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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, August 29, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT7-03A
GMTU MT7-03A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2024
MT7-03A
50-103-20830-01-00
223-084-0
W
SPT
8255
2230840 2064
1915 1917 1919 1920
250 275 275 275
4YRTST P
Sully Sullivan
7/15/2024
4 year MIT-IA no issues. Tested to 2900 for 500 psi dp
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:GMTU MT7-03A
Inspection Date:
Tubing
OA
Packer Depth
760 2900 2840 2835IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240717092423
BBL Pumped:3 BBL Returned:3
Thursday, August 29, 2024 Page 1 of 1
9
9
9
9
9
9
99
9 9
9 9 9
9 9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.29 15:23:23 -08'00'
Originated: Delivered to:5-Jul-24
Alaska Oil & Gas Conservation Commiss 05Jul24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24
2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24
1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24
CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24
CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24
3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24
2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24
2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24
2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24
MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24
MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39122
T39123
T39124
T39125
T39126
T39127
T39128
T39129
T39130
T39131
T39132
T39133
MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.05 10:30:21 -08'00'
Originated: Delivered to:19-May-24
Alaska Oil & Gas Conservation Commiss 19May24-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1A-03 50-029-206150-00-00 181-088 Kuparuk River WL Plug FINAL FIELD 3-Feb-24
3S-22 50-10320446-00-00 203-011 Kuparuk River WL IBC-CBL FINAL FIELD 5-Feb-24
3M-05 50-103-20875-00-00 223-126 Kuparuk River WL Isealate FINAL FIELD 10-Feb-24
2F-15 50-029-21048-00-00 183-172 Kuparuk River WL Isealate FINAL FIELD 13-Feb-24
MT7-14A 50-103-20856-01-00 223-064 Greater Mooses Tooth WL PPROF FINAL FIELD 20-Feb-24
MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24
3G-27 50-103-20801-00-00 219-039 Kuparuk River WL TTiX IPROF FINAL FIELD 2-Apr-24
2W-17 50-029-23370-00-00 207-135 Kuparuk River WL PPROF FINAL FIELD 9-Apr-24
1E-23 50-029-20858-00-00 182-184 Kuparuk River WL IPROF FINAL FIELD 10-Apr-24
1E-01 50-029-20464-00-00 180-039 Kuparuk River WL IPROF FINAL FIELD 11-Apr-24
1D-37 50-029-22992-00-00 200-204 Kuparuk River WL PPROF FINAL FIELD 12-Apr-24
3G-09 50-103-20129-00-00 190-067 Kuparuk River WL Punch-Cut FINAL FIELD 13-Apr-24
2P-420 50-103-20391-00-00 201-182 Kuparuk River WL CIBP-Cut FINