Geologist and Drilling Engineer.
• Flow Rate: 350-550 GPM, target min. AV's 200 FPM, 385 GPM
• RPM: 120+
• Ensure shaker screens are set up to handle this flowrate. Ensure shakers are running slightly
wet to maximize solids removal efficiency. Check for holes in screens on every connection.
• Keep pipe movement with pumps off to slow speeds, to keep surge and swab pressures low
• Take MWD surveys every stand, can be taken more frequently if deemed necessary, ex:
concretion deflection
• Monitor Torque and Drag with pumps on every 5 stands
• Monitor ECD, pump pressure & hookload trends for hole cleaning indication
• Surveys can be taken more frequently if deemed necessary.
• Good drilling and tripping practices are vital for avoidance of differential sticking. Make
every effort to keep the drill string moving whenever possible and avoid stopping with the
BHA across the sand for any extended period of time.
• Use ADR to stay in section. Reservoir plan is to stay in NB/NC sand.
• Limit maximum instantaneous ROP to < 250 FPH. The sands will drill faster than this, but
when concretions are hit when drilling this fast, cutter damage can occur.
• Target ROP is as fast as we can clean the hole without having to backream connections
• Schrader Bluff Concretions: 5-10% of lateral
• MPD will be utilized to monitor pressure build up on connections.
• 8-1/2" Lateral A/C:
• There are no wells with a clearance factor <1.0
15.15 Reference: Open hole sidetracking practice:
• If a known fault is coming up, put a slight "kick-off ramp" in wellbore ahead of the fault so
we have a nice place to low side.
• Attempt to lowside in a fast drilling interval where the wellbore is headed up.
• Orient TF to low side and dig a trough with high flowrates for the first 10 feet, working
string back and forth. Trough for approximately 30 minutes.
• Time drill at 4 to 6 feet per hour with high flow rates. Gradually increase ROP as the
onenhole sidetrack is achieved.
Page 29 /
H
Hilcorp
e��y comy.e,
Milne Point Unit
M-43 SB Producer
Drilling Procedure
15.16 At TD, CBU at least 4 times at 200 ft/min AV (385+ GPM) and rotation (120+ RPM). Pump
tandem sweeps if needed
• Monitor BU for increase in cuttings, cuttings in laterals come back in waves and not a
consistent stream, circulate more if necessary
• If seepage losses are seen while drilling, consider reducing MW at TD to 9.0 ppg minimum
15.17 Mix and pump 40 bbl 10 ppb SAPP pill. Line up to a closed loop system and circulate three SAP
pills with 50 bbl in between. Displace out SAP pills. Monitor shakers for returns of mud filter
cake and calcium carbonate. Circulate the well clean.
• Losses during the cleanup of the wellbore are a good indication that the mud filter cake is
being removed, including an increase in the loss rate.
15.18 Displace 1.5 OH + Liner volume with viscosified brine.
• Proposed brine blend (aiming for an 8 on the 6 RPM reading) -
KCl:
7.1bbp for 2%
NaCl:
60.9 ppg for 9.4 ppg
Lotorq:
1.5%
Lube 776:
1.5%
Soda Ash:
as needed for 9.5pH
Busan 1060:
0.42 ppb
Flo -Vis Plus:
1.25 ppb
• Monitor well for loss rate and contact Drilling Engineer and/or Ops Engineer if further
discussion needed prior to BROOK
15.19 Monitor the returned fluids carefully while displacing to brine. After 4 (or more) BU, Perform
production screen test (PST). The brine has been properly conditioned when it will pass the.
production screen test (0 350 ml samples passing through the screen in the same amount of
time which will indicate no plugging of the screen). Reference PST Test Procedure
15.20 BROOH with the drilling assembly to the 9-5/8" casing shoe
• Circulate at full drill rate (less if losses are seen, 350 GPM).
• Rotate at maximum rpm that can be sustained.
Pulling speed 5 — 10 min/stand (slip to slip time, not including connections), adjust as
dictated by hole conditions.
If back reaming operations are commenced, continue back reaming to the shoe
Page 30
H
Hilc
E'er cjorp
m�,
Milne Point Unit
M-43 SB Producer
Drilling Procedure
15.21 If abnormal pressure has been observed in the lateral, utilize MPD to close on connections while
BROOK
15.22 CBU minimum two times at 9-5/8" shoe and clean casing with high vis sweeps.
15.23 Monitor well for flow / monitor for pressure build up with MPD. Increase fluid weight if
necessary
• Wellbore breathing has been seen on past MPU SB wells. Perform extended flow checks to
determine if well is breathing, treat all flow as an influx until proven otherwise
15.24 POOH and LD BHA.
15.25 Continue to POOH and stand back BHA if possible. Rabbit DP on TOOH, ensure rabbit
diameter is sufficient for future ball drops.
15.26 Only LWD open hole logs are planned for the hole section (GR + Res). There will not be any
additional logging runs conducted.
Page 31
H
Hilcorp
Ute.,..,
16.0 Run 4-1/2" Screen Liner
Milne Point Unit
M-43 SB Producer
Drilling Procedure
16.1 Confirm VBR's have been tested on 4-1/2" and 5" test joints to 250/3,000 psi.
16.2 Well control nrenaredness: In the event of an influx of formation fluids while running the 4-
1/2" production screens, the following well control response procedure will be followed:
• PU & MU the 5" safety joint (with 4-1/2" crossover installed on bottom, TIW valve in open
position on top, 4-1/2" handling joint above TIW). This joint shall be fully MU and available
prior to running the first joint of 4-1/2" screen.
• Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close
TIW valve.
• Proceed with well kill operations.
16.3 If an inner string is ran, Well control preparedness: In the event of an influx of formation
fluids while running the 2-3/8" inner string inside the 4-1/2" production screens:
• PU & MU the 5" safety joint (with 4-1/2" x 2-3/8" triple connect crossover installed on
bottom, TIW valve in open position on top, 2-3/8" handling joint above TIW). MU 2-3/8"
and then 4-1/2" to triple connect.
• This joint shall be fully MU with crossovers prior to running the first joint of wash pipe.
• Slack off and position the 5" DP across the BOP, shut in ram or annular on 5" DP. Close
TIW valve. Proceed with well kill operations.
16.4 RU 4-1/2" screen running equipment.
• Ensure 4-1/2" x NC -50 crossover is on rig floor and MU to FOSV.
• Ensure all casing has been drifted on the deck prior to running.
• Be sure to count the total # of joints on the deck before running.
Keep hole covered while RU casing tools.
Record OD's, ID's, lengths, SN's of all components w/ vendor & model info.
16.5 Run 4-1/2" screen production liner — Reference screen handling and running procedure.
• Use Best O Life 2000 AG thread compound. Dope pin end only with paint brush. Wipe off
excess. Thread compound will plug the screens.
• Utilize a collar clamp until weight is sufficient to keep slips set properly.
• Run packoff and float shoe on bottom.
• 4-1/2" Screens should auto —fill, top off with completion brine if needed
• Swell packers will not be required on this completion unless the well is drilled out of zone
• If needed, install swell packers as per the lower completion tally.
• Remove protective packaging on swell packers just prior to picking up
• Do not place tongs or slips on the packer element
4-1/2",13.5 #, L-80, Hydril 625 Torque
OD
Minimum
Optimum
Operating Torque
4-1/2"
8,000 ft -lbs
9,600 ft -lbs
12,800 ft -lbs
Page 32
Milne Point Unit
M-43 SB Producer
Hilcol-T Drilling Procedure
E1-22
Wedge 625(P) 1013112017
Omide Diameter4.500
in
Min. Wall
87.6
GEOMETRY
Thickness
P) Grade L80
Naninal00
4.500 in.
Nominal Weight
13MItet
Type 1
3195 in.
Wall Thickness
0,280 in
Connectwn OD
REGULAR
COUPLING
PIPE BODY
OD T.L ii.
API
Option
PERFORMANCE
8o0y: Red
1si Band: Red
Grade
LBO Type V
Drift
API SL ndard
1st Bard: Broom
2nd Bald'.
CceiEw
8540 psi
2nd Bard:.
Brown
(=ONNECTION DATA
3d Band: -
3rd Band: -
GEOMETRY
Type
Casing
4th Band :-
PIPE BODY DATA
GEOMETRY
Naninal00
4.500 in.
Nominal Weight
13MItet
Drift
3195 in.
Nominal ID
3320 in.
Wall Thiishress
0190m
PlainE Weight
13.051bs.Nt
OD T.L ii.
API
PERFORMANCE
Body Yield s enph
307 c1DDD lbs
Imenal Yield
9020 Psi
sMYs
80000 psi
CceiEw
8540 psi
(=ONNECTION DATA
GEOMETRY
Cormclion 00
4.714 in.
Conneanon ID
3SO in.
Mali Lass
4.830 in.
Threads per in
3.59
Conneoeon OD OpMn
REGULAR
PERFORMANCE
Tension ESwtienry
91.0%
Joint Yield Strength
279.370xff)W
Internal Pressure Capacity
9020.000 Psi
Ibs
Caopression Elfiaency
94.5%
Campressoon Stnsrrh
290.1150000
Max. Allowable Ben&n8
73.7'!1008
bs
External Pressure Capacity
BUD -000 psi
MAKE-UP TORQUES
Minimum
80001
Optimum
9800 ft4bs
Maximum
12800 fl -lbs
OPERATION LIMB TORQUES
OperatinBTorque
128001
Yield Toryue
15000 fl-Ibs
Page 33
H
HilcoI
E.�C�.
Milne Point Unit
M-43 SB Producer
Drilling Procedure
16.6. Ensure to run enough liner to provide for approx 150' overlap inside 9-5/8" casing. Ensure
hanger/packer will not be set in a 9-5/8" connection.
• AOGCC regulations require a minimum 100' overlap between the inner and outer strings as
per 20 AAC 25.030(d)(6). Do not place liner hanger/packer across 9-5/8" connection.
16.7. Before picking up Baker SLZXP liner hanger / packer assembly, count the # of joints on the pipe
deck to make sure it coincides with the pipe tally.
16.8. MU Baker SLZXP liner top packer to 4-1/2" liner.
16.9. Inner string may or not be ran, depending on out of zone excursion and condition of lateral. Have
2-3/8" inner string available if needed.
16.10. Note: PU, SO, ROT and torque of liner. Run liner in the hole one stand and pump through liner
hanger to ensure a clear flow path exists.
16.11. RIH with liner on 5" HWDP no faster than 30 ft/min — this is to prevent buckling the liner and
drill string and weight transfer to get liner to bottom with minimal rotation. Watch displacement
carefully and avoid surging the hole or buckling the liner. Slow down running speed if
necessary.
• Ensure 5" HWDP has been drifted
• There is no inner string planned to be run, as opposed to previous wells. The DP should auto
fill. Monitor FL and if filling is required due to losses/surging.
16.12. Slow in and out of slips. Ensure accurate slack off data is gathered during RIH. Record shoe
depth + SO depth every stand. Record torque value if it becomes necessary to rotate the string to
bottom.
16.13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
& 20 RPM.
16.14. If any open hole sidetracks have been drilled, monitor sidetrack depths during run in and ensure
shoe enters correct hole.
16.15. TIH deeper than planned setting depth. Last motion of the liner should be up to ensure it is set in
tension.
16.16. Rig up to pump down the work string with the rig pumps.
16.17. Break circulation. Begin circulating at —1 BPM and monitor pump pressures. Do not exceed
1,600 psi while circulating. Pusher tool is set at 2,100 psi with 5% shear screws but it should be
discussed before exceeding 1,600 psi. Note all losses. Confirm all pressures with Baker.
Page 34
16.18. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill
pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger.
16.19. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the
WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do
not allow ball to slam into ball seat.
16.20. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes.
Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in
compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi
to release the HRDE running tool.
16.21. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without
pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20
RPM and set down 50K again.
16.22. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted.
16.23. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If
packer did not test, rotating dog sub can be used to set packer. If running tool cannot be
hydraulically released, apply LH torque to mechanically release the setting tool.
16.24. PU pulling running tool free of the packer and displace with at max rate to wash the liner top.
Pump sweeps as needed.
16.25. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned,
LD DP on the TOOK
Note: Once running tool is LD, swap to the completion AFE.
16.26. MU 3-1/2" wash tool and RIH with remaining DP out of derrick to liner top.
16.27. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well
to clean filtered brine after no solids are returned.
16.28. POOH and LD remaining 5" HWDP
Page 35
Milne Point Unit
M-43 SB Producer
Hilco
row
Drilling Procedure
16.18. Prior to setting the hanger and packer, double check all pipe tallies and record amount of drill
pipe left on location. Ensure all numbers coincide with proper setting depth of liner hanger.
16.19. Shut down pumps. Drop setting ball (ball seat now located in HRDE setting tool and not at the
WIV) down the workstring and pump slowly (1-2 BPM). Slow pump before the ball seats. Do
not allow ball to slam into ball seat.
16.20. Continue pressuring up to 2,700 psi to set the SLZXP liner hanger/packer. Hold for 5 minutes.
Slack off 20K lbs on the SZXP liner hanger/packer to ensure the HRDE setting tool is in
compression for release from the SLZXP liner hanger/packer. Continue pressuring up 4,500 psi
to release the HRDE running tool.
16.21. Bleed DP pressure to 0 psi. Pick up to expose rotating dog sub and set down 50K without
pulling sleeve packoff. Pick back up without pulling sleeve packoff, begin rotating at 10-20
RPM and set down 50K again.
16.22. PU to neutral weight, close BOP and test annulus to 1,500 psi for 10 minutes charted.
16.23. Bleed off pressure and open BOPE. Pickup to verify that the HRD setting tool has released. If
packer did not test, rotating dog sub can be used to set packer. If running tool cannot be
hydraulically released, apply LH torque to mechanically release the setting tool.
16.24. PU pulling running tool free of the packer and displace with at max rate to wash the liner top.
Pump sweeps as needed.
16.25. POOH. LD and inspect running tools. If setting of liner hanger/packer proceeded as planned,
LD DP on the TOOK
Note: Once running tool is LD, swap to the completion AFE.
16.26. MU 3-1/2" wash tool and RIH with remaining DP out of derrick to liner top.
16.27. Wash through liner top at max rate and circulate hole clean. Pump sweeps around. Displace well
to clean filtered brine after no solids are returned.
16.28. POOH and LD remaining 5" HWDP
Page 35
17.0 Run 7" Tieback
17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder
to be used for tie -back space out calculation.
17.2 Confirm 4-1/2" x 7" VBRs have been tested with 7" test joint to 250/3,000 psi.
17.3 RU 7" casing handling equipment.
• Ensure XO to DP made up to FOSV and ready on rig floor.
• Rig up computer torque monitoring service.
• String should stay full while running, RU fill up line and check as appropriate.
17.4 PU 7" tieback seal assembly and set in rotary table. Ensure 7" seal assembly has (4) 1" holes
above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7"
annulus.
17.5 M/U first joint of 7" to seal assembly.
17.6 Run 7", 26#, L-80, TXP tieback to position seal assembly two joints above tieback sleeve.
Record up & down weights.
7" 26# TXP MU Torque
OD
Minimum
Optimum
Maximum
Yield Torque
7"
Milne Point unit
14,750 ft -lbs
16,230 ft -lbs
23,400 ft -lbs
M-43 SB Producer
HilHilcol�Ty
cmnpmy
Drilling Procedure
17.0 Run 7" Tieback
17.1 RU and pull wear bushing. Get an accurate measurement of RKB to tubing hanger load shoulder
to be used for tie -back space out calculation.
17.2 Confirm 4-1/2" x 7" VBRs have been tested with 7" test joint to 250/3,000 psi.
17.3 RU 7" casing handling equipment.
• Ensure XO to DP made up to FOSV and ready on rig floor.
• Rig up computer torque monitoring service.
• String should stay full while running, RU fill up line and check as appropriate.
17.4 PU 7" tieback seal assembly and set in rotary table. Ensure 7" seal assembly has (4) 1" holes
above the first seal. These holes will be used to spot diesel freeze protect in the 9-5/8" x 7"
annulus.
17.5 M/U first joint of 7" to seal assembly.
17.6 Run 7", 26#, L-80, TXP tieback to position seal assembly two joints above tieback sleeve.
Record up & down weights.
7" 26# TXP MU Torque
OD
Minimum
Optimum
Maximum
Yield Torque
7"
13,280 ft -lbs
14,750 ft -lbs
16,230 ft -lbs
23,400 ft -lbs
Page 36
TXPO BTC
Page 37
Milne Point Unit
M-43 SB Producer
Drilling Procedure
m `aa.12/0612018
outside Diameter
7,000 in.
Min. Wall
87-5%
OPERATION LIMIT TORQUES
Opera5ng Taque 20000 ft -Es YieldTorgoe 23400 ft -lbs
Thickness
(') Grade LBO
Type 1
Wall Thickness
0.362 is
Connection OD
REGULAR
Option
COUPLING
PIPE 900Y
Body: Red
1st Band. Red
Grade
LBO Type 1'
Drift
API Standard
1st Band: Brown
2nd Band
2nd Band:-
Brawn
Type
Casing
3rd Band:-
3rd Band :-
III, Band. -
1!PE 3UG'%DAJI,
GEOMETRY
Nominal OD
7.000 in.
Nominal Weaght
261bs� t
Ddh
6,151 n.
Nominal ID
6176 in.
Wall Thickness
0.362 in.
Plain End Weight
25.691:Ni1
OD Tclerercx
API
PERFORMANCE
Body Yield Strength
604 rt Opo Its
Interna Yield
7240
S6fYS
80000 psi
Collapse
5410 psi
GONNECTIn°. DAIA
GEOMETRY
Cenneciian OD
7.656 in
Coupling Length
10.200in
Cennec0an ID
6.264 h
Make-up Loss
4.579 in.
Threads per in
5
Ccnnxden OD Otccn
REGULAR
PERFORMANCE
Tension El6wk¢ry 100.0?i
Camplencri E6ciery 100%
EAemal Prassure Caps*iN 5410 ODD psi
Jocit "Ad Strength 604.000 xHf4 lr4wal Presvlre Capacity 1" 7240.000 psi
IN
Compression Strangth 5000111 1IX0 Maz.Alvuable Bening 52'100A
Its
MAKE-UP TORQUES
unimum 13280 hdn Optinlan 14750 ft4bs Maxmlm
16230 h -P -c
OPERATION LIMIT TORQUES
Opera5ng Taque 20000 ft -Es YieldTorgoe 23400 ft -lbs
Notes
This connection is fully interchangeable with:
TXPJ BTC - 7 in. - 23 129 1 32135 138 Ibslft
[t] Internal Pressure Capacity related to structural resistance only. Internal pressure leak resistance as per section
10.3 API 5C3 1 ISO 10400 - 2007.
17.7 MU 7" to DP crossover.
17.8 MU stand of DP to string, and MU top drive.
17.9 Break circulation at 1 BPM and begin lowering string.
17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off
pressure, leave standpipe bleed off valve open.
17.11 Continue lowering string and land out on no-go. Set down 5 — l OK and mark the pipe as "NO-
GO DEPTH".
17.12 PU string & remove unnecessary 7" joints.
17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing
hanger is landed. Ensure one full joint is below the casing hanger.
17.14 PU and MU the the 7" casing hanger with landing joint.
17.15 Ensure circulation is possible through 7" string.
17.16 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus.
17.17 With seals stabbed into the tieback sleeve, spot diesel freeze protection from 2,500' TVD to
surface in 9-5/8" x 7" annulus by reverse circulating through the holes in the seal assembly.
Ensure annular pressure are limited to prevent collapse of the 7" casing (verify collapse pressure
of the 7" tieback assembly).
17.18 SO and land hanger. Confirm the hanger has seated properly in the wellhead. Make note of
actual weight on the hanger in the morning report.
17.19 Back out landing joint. MU packoff running tool and install packoff on bottom of landing joint.
Set tubing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes.
17.20 R/D casing running tools.
17.21 PT 9-5/8" x 7" annulus to 1,000 psi for 30 minutes charted.
Page 38
Milne Point Unit
M-43 SB Producer
Hilco•rp
Energy C=n y
Drilling Procedure
17.7 MU 7" to DP crossover.
17.8 MU stand of DP to string, and MU top drive.
17.9 Break circulation at 1 BPM and begin lowering string.
17.10 Note seal assembly entering tieback sleeve with a pressure increase, stop pumping and bleed off
pressure, leave standpipe bleed off valve open.
17.11 Continue lowering string and land out on no-go. Set down 5 — l OK and mark the pipe as "NO-
GO DEPTH".
17.12 PU string & remove unnecessary 7" joints.
17.13 Space out with pups as needed to leave the no-go 1 ft above fully no-go position when the casing
hanger is landed. Ensure one full joint is below the casing hanger.
17.14 PU and MU the the 7" casing hanger with landing joint.
17.15 Ensure circulation is possible through 7" string.
17.16 RU and circulation corrosion inhibited brine in the 9-5/8" x 7" annulus.
17.17 With seals stabbed into the tieback sleeve, spot diesel freeze protection from 2,500' TVD to
surface in 9-5/8" x 7" annulus by reverse circulating through the holes in the seal assembly.
Ensure annular pressure are limited to prevent collapse of the 7" casing (verify collapse pressure
of the 7" tieback assembly).
17.18 SO and land hanger. Confirm the hanger has seated properly in the wellhead. Make note of
actual weight on the hanger in the morning report.
17.19 Back out landing joint. MU packoff running tool and install packoff on bottom of landing joint.
Set tubing hanger packoff and RILDS. PT void to 3,000 psi for 10 minutes.
17.20 R/D casing running tools.
17.21 PT 9-5/8" x 7" annulus to 1,000 psi for 30 minutes charted.
Page 38
H
Hilcrp
En -22_
18.0 Run Upper Completion
Milne Point Unit
M-43 SB Producer
Drilling Procedure
18.1 Confirm VBR's have been tested on 4-1/2" and 5" test joints to 250/3,000 psi.
18.2 RU to run 4-1/2" completion. Verify the jet pump completion components and depths with Ops
Engineer.
18.3 PU, MU and RIH with the following 4-1/2" jet pump completion:
a. WLEG
b. XX joints, 4-1/2", 12.6#, L-80, TXP tubing
c. 3.813" XN nipple (no-go ID = 3.725") with RHC plug body installed, 10' handling pups
above and below.
d. 1 joint, 4-1/2", 12.6#, L-80, TXP tubing
e. Retrievable Packer, 7" x 4-1/2"
f. 1 joint, 4-1/2", 12.6#, L-80, TXP tubing
g. 3.813" X nipple, 10' handling pups above and below
h. 4-1/2" Multi -Drop Gauge Mandrel with gauge installed
�rJ�P i. Sliding Sleeve with 3.813" X nipple
j. 4-1/2" Gauge Mandrel with gauge installed
k. XX joints, 4-1/2", 12.64, L-80, TXP tubing
18.4 Continue to RIH to setting depth.
i. Ensure appropriate well control crossovers on rig floor and ready.
ii. Monitor displacement from wellbore while RIH.
18.5 PU and MU the tubing hanger with blast pup joint and landing joint. Terminate the TEC wire.
18.6 Record PU and SO weights before landing hanger on the tally along with band/clamp summary.
18.7 Land tubing hanger and RILDS.
18.8 LD landing joint.
18.9 Install BPV. ND BOP. Install the plug off tool into the BPV.
18.10 NU the tubing head adapter and tree. Test tubing hanger void to 500/5,000 psi. Terminate the
cap strings.
18.11 PT the tree to 250/5,000 psi tree. Pull the plug off tool and BPV.
18.12 RU LRS. Reverse circulate 80 bbls of diesel (actual volume determined by base of the
permafrost) down the IA taking returns up the tubing. Place the tubing and IA in
communication. Allow time for the diesel to u -tube and equalize.
Page 39
H
Hilcorp
E�
Milne Point Unit
M-43 SB Producer
Drilling Procedure
18.13 Close the master valve and set the ball & rod on top. RU the lubricator, open the master valve to
drop the ball & rod and close the master valve. RD the lubricator. RU to set the packer and to
PT.
18.14 Slowly pressure up to 3,500 psi to set the packer. -�
18.15 PT the 4-1/2" tubing to 3,500 psi for 30 minutes charted. i� I
18.16 Bleed tubing to 2,000 psi. ,L
18.17 PT the IA to 3,500 psi for 30 minutes charted testing the packer and 7" casing. 9
18.18 RD testing equipment.
18.19 Install all tree gauges. Secure the tree and cellar. Releease the rig.
18.20 RDMO Doyon 14.
18.21 Turn the well over to operations via handover form.
18.22 RU HES slickline.
a. Open the sliding sleeve by shifting the sleeve down into the open position.
b. Pull the ball & rod from RHC plug body.
c. Pull the RHC plug body from XN nipple.
d. Set 12C jet pump in the sliding sleeve (verify jet pump size with Production Engineer).
18.23 RD HES slickline.
18.24 Prepare to hand over well to production. Ensure necessary forms filled out and well handedover
with valve alignment as per operations personnel.
18.25 Notify AOGCC of SVS testing. Test SVS on horizontal run of tree within 5 days of the start of
production. Set low pressure trip below 275 psi Moose Pad header & separator pressure.
Page 40
19.0 Doyon 14 Diverter Schematic
21-V4' 2M Rce1-
21-v4' 2M—
O",w'T-
21-114'21
Spacer Spot
16-14. 3M:
21-114' 2M DSI
Page 41
Milne Point Unit
M-43 SB Producer
Drilling Procedure
.16' Full OWiN Knde Va1M
`16'Dr er Llm
20.0 Doyon 14 BOP Schematic
KAl Lme1�
Page 42
Milne Point Unit
M-43 SB Producer
Drilling Procedure
4-1/2" x 7 VBR
Blind Rams
x 5Md HCR
poke Lne
BI Gale Valle
13-1/2" x 6" VBR
H
Hilcorp
Evop' Cmn2
21.0 Wellhead Schematic
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Page 43
K �
i
h
1 rR�r�Y\T{�Th��
11
tq
-
i
Page 43
Milne Point unit
M-43 SB Producer
Hilcotp Drilling Procedure
�. 22
22.0 Days Vs Depth
0
2000
4000
6000
L
w 8000
Z
61
N 10000
a
Page 44
12000
14000
16000
18000
MPU M-43 NB/NC Days vs Depth
11
0 5 10 15 20 25
Days
23.0 Formation Tops & Information
Milne Point Unit
M-43 SB Producer
Drilling Procedure
MPU M-43 Formations
(wp04)
MD
(ft)
TVDss
(ft)
TVD
(ft)
Formation Pressure
(psi)
EMW
(ppg)
Base Permafrost
2337
1830
1888
830.72
8.46
Ugnu LA3
4665
3200
3258
1433.52
8.46
Schrader Bluff NA
6074
3726
3784
1664.96
8.46
Schrader Bluff NB
6566
3763
3821
1681.24
8.46
L -Pad Data Sheet Formation Description (Closest & Most Analogous MPU Pad to Moose Pad)
GENERALIZED GEOLOGICAL
FORK A T
SS
GEOLOGICAL
COMMENTS
TVD
FM
LITH
DESCRIPTION
a. oa
NOTE: Ss Individual Well Program for
ae w
Gude
specific casing design, depths, sizes,
• m
6Cb
weights, gradea and connections.
111IcerRehdatm coarse to medbm sand and small gavel
E
wig Mn..Id.lane.
IF SIGNIFICANT AMOUNTS OF GRAVEL
1,000'
e.
ARE ENCOUNTERE D WHEN DRILLIN G THE
f- SURFACE HOLE, THE VISCOSITY OF THE
'
MUD SYSTEM SHOULD IMMEDIATELY BE
RAISED TO 750 SEC TO ENSURE
EFFECTIVE HOLE CLEANING.
1750•
Base permafrost
bbroeds of sand. cloys .m shale.. Mth A.W al.ral
2.000'
sEw a coal. wamh pos ibb sidetracking wrJle
wasNnd.amna 503 a Las.
ssye
rata,
♦. No hydrates encountered on L -Pad wells
drilled to date.
tomlwed lmapem of a,m, mys am slusbnea Win
occasbrul snows of coal. Traces of ppim at •/. 31001t
3.000'
bbrval a7-./. sem ficanee sdcay and tight Roll.
aay bbrgam penmen 3m and 4500 It
C
Sar-
L
A
3657-
saen.
UGNU: series of ....IN upward ands rTlch an
1-A9.C.01
Y
mads w a: (".top b nab.) wars. send ilrw.am.
shysnala savor d.velope0 iaervwirg elutes asyw
UGNU
propreaa into the Lam III(des,n).
tgwand Schnaarauat Possida Mdrwarboneumibd
L..da
los w corner of Mwmt 11041ilne Uelop.narea IS
lav)
do ,nsl.lure am WI.
-3719'
Wan.
I+la.Gl
sono.
(fust
Schrader Bluff Sands:
4,000'�
Iaac.u.
c.almma layering <mnenhg upwam samsas abw. m Schroder 61u1F: Possible lost circulation
e.n
.aceplmoncwansed.mwlgw..jora al. zone while drilling long strings and running
•4170'
os....
Gay rich sial. laanal1300 to4600It
ugw.nescnraderelaf: P.asidehydrourooneumimd casing. Recommend deep setting surface
JOA)
I+ae
bsweomerof Munedealoperrnt w7.ml.A.re casing for Kuparuk long strings. Also, the
OE.n
completed In qo Schrader Bluff sand. Nonhemareaa
Schroder u sands area potential
Schrader
L Pm is dowmtmcm* am wet
differentiall stuck pipe interval If left un -cased
Bluff
C
surface uslrg pairs In stab below for Kuparuk long strings.
Sands:
I
SdmOerBluff 09samfor bnperreach wale.
Page 45
Milne Point unit
M-43 S8 Producer
Hilco.Ty Drilling Procedure
u Comyoy
E
24.0 Anticipated Drilling Hazards
12-1/4" Hole Section:
Lost Circulation
Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost
circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
Gas Hydrates i
Gas hyrates have not been seen on Moose pad. However, be prepared for them. Remember that hydrate
gas behave differently from a gas sand. Additional fluid density will not prevent influx of gas hydrates,
but can help control the breakout at surface. Once a gas hydrate has been disturbed the gas will come
out of the hole. Drill through the hydrate section as quickly as possible while minimizing gas belching.
Minimize circulation time while drilling through the hydrate zone. Excessive circulation will accelerate
formation thawing which can increase the amount of hydrates released into the wellbore. Keep the mud
circulation temperature as cold as possible. Weigh mud with both a pressurized and non -pressurized
mud scale. The non -pressurized scale will reflect the actual mud cut weight. Add 1.0 — 2.0 ppb
Lecithin to the system to help thin the mud and release the gas. Isolate/dump contaminated fluid to
remove hydrates from the system.
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with high viscosity sweeps as necessary. Optimize
solids control equipment to maintain density, sand content, and reduce the waste stream. Monitor ECDs
to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe rotation is
critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe moving to
avoid washing out a particular section of the hole. Ensure to clean the hole with rotation after slide
intervals. Do not out drill our ability to clean the hole.
Anti -Collison:
Take directional surveys every stand, take additional surveys if necessary. Continuously monitor
proximity to offset wellbores and record any close approaches on AM report. Well Specific:
• There are no wells with a clearance factor <1.0
Wellbore stability (Permafrost, running sands and gravel, conductor broaching):
Washouts in the permafrost can be severe if the string is left circulating across it for extended periods of
time. Keep mud as cool as possible by taking on cold water and diluting often. High TOH and RIH
speeds can aggravate fragile shale/coal formations due to the pressure variations between surge and
swab. Bring the pumps on slowly after connections. Monitor conductor for any signs of broaching.
Maintain mud parameters and increase MW to combat running sands and gravel formations.
H2S:
Treat every hole section as though it has the potential for 112S. No H2S events have been documented
on drill wells on this pad.
Page 46
Milne Point Unit
M-43 SB Producer
Drilling Procedure
1. The AOGCC will be notified within 24 hours if 1-12S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic 1-12S detection equipment meeting the requirements
of 20 AAC 25.066.
3. In the event H2S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Page 47
H
Hilcorp
Evan Compmy
8-1/2" Hole Section:
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Hole Cleaning:
Maintain rheology of mud system. Sweep hole with low -vis water sweeps. Ensure shakers are set up
with appropriate screens to maximize solids removal efficiency. Run centrifuge continuously. Monitor
ECDs to determine if additional circulation time is necessary. In a highly deviated wellbore, pipe
rotation is critical for effective hole cleaning. Rotate at maximum RPMs when CBU, and keep pipe
moving to avoid washing out a particular section of the wellbore. Ensure to clean the hole with rotation
after slide intervals. Do not out drill our ability to clean the hole. Maintain circulation rate of> 300
gpm
Lost Circulation: '
Ensure adequate amounts of LCM are available. Monitor fluid volumes to detect any early signs of lost
circulation. For minor seepage losses, consider adding small amounts of calcium carbonate.
Faulting: ✓
There is at least (1) fault that will be crossed while drilling the well. There could be others and the
throw of these faults is not well understood at this point in time. When a known fault is coming up,
ensure to put a "ramp" in the wellbore to aid in kicking off (low siding) later. Once a fault is crossed,
we'll need to either drill up or down to get a look at the LWD log and determine the throw and then
replan the wellbore.
H2S:
Treat every hole section as though it has the potential for 1-12S. No H2S events have been documented
on drill wells on this pad.
1. The AOGCC will be notified within 24 hours if H2S is encountered in excess of 20 ppm during
drilling operations.
2. The rig will have fully functioning automatic H2S detection equipment meeting the requirements
of 20 AAC 25.066.
3. In the event 1-12S is detected, wellwork will be suspended and personnel evacuated until a
detailed mitigation procedure can be developed.
Abnormal Pressures and Temperatures:
Reservoir pressures are expected to be normal. Abnormal (offset injection) pressure has been seen on M -
Pad. Utilize MPD to mitigate any abnormal pressure seen.
Anti -Collision
Take directional surveys every stand, take additional surveys if necessary. Continuously monitor
drilling parameters for signs of magnetic interference with another well. Reference A/C report in
directional plan. Well Specific:
There are no wells with a clearance factor <1.0
Page 48
H
HilcoT
E^aBY CmnV®Y
25.0
Page 49
14
I�
TM
1
Nam
WIN
Milne Point Unit
M-43 5B Producer
Drilling Procedure
N
V
n
Hilcorp 22
E,� c
26.0 FIT Procedure
Formation Integrity Test (FIT) and
Leak -Off Test (LOT) Procedures
Procedure for FIT:
Milne Point Unit
M-43 SB Producer
Drilling Procedure
1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe).
2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe.
3. Close the blowout preventer (ram or annular).
4. Pump down the drill stem at 1/4 to 1/2 bpm.
5. On a graph with the recent casing test already shown, plot the fluid pumped (volume or strokes) vs.
drill pipe pressure until appropriate surface pressure is achieved for FIT at shoe.
6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes.
Record time vs. pressure in 1 -minute intervals.
7. Bleed the pressure off and record the fluid volume recovered.
The pre -determined surface pressure for each formation integrity test is based on achieving an EMW at
least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick
tolerance in case well control measures are required.
Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of
stopping at a pre -determined point, surface pressure is increased until the formation begins to take fluid;
at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure
monitored as with an FIT.
Ensure that casing test and subsequent FIT tests are recorded on the same chart. Document incremental
volume pumped and returned during test.
Page 50
O
N
CHOKE MANIFOLD
A:[CxL_l
LEGEND
White Handled Valves
Normally Open
Red Handled Valves
Normally Closed
Date: 08-22-14 Rev.3
NOTES:
1) Valve A is a 3-1116" SM Remote Operated
Hydraulic Choke Valve.
2) Valve B is a 3-1/8" SM Adjustable Choke Valve.
3) Valve I is a 2.1/16" 5M Manual Gate Valve.
4) Valves 2-14 are 3-1/8" SM Manual Gate Valves.
Divert Line
From
BOP
Divert Line
To Mud/Gas
Separator
7i
H
Hilcorp
E,R c�vmr
Milne Point Unit
M-43 SB Producer
Drilling Procedure
28.0 Casing Design
Calculation & Casing Design Factors
DATE: 2.26.2020
WELL: MPU M-43
DESIGN BY: Joe Engel
Criteria:
Hole Size 12-1/4" Mud Density: 9.2 ppg
Hole Size 8-1/2" Mud Density: 9.2 ppg
Hole Size Mud Density:
Drilling Mode
MASP: 1336 psi (see attached MASP determination & calculation)
MASP:
Production Mode
MASP: 1336 psi (see attached MASP determination & calculation)
Collapse Calculation:
Section Calculation
1 Normal gradient external stress (0.494 psi/ft) and the casing evacuated for the internal stress
Page 52
Casing Section
Calculation/Specification
1
2 3 4
Casing OD
9£/8"
4-112"
Screens
Top (MD)
0
6,508
Top (TVD)
0
3,818
Bottom (MD)
6,508
15,860
Bottom (TVD)
3,818
3,578
Length
6,508
9,352
Weight (ppf)
40
12.6
Grade
L-80
L-80
Connection
DWC
H625
Weight w/o Bouyancy Factor(Ibs)
260,320
117,835
Tension at Top of Section (Ibs)
260,320
117,835
Min strength Tension (1000 lbs)
916
279
Worst Case Safety Factor (Tension)
3.52 v
2.37
Collapse Pressure at bottom (Psi)
1,886
1,768
Collapse Resistance w/o tension (Psi)
3,090
8,540
Worst Case Safety Factor (Collapse)
1.64
4.83
MASP (psi)
1,336
1,336
Minimum Yield (psi)
5,750
9,020
Worst case safety factor (Burst)
4.30
6.76
Page 52
H
Hilcorp
T Company
Eu
29.0 8-1/2" Hole Section MASP
Maximum Anticipated Surface Pressure Calculation
Rllcorp 8-1/2' Hole Section
MPU M-43
Milne Point Unit
MD ND
Planned Top: 6508 3818
Planned TD: 15860 3578
Milne Point Unit
M-43 SB Producer
Drilling Procedure
Anticipated Formations and Pressures:
Formation TVD TVDss Est Pressure Oil/Gas/Wet PPG Grad
Schrader Bluff NBSand 1 3,818 1 3,776 1 1680 Oil 8.46 1 0.440'
Offset Well Mud Densities
wall MW range Too (TVDI Bottom fTVD) Date
MPU L-52
8.8-9.35
Surface
3952
2017 -
MPU L-51
8.9-9.3
Surface
3930
2037 ,
MPU L-53
9-9.25
Surface
3891
2017
MPUJ-27
9-9.3
Surface
3666
2015
MPUJ-28
9-9.3
Surface
3617
2015
MPI - 19
9 - 9.3 ppg
Surface
4,079
2004
MPI - 18
9- 10ppg
Surface
3,848
2011
MPI - 17
9- 9.5 ppg
Surface
3,864
2004
Assumptions:
1. Field test data suggests the Fracture Gradient in the Schrader Bluff is btwn 11.5 and 15 ppg EMW.
2. Maximum planned mud density for the 8-1/2' hole section is 9.5 ppg. -
3. Calculations assume full evacuation of wellbore togas
Fracture Pressure at 9-5/8" shoe considering a full column of gas from shoe to surface:
3818 (ft) x 0.78(psi/ft)= 2978
2978(psi)-[0.1(psi/ft)•3818(ft)]= F2596 psi
MASP from pore pressure (complete evacuation of wellbore to gas from Schrader Bluff NB sand)
3818 (ft) x 0.45(psi/ft)= 1718.0 psi
1718(psi)-0.1(psi/ft)•3818(ft) 1336.0 psi
Summary: \
1. MASP while drilling8-1/2' production hole is governed by pore
of entire wellbore togas at 0.1 psi/ft.
Page 53
n
30.0 Spider Plot (NAD 27) (Governmental Sections)
Milne Point Unit
M-43 SB Producer
Hilcorp
Eo -tT
Drilling Procedure
30.0 Spider Plot (NAD 27) (Governmental Sections)
G !
`�t'.
+ -'
Sei�12"'
�
KUP
-A\ DL388235 ,"
di�,•
ADL ,. -Se
533023
REUNIT
-r--•1_��1APIff
6I-43 SHL
In
\
V11 •� Sec_13\>
t1 ``I
/ •Sec. 16 I
Seo. 14/ �1
♦` ,/~
'\
1 DI
.'S
P,
�1 1
10
(POINT UNIT
1
,I1 As3za'
U013NO09E` 1
r ADLOT351S
/1
ADdO 5514'•i ♦
1/ �
`�
U013NO10E
� ♦`, /'I
1 1 ♦ 1 1\ A �`
4
`
/ \ IA. •.♦ Se, 24` ♦ `e,
1 I
SEC..ta '
1 1 I
1 n ♦ ♦
f633'i
%
I
1 /
1 I 1 I / `� ♦
l,- L.3sPe'. i-3 : :A... LS; �; t L -43 HHI
•,.xa
Elk' PM 14 T
aox PAD
5 Legend \DL023319
ADL025317
cec 26
�\
€ • LI -43 SHL Otho Surface Holet(SHL) KUPARUK
RIVER UNIT
"�ONtro Botwrn Hdes (BHL)
""' _ _
X 6443 TPH
- - - Oohel Well Paths
Sec. 3G
T AI -43 BHL O Oil and Gas Unit Boundary '"'1
ifi3fi!
Pad FDOtPrina
Alaska State Plane Zone 4 NAC T 927
Hi Milne Point Unit
MPU M-43 Well 0 1.000 2.000 7ff
„
oam q000000q==== Feet
Iw zs.,au_e
WP --04
Page 54
H
Hilcorp
Eongy Campo2
31.0 Surface Plat (As Staked) (NAD 27)
Milne Point Unit
M-43 SB Producer
Drilling Procedure
M
1
i
23
I ME SITE
VICINITY MAP
NTS
GRAPHSCALE
A.S.P.PLANT
COORDINATES
C00ROINATES
0 IN ;100 40
GEODETC
POSITION DDD)
SURVEYOR'S CERTIFICATE
PAO
ELEVATION
CELLAR
BOX EL.
1 HEREAT CfRTDY THAT I AM
I NMI)
N: 1,292..06
_ SEG 12S
SEG It
I
M-44 +
EC.
SEC.
25.3'
M-43
I
E-205509
M-10 ■
MALE 8Y ME CN UNDER MY DIRECT
111' FEL
I
M-4
Y- 6,027,689.70
DIMENSONS AND MER DETAINS ARE
I
70.4872191'
M-111 •
LEGEND
NOTES:
M-44
X- 534,143.85
I. ALA9G STAIE PLANE WORDNATES APE 16A4127, ZONE 4,
•
M-13
I
I
M-12 ■
4 BASS E NWZCHTK AND NWOCAL CONIVOL ARE MWSE PAD
I
■
M-14
M-20 ■
6 PEFII2DVEE EELD SOCK! HC19-W POP 69-71
M-37 ■
■
M-15
M-21
I
I
■
M-,6
M-58 ■
M-22 ■
I
■
M-17
M-23 ■
■
M-13
uIJ
I ■
M.61
I M-24 •
•
Y-19
I
I
I ■
I
M -D4 ■
Y-03 ■
■
M-05
I
MOOSE PAO
M -DS
Milne Point Unit
M-43 SB Producer
Drilling Procedure
M
1
i
23
I ME SITE
VICINITY MAP
NTS
GRAPHSCALE
A.S.P.PLANT
COORDINATES
C00ROINATES
0 IN ;100 40
GEODETC
POSITION DDD)
SURVEYOR'S CERTIFICATE
PAO
ELEVATION
CELLAR
BOX EL.
1 HEREAT CfRTDY THAT I AM
I NMI)
N: 1,292..06
PROPERLY RECISERED " LICENSED
1 N 2W m
5,037' FSL
TO PRACTICE LAID "VEYDIG IN
INE STATE DF ALASKA ANO THAT
25.3'
M-43
1,415 AS-9JILT REPRESENTS A SURVEY
E-205509
170'29'13.993
49'43'17.982'
MALE 8Y ME CN UNDER MY DIRECT
111' FEL
SJPERYISON AND THAT All
Y- 6,027,689.70
DIMENSONS AND MER DETAINS ARE
70'29'13.989'
70.4872191'
CNIIECT AS C4 DECEMBER 22 2019.
LEGEND
NOTES:
M-44
X- 534,143.85
I. ALA9G STAIE PLANE WORDNATES APE 16A4127, ZONE 4,
149'43'15.335'
AS-EAAT CONDUCTOR
2 CEDDEM MIN NS ARE NAW).
■ MTI- COjcJ
4 BASS E NWZCHTK AND NWOCAL CONIVOL ARE MWSE PAD
MOKNEATS SM -A 4P 5119 ME AND SM S.
4. NPI MOOSE ANJPGAE PAD SCALE FA" IS 096590,1
S DATE OE SLRYE XCEMMR a 299.
6 PEFII2DVEE EELD SOCK! HC19-W POP 69-71
IrlraYrn YATWN DPAMAG. rn 9re. 14. 1 13 N_ R. 9 E.. UMIAT
MERIDIAN. ALASKA
i
WELL
NO.
A.S.P.PLANT
COORDINATES
C00ROINATES
GEODETIC
POSITION DMS
GEODETC
POSITION DDD)
SECTION
OFFSETS
PAO
ELEVATION
CELLAR
BOX EL.
Y- 6.027,889 70
N: 1,292..06
70.4872203'
5,037' FSL
25.1'
25.3'
M-43
X= 534,05389
E-205509
170'29'13.993
49'43'17.982'
149.7216618'
111' FEL
Y- 6,027,689.70
N= 1,292.06
70'29'13.989'
70.4872191'
5,036' FSL
25.1'
25.'
M-44
X- 534,143.85
E- 2145.06
149'43'15.335'
149.7209265'
21FEL
HilcorpAlaslLa
6
rP MPU MOOSE PAD R4s�
AS -BUILT CONDUCTORS
Aa ..vrna n x mN.iA+4® �. _]DIE WELLS M-43 & M-44 1 a 1
•x _ws
Page 55
32.0 Schrader Bluff Nb Sand Offset MW vs TVD Chart
SB NB Offset MW vs MD
EMW, ppg
85 9.5 10.5 11.5 12.5
0
Milne Point unit
2000
4000 $
M-43 SB Producer
1
6000
Hilcorp
Evugy Compevy
Drilling Procedure
32.0 Schrader Bluff Nb Sand Offset MW vs TVD Chart
SB NB Offset MW vs MD
EMW, ppg
85 9.5 10.5 11.5 12.5
—J-27 (2015) J-28 (2015) —L-53 (2017)
--L-52 (2017)—L-51 (2017)
Page 56
0
2000
4000 $
1
6000
0
8000
10000
12000
14000
16000
—J-27 (2015) J-28 (2015) —L-53 (2017)
--L-52 (2017)—L-51 (2017)
Page 56
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Plan: MPU M-43 - Slot 52
MPU M-43
Plan: MPU M-43 wp04
Standard Proposal Report
25 February, 2020
HALLIBURTON
Sperry Drilling Services
Project: Milne Point
Site; MPI Moose Pad
Well: Plan: MPU M4 - Slot 52
Wellbore: MPU M-43
Design; MPU M43 wp
NAWBUiiTON
Hlkorp Nash, LLC
CaWINun memo : Minimum Curvature
Eno, macam: ISCWSA
said. lrev= Cburt Approach 3D
came Surface: Pedal Curve
Warning Whorl : Emm Re6o
r
r
Bed
MO
Iro
Pzl
ND
°W-8
°EFW
µV clogµ
ry TFece.
Vied
Target
Mnolafmn
1
33W
o.00
o.c0
33so
000
000
0.00
000
000
."
MPI.J."W1072]Mi3)
z
260.011
O0o
090
280.00
0.00
0.00
0.00
0go
000
.0 Uir 811.0: 2WMD. 2B] TVD
3
4Woo
6
30.00
47963
9.06
5.23
3.00
30.00
343
MPU M43 x1'11 -6P1
5]nOff 4-H 0P:4PO M0,4R63'NU
4
760.00
1535
6203
14466
V..
4420
403
.00
)092
3000
3750
6
1]19]6
54.11
WN
1526]8
26$45
SUrW
403
4.17
30438
usfUn)
End or' 1]19]8' MD, 15816' TYD
6376546
54.11
me ge
2]3]71
94362
203592
00o
000
-1.725
Sand Dir 411W. 378546' MD. 2]3].71WI
]
6207.%
0800
16].55
3]9].8]
W8
W1020
400
100.04
-174.16
End or'. 62%.98 MD. $797 ND
a
6507%
88.0
18].55
301360
-391.57
U74.72
000
0.00
112.38
MPU Mia vy04-Heel
eard De Pry W: 65U7%MD38136TV0
9
665339
9139
11023
.2223
53907
370366
460
26.46
25725
End or M8. In MD, 3922.2) ND
10
7625.19
91 39
1]023
3]9800
-1491 5]
3867]0
00
000
119481
MPU MA3.04-CPI
&,,t Di4-M0Y 7825.19'MD, 37%8'M
11
]9]0.%
9188
104.05
37890
-183555
04
3890
4.0
U60
18.29
53
End W :]9]055 MD. 3]89.6 ND
12
12424]5
91 66
18405
3658.
SP673
35]0]6
000
00
5%652
MPVMi3wT/.A-CM
Skirt Dir4Y1W: 12424VW.W8.8TV
13
12435.80
9t 92
104.41
365346
93>54
356996
do
5723
599935
Enr Dir : 124358'MD.Wei,I TrD
14
14222.03
Bf 92
184.41
359873
-0%].86
U3265
"0
0.00
]]8476
filed Doo°/10':142II 03'00. 3590.]3
15
1431993
re om
10444
359800
4165.27
.2510
400
1]95]
]88267
MPU M43 wpp4-CP3
16
1436023
85.39
104.45
300]]
d2%40
.21%
400
17965
]92242
Ead01r : 143023'M1R3601]'TVD
1]
1401.20
W39
184.45
361595
405.17
UO3.32
0.00
0.00
816341
6kd or 4910m, 146012 MD, W1595'N
18
1469154
90.00
164.34
%1880
-0535.18
339810
•00
-1.N
625369
MPU M<3 ap.-W4
19
1474185
82.00
iso ]4
361782
.4565 .14
339261
4.0
-007
.,1
End D'u: 14]4185' MD. W17.92 ND
20
15860.31
920
1%.34
35]8.80
4699.80
33030
0.00
0.0
Gull
MPU Mi3 x1.44 -Toe
Tolel Depth: 15W 31 W. 3578.6 Tub
D
Sart De 3nIW' 211 MD. 2W-
Sna 01, 4°HW:4W MD, 479639VD
End D6 :171976 MD,152678'Tw
rO 'o
ip100a p p
� . F
nLL
PflCGRNADate:
ca
1500
Mfg-l2-11T029oD3
v
- . ._ _ - - _ _ _
rcra,6URVEY
trumutua mr, MPU Ml Set alr
BMxlm
Tool
M'In9 Evet'eq 35.r LanaWw
3880.40a.e t00% OOSBI L1
]t58qu ypJ.M a695et LN[0
MPU Mi ,am (MPU MA3)
3_CR1roCL_Cey
LB
re
MPU M43 wp04(MN Mi3)
3_MVNrIFR3°MS°3e
650].%
."
MPI.J."W1072]Mi3)
3 MVI0°IFfl2°MS°Ba
�
r
LA3
CAeNG DUALS
--
AG§ -. 6516"v01n"
ND ND83 MO Ed. Neme
Me
��
3013. 3]6000 650795 B-Sr0 95_x121..
ewansx grLl xea"er-ra rrc uv
a4nxrg5B.eonnl
35]8.80 3520.001588031 85/8 8516'x01?
hur.IM%R°Nrarce., u r n to
mei oege eal°rew: MPU Ma] Prnm4 xxe a xmmn dome,M
xpM-CP4
D
Sart De 3nIW' 211 MD. 2W-
Sna 01, 4°HW:4W MD, 479639VD
End D6 :171976 MD,152678'Tw
750-
rO 'o
ip100a p p
� . F
PflCGRNADate:
ca
1500
Mfg-l2-11T029oD3
Vanda@d: YeaV..a"
- . ._ _ - - _ _ _
rcra,6URVEY
criedFmcriedTo
BurveyNlen
Tool
..
350..
MPU Mi ,am (MPU MA3)
3_CR1roCL_Cey
350.00
650].%
MPU M43 wp04(MN Mi3)
3_MVNrIFR3°MS°3e
650].%
15860.31
MPI.J."W1072]Mi3)
3 MVI0°IFfl2°MS°Ba
750-
rO 'o
ip100a p p
� . F
((J.0
ca
1500
. - _ -
K NQ . _ _ - _ - _
- - _ - _ _ ..- nn p
TSpO ry �o F q�Rp
]
- . ._ _ - - _ _ _
- _ - _ " jn..
9
e3'
t
p
dPRF
svf
2p� G A �i+y'y
ra
�
ry49 £
^��
2250
y, 8"' 0 '� ^4+ ,
n
h
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3000
> 2
OsrC $R
4 4i Nc? �
d R
35 W
�
r
LA3
4
--
AG§ -. 6516"v01n"
�UCNU
Me
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BB NA
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a rn
-MPU M43 x104
So us moan
9518 12 114^
�
�
� in,
8
x
8
a 8
0
g
MPU Mi3
xpM-CP4
MPU Mi3 rqM-Heel
MPU M43 x1'11 -6P1
MPU
043 rry09-cm
MPU M43 m-CP3
MFLI Mi3x 4-T00
FTT
-3000 -2250
-1500 -750 0 750
1500 2250
3000
3750
4500
5250
6000 6750
7500 8250
9000
9750 10500 11250
Vet -tical Section at 184.34' (1500
usfUn)
a
HALLIBURTON Project: Milne Point
Site: M Pt Moose Pad
sPe.w 0,01ing Well: Plan: MPU M-43 - Slot 52
Wellbore: MPU M-43
i •
Plan: MPU M-43 wp04
I
WELL DETAB$'. Han: MPU M43 - Slot 52
25.10
+N/ -S +E1 -W NoMing Easlins LanOude I .,mude
0.00 0,00 6021889.70 53405389 70" 29' 13 993 N 14V 43' 17.982 W
REFERENCE INFORMATION
LrvoNlnale (NO Reference: Wen Plan: MPU M43 - BIW 52. Tme N0011
V mue) (ND) Reference: MPU µ43 Planned! RKB SB.BOusfl (Doyon 14)
Measured DepN Relamnue: MPU M43 Planned RKB @ 58.80usfl (Down 14)
Calalalion Whod Minimum Curvature
2250-
TVD
3818.80
3578.80
TVDSS
3760.00
3520.00
MD Size Name
6507.96 9-5/8 95/8"x121/4"
15860.31 6-58 6 58" x 8 12"
1500
4
h g
Ay
$0
750-
8
��=,--S+mt
0
0—
Dir3°/1:260 MD, 280TVD
-
ai$---_
-
-
Start&Fi 11,00: 48Q MD, 499.63TVD
954"x121/4"
End Dir _ 1719.76,152&78'TVD
Nffll M43 w,04 - Heel
-750
Sten Dir 4'/100: 3785.46' N0; 1737,71TVD
actor :620796' MD, 379] BTTVD
Sran Dir4 /100': 650796' MD, 3818.8TVD
500
End Dir :6656.39'tvm, 382221 TVD
MPU M43 wPOd - CPI
Start Dir 4°/100': 7625.19MD, 3798 8T9D '
2250
End Dir ]9]0.56MD, 3789.5' TVD
Start Dme/100'. 12424.7&IWD,3658,8WD MPU M43u04-CP2
Endow 12435.6,365846'TVD
Starr Dir4Y100: 1422203'MD,3598.73TVD MPU M-43 wp04-CP3
End Or 1436023'bm, 360077 TVD b M-43%pW-CP4
SWDIO/100': 14601.2b ,3615.9SI)'➢--
End Dir 14]4165'MD,361792'TVD
• 65B"x81k'
Total Depth : 15860.31' MD, 35]8.8' TVD
E 35]9
MPU 509 BuRW MPU M43 typpq h1PU M43 04-T. \I
I
4500 -750 0 750 1500 2250 3000 3750 4500 5250 6000
West( -)/East(+) (1500 nsftlin)
6750 7500 8250 9000
HALLIBURTON
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt Moose Pad
Well:
Plan: MPU M-43 - Slot 52
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU M-43 - Slot 52
TVD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Project Milne Point, ACT, MILNE POINT
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 1 Using geodetic scale factor
Site M Pt Moose Pad
Site Position:
Northing:
From: Map
Easting:
Position Uncertainty: 5.00 usft
Slot Radius:
well Plan: MPU M-43 - Slot 52
Well Position +N/ -S 0.00 usft
Northing:
+E/ -W 0.00 usft
Easting:
Position Uncertainty 0.50 usft
Wellhead Elevation:
Wellbore MPU M-43
Magnetics Model Name
BGGM2019
Design
Audit Notes:
Version:
Vertical Section:
MPU M-43 wp04
Sample Date
3/20/2020
Phase:
Depth From (TVD)
(usft)
33.50
6,027,877.65usft Latitude:
533,363.92 usft Longitude:
13-3/16" Grid Convergence:
6,027,889.70 usft
534,053.89 usft
25.30 usfl
Declination
16.08
PLAN
+N/ -S
(usft)
0.00
70" 29' 13.905 N
149° 43'38.286 W
0.26 °
Latitude: 70° 29'13.993 N
Longitude: 149° 43'17.982 W
Ground Level: 25.10 usft
Dip Angle Field Strength
(°) (nT)
80.89 57,392.65324795
Tie On Depth:
+EI -W
(usft)
0.00
33.50
Direction
l°)
184.34
22&1020 6:00:57PM Page 2 COMPASS 5000.15 Build 91E
2/25/2020 6:00:57PM Page 3 COMPASS 5000.15 Build 9117
Halliburton
H A L L I B U R TO N
Standard Proposal Report
Database:
NORTH US
+ CANADA
Local Co-ordinate Reference: Well
Plan: MPU M-43
- Slot 52
Company:
Hilcorp Alaska, LLC
TVD Reference:
MPU
M-43 Planned
RKB @ 58.80usft (Doyon 14
Project:
Milne Point
MD Reference:
MPU
M-43 Planned
RKB Q 58.80usft (Doyon 14
Site:
M Pt Moose
Pad
North Reference:
True
Well:
Plan: MPU M-43 - Slot 52
Survey Calculation
Method: Minimum Curvature
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Plan Sections
Measured
Vertical
TVD
Dogleg
Build
Turn
Depth
Inclination Azimuth
Depth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
Tool Face
(usft)
(°)
(°)
(usft)
usft
(usft)
(usft)
(°I100usft)
(°/100usft)
(°/100usft)
(°)
33.50
0.00
0.00
33.50
-2530
0.00
0.00
0.00
0.00
0.00
0.00
280.00
0.00
0.00
280.00
221.20
0.00
0.00
0.00
0.00
0.00
0.00
480.00
6.00
30.00
479.63
420.83
9.06
5.23
3.00
3.00
0.00
30.00
750.00
15.35
62.83
744.86
686.06
37.69
44.20
4.00
3.46
12.16
50.00
1,719.76
54.11
66.06
1,526.78
1,467.98
264.45
536.38
4.00
4.00
0.33
4.17
3,785.46
54.11
66.06
2,737.71
2.67891
943.62
2,065.92
0.00
0.00
0.00
0.00
6,207.96
86.00
167.55
3,797.87
3,739.07
-99.34
3,610.20
4.00
1.32
4.19
100.04
6,507.96
86.00
167.55
3,818.80
3,760.00
-391.57
3,674.72
0.00
0.00
0.00
0.00
6,658.39
91.39
170.23
3,822.23
3,763.43
-539.07
3,703.68
4.00
3.58
1.78
26.48
7,625.19
91.39
170.23
3,798.80
3,740.00
-1,491.57
3,867.70
0.00
0.00
0.00
0.00
7,970.56
91.68
184.05
3,789.50
3,730.70
-1,835.55
3,884.90
4.00
0.08
4.00
88.60
12,424.76
91.68
184.05
3,658.80
3,600.00
-6,276.73
3,570.76
0.00
0.00
0.00
0.00
12,435.60
91.92
184.41
3,658.46
3,599.66
-6,287.54
3,569.96
4.00
2.16
3.37
57.23
14,222.03
91.92
184.41
3,598.73
3,539.93
-8,067.68
3,432.65
0.00
0.00
0.00
0.00
14,319.93
88.00
184.44
3,598.80
3,540.00
-8,165.27
3,425.10
4.00
-4.00
0.03
179.57
14,360.23
86.39
184.45
3,600.77
3,541.97
-8,205.40
3,421.98
4.00
-4.00
0.02
179.65
14,601.20
86.39
184.45
3,615.95
3,557.15
_8,445.17
3,403.32
0.00
0.00
0.00
0.00
14,691.54
90.00
184.34
3,618.80
3,560.00
-8,535.18
3,396.40
4.00
4.00
-0.12
-1.74
14,741.65
92.00
184.34
3,617.92
3,559.12
-8,585.14
3,392.61
4.00
4.00
-0.01
-0.07
. 15,860.31
92.00
184.34
3,578.80
3,520.00
-9,699.90
3,308.06
0.00
0.00
0.00
0.00
2/25/2020 6:00:57PM Page 3 COMPASS 5000.15 Build 9117
Planned Survey
Measured
Halliburton
H A LL I B U RTO N
Standard Proposal Report
Database: NORTH US + CANADA
Local Co-ordinate Reference:
Well Plan: MPU M-43 - Slot 52
Company: Hilcorp Alaska, LLC
TVD Reference:
MPU M-43 Planned IRKS @ 58.80usft (Doyon 14
Project: Milne Point
MD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
Site: M Pt Moose Pad
North Reference:
True
Well: Plan: MPU M-43 - Slot 52
Survey Calculation Method:
Minimum Curvature
Wellbore: MPU M-43
+N1 -S
+El -W
Design: MPU M-43 wp04
Easting
Planned Survey
Measured
Vertical
Map
Map
Depth
Inclination Azimuth
Depth
TVDss
+N1 -S
+El -W
Northing
Easting
DLS
Vert Section
(usft)
V)
(')
(usft)
usft
(usft)
(usft)
(usft)
(usft)
-25.30
33.50
0.00
0.00
33.50
-25.30
0.00
0.00
6,027,889.70
534,053.89
0.00
0.00
100.00
0.00
0.00
100.00
41.20
0.00
0.00
6,027,889.70
534,053.89
0.00
0.00
200.00
0.00
0.00
200.00
141.20
0.00
0.00
6,027,889.70
534,053.89
0.00
0.00
280.00
0.00
0.00
280.00
221.20
0.00
0.00
6,027,889.70
534,053.89
0.00
0.00
Start Dir 311100'
: 280'
MD,
280'TVD
300.00
0.60
30.00
300.00
241.20
0.09
0.05
6,027,889.79
534,053.94
3.00
-0.09
400.00
3.60
30.00
399.92
341.12
3.26
1.88
6,027,892.97
534,055.76
3.00
-3.40
480.00
6.00
30.00
479.63
420.83
9.06
5.23
6,027,898.78
534,059.08
3.00
-9.43
Start Dir
4-1100'
: 480'
MD,
479.63'TVD
500.00
6.54
35.39
499.52
440.72
10.89
6.41
6,027,900.62
534,060.25
4.00
-11.35
600.00
9.80
52.13
598.50
539.70
20.77
16.43
6,027,910.54
534,070.23
4.00
-21.95
700.00
13.46
60.23
696.44
637.64
31.77
33.26
6,027,921.62
534,087.00
4.00
-34.20
750.00
15.35
62.83
744.86
686.06
37.69
44.20
6,027,927.58
534,097.91
4.00
40.92
800.00
17.35
63.32
792.84
734.04
44.06
56.75
6,027,934.01
534,110.43
4.00
48.22
900.00
21.34
64.03
887.17
828.37
58.72
86.44
6,027,948.81
534,140.05
4.00
-65.10
1,000.00
25.34
64.52
978.97
920.17
75.90
122.13
6,027,966.15
534,175.66
4.00
-84.93
1,100.00
29.33
64.89
1,067.79
1,008.99
95.51
163.64
6,027,985.95
534,217.08
4.00
-107.62
1,200.00
33.33
65.18
1,153.19
1,094.39
117.44
210.78
6,028,008.10
534,264.10
4.00
-133.06
1,300.00
37.33
65.41
1,234.76
1,175.96
141.60
263.30
6,028,032.49
534,316.51
4.00
-161.12
1,400.00
41.33
65.60
1,312.10
1,253.30
167.87
320.96
6,028,059.02
534,374.05
4.00
-191.68
1,441.41
42.98
65.67
1,342.80
1,284.00
179.34
346.28
6,028,070.60
534,399.31
4.00
-205.03
SV5
1,500.00
45.32
65.76
1,384.83
1,326.03
196.12
383.47
6,028,087.55
534,436.42
4.00
-224.57
1,600.00
49.32
65.91
1,452.60
1,393.80
226.20
450.54
6,028,117.94
534,503.34
4.00
-259.65
1,700.00
53.32
66.03
1,515.09
1,456.29
257.98
521.83
6,028,150.05
534,574.48
4.00
-296.73
1,719.76
54.11
66.06
1,526.78
1,467.98
264.45
536.38
6,028,156.58
534,589.00
4.00
-304.28
End
Dir
: 1719.76' MD, 1526.78' TVD
1,800.00
54.11
66.06
1,573.82
1,515.02
290.83
595.80
6,028,183.23
534,648.29
0.00
-335.09
1,900.00
54.11
66.06
1,632.44
1,573.64
323.71
669.84
6,028,216.44
534,722.18
a00
-373.47
2,000.00
54.11
66.06
1,691.06
1,632.26
356.59
743.89
6,028,249.66
534,796.06
0.00
411.86
2,100.00
54.11
66.06
1,749.68
1,690.88
389.47
817.93
6,028,282.87
534,869.95
0.00
-450.25
2,200.00
54.11
66.06
1,808.30
1,749.50
422.35
891.97
6,028,316.08
534,943.83
0.00
-488.64
2,300.00
54.11
66.06
1,866.92
1,808.12
455.23
966.02
6,028,349.30
535,017.72
0.00
-527.02
2,337.32
54.11
66.06
1,888.80
1,830.00
467.50
993.66
6,028,361.70
535,045.30
0.00
-541.35
BPRF
2,400.00
54.11
66.06
1,925.54
1,866.74
488.10
1,040.06
6,028,382.51
535,091.61
0.00
-565.41
2,402.15
54.11
66.06
1,926.80
1,868.00
488.81
1,041.65
6,028,383.23
535,093.19
0.00
-566.23
SV1
2,500.00
54.11
66.06
1,984.16
1,925.36
520.98
1,114.11
6,028,415.73
535,165.49
0.00
-603.80
2,600.00
54.11
66.06
2,042.78
1,983.98
553.86
1,188.15
6,028,448.94
535,239.38
0.00
-642.19
2,700.00
54.11
66.06
2,101.40
2,042.60
586.74
1,262.20
6,028,482.15
535,313.26
0.00
-680.57
2,800.00
54.11
66.06
2,160.03
2,101.23
619.62
1,336.24
6,028,515.37
535,387.15
0.00
-718.96
2,900.00
54.11
66.06
2,218.65
2,159.85
652.50
1,410.29
6,028,548.58
535,461.04
0.00
-757.35
3,000.00
54.11
66.06
2,277.27
2,218.47
685.37
1,484.33
6,028,581.80
535,534.92
0.00
-795.74
3,100.00
54.11
66.06
2,335.89
2,277.09
718.25
1,558.38
6,028,615.01
535,608.81
0.00
-834.12
225/2020 6:00r57PM
Page 4
COMPASS
5000.15 Build 91E
HALLIBURTON
Database:
NORTH US+CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt Moose Pad
Well:
Plan: MPU M43 -Slot 52
Wellbore:
MPU M43
Design:
MPU M43 wp04
Planned Survey
Measured Vertical
Depth Inclination Azimuth Depth TVDss
(usft) (°) (°) (usft) usft
3,200.00 54.11 66.06 2,394.51 2,335.71
3,300.00 54.11 66.06 2,453.13 2,394.33
3,400.00 54.11 66.06 2,511.75 2,452.95
3,500.00 54.11 66.06 2,570.37 2,511.57
3,600.00 54.11 66.06 2,628.99 2,570.19
3,700.00 54.11 66.06 2,687.61 2,628.81
3,785.46 54.11 66.06 2,737.71 2,678.91
Start Dir 4°/100' : 3785.46' MD, 2737.71'TVD
3,800.00 54.01 66.76 2,746.24 2,687.44
3,900.00 53.44 71.68 2,805.43 2,746.63
4,000.00 53.08 76.65 2,865.27 2,806.47
4,005.87 53.06 76.94 2,868.80 2,810.00
UG_COAL1
4,100.00 52.92 81.65 2,925.48 2,866.68
4,200.00 52.98 86.66 2,985.75 2,926.95
4,300.00 53.24 91.66 3,045.80 2,987.00
4,400.00 53.71 96.60 3,105.34 3,046.54
4,500.00 54.39 101.47 3,164.07 3,105.27
4,600.00 55.25 106.25 3,221.71 3,162.91
4,665.61 55.92 109.33 3,258.80 3,200.00
LA3
4,700.00 56.30 110.92 3,277.98 3,219.18
4,800.00 57.52 115.47 3,332.60 3,273.80
4,900.00 58.89 119.89 3,385.31 3,326.51
5,000.00 60.42 124.17 3,435.84 3,377.04
5,100.00 62.07 128.33 3,483.96 3,425.16
5,200.00 63.85 132.35 3,529.44 3,470.64
5,232.95 64.46 133.65 3,543.80 3,485.00
UGNU MB
5,300.00 65.74 136.25 3,572.04 3,513.24
5,400.00 67.72 140.03 3,611.56 3,552.76
5,500.00 69.79 143.71 3,647.80 3,589.00
5,600.00 71.93 147.28 3,680.60 3,621.80
5,700.00 74.13 150.77 3,709.80 3,651.00
5,800.00 76.39 154.18 3,735.24 3,676.44
5,900.00 78.70 157.53 3,756.80 3,698.00
6,000.00 81.04 160.82 3,774.39 3,715.59
6,074.06 82.80 163.23 3,784.80 3,726.00
SB NA
6,100.00 83.42 164.07 3,787.91 3,729.11
6,207.96 86.00 167.55 3,797.87 3,739.07
End Dir : 6207.96' MD, 3797.87' TVD
6,300.00 86.00 167.55 3,804.29 3,745.49
6,400.00 86.00 167.55 3,811.27 3,752.47
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU M-43 - Slot 52
TVD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
MPU M43 Planned RKB @ 58.80usft (Doyon 14
North Reference:
True
Survey Calculation Method:
Minimum Curvature
225/2020 6:00:57PM Page 5 COMPASS 5000.15 Build 91E
Map
Map
+NIS
+E/ -W
Northing
Easting
DLS
Vert Section
(usft)
(usft)
(usft)
(usft)
2,335.71
751.13
1,632.42
6,028,648.22
535,682.69
0.00
-872.51
784.01
1,706.47
6,028,681.44
535,756.58
0.00
-910.90
816.89
1,780.51
6,028,714.65
535,830.47
0.00
-949.29
849.77
1,854.55
6,028,747.86
535,904.35
0.00
-987.67
882.64
1,928.60
6,028,781.08
535,978.24
0.00
-1,026.06
915.52
2,002.64
6,028,814.29
536,052.12
0.00
-1,064.45
943.62
2,065.92
6,028,842.68
536,115.27
0.00
-1,097.25
948.33
2,076.71
6,028,847.44
536,126.03
4.00
-1,102.77
976.93
2,152.04
6,028,876.38
536,201.23
4.00
-1,136.99
998.80
2,229.09
6,028,898.59
536,278.17
4.00
-1,164.62
999.87
2,233.67
6,028,899.69
536,282.73
4.00
-1,166.04
1,013.83
2,307.49
6,028,913.98
536,356.48
4.00
-1,185.54
1,021.94
2,386.84
6,028,922.46
536,435.79
4.00
-1,199.64
1,023.11
2,466.77
6,028,923.99
536,515.70
4.00
-1,206.85
1,017.32
2,546.88
6,028,918.57
536,595.83
4.00
-1,207.13
1,004.60
2,626.78
6,028,906.21
536,675.79
4.00
-1,200.50
985.01
2,706.09
6,028,886.99
536,755.18
4.00
-1,186.97
968.47
2,757.62
6,028,870.69
536,806.77
4.00
-1,174.38
958.65
2,784.42
6,028,861.00
536,833.62
4.00
-1,166.61
925.65
2,861.38
6,028,828.35
536,910.72
4.00
-1,139.53
886.17
2,936.61
6,028,789.22
536,986.12
4.00
-1,105.85
840.39
3,009.73
6,028,743.78
537,059.45
4.00
-1,065.74
788.55
3,080.39
6,028,692.27
537,130.34
4.00
-1,019.40
730.90
3,148.25
6,028,634.93
537,198.45
4.00
-967.05
710.68
3,169.93
6,028,614.81
537,220.22
4.00
-948.52
667.71
3,212.97
6,028,572.05
537,263.45
4.00
-908.94
599.30
3,274.23
6,028,503.92
537,325.02
4.00
-845.36
525.99
3,331.75
6,028,430.89
537,382.87
4.00
-776.61
448.15
3,385.24
6,028,353.30
537,436.71
4.00
-703.04
366.16
3,434.44
6,028,271.54
537,486.27
4.00
-625.01
280.40
3,479.10
6,028,186.00
537,531.33
4.00
-542.88
191.31
3,519.02
6,028,097.10
537,571.65
4.00
-457.06
.99.32
3,554.00
6,028,005.28
537,607.05
4.00
-367.98
29.58
3,576.62
6,027,935.65
537,629.98
4.00
-300.16
4.86
3,583.86
6,027,910.97
537,637.34
4.00
-276.06
-99.33
3,610.20
6,027,806.91
537,664.15
4.00
-174.15
-188.99
3,629.99
6,027,717.35
537,684.35
0.00
-86.25
-286.40
3,651.50
6,027,620.05
537,706.30
0.00
9.25
225/2020 6:00:57PM Page 5 COMPASS 5000.15 Build 91E
HALLIBURTON
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt Moose Pad
Well:
Plan: MPU M-43 - Slot 52
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Planned Survey
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU M-43 - Slot 52
TVD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Measured
Map
Map
Vertical
1,565.72
+El -W
Depth
Inclination Azimuth
Depth
TVDss
+NI -S
(usft)
(I
(I
(usft)
usft
(usft)
6,507.96
86.00
167.55
3,818.80
3,760.00
-391.57
Start Dir 4°/100' : 6507.96' MD,
3818.8'TVD
-9 5/8" x 121/4"
6,027,425.04
6,566.07
88.08
168.59
3,821.80
3,763.00
-448.34
SB NB (heel)
257.25
3,710.74
6,027,326.69
537,766.88
6,600.00
89.30
169.19
3,822.58
3,763.78
-481.62
6,658.39
91.39
170.23
3,822.23
3,763.43
-539.07
End Dir
: 6658.39' MD, 3822.23' TVD
537,819.12
0.00
6,700.00
91.39
170.23
3,821.22
3,762.42
-580.06
6,800.00
91.39
170.23
3,818.80
3,760.00
-678.59
6,900.00
91.39
170.23
3,816.37
3,757.57
-777.11
7,000.00
91.39
170.23
3,813.95
3,755.15
-875.63
7,100.00
91.39
170.23
3,811.53
3,752.73
-974.15
7,200.00
91.39
170.23
3,809.10
3,750.30
-1,072.67
7,300.00
91.39
170.23
3,806.68
3,747.88
-1,171.19
7,400.00
91.39
170.23
3,804.26
3,745.46
-1,269.71
7,500.00
91.39
170.23
3,801.83
3,743.03
-1,368.23
7,600.00
91.39
170.23
3,799.41
3,740.61
-1,466.75
7,625.19
91.39
170.23
3,798.80
3,740.00
-1,491.57
Start Dir 4°/100' : 7625.19' MD,
3798.8'TVD
7,700.00
91.46
173.22
3,796.94
3,738.14
-1,565.57
7,800.00
91.55
177.22
3,794.32
3,735.52
-1,665.17
7,900.00
91.63
181.22
3,791.54
3,732.74
-1,765.10
7,970.56
91.68
184.05
3,789.50
3,730.70
-1,835.55
End Dir
: 7970.56' MD, 3789.5' TVD
8,000.00
91.68
184.05
3,788.64
3,729.84
-1,864.90
8,100.00
91.68
184.05
3,785.71
3,726.91
-1,964.61
8,200.00
91.68
184.05
3,782.77
3,723.97
-2,064.32
8,300.00
91.68
184.05
3,779.84
3,721.04
-2,164.02
8,400.00
91.68
184.05
3,776.90
3,718.10
-2,263.73
8,500.00
91.68
184.05
3,773.97
3,715.17
-2,363.44
8,600.00
91.68
184.05
3,771.03
3,712.23
-2,463.15
8,700.00
91.68
184.05
3,768.10
3,709.30
-2,562.85
8,800.00
91.68
184.05
3,765.16
3,706.36
-2,662.56
8,900.00
91.68
184.05
3,762.23
3,703.43
-2,762.27
9,000.00
91.68
184.05
3,759.30
3,700.50
-2,861.98
9,100.00
91.68
184.05
3,756.36
3,697.56
-2,961.69
9,200.00
91.68
184.05
3,753.43
3,694.63
-3,061.39
9,300.00
91.68
184.05
3,750.49
3,691.69
-3,161.10
9,400.00
91.68
184.05
3,747.56
3,688.76
-3,260.81
9,500.00
91.68
184.05
3,744.62
3,685.82
-3,360.52
9,600.00
91.68
184.05
3,741.69
3,682.89
-3,460.23
9,700.00
91.68
184.05
3,738.75
3,679.95
-3,559.93
9,800.00
91.68
184.05
3,735.82
3,677.02
-3,659.64
9,900.00
91.68
184.05
3,732.89
3,674.09
-3,759.35
10,000.00
91.68
184.05
3,729.95
3,671.15
-3,859.06
3,882.83
Map
Map
0.00
1,565.72
+El -W
Northing
Easting
DLS
Vert Section
(usft)
(usft)
(usft)
3,760.00
1,765.63
3,674.72
6,027,515.00
537,730.00
0.00
112.36
3,686.71
6,027,458.29
537,742.25
4.00
168.06
3,693.25
6,027,425.04
537,748.94
4.00
200.76
3,703.68
6,027,367.65
537,759.63
4.00
257.25
3,710.74
6,027,326.69
537,766.88
0.00
297.59
3,727.71
6,027,228.26
537,784.30
0.00
394.55
3,744.67
6,027,129.82
537,801.71
0.00
491.50
3,761.64
6,027,031.39
537,819.12
0.00
588.45
3,778.60
6,026,932.96
537,836.54
0.00
685.41
3,795.57
6,026,834.53
537,853.95
0.00
782.36
3,812.53
6,026,736.10
537,871.37
0.00
879.32
3,829.50
6,026,637.66
537,888.78
0.00
976.27
3,846.46
6,026,539.23
537,906.20
0.00
1,073.23
3,863.43
6,026,440.80
537,923.61
0.00
1,170.18
3,867.70
6,026,416.00
537,928.00
0.00
1,194.60
3,878.46
6,026,342.06
537,939.10
4.00
1,267.58
3,886.79
6,026,242.51
537,947.88
4.00
1,366.26
3,888.15
6,026,142.60
537,949.69
4.00
1,465.80
3,884.90
6,026,072.14
537,946.77
4.00
1,536.29
3,882.83
6,026,042.78
537,944.83
0.00
1,565.72
3,875.78
6,025,943.05
537,938.24
0.00
1,665.68
3,868.72
6,025,843.32
537,931.64
0.00
1,765.63
3,861.67
6,025,743.59
537,925.05
0.00
1,865.59
3,854.62
6,025,643.86
537,918.45
0.00
1,965.54
3,847.56
6,025,544.13
537,911.86
0.00
2,065.50
3,840.51
6,025,444.41
537,905.26
0.00
2,165.45
3,833.46
6,025,344.68
537,898.66
0.00
2,265.41
3,826.41
6,025,244.95
537,892.07
0.00
2,365.37
3,819.35
6,025,145.22
537,885.47
0.00
2,465.32
3,812.30
6,025,045.49
537,878.88
0.00
2,565.28
3,805.25
6,024,945.76
537,872.28
0.00
2,665.23
3,798.20
6,024,846.03
537,865.69
0.00
2,765.19
3,791.14
6,024,746.30
537,859.09
0.00
2,865.14
3,784.09
6,024,646.57
537,852.50
0.00
2,965.10
3,777.04
6,024,546.84
537,845.90
0.00
3,065.05
3,769.98
6,024,447.11
537,839.31
0.00
3,165.01
3,762.93
6,024,347.38
537,832.71
0.00
3,264.97
3,755.88
6,024,247.66
537,826.11
0.00
3,364.92
3,748.83
6,024,147.93
537,819.52
0.00
3,464.88
3,741.77
6,024,048.20
537,812.92
0.00
3,564.83
2,252020 6:00.57PM Page 6 COMPASS 5000.15 Build 91E
Halliburton
H A LL I B U R TO N
Standard
Proposal Report
Database:
NORTH US
+ CANADA
Local Co-ordinate Reference: Well Plan: MPU M-43 - Slot 52
Company:
Hilcorp Alaska, LLC
TVD Reference:
MPU
M-43 Planned
RKB @ 58.80usft (Doyon 14
Project:
Milne Point
MD Reference:
MPU
M-43 Planned
RKB @ 58.80usft (Doyon 14
Site:
M Pt Moose
Pad
North Reference:
True
Well:
Plan: MPU M-43 - Slot 52
Survey Calculation
Method: Minimum
Curvature
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Planned Survey
Measured
Vertical
Map
Map
Depth Inclination Azimuth
Depth
TVDss
+N/ -S
+EI -W
Northing
Easting
DLS
Vert Section
(usft)
(1)
(^)
(usft)
usft
(usft)
(usft)
(usft)
(usft)
3,668.22
10,100.00
91.68
184.05
3,727.02
3,668.22
-3,958.76
3,734.72
6,023,948.47
537,806.33
0.00
3,664.79
10,200.00
91.68
184.05
3,724.08
3,665.28
-4,058.47
3,727.67
6,023,848.74
537,799.73
0.00
3,764.74
10,300.00
91.68
184.05
3,721.15
3,662.35
4,158.18
3,720.62
6,023,749.01
537,793.14
0.00
3,864.70
10,400.00
91.68
184.05
3,718.21
3,659.41
4,257.89
3,713.56
6,023,649.28
537,786.54
0.00
3,964.66
10,500.00
91.68
184.05
3,715.28
3,656.48
4,357.60
3,706.51
6,023,549.55
537,779.95
0.00
4,064.61
10,600.00
91.68
184.05
3,712.35
3,653.55
-4,457.30
3,699.46
6,023,449.82
537,773.35
0.00
4,164.57
10,700.00
91.68
184.05
3,709.41
3,650.61
-4,557.01
3,692.40
6,023,350.09
537,766.76
0.00
4,264.52
10,800.00
91.68
184.05
3,706.48
3,647.68
4,656.72
3,685.35
6,023,250.36
537,760.16
0.00
4,364.48
10,900.00
91.68
184.05
3,703.54
3,644.74
4,756.43
3,678.30
6,023,150.63
537,753.56
0.00
4,464.43
11,000.00
91.68
184.05
3,700.61
3,641.81
4,856.13
3,671.25
6,023,050.90
537,746.97
0.00
4,564.39
11,100.00
91.68
184.05
3,697.67
3,638.87
4,955.84
3,664.19
6,022,951.18
537,740.37
0.00
4,664.34
11,200.00
91.68
184.05
3,694.74
3,635.94
-5,055.55
3,657.14
6,022,851.45
537,733.78
0.00
4,764.30
11,300.00
91.68
184.05
3,691.80
3,633.00
-5,155.26
3,650.09
6,022,751.72
537,727.18
0.00
4,864.26
11,400.00
91.68
184.05
3,688.87
3,630.07
-5,254.97
3,643.04
6,022,651.99
537,720.59
0.00
4,964.21
11,500.00
91.68
184.05
3,685.94
3,627.14
-5,354.67
3,635.98
6,022,552.26
537,713.99
0.00
5,064.17
11,600.00
91.68
184.05
3,683.00
3,624.20
-5,454.38
3,628.93
6,022,452.53
537,707.40
0.00
5,164.12
11,700.00
91.68
184.05
3,680.07
3,621.27
-5,554.09
3,621.88
6,022,352.80
537,700.80
0.00
5,264.08
11,800.00
91.68
184.05
3,677.13
3,618.33
-5,653.80
3,614.82
6,022,253.07
537,694.21
0.00
5,364.03
11,900.00
91.68
184.05
3,674.20
3,615.40
-5,753.50
3,607.77
6,022,153.34
537,687.61
0.00
5,463.99
12,000.00
91.68
184.05
3,671.26
3,612.46
-5,853.21
3,600.72
6,022,053.61
537,681.01
0.00
5,563.95
12,100.00
91.68
184.05
3,668.33
3,609.53
-5,952.92
3,593.67
6,021,953.88
537,674.42
0.00
5,663.90
12,200.00
91.68
184.05
3,665.40
3,606.60
-6,052.63
3,586.61
6,021,854.15
537,667.82
0.00
5,763.86
12,300.00
91.68
184.05
3,662.46
3,603.66
-6,152.34
3,579.56
6,021,754.42
537,661.23
0.00
5,863.81
12,400.00
91.68
184.05
3,659.53
3,600.73
-6,252.04
3,572.51
6,021,654.70
537,654.63
0.00
5,963.77
12,424.76
91.68
184.05
3,658.80
3,600.00
-6,276.73
3,570.76
6,021,630.00
537,653.00
0.00
5,988.52
Start Dir 4°1100' : 12424.76' MD, 3658.8'TVD
12,435.60
91.92
184.41
3,658.46
3,599.66
-6,287.54
3,569.96
6,021,619.19
537,652.25
4.00
5,999.35
End Dir :
12435.6' MD, 3658.46' TVD
12,500.00
91.92
184.41
3,656.31
3,597.51
-6,351.71
3,565.01
6,021,555.01
537,647.60
0.00
6,063.72
12,600.00
91.92
184.41
3,652.96
3,594.16
-6,451.36
3,557.33
6,021,455.33
537,640.37
0.00
6,163.66
12,700.00
91.92
184.41
3,649.62
3,590.82
-6,551.01
3,549.64
6,021,355.66
537,633.14
0.00
6,263.60
12,800.00
91.92
184.41
3,646.28
3,587.48
-6,650.65
3,541.95
6,021,255.99
537,625.91
0.00
6,363.55
12,900.00
91.92
184.41
3,642.93
3,584.13
-6,750.30
3,534.27
6,021,156.32
537,618.68
0.00
6,463.49
13,000.00
91.92
184.41
3,639.59
3,580.79
-6,849.95
3,526.58
6,021,056.64
537,611.45
0.00
6,563.44
13,100.00
91.92
184.41
3,636.24
3,577.44
-6,949.60
3,518.89
6,020,956.97
537,604.22
0.00
6,663.38
13,200.00
91.92
184.41
3,632.90
3,574.10
-7,049.25
3,511.21
6,020,857.30
537,596.99
0.00
6,763.32
13,300.00
91.92
184.41
3,629.56
3,570.76
-7,148.89
3,503.52
6,020,757.63
537,589.76
0.00
6,863.27
13,400.00
91.92
184.41
3,626.21
3,567.41
-7,248.54
3,495.84
6,020,657.95
537,582.53
0.00
6,963.21
13,500.00
91.92
184.41
3,622.87
3,564.07
-7,348.19
3,488.15
6,020,558.28
537,575.30
0.00
7,063.16
13,600.00
91.92
184.41
3,619.53
3,560.73
-7,447.84
3,480.46
6,020,458.61
537,568.07
0.00
7,163.10
13,700.00
91.92
184.41
3,616.18
3,557.38
-7,547.49
3,472.78
6,020,358.94
537,560.84
0.00
7,263.04
13,800.00
91.92
184.41
3,612.84
3,554.04
-7,647.14
3,465.09
6,020,259.26
537,553.61
0.00
7,362.99
13,900.00
91.92
184.41
3,609.50
3,550.70
-7,746.78
3,457.40
6,020,159.59
537,546.39
0.00
7,462.93
14,000.00
91.92
184.41
3,606.15
3,547.35
-7,846.43
3,449.72
6,020,059.92
537,539.16
0.00
7,562.88
14,100.00
91.92
184.41
3,602.81
3,544.01
-7,946.08
3,442.03
6,019,960.25
537,531.93
0.00
7,662.82
2/252020 6:00:57PM
Page 7
COMPASS 5000.15 Build 91E
HALLIBURTON
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt Moose Pad
Well:
Plan: MPU M-43 - Slot 52
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Planned Survey
Measured
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
Vertical
North Reference:
Depth
Inclination Azimuth
Depth
TVDss
(usft)
(1)
V)
(usft)
usft
14,200.00
91.92
184.41
3,599.46
3,540.66
14,222.03
91.92
184.41
3,598.73
3,539.93
Start Dir
401100' : 14222.03' MD, 3598.73'TVD
14,300.00
88.80
184.43
3,598.24
3,539.44
14,319.93
88.00
184.44
3,598.80
3,540.00
14,360.23
86.39
184.45
3,600.77
3,541.97
End Dir
: 14360.23' MD, 3600.77' TVD
3,421.98
14,400.00
86.39
184.45
3,603.28
3,544.48
14,500.00
86.39
184.45
3,609.58
3,550.78
14,601.20
86.39
184.45
3,615.95
3,557.15
Start Dir401100' : 14601.2' MD,
3615.95'TVD
14,691.54
90.00
184.34
3,618.80
3,560.00
14,700.00
90.34
184.34
3,618.78
3,559.98
14,741.65
92.00
184.34
3,617.92
3,559.12
End Dir
: 14741.65' MD, 3617.92' TVD
-8,585.14
14,800.00
92.00
184.34
3,615.88
3,557.08
14,900.00
92.00
184.34
3,612.39
3,553.59
15,000.00
92.00
184.34
3,608.89
3,550.09
15,100.00
92.00
184.34
3,605.39
3,546.59
15,200.00
92.00
184.34
3,601.89
3,543.09
15,300.00
92.00
184.34
3,598.40
3,539.60
15,400.00
92.00
184.34
3,594.90
3,536.10
15,500.00
92.00
184.34
3,591.40
3,532.60
-15,600.00
92.00
184.34
3,587.90
3,529.10
15,700.00
92.00
184.34
3,584.41
3,525.61
15,800.00
92.00
184.34
3,580.91
3,522.11
15,860.31
92.00
184.34
3,578.80 -
3,520.00
Total Depth : 15860.31' MD, 3578.8' TVD
6,018,365.79
Halliburton
Standard Proposal Report
Local Co-ordinate Reference: Well Plan: MPU M-43 - Slot 52
TVD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
North Reference:
True
Survey Calculation Method:
Minimum Curvature
2252020 6:00:57PM Page 8 COMPASS 5000.15 Build 91E
Map
Map
+Nl-S
+E/ -W
Northing
Easting
DLS
Vert Section
(usft)
(usft)
(usft)
(usft)
3,540.66
-8,045.73
3,434.35
6,019,860.57
537,524.70
0.00
7,762.76
-8,067.68
3,432.65
6,019,838.62
537,523.11
0.00
7,784.78
-8,145.41
3,426.64
6,019,760.87
537,517.45
4.00
7,862.74
-8,165.27
3,425.10
6,019,741.00
537,516.00
4.00
7,882.67
-8,205.40
3,421.98
6,019,700.86
537,513.06
4.00
7,922.91
-8,244.97
3,418.90
6,019,661.28
537,510.17
0.00
7,962.60
-8,344.47
3,411.16
6,019,561.76
537,502.88
0.00
8,062.40
-8,445.16
3,403.32
6,019,461.04
537,495.51
0.00
8,163.40
-8,535.18
3,396.40
6,019,371.00
537,489.00
4.00
8,253.69
-8,543.62
3,395.76
6,019,362.57
537,488.40
4.00
8,262.14
-8,585.14
3,392.61
6,019,321.03
537,485.44
4.00
8,303.78
-8,643.28
3,388.20
6,019,262.87
537,481.30
0.00
8,362.10
-8,742.94
3,380.64
6,019,163.20
537,474.19
0.00
8,462.04
-8,842.59
3,373.09
6,019,063.52
537,467.09
0.00
8,561.97
-8,942.24
3,365.53
6,018,963.84
537,459.99
0.00
8,661.91
-9,041.89
3,357.97
6,018,864.17
537,452.89
0.00
8,761.85
-9,141.55
3,350.41
6,018,764.49
537,445.79
0.00
8,861.79
-9,241.20
3,342.85
6,018,664.82
537,438.69
0.00
8,961.73
-9,340.85
3,335.29
6,018,565.14
537,431.59
0.00
9,061.67
-9,440.50
3,327.73
6,018,465.46
537,424.49
0.00
9,161.61
-9,540.16
3,320.18
6,018,365.79
537,417.38
0.00
9,261.55
-9,639.81
3,312.62
6,018,266.11
537,410.28
0.00
9,361.49
-9,699.90
3,308.06
6,018,206.00
537,406.00
0.00
9,421.75
2252020 6:00:57PM Page 8 COMPASS 5000.15 Build 91E
uning vomrs
Hole
Measured
Vertical
Depth
Depth
Halliburton
H A LL I B U R TO N
6,507.96
3,818.80 9 5/8" x 12 1/4"
15,860.31
3,578.80 6 5/8" x 8 1/2"
Standard Proposal Report
Database: NORTH US + CANADA
UG_COAL1
Local Co-ordinate Reference:
Well Plan:
MPU M-43 - Slot 52
6,566.07
Company: Hilcorp Alaska, LLC
SB_NB (heel)
TVD Reference:
1,926.80
MPU M43 Planned RKB @ 58.80usft (Doyon 14
Project: Milne Point
1,888.80
MD Reference:
5,232.95
MPU M-43
Planned RKB @ 58.80usft (Doyon 14
Site: M Pt Moose Pad
3,258.80
North Reference:
6,074.06
True
SB—NA
Well: Plan: MPU M-43 - Slot 52
Survey Calculation Method:
Minimum
Curvature
Wellbore: MPU M-43
Design: MPU M43 wp04
Targets
Target Name
- hit/miss target Dip Angle
Dlp Dir. TVD
+NIS
+EI -W
Northing
Easting
- Shape
0
(1 (usft)
(usft)
(usft)
(usft)
(usft)
MPU M43 wp04 - Toe
0.00
0.00 3,578.80
-9,699.90
3,308.06
6,018,206.00
537,406.00
- plan hits target center
- Point
MPU M43 wp04 - CP3
0.00
0.00 3,598.80
-8,165.27
3,425.10
6,019,741.00
537,516.00
- plan hits target center
- Point
MPU M-43 wp04-CP2
0.00
0.00 3,658.80
-6,276.73
3,570.76
6,021,630.00
537,653.00
- plan hits target center
- Point
MPU M-43 wp04 - Heel
0.00
0.00 3,818.80
-391.57
3,674.72
6,027,515.00
537,730.00
- plan hits target center
- Point
MPU M43 wp04 - CP1
0.00
0.00 3,798.80
-1,491.57
3,867.70
6,026,416.00
537,928.00
- plan hits target center
- Point
MPU M43 wp04 - CP4
0.00
0.00 3,618.80
-8,535.18
3,396.40
6,019,371.00
537,489.00
- plan hits target center
- Point
uning vomrs
Hole
Measured
Vertical
Depth
Depth
(usft)
(usft) Name
6,507.96
3,818.80 9 5/8" x 12 1/4"
15,860.31
3,578.80 6 5/8" x 8 1/2"
Formations
Hole
Diameter
Measured
Vertical Vertical
12-1/4
Depth
Depth Depth SS
(usft)
(usft)
Name
4,005.87
2,868.80
UG_COAL1
1,441.41
1,342.80
SV5
6,566.07
3,821.80
SB_NB (heel)
2,402.15
1,926.80
SV1
2,337.32
1,888.80
BPRF
5,232.95
3,543.80
UGNU MB
4,665.61
3,258.80
LA3
6,074.06
3,784.80
SB—NA
Casing
Hole
Diameter
Diameter
9-5/8
12-1/4
6-5/8
8-1/2
Dip
Dip Direction
Lithology (') (1
225/2020 6:00:67PM Page 9 COMPASS 5000.15 Build 91E
Halliburton
HALLI B U RTO N Standard Proposal Report
Database:
NORTH US + CANADA
Company:
Hilcorp Alaska, LLC
Project:
Milne Point
Site:
M Pt Moose Pad
Well:
Plan: MPU M-43 - Slot 52
Wellbore:
MPU M-43
Design:
MPU M-43 wp04
Plan Annotations
Local Co-ordinate Reference:
Well Plan: MPU M-43 - Slot 52
TVD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
MD Reference:
MPU M-43 Planned RKB @ 58.80usft (Doyon 14
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
280.00
280.00
0.00
0.00
Start Dir 3-1100': 280' MD, 280'TVD
480.00
479.63
9.06
5.23
Start Dir 40/100': 480' MD, 479.63'TVD
1,719.76
1,526.78
264.45
536.38
End Dir : 1719.76' MD, 1526.78' TVD
3,785.46
2,737.71
943.62
2,065.92
Start Dir 401100': 3785.46' MD, 2737.71P/D
6,207.96
3,797.87
-99.33
3,610.20
End Dir : 6207.96' MD, 3797.87' TVD
6,507.96
3,818.80
-391.57
3,674.72
Start Dir 40/100' : 6507.96' MD, 3818.8'TVD
6,658.39
3,822.23
-539.07
3,703.68
End Dir : 6658.39' MD, 3822.23' TVD
7,625.19
3,798.80
-1,491.57
3,867.70
Start Dir 40/100' : 7625.19' MD, 3798.8'TVD
7,970.56
3,789.50
-1,835.55
3,884.90
End Dir : 7970.56' MD, 3789.5' TVD
12,424.76
3,658.80
-6,276.73
3,570.76
Start Dir 40/100' : 12424.76' MD, 3658.87VD
12,435.60
3,658.46
-6,287.54
3,569.96
End Dir : 12435.6' MD, 3658.46' TVD
14,222.03
3,598.73
-8,067.68
3,432.65
Start Dir 40/100' : 14222.03' MD, 3598.73'TVD
14,360.23
3,600.77
-8,205.40
3,421.98
End Dir : 14360.23' MD, 3600.77' TVD
14,601.20
3,615.95
-8,445.16
3,403.32
Start Dir 40/100' : 14601.2' MD, 3615.95'TVD
14,741.65
3,617.92
-8,585.14
3,392.61
End Dir : 14741.65' MD, 3617.92' TVD
15,860.31
3,578.80
-9,699.90
3,308.06
Total Depth : 15860.31' MD, 3578.8' TVD
2252020 6:00:57PM Page 10 COMPASS 5000.15 Build 91E
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Plan: MPU M-43 - Slot 52
MPU W43
MPU M-43 wp04
Sperry Drilling Services
Clearance Summary
Anticollision Report
25 February, 2020
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt Moose Pad - Plan: MPU M43 - Slot 52 - MPU M-43 - MPU M43 w 04
Well Coordinates: 6,02],889]0 N, 534,053.89 E (]0° 29' 13.99" N, 149° 43' 19.98" W)
Datum Height: MPU M-43 Planned RKB @ 58.89usft (Doyon 14)
Scan Range: 33.50 to 6,507.96 usft. Measured Depth.
Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usft
Geodetic Scale Factor Applied
Version: 5000.15 Build: 91E
Scan Type:
Scan Type: 25M ,
HALLIBURTON
Sperry Drilling Services
HALLIBURTON
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU M-43 wp04
Hileorp Alaska, LLC
Milne Point
Closest Approach 3D Proximity Scan on Current Survey Data (Noah Reference)
Reference Design: M Pt Moose Pad - Plan: MPU Mia - Slot 52. MPU Mia - MPU M43 wp04
Scan Range: 33.50 to 6,507.96 usfl. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 usfl
Measured Minimum @Measured Ellipse @Measuretl Clearance Summary Based on
Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning
Comparison Well Name- Wellbore Name -Design (usft) (usR) (usfl) (usft) ui
M Pt L Pad
MPL-20 - MPL-20 - MPL-20
MPL-32 - MPL-32 - MPL-32
MPL-32 - MPL-32 - MPL-32
MPL-32 - MPL-32 - MPL-32
M Pt Moose Pad
MPU M -10 -MPU M -10 -MPU M-10
MPU M-10 - MPU M-10 - MPU M-10
MPU M-10 - MPU M-10 - MPU M-10
MPU M -10 -MPU M-10PB1 - MPU M-10PB1
MPU M-10 - MPU M-10PB1 - MPU M-10PS1
MPU M-10 - MPU M-10PB1 - MPU M-10PS1
MPU M-10 - MPU M-10PB2 - MPU M-10PB2
MPU M-10- MPU M-10PB2 - MPU M-10PB2
MPU M-10- MPU M-10PB2 - MPU M-10PB2
MPU M -10 -MPU M-10PB3- MPU M-10PB3
MPU M-10 - MPU M-10PB3- MPU M-10PB3
MPU M -10 -MPU M-10PB3- MPU M-10PB3
MPU M-11 -MPU M-11 -MPU M-11
MPU M-11 -MPU M-11 -MPU M-11
MPU M-11 -MPU M-11 -MPU M-11
MPU M-12 - MPU M-12 - MPU M-12
MPU M-12 - MPU M-12 - MPU M-12
MPU M-12 - MPU M-12 - MPU M-12
MPU M-12- MPU M-12PB1 -MPU M-12PB1
MPU M-12 -MPU M-12PB1 -MPU M-12PB1
MPU M-12 -MPU M -12P81 -MPU M-12PB1
MPU M-12 - MPU M -12P82 - MPU M-12PS2
6,507,96
798.27
6,50796
634.51
9,891.99
4875 Clearance Factor
Pass -
5,983.50
684.05
5,983.50
545.57
10035.65
5,605 Clearance Factor
Pass -
6.43920
491.55
6,439.20
436,59
10,172.70
8.944 Centre Distance
Pass -
6,50]96
495.78
6,507.96
432.99
10,195.89
7.8% Ellipse Separation
Pass -
947.80
4535
947.80
38.89
930.58
7.016 Cents Distance
Pass -
5,783.50
120.64
5,783.50
3168
5,349.43
1.356 Ellipse Separation
Pass -
5,806.50
133.48
5,808.50
31.94
5,363.77
1.315 Clearance Factor
Pass -
947,80
45.35
947.80
38.89
930.58
7016 Centre Distance
Pass -
5,783.50
120.64
5,783.50
31.68
5,349.43
1.356 Ellipse Separation
Pass -
5,808.50
13348
5,808.50
31.93
5,363.77
1.314 Clearance Factor
Pass -
94780
45.35
94780
38.89
930.58
7.016 Centre Distance
Pass -
5,783.50
120.64
5,783.50
31.68
5,349.43
1.356 Ellipse Separation
Pass -
5,806.50
133.48
5,806.50
31.94
5,36377
1.315 Clearance Factor
Pass -
947.80
45.35
947.80
3889
930.58
7016 Centre Distance
Pass -
5,783.50
120.64
5,783.50
31.68
5,34943
1356 Ellipse Separation
Pass -
5,808.50
13348
5,808.50
31.94
5,363.77
1,315 Clearance Factor
Pass -
33.50
30.01
33.50
28.60
34.34
21.262 Centre Distance
Pass -
58.50
30.04
58.50
28.57
58.99
2o%7 Ellipse Separation
Pass -
6,458.50
175.66
6,458.50
93.12
6,181.46
2.128 Clearance Factor
Pass -
33.50
120.01
33.50
11860
34.25
85.015 Centre Distance
Pass -
158.50
120.39
158.50
118.38
158.04
80646 Ellipse Separation
Pass -
6,507.%
930.52
6,507.96
816.63
6,457.94
8.170 Clearance Factor
Pass -
33.50
120.01
33.50
118.60
34.25
85.015 Centre Distance
pass -
158.50
120.39
158.50
118.38
158.04
60646 Ellipse Separation
Pass -
1,208.50
202.48
1,20850
192.22
1,26162
19740 Clearance Factor
Pass -
33.50
120.01
33.50
118.60
34.25
65.015 Centre Distance
Pass -
25 February, 2020 - 18:01 Page 2 of 8 COMPASS
HALLIBURTON
Hileorp Alaska, LLC
Milne Point
Anticollision Report for Plan: MPU W43 - Slot 52 - MPU M-43 wp04
30686
193.02
306.86
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
309.38
74.467 Centre Distance
Pass -
Reference Design: MPI Moose Pad - Plan: MPU MJ -Slot 52 -MPU M43 -MPU M43 wp04
30850
193.02
308.50
Scan Range: 33.50 to 6,507.96 ush. Measured Depth.
311.04
74.210 Ellipse Separation
Pass -
Scan Radius Is Unlimited. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,500.00 usR
808.50
272.59
808.50
Measured Minimum @Measuretl Ellipse
@Measured
Clearance Summary Based on
Pass -
Site Name Depth Distance Depth Separation
Depth
Factor Minimum
Separation Warning
Comparison Well Name -Wellbore Name - Design (ui (usff) (.SR) (ustt)
Matt
141.353 Ellipse Separation
Pass -
M PU M -I2 -MPU M-12PB2-MPU M-12PB2 158.50 120.39 158.50 118.38
158.04
50.046 Ellipse Separation
Pass -
•PUM-I2-MPU M-12PB2-MPU M42PB2 6,507.96 930.52 6,507.96 81650
6,457.94
8.161 Clearance Factor
Pass -
MPU M -I3 -MPU M -131 -MPU M-13 295.95 13669 295.95 134.29
297.15
56.923 Centre Distance
Pass -
MPUM-I3-MPU M -13i -MPU M-13 30850 136]3 308.50 134.26
30970
55.356 Ellipse Separation
Pass -
MPU M -I3 -MPU M -13i -MPU 5-13 73350 193.17 733.50 188.33
717.39
39.874 Clearance Factor
Pass -
MPU M -I4 -MPU M -14 -MPU M-14
30686
193.02
306.86
190.43
309.38
74.467 Centre Distance
Pass -
MPU M -I4 -MPU M -I4 -MPU M-14
30850
193.02
308.50
190.42
311.04
74.210 Ellipse Separation
Pass -
MPU M -I4 -MPU M -14 -MPU M-14
808.50
272.59
808.50
266.99
78447
48710 Clearance Factor
Pass -
MPU M -15i -MPU M-15MPUM-15i
33.50
270.19
33.50
268.28
33.94
141.353 Ellipse Separation
Pass -
MPU M -15i -MPU MA5-MPU M -15i
958.50
410.97
958.50
404.40
922.31
62.555 Clearance Factor
Pass -
MPU M -15i -MPU M-15PB1 - MPU M-15PB1
33.50
270.19
33.50
268.28
33.94
141.353 Ellipse Separation
Pass -
MPU M -15i -MPU M-15PB1-MPU M-15PB1
958.50
410.97
958.50
404.40
922.31
62555 Clearance Factor
Pass -
MPU M -16 -MPU M -I6 -MPU M-16
33.50
352.48
33.50
351.07
34.18
249.694 Ellipse Separation
Pass -
MPU M -I6. MPU M -16 -MPU M-16
1,133.50
572.98
1,133.M
565.26
1,069.96
74.239 Clearance Factor
Pass -
MPU M -17i -MPU M-i7i-MPU M-171
33.50
438.00
33.M
436.59
Moo
310.273 Centre Distance
Pass -
MPU M -17i -MPU M -17i -MPU M-1 7i
283.50
438.40
283.M
43601
282.19
183.154 Ellipse Separation
Pass -
IsPUM-171-MPU M -17i -MPU M -1 7i1,133.50
65.07
1,133.0
648.26
1,057.15
84.059 Clearance Factor
Pass-
M PU M -I8 -MPU MA8-MPU M-18
3350
46666
33.5
465.45
MM2
330.719 Centre Distance
Pass -
•PUM-I8-MPU M -IB -MPU M-18
58.50
466.88
58.0
46543
57.96
320.183 Ellipse Separation
Pass -
MPU M -I8 -MPU M -I8 -MPU M-18
1.133.50
687.91
1.133.5
680.22
1,04550
89.482 Clearance Factor
Pass -
MPU M -I8 -MPU M-18PB1-MPU M-19PB7
33.50
466.86
33.50
465.45
34.42
330.719 Centre Distance
Pass -
MPUM-1a-MPU M-18PB1-MPU M-18PB1
58.50
466.88
58.50
465.43
5]96
320.183 Ellipse Separation
Pass -
MPU M -I8 -MPU M-18PB1-MPU M-18PB1
1,133.50
687.91
1,133.50
680.22
1,045.50
89.481 Clearance Factor
Pass-
MPU M -I8 -MPU M-18PB2-MPU M-18PB2
33.50
466.86
33.50
465.45
3442
330719 Centre Distance
Pass -
MPU M -I8 -MPU M-18PB2-MPU M-18PB2
58.50
466.88
58.50
465.43
57.96
320.183 Ellipse Separation
Pass -
MPU M -I8 -MPU M-18PB2-MPU M-18PB2
1.13350
687.91
1,133.50
580.22
1045.50
89.482 Clearance Factor
Pass -
MPU M -19i -MPU M -191 -MPU M-191
237.41
554.13
237.41
551.85
238.07
242,744 Centre Distance
Pass -
MPU M-191 - MPU M -191 -MPU M-191
283.50
M4.18
283.50
551.69
283.03
222.715 Ellipse Separation
Pass -
MPU M -19i -MPU M -191 -MPU M -19i
11585
613.76
ijii8S0
80576
1,012.99
101.664 Clearance Factor
Pass-
MPU M -19i -MPU M-19PB1-MPU M-19PB1
237.41
554.13
23241
551.85
238.07
242.74 Centre Distance
Pass -
25 February, 2020 - 1801 Page 3 of 8 COMPASS
HALLIBURTON
Hileorp Alaska, LLC
Milne Point
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU W43 wp04
283.50
210.22
283.50
Closest Approach an Proximity Scan on Current Survey Data (North Reference(
283.85
92.002 Centre Distance
Pass -
MPU M -20 -MPU M-20PB1-MPU M-20PB1
Reference Design: MPt Moose Pad - Plan: MPU M43 -Slot 52 -MPU M43 -MPU M-03 wp04
210.32
308.50
207.90
308.83
Scan Range: 33.50 to 6,507.96 usan. Measured Depth.
Pass -
MPU M -20 -MPU M-20PB1 - MPU M -20P81
2,783.50
1,051.77
Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,500.00 usff
1,010.99
2,965.45
25.789 Clearance Factor
Pass -
Measured Minimum. @Measured
Ellipse
@Measuretl
Clearance Summary Based on
207.93
Site Name Depth Distance Depth
Separation
Depth
Factor Minimum
Separation Warring
Comparison Well Name -Wellbore Name - Design (usR) loan) loan)
(usR)
Ulan
308.83
86.915 Ellipse Separation
MPU M -191 -MPU M-19PBI-MPU M-19PB1 283.50 554.18 283.50
551.69
283.03
222.715 Ellipse Separation
Pass -
MPU M -19i -MPU M-19PB1-MPU M-19PB1 1,158.50 813.76 1,158.50
80576
1,012.99
101.650 Clearance Factor
Pass -
MPU M -20 -MPU M -20 -MPU M-20 283.50 21022 283.50
207.93
28385
92.002 Centre Distance
Pass -
MPUM-20-MPU M -20 -MPU M-20 30850 210.32 308.50
207.90
30883
86.915 Ellipse Separation
Pass -
MPU M -20 -MPU M -20 -MPU M-20 2.783.50 1,051.77 2,783.50
1010.99
2,965.45
25.789 Clearance Factor
Pass -
MPU M -20 -MPU M-20PB1-MPU M-20PBI
283.50
210.22
283.50
20793
283.85
92.002 Centre Distance
Pass -
MPU M -20 -MPU M-20PB1-MPU M-20PB1
308.50
210.32
308.50
207.90
308.83
86.915 Ellipse Separation
Pass -
MPU M -20 -MPU M-20PB1 - MPU M -20P81
2,783.50
1,051.77
2,783.50
1,010.99
2,965.45
25.789 Clearance Factor
Pass -
MPU M -20 -MPU M-20PB2-MPU M-20PB2
283.50
210.22
283.50
207.93
283.85
92.002 Centre Distance
Pass -
MPU M -20 -MPU M-20PB2-MPU M-20PB2
Matto
210.32
306.50
207.90
308.83
86.915 Ellipse Separation
Pass -
MPUM-20-.MPU M-20PB2-MPU M-20PB2
2,783.50
1,051.77
2,783.50
1,01099
2,965.45
25189 Clearance Factor
Pass-
MPU M34 -MPU M -34 -MPU M-34
296.38
295.23
296.38
292.66
298.43
114.592 Centre Distance
Pass -
MPU M34 -MPU M -34 -MPU M-34
308.50
295.27
308.50
292.64
310.38
112.178 Ellipse Separation
Pass -
MPU M34 -MPU M34 -MPU M-34
858.50
416.63
858.50
410.85
784.94
71.987 Clearance Factor
Pass -
MPU M35i-MPU M -3N -MPU M35i
33.50
21865
33.50
216.74
34.40
114.391 Ellipse Separation
Pass -
MPU M35i-MPU M -35i -MPU M35i
858.50
34646
858.50
340.63
81044
59.462 Clearance Factor
Pass-
MPU M -35i -MPU M35PB1-MPU M35PB1
33.50
218.65
33.50
216.74
34.40
114.391 Ellipse Separation
Pass -
MPU M-351 - MPU M35PB1-MPU M35PB1
Ill
346.46
858.50
340.63
81044
59.462 Clearance Factor
Pass -
Man :MPU M -27 -M -27-M-27 wp02
258.50
123.71
258.50
121.10
238.70
47.441 Centre Distance
Pass -
Ran :MPU M -27 -M -27-M-27 wp02
283.50
12372
283.50
120.98
263.70
45,203 Ellipse Separation
Pass -
Plan :MPU M -27 -M -27-M-27 wp02
3,408.50
1,338.51
3,408.50
1,27192
3,534.08
20.101 Clearance Factor
Pass-
Plan : MPU M -28i - M -28i - M -28i wp01
258.50
127.32
258.50
124.72
238.70
48,840 Centre Distance
Pass -
Plan :MPU M -2M -M -28i -M-281 wp01
283.50
127.33
283.50
124.59
263.70
46.537 Ellipse Separation
Pass -
Plan :MPU M -28i -M -28i -M -28i wp01
5,133.50
579.40
5,133.50
523.35
5,448.83
10.336 Clearance Factor
Pass -
Plan. MPU M -29 -M -29-M-29 wpO2
258.50
13755
258.50
134.94
23570
52.796 Centre Distance
Pass -
Plan: MPU M-29 - M-29 - M-29 wp02
5,208.50
146.43
6,208.50
81.95
5,748.66
2.271 Ellipse Separallon
Pass -
Plan MPU M -29 -M -29-M-29 wp02
6,28350
166.80
6,283.50
88.79
5,695.19
2.138 Clearance Factor
Pass-
Plan : MPU M30i-M-30i-M30i wp02
258.50
153.06
258.50
150.45
238.70
58.796 Cenhe Distance
Pass -
Plan :MPUM-301-M-3N-M30i wp02
308.50
153.16
308.50
150.31
28806
53688 Ellipse Separation
Pass -
Plan: MPU M41Q-MJOi-M30i wp02
5,858.50
973.89
5,858.50
870.52
5,667.10
9,421 Clearance Factor
Pass -
25 February, 2020 - 18:01 Page 4 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU M-43 WP04
Hilcorp Alaska, LLC
Milne Point
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
258.50
180.08
258.50
177.01
258.40
Reference Design: MPt Moose Pad - Plan: MPU M43 -Slot 62 -MPU M43 -MPU M43
wp04
Plan MPU M-46 (MPU M-20 P2 - Slot 40) - M-20 Phas
308.50
180.18
308.50
Scan Range: 33.50 to 6,507.96 usft. Measured Depth.
308.40
54.315 Ellipse Separation
Pass -
Plan. MPU M46(MPUM-20 P2. Slot 40)-M-20 Pha:
1,533.50
375.96
Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited.
Max Ellipse Separation Is 1,500.00 usft
1,595.83
27.191 Clearance Factor
Pass -
Proposal: MPU M-09DSW-AP Hill -M-09DSW-APH
Measured Minimum
@Measured
Ellipse
@Measured
Clearance Summary Based on
4.383 Clearance Factor
Site Name
Depth Distance
Depth
Separation
Depth
Factor Minimum
Separation Warning
Comparison Well Name -Wellbore Name - Design
Wall) usft)
(usft)
(usft)
us"
258,50
147.31
PIan MPU M44i-Slot 58 -MPU M44i-MPU M44
1,132.28 64.29
1,132.28
58.7
1,096.55
10.342 Centre Distance
Pass -
Ram MPU M -04i -Slot 58 -MPU M -44i -MPU M44
1,158.50 6445
1,158.50
58.05
1,121.25
10071 Ellipse Separation
Pass -
Pan MPU M -04i -Slot 58 -MPU M -04i -MPU M44
1508.50 101.27
1,508.50
88.83
1,448.23
8.137 Clearance Factor
Pass -
Plan MPU M45 -MPU M45 -MPU M45 wool
258.50 60.09
258.50
57.63
258.40
24.464 Centre Distance
Pass -
Plan MPU M45 -MPU 1045 -MPU M45 wool
308.50 60.14
308.50
57.48
308.63
22832 Ellipse Separation
Pass -
Plan MPU M45 -MPU M45 -MPU M45 wool
608.50 7oO5
608.50
66.14
611.85
12938 Clearance Factor
Pass -
Plan MPU M46 (MPU M-20 P2 -Slot 40)-M-20 Phas
258.50
180.08
258.50
177.01
258.40
58.758 Centre Distance
Pass -
Plan MPU M-46 (MPU M-20 P2 - Slot 40) - M-20 Phas
308.50
180.18
308.50
176.87
308.40
54.315 Ellipse Separation
Pass -
Plan. MPU M46(MPUM-20 P2. Slot 40)-M-20 Pha:
1,533.50
375.96
1,533.5)
362.14
1,595.83
27.191 Clearance Factor
Pass -
Proposal: MPU M-09DSW-AP Hill -M-09DSW-APH
6,30850
554.54
6,308.50
428.03
6,13281
4.383 Clearance Factor
Pass -
Proposal: MPU M-09DSW-AP Hill -M-09DSW-APH
6,50796
47349
6,507.96
381.12
6,164.60
5.126 Ellipse Separation
Pass-
Slot 42-Placeholder-Slot 42-Placeholder-Slot 42-
258.50
149.94
258,50
147.31
220.70
56.972 Centre Distance
Pass -
Slot 42-Placeholder-Slot 42-PlacehDltler-Slot 42-
308.50
150.05
308.50
147.16
270.70
52.019 Ellipse Separation
Pass -
Slot 42-Placeholder-Slot 42-Placeholder-Slot 42-
758.50
200.01
758.50
194.62
715.25
37.70 Clearance Factor
Pass -
Slot 4bReconsider -Slot 43-PlacehDltler-Slot 43-
258.50
172.28
258.50
169.64
220]0
65.291 Centre Distance
Pass -
Slot 43-Placehdder-Slot 43-PlacehDltler-Sim 43-
283.50
172.29
283.50
169.52
245.70
62.243 Ellipse Sepmation
pass -
Slot 43-Placeholder-Slot 43-Placeholder-Slot 43-
783.50
239.03
783.50
233.46
739.26
42.921 Clearance Factor
Pass-
Slot 45-Placeholtler-Slot 45-Placeholtler-Slot 45-
258.50
152.93
256.50
150.29
220.70
57.915 Centre Distance
Pass -
Slot 45-Place,hDider-Sim 45-PlacehDltler-Slot 45-
283.50
152.93
283.50
15016
245.70
55.207 Ellipse Separation
Pass -
Slot 45-Placeholder-Slot 45-Placeholder-Slot 45-
783.50
218.42
78350
212.85
739.26
39.206 Clearance Factor
Pass -
Slot 16-Placeholder-Slot 46-Plawholder-Slot 46-
258.50
89.90
258.5)
8727
220.70
34.158 Centre Distance
Pass -
Slot 46-Placeholder-Slot 46-Placeholder-Slot 46-
308.53
90.00
308.50
87.12
270.70
31.203 Ellipse Separation
Pass -
Slot 16-Placeholder-Slot 46-Placeholder-Slot 46-
60850
109.52
608.50
105.11
569.07
24.855 Clearance Factor
Pass-
Slot 49-Placeholder-Slot 49-Placeholder-Slot 49-
258.50
127.27
258.50
124.63
220.70
48.140 Centre Distance
Pass -
Slot 49-PlacehDltler-Slot 49-Placeholder-Slot 49-
283.50
127.28
283.50
124.50
245.70
45.883 Ellipse Separation
Pan -
Slot 49-PlacehDltler-Slot 49-Placeholder-Slot 49-
783.50
185.06
783.50
179.49
739.26
33.191 Clearance Factor
Pass -
Slot 54-Placeholder-Slot 54-Placeholder-Slot 54-
583.88
24.63
583.88
20.38
544.80
5.796 Ellipse Separation
Pass -
SIM 54-Placehdtler-Slot 54-Placeholtler-Slot 54-
633.50
25.72
633.50
21.15
593.65
5631 Clearance Factor
Pass -
25 February, 2020 - 18:01 Page 5 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU W43 wp04
From
(usft)
3350
350.00
6,50] 96
To
(mi
350.00 MPU M43 wp0
6,501 MPUM43wpN
15,650.31 MPU M43 wp0
Survey/Plan
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres,
Clearance Factor= Distance Between Profiles / (Distance Behveen Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method
Survey Tool
3_Gyro-GC_Csg
3_MWDHFR2+MS+Seg
3 MWD+IFR2+MS+Sag
Hilcorp Alaska, LLC
Milne Point
25 February, 2020 - 18:01 Page 6 of 8 COMPASS
Prvjeel: Mllne P0inl
REFERENCE INFORWTION
WFyL pEI'gllSpurt FpU Mia-Sb152 NMIn]DNDCDN CgJl15) PJ�o] .
MALLIBYRTION
Site: M Pl Moose PaE
mlwsl aa'm.': uPu we pHu mane ly. i�rvenavm
5.10
m1l: Plan: MPU M -43 -SM 53
v'm'i Rv%a..... a m ® l%wn lal
XNBgY&veri(Cawntal
M"""'d e'�wa
yyy P ^8
Wilma., MPU rr443
ni'.Nwma50n
n nmum w
Dfe 000 02T199W 53.11.1 7P2913003N I4V 4P 11%2W
Plan: MPU M.43 Wp04
uavEV Pamaw N SekCi0n 6fitt¢nPN UAl1ia
ORvomma-n%oaom
NO GL0R4L FILTER. U5i350
W 3JSOT015800.31
To 15a
m'an>'aTe
Em
mpm'mm w io N'rv.� Wn CASMG DETAILS
Ladder/ S.F. Plots�""O'"APO""'
a
•1
ewr.sa 15ae0.at mvuw u. W.., i a� isaa•vs vs TVD '70355 MD Six N.
Of
1818.80 376000 6307.'. 15 95/8',.12
]5]880 333000 13850.31 6 -SA i8 6518".c 81x'tl'
18000
1500D
I
cO MP
12
N SI0t4
Pl..h.lder
0.90.00—
NIPQ
M44 W,02 j
Ir
W
b MPU
-00 yl
d 8000
-
-�-
MPU
b
5 Wp01 I'
d MPU
11
30M-
- �--_--
y
�
U
t
Slol
-PlauM1oiOx
l
0.00
0 350 700 1050 1400 17150 21100 2450 2800 3150 3500 3050 4200 4550 4900 5250 5600 5950 63100 6650
Measured Depth (700 ustUin)
4,00
I
I
i
i
Iii
I
g
300
I
I
LL
I
s°
Collision Risk Procedures R qq.
m 2,00-
,00
Collision Avoidance Req,
Collision
On
NOGOZone-Stop Onlling
10o
NOERRORS
0.00
0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3650 4200 4550 4900 5250 5600 5950 6300 6650
Measured Depth (700 usfifin)
Hilcorp Alaska, LLC
Milne Point
M Pt Moose Pad
Plan: MPU M-43 - Slot 52
MPU M-43
MPU M-43 wp04
Sperry Drilling Services
Clearance Summary
Anticollision Report
25 February, 2020
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: MPt Moose Pad -Plan: MPU M43 -Slot 52 -MPU M -43 -MPU M33wp04
Well Coordinates: 6,02],889.]0 N, 534,053.89 E (70° 29' 13.99" N, 149° 43' 17.98" W)
Datum Height MPU M43 Planned RKB @ 58.80usft (Doyon 14(
Scan Range: 6,507.96 to 15,860.31 deft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,500.00 daft
Geodetic Scale Factor Applied
Version: 5000.15 Build; 91E
Scan Type: • • -
Scan Type: 2500
HALLIBURTON
Sperrll Drilling Serviees
HALLIBURTON
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU W43 wp04
Hilcorp Alaska, LLC
Milne Point
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: M Pt Moose Pari - Plan: MPU M43 - Slot 52 - MPU M43 - MPU M43 Wp04
Scan Range: 6,607.96 to 15,660.31 usft. Measured Depth.
Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation Is 1,600.00 usft
Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on
Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning
Comparison Well Name -Wellbore Name - Design (usft) (usft) (usft) (usft) usft
M Pt L Pad
MPL-20 - MPL-20 - MPL-20
MPL-20 - MPL-20 - MPL-20
MPL-20 - MPL-20 - MPL-20
MPLJ2 - MPL-32 - MPL-32
MPLJ2 - MPL-32 - MPL-32
MPL-32 - MPL-32 - MPL-32
MPL35 - MPL-35 - MPL-35
MPLJ5 - MPL-35 - MPL-35
MPI415-MPL-35-MPL-35
M PLJS - MPL-35A - M P LJ5A
MPL415 - MPL-35A- MPL-35A
MPL-35 - MPL-35A- MPL35A
MPL415-MPL-35APB1 -MPL-35APBI
MPLJ5 - MPL-35APB1 -MPL-35APB1
MPL-35-MPL-35APB1-MPL35APB1
MPL-35 - MPL-35APB2 - MPL35APB2
MPL-35 - MPL-35APS2 - MPL435APB2
MPL-35 - MPL-35APM - MPL35APB2
MPL-35 - MPL-35APM - MPL-35APB3
MPL-35 - MPL-35APM - MPL-35APB3
MPL-35 - MPL-35APM - MPL-35APB3
MPL-36 - MPL-36 - MPL-36
MPL-36 - MPL36 - MPL-36
MPL-36 - MPL-36 - MPL-36
MPL-36 - MPL36L1 - MPL361-1
MPL-36 - MPL361-1 - MPL-361-1
MPL-36 - MPL361-1 - MPL36L1
MPL36-MPL4161-I FBI -MPLJ6LI PBI
7,207.96
264.71
7,207.96
141.77
10,235.82
2.153 Clearance Factor
Pass -
7,28296
23095
7,282.96
131.12
10,27418
2.313 Ellipse Separation
Pass -
7,39396
209.99
7,393.96
144.34
10,327.52
3.199 Centre Distance
Pass -
6,50796
495.78
6,507.96
432.99
10,195.89
7.896 Centre Distance
Pass -
6,53296
499.59
6,532.96
432.59
10,204.60
7,456 Ellipse Separation
Pass -
6,882.96
66360
6,882.96
534.57
10,345.39
5.143 Clearance Factor
Pass -
11,032.96
1,443.32
11,032.96
1,288.92
12,949.86
9.348 Clearance Factor
Pass -
11,882.96
1,321.49
11,8B2.96
1,200.94
13,609.36
10.963 Ellipse Separation
Pass -
11,984.00
1,319.54
11,984.00
1,203.13
13,66930
11.335 Centre Distance
Pass -
11,032.96
1,443.32
11,032.96
1,288.74
12,95066
9.337 Clearance Factor
Pass -
11882.96
1,321.49
11,882.96
1,200.77
13,610.16
10.947 Ellipse Separation
Pass -
11,984.00
1,319.54
11,984.00
1,202.98
13,670.10
11.321 Centre Distance
Pass -
11,032.96
1,443.32
11,032.96
1,288.61
12,95066
9.330 Clearance Factor
Pass -
11,882.96
1,321.49
11,882.96
1,200.65
13,61016
10.936 Ellipse Separation
Pass -
11,984.00
1,319.54
11,984.00
1202.86
13,670.10
11.308 Centre Distance
Pass -
11,032.96
1,443.32
11,032.96
1,288.61
12,95066
9.330 Clearance Factor
Pass -
11,882.96
1,321.49
11,882.96
1,200.65
13,610.16
10.936 Ellipse Separation
Pass -
11,984.00
1,31854
11984.00
1,202.86
13,670.10
11.308 Centre Distance
Pass -
11,032.96
1,44332
11,032.96
1,288.61
12,950.66
9.330 Clearance Factor
Pass -
11,582.96
1,32149
11,882.96
1,200.65
13,61016
10.936 Ellipse Separmon
Pass -
11,984.00
1,319.54
11,984.00
1,202.86
13,670.10
11.308 Centre Distance
Pass -
8,157.96
515.38
8,157.96
391.70
11,01154
4.167 Clearance Factor
Pass -
8,432.96
441.31
8,432.96
355.41
11,210.37
5.138 Ellipse Separation
Pass -
8,561.62
431.96
8,561.62
36339
11,299.22
6.299 Centre Distance
Pass -
8,157.96
515.38
8,157.96
39039
11,011.54
4.123 Clearance Factor
Pass -
8,407.96
44532
8,407.96
354.61
11,192.12
4.909 Ellipse Separation
Pass -
8,56162
431.96
8,561.62
363.08
11,299.22
6.271 Centre Distance
Pass -
8,157.96
515.38
8,157,96
389.40
11,011.54
4.091 Clearance Factor
Pass -
25 February. 2020 - 18:02 Page 2 of 8 COMPASS
Hileorp Alaska, LLC
HALLIBURTON Milne Point
Anticollision Report for Plan: MPU W43 - Slot 52 - MPU M-43 wp04
6,507.%
709.00
6,50]96
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
5,772.95
L785 Clearance Factor
Pass -
MPU M-10- MPU M-10PBI - MPU M-10PB1
6,507,96
Reference Design: MPt Moose Pad - Plan: MPU M43 -Slot 62. MPU M43 -MPU M43
sp04
560.82
5,772.95
4.785 Clearance Factor
Pass -
Scan Range: 6,507.96 to 15,860.31 usft. Measured Depth.
6,507.%
70SW
6,507.96
560.83
5,77295
Scan Radius is Unlimited . Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is 1,500.00 usft
Pass -
MPU M -10 -MPU M-1OP83-MPU M-10PB3
6,507.%
709.00
Measured Minimum
@Measured
Ellipse
@Measured
Clearance Summary Based on
MPU MAI -MPU M-11 -MPU M-11
Site Name Depth Distance
Depth
Separation
Depth
Factor Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design (usft) (usft)
(usft)
(usft)
usft
6,613.00
99.03
MPL36 - MPL-361-1 FBI -MPL-361-1 PBI 8,407.96 445.32
8,407.96
353.95
11,192.12
4.874 Ellipse Separation
Pass -
MPL-36-MPL36L1 PBI -MPL-36LI PB1 8,561.62 431.96
8,561.62
362.84
11,299.22
6.249 Centre Distance
Pass -
MPL36-MPL-WPB1-MPL-WPB1 8,157.96 515.38
8,157.96
391.71
11,011.54
4.167 Clearance Factor
Pass -
MPL36-MPL36PB1-MPL-WPB1 8,432.96 441.31
8,432.96
35541
11,210.37
5.138 Ellipse Separation
Pass -
MPL-36 - MPL-WPB1 - MPL-36PB1 8,551.62 431.96
8,561.62
363.39
11,299.22
6.299 Gene Distance
Pass-
MPU L53 -MPU L -53 -MPU L43 12,007.96 826.05
12,007.96
605.30
14,800.00
3.742 Clearance Factor
Pass -
MPUL53-MPU L -53 -MPU L53 12,032.96 825.32
12,032.96
605.06
14,800.00
3,747 Ellipse Separation
Pass -
MPUL-53-MPU L -53 -MPU L-53 12,044.59 825.24
12,044.59
605.25
14,800.00
3.751 Centre Distance
Pass -
M Pt Moose Pad
MPU M -10 -MPU M -10 -MPU M-10
6,507.%
709.00
6,50]96
560.83
5,772.95
L785 Clearance Factor
Pass -
MPU M-10- MPU M-10PBI - MPU M-10PB1
6,507,96
709.00
6,57.96
560.82
5,772.95
4.785 Clearance Factor
Pass -
MPU M -10 -MPU M-10PB2-MPU M-10PB2
6,507.%
70SW
6,507.96
560.83
5,77295
4.785 Clearance Factor
Pass -
MPU M -10 -MPU M-1OP83-MPU M-10PB3
6,507.%
709.00
6,57.96
560.83
5,77295
4785 Clearance Factor
Pass -
MPU MAI -MPU M-11 -MPU M-11
6,507.96
154.53
6,507.%
85.91
6,214.84
2.252 Ellipse Separation
Pass -
MPU M-11 -MPU M-11 -MPU M-11
6,613.00
13380
6,613.00
99.03
6,289.76
3.865 Centre Distance
Pass -
MPUM-II- MPU M -1I -MPU M-11
6,782.96
182.82
6,782.96
101.35
6,40464
2.244 Clearance Factor
Pass-
MPU M -I2 -MPU M -I2 -MPU M-12
7,632.96
202.51
7,632.96
105.73
7,23579
2.092 Clearance Factor
Pass -
MPU M -I2 -MPU M -I2 -MPU M-12
7,70]96
172.09
7,707.96
97.04
7,285.55
2.293 Ellipse Separation
Pass -
MPU M -I2 -MPU M -I2 -MPU M-12
7,807.04
154.43
7,807.04
116.47
7,347.81
4.068 Centre Distance
Pass -
MPU M -I2 -MPU M -12P02 -MPU M-12PM
7,632.96
202.51
7,632.96
105.60
7,235.79
2.090 Clearance Factor
Pass -
MPUM-I2-MPU M-12PB2-MPU M-12PB2
7707.96
17209
7,707.96
96.91
7,285.55
2.289 Ellipse Separation
Pass -
MPU M -I2 -MPU M-12PB2-MPU M-12PB2
7,807.04
154.43
7,807.04
116.35
7,347.81
4.055 Centre Distance
Pass-
M PU M -I3 -MPU M -13i -MPU M43
8,557.96
231.09
8,557.96
127.89
7,08823
2.239 Clearance Factor
Pass -
•PUM-I3-MPU M -13i -MPU M-13
8,632.96
195.45
8,632.96
118.15
7,125.31
2.528 Ellipse Separation
Pass -
•PUM-I3-MPU M -13i -MPU M-13
8,728.55
176.72
8,728.55
138.76
7,171.87
4.656 Centre Distance
Pass -
MPU M -I4 -MPU M -I4 -MPU M-14
9,482.96
223.82
9,482.96
106.50
7,565.47
1.908 Clearance Factor
Pass -
MPU M -I4 -MPU M -I4 -MPU M-14
9,557.96
186.31
9,55796
96.14
7,600.47
2.W6 Ellipse Separation
Pass -
MPU M -I4 -MPU M -I4 -MPU MA4
9,656.57
165.72
9,655.7
122.21
7,64874
3.809 Centre Distance
Pass-
MPU M -151 -MPU M -I5 -MPU M-151
10,432.96
213.59
10,432.96
96.81
7,963.35
1.829 Clearance Factor
Pass -
MPU M -15i -MPU M -I5 -MPU M -15i
10,482.96
187.82
10,48296
89.03
7,98879
1.901 Ellipse Separation
Pass -
25 February, 2020 - 18:02 Page 3 of 8 COMPASS
Hileorp Alaska, LLC
MALLIBURTON
Milne Point
Anticollision Report for Plan: MPU M-43 -
Slot 52 - MPU M-43 wp04
ClosestApproach 3D Proximity Scan on Current Survey Data (North Reference)
Reference Design: MPI Moose Pad - Plan: MPU M -43 -Slot 52 -MPU M43 -MPU Mia
arp04
Scan Range: 6,507.96 to 16,860.31 usft. Measured Depth.
Scan Radius Is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse
Separation is 1,500.00 usft
Measured
Minimum
@Measuretl
Ellipse
@Measuretl
Clearance Summary Based on
Site Name
Depth
Distance
Depth Separation
Depth
Factor Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
lusft)
(usft)
(usft)
(usft)
usft
MPU M-0Si-MPU M -15 -MPU M-151
1000.55
159.18
10,60055
11364
8,051.14
3.495 Centre Distance
Pass-
MPUM-151-MPU M-15PB1-MPU M-151381
10,432.96
216.22
10,432.96
6B.17
7,687.00
1.480 Clearance Factor
Pass -
MPU M -15i -MPU M-15PB1-MPU M-15PB1
10,45298
208.91
10,457.96
66.87
7,887.00
1.477 Ellipse Separation
Pass -
MPU M -151 -MPU M-15PB1-MPU M-15PB1
10,524.21
196.02
10,524.21
82.71
7,887.00
1,730 Centre Distance
Pass -
MPUM-16-MPU M -I6 -MPU M-16
11,407.96
214.80
11,407.96
87.42
8.57020
1.686 Clearance Factor
Pass -
• PU M-16 - M PU M -I6 -MPU M-16
11,432.96
202.00
11,432.96
84.31
8,582.43
1.716 Ellipse Separation
Pass -
•PUM-I6-MPU M -16 -MPU M-16
11,564.33
16749
11,564.33
112.99
8,650.39
3.073 Centre Distance
Pass-
•PU M -17i -MPU M -17i -MPU M -1 7i12,432.96
180.19
12,43296
34.77
9,350.76
1.239 Clearance Factor
Pace -
MPU M -17i -MPU MAT - MPU M -17i
12,457.96
167.03
12,457.96
32.87
9,363.98
1.245 Ellipse Sepandlon
Pass -
MPU MAT -MPU M -17i -MPU WWI
12,574.85
135.31
12,574.85
72.96
9,427.37
2.170 Centre Distance
Pass -
MPUM-18-MPU M -IB -MPU M-18
13,382.96
176.87
13,382.96
34.07
10,195.66
1239 Cluster. Factor
Pass -
•PUM-18-MPU M -IB -MPU M-16
13,50]66
139.74
13,507.68
69.83
10,255.84
1.993 Centre Distance
Pass-
MPU M -18 -MPU M-18PB1-MPU M-18PB1
13,509.98
125.94
13,509.98
57.77
10,268.13
1847 Centre Distance
Pass -
MPUM-18-MPU M-18PB1-MPU M-18PB1
13,632.98
164.71
13,632.96
1282
10,330.43
1.0114 Ellipse Sepa20on
Pass -
MPU M -18 -MPU M-18PB1-MPU M-18PB1
13,657.96
179.42
13,657.96
13.42
10,342.94
1.081 Clearance Factor
Pass -
MPUM-18-MPU M-18PB2-MPU M-18PB2
13,382.96
176.87
13,382.96
33.94
10,195.66
1.237 Clearance Factor
Pass -
MPU M -18 -MPU M-18PB2-MPU M-18PB2
13,507.68
139.74
13,507.68
69.50
10,255.84
1.989 Centre Distance
Pass-
MPU M -191 -MPU M -191 -MPU M191
14,517.21
140.40
14.517.21
62.95
11,082.95
1.813 Centre Distance
Pass -
MPUM-191-MPU M -191 -MPU M-191
14,632.96
17187
14,632.96
21.49
11,144.97
1.143 Ellipse Separation
Pass -
MPUM-191-MPU M -191 -MPU M-191
14,657.96
185.26
14,657.96
22.24
11,158.17
1.136 Clearance Factor
Pass -
MPU M-191 - MPU M-19PB1-MPU M-19PB1
14,517.21
14040
14,517.21
62.73
11,082.95
1.808 Centre Distance
Pass -
MPUM-191-MPU M -19P81 -MPU M-19PB1
14,632.96
171.67
14,632.96
21.24
11,144.97
1.141 Ellipse Separation
Pass -
MPUM-19i-MPU M -19P81 -MPU M-19PB1
14,657.96
185.28
14,657.96
21.98
11,158.17
1.135 Clearance Factor
Pass-
MPU M34 -MPU M34 -MPU M-34
12,682.98
309.25
12,582.96
158.87
9,19989
2.057 Clearance Factor
Pass -
MPUM34-MPU M34 -MPU M-34
12,782.96
27228
12,782.96
147.28
9,267.83
2.178 Ellipse Separation
Pass -
MPU M -34 -MPU M -34 -MPU M-34
12,989.34
239.65
12,989.34
17841
9,427.57
3.790 Centre Distance
Pass -
MPU M -35i -MPU M -35t -MPU M -35i
11,482.96
32280
11,482.96
190.39
8,33298
2.438 Clearance Factor
Pass -
MPU M35i-MPU M -35i -MPU M -35i
11,607.96
277.44
11,607.96
17347
8.422.89
2668 Ellipse Separation
Pass -
MPU M -35i -MPU M -35i -MPU M -35i
11,777.41
25227
11,77741
19526
8,543.62
4.425 Centre Distance
Pass-
MPU M35i-MPU M-35PB1-MPU M-35PB1
10,37.96
1,151.54
10,307.96
98601
6,954.00
6.957 Clearance Factor
Pass -
25 February, 2020 - 18 02
Page 4 of 8
COMPASS
HALLIBURTOiN
Hileorp Alaska, LLC
Milne Point
Anticollision Report for Plan: MPU M-43 - Slot 52 - MPU W43 wp04
To
Survey/Plan
Survey Tool
Closest Approach 3D Proximity Scan on Current Survey Data (North Reference)
(usft)
33.50
350.00
Reference Design: MPt Moose Pad - Plan: MPU M -03 -Slot 52 -MPU M -03 -MPU M43
wp04
350.00
6,507.96
MPU M43 wpD4
3_MM+IFR2+MS+Sag
Scan Range: 6,507.96 to 15,860.31 usk Measured Depth.
15,860.31
MPU MA3 wp04
3MWO-IFR2+MS+Sag
Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited.
Max Ellipse Separation is 1,500.00 usft
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor Minimum
Separation Warning
Comparison Well Name -Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
us"
MPU M -35i -MPU M-35PB1-MPU M-35PB1
10,532.96
1,11470
10,532.95
959.63
6,954.00
7.189 Ellipse Separation
Pass -
MPU M -35i -MPU M-35PB1-MPU M-35PBI
1D,605.99
1,112.30
10,60599
961.38
6,954.00
7.370 Centre Distance
Pass -
PlanMPU M -281 -M -28i -M -28i wp01
6,507.96
1,062.08
6,507.96
1,006AB
4,861.33
19.104 Ellipse Separation
Pass -
Plain MPU M -28i -M -281 -M -28i wp01
6,757.96
1,215.73
6,757.96
1,148.85
4,800.00
18.178 Clearance Factor
Pass -
Plan :MPU M -29 -M -29-M-29 wp02
6,507.96
290.70
6,507.96
192.32
5,559.74
2.955 Clearance Factor
Pass-
Plan: MPU M -30i -M -30i -M -30i wp02
6,612.66
654.66
6,612.66
602.08
5,535.28
12452 Centre Distance
Pass-
Plan:MPU M -30i -M -30i -M -30i wp02
6,73298
663.67
6,732.96
595.58
5,510.86
9.747 Ellipse Separation
Pass -
Plan: MPU M -30i -M -30i -M -30i wp02
7,132.96
825.05
7,132.96
706.04
5,455.34
6.933 Clearance Factor
Pass -
Plan: MPUM-04i-Slot 58 -MPU M -04i -MPU M -44w
7,494.86
907.63
7,494.86
836.66
7,145.76
12.789 Centre Distance
Pass -
Plan: MPU M -04i -Slot 58 -MPU M -44i -MPU M -44w
15,860.31
926.96
15,860.31
651.36
15,285.33
3.363 Clearance Factor
Pass-
Proposal: MPU M-09DSW-AP Hill -M-09DSW-APH
6,507.96
473.49
6,507.95
381.12
6,16460
5.126 Clearance Factor
Pass -
Proposal: MPUM-09DSW-AP Hill -M-09DSW-APH
6,628.09
458.95
6,62609
394.79
6,17893
7.153 Centre Distance
Pass -
Milne Point Exploration
MPU-Liviano-01-Liviano-01-Liviano-01
12,274.50
519.34
12,274.50
421.19
3,948.08
5,291 Centre Distance
Pass-
MPU-Livianc-0i-Liviano-0l-Liviano-01
12,30]96
520.41
12,307.96
420.24
3,945.74
5.1% Ellipse Separation
Pass -
MPU{iviano-0l-Liviano-0l-Liviano-01
12,407.96
536.12
12,40796
430.11
3,938.68
5.057 Clearance Factor
Pass -
MPUlrviano-0l-Liviano-0lA-Liviano-01A
12,305.74
595.15
12,305]4
594.67
3.873.29
6.932 Centre Distance
Pass -
MPU-Liviano-0l-Liviarm-0lA-Litiano-01A
12,332.96
695,68
12,332.96
594.29
3,871.47
6.862 Ellipse Separation
Pass -
MPU-Liviano-0l-Liviano-0l A-Uhlano-01A
12,457.96
711.73
12,457.96
60580
3,862.99
6.719 Clearance Factor
Pass -
From
To
Survey/Plan
Survey Tool
(usft)
(usft)
33.50
350.00
MPU M43 wpD4
3_Gyro-GCCsg
350.00
6,507.96
MPU M43 wpD4
3_MM+IFR2+MS+Sag
6,507.96
15,860.31
MPU MA3 wp04
3MWO-IFR2+MS+Sag
25 February, 2020 - 18:02 Page 5 of 8 COMPASS
HALLIBURTON
Anticollision Report for Plan: MPU W43 - Slot 52 - MPU W43 wp04
Ellipse error terms are corelated across survey tool tie -on points.
Calculated ellipses incorporate surface eras.
Separation Is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor= Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum CurvaNre method.
Rilcorp Alaska, LLC
Milne Point
25 February, 2020 - 1a02 Page 6of8 COMPASS
FIALLIBUFITON Pm1eG:"be Point
REFERENCE INFCRIMTICN VIpI DE AW:MWMU-Sbt52 MD 192](NRpCON CCNUS) MakvieneM
Site: MPR Moose Petl
23 10
v ��� Well: Fan: MPU XL43-Slot 52
°` v ��a
s.IQwl n.m.ee: uw µnpMM.a arce0edeow toetvnl{I
a µ{Cwnmd not ®at93 11 npn dal aWS aY/-W NOMinB E=305 llnnUc I.*Wn
WeIIWre: MPU X}43
dk0na'�Ne MPU
n e. . urvuv. OW
OW w2litt SJ{03389 A°2P Ia"3N 14T43 179U
Plan: MPU MJ3 w,64
auP.ev pnosarw
Paassaliwmw
er
NO GLOa4LFILTFA'. UZW9user NletlP3 cNena
®
wa: w Imra.m v.obe.
15NO3ektlione
9.50 151E0.31
Ladder/ SF. Plots
0
..w4 wpv wN
oeson
CASING DEfALLS
2 of
+e.w. wpa M,m
nm ee Mw Muee iMz az.rus•o
�n yn<ww M-4n �Px.ue.e.y
TVD WDSS MD St. Nano
JHI6 tl0 3760 C0 6507,96 9-518 95/3',121W
`
35790 352000 15860.31 6-3B 6W.SlR"
U
v V
pit 5000
I
!
1 ]]3]]]
9000
�I.
tI
f
I
--
U
U 30.00
L
i
U,
T-1
0 00
.
65M 70M 7500 8000 8500 9000 9500 10000 10500 11000 11500 12WO 1250D 131X00 13500 14000 14500 15000 15500 1600
Measured Depth (1000 ustUin)
MPU M-1
- Pkii
1.74
__..—
40
A
I
MPU'1
M-1
U
M-18
t5 3 00—_
L. __ .
iI
—J
LL
a
Collision Risk
Pmoedures
Req
q
!
A200
Collision Avoidance Req.
to
1.00
No-Go Zone - Stop Drilling
I
1
!
NOERRORS
I
i
0.00
1
I
I
.S. 7000 ]500 8000 850 9000 9500 1000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 16000
Measured Depth (1000 usft/in)
TRANSMITTAL LETTER CHECKLIST
WELL NAME: �[� / V3
PTD: 2-0
Development Service Exploratory _ Strraatigraaphis Test Non -Conventional
FIELD: / dlIA e- �� r { (� POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. , API No. 50- _
be function the original
(If last two digits
Production should continue to reported as a of
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50-_-
_-� from records, data and logs acquired for well
name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a
Spacing
conservation order approving a spacing exception. (Company Name)
Exception
Operator assumes the liability of any protest to the spacing exception
that may occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are fust caught and 10' sample intervals through taret zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non-
(name of well until after (Company Name) has designed and
Conventional
implemented a water well testing program to provide baseline data on
Well
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by (Company Name) in the attached application, the following well logs
are also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
Jcomposite
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 MILNE POINT, SCHRADER BLFF OIL - 525140
Well Name: MILNE PT UNIT M-43 Program DEV Well bore seg ❑
PTD#: 2200200 Company H lcorp Alaska LLC _ Initial Class/Type
DEV/PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached_ - - _ _ _ - - -
NA_
2
Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
- - - - Surf_ Loc, -Top PI & TD all lie with in_ADL0025514; however, aportion-of Well passes_thru ADL038823-5,.
3
Unique well -name and number - - _ _ _ _ _ - - - - - - - _Yes
_
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
4
Well located in_a_ defined pool - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - -
Yes
Milne Point Schrader_ Bluff_ Oil Pool (525140), governed by- CO 477, amended by CO 477.05.
5
Well located proper distance from_ drilling unit -boundary - _ _ _ _ _ _ _ _ _Yes
CO 477.05_ specifies:_ "There are no restrictions as to -well spacing except that no pay -shall----
6
Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - _ _ - - - - - -
Yes -
- - be opened_in a well closer than 500 feet from the exterior boundary of the affected area." - - -
7
Sufficient acreage -available in -drilling unit - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- _ _ _ _ - As planned, well conforms to spacing requirements. - _ - - - - - - -
8
-If deviated, is_wellbore plat -included
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 administrativ_e_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes _
_ _ _ _ _ _ _ _ _ _ _ - _
13
_Can permit beapprWed before 15-day_wait- - - - - - - - - - - - - - - - - - - -
Yes
SFD 2/28/2020
- - - - - - - - -
- - - - - - - - - - - - - - - - - - - _ - _ _ _ - - - - _ - - _ -
14
Well -located within area and -strata authorized by Injection Order# (put_10# in comments)_(For_
NA. _
- - _ _ - - - - - - - _ ---------------------------------------------
15
All wells _wit hin 1/4 -mile area_of review identified (For service well only)- - - - - - - - - - - - - -
NA_ _
_ _ _ _ _ _ - - - - -
16
Pre -produced injector: duration_of preproduction less than_3 months- (For service well only) _ _
NA- -
- - - - - - - - - - - - - -
17
N_onconven. gas -conforms to AS31.05.030(j.1_.A),02A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
_N_A_ -
- - - - - _ _ _ - _ -------------------------
18
Conductor string -provided _ _ - - . _ _ _ - - -
----------------------------
Yes -
- _ - _ _ . 20" conductor set 113 ft - - - - - _ _--
Engineering
19
Surface casin rotects all -known- USDWs - - - - - - - - - - - - - - - _ _ _ _ _ _
9 P-
NA_ -
- - - - - - No aquifers ..._ permafrost_a_rea_ - - - - - -
20
CMT -vol _adequate _to circulate_on conductor_& su_n`_csg - - - - - - - - - - - - - - - - - - - - - - - -Yes
-
- _ - _ _ _ 9 5/8" casing will be fully cemented._ 2 Stage. _ES tool at 2500 ft MD
21
CMT_vol_adequate to tie-in long string to -surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Yes -
_ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - -
22
CMT -will coverall know_n_pro_ductive horizons- - - - - - - - - - - - - - - - -
Yes _
- - - - - La_teral_w_i11_have screens. _No swell packers _
-
23
Casing designs adequate for CJ, B &_permafr_ost- - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - - BTC calculations are_provided._ _ - - - - - - - - - - - - - - - - - - - - - - - - - - -
24
Adequate tankage_or reserve pit
Yes _
_ _ _ _ _ _ Rig has steel pits. All drilling waste to be transported to disposal well.
25
If_a_re-drill, has_a_ 1.0-403 for abandonment been approved - - - _ - -
NA- -
- - - - - - - - - - - - - - - - - - - - - -
26
Adequate wellbore separation proposed- - - - _ _ _ - _ -
----------
Yes -
- - No issues._Moose pad.
27
If_diverter required, does itmeet_ regulations_ _ _ .
Yes -
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
Appr Date
28
-Drilling fluid_ program schematic-& equip list adequate_ - - - - - - - - - - - - -
Yes .
- - _ - - Max formation_ press= 1681 _psi_ .44 psi/ft_ Will drill with 8.9- 9.5 ppg_mud-
GLS 3/10/2020
29
BOPEs,_do they meet_ regulation _ -
Yes
- - _ Doyon 14 has 13 5/$' BOPE 5000_psi_WP - - - - _ - -
30
BOPE_press rating appropriate; test to -(put psig in comments)_ - - - - _ -
Yes -
- - - - _ MASP= 1336 psi Will test BOPE_to 3000_psi- _ _ - - - - _ - -
31
Choke_manifold complies w/API_RP-53 (May 84)_ - - - - - - - - - - - - - - - - - - . _
Yes -
- - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ - - - - - -
32
Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - -
Yes -
- - - - - _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
33
Is presence_ of H2S gas_ probable _ _ _ _ _
N_o_
34
Mechanical_condition of wells within AOR verified (For service well only) - - - - - - - - - - - - -
-N_A_
- - - - _ _ _ _ _ -
35
Permit--- - - - issued w/o hydrogen _sulfide measures - - - - - - - - - - - - - - - - - - - - - -
Yes
H2S not anticipated from drilling of offset wells; however, rig has H2S sensors and alar_m_s- - - - - - - -
Geology
36
Data_p_resented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - -
Yes
Gas_ hydrates not expected from drilling -of offset wells. -However, mitigation -measures are discussed -in - - -
Appr Date
37
Seismic analysis_ of shallow gas _zones - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
NA. -
- _ "Anticipated _Drilling Hazards"- section.- Abnormal pressure has been encountered in_M-Pad wells - - - - - - - -
SFD 2/28/2020
38
Seabed condition survey (if off_ -shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - --
--
NA_ -
- - - - - due to nearby injection. Managed Pressure Drilling will be used -to monitor and_control pressure, _ _ _ _ _ _ _ - -
39
Contact-name/phone for weekly -progress reportsplo
_[exratory only) _ - - -
NA_
Onsite materials su_fficient_to build system to_1_ppg above highest anticipated mud weight__ _ _ _ _ _ _ _ _ _ _ _
Geologic Engineering Public Wellbore breathing possible, discussed on p. 31.
Commissioner: Date: Commissioner: Date Commissioner Date
— 3112-12,0 reverse Jet pump completion. GLS
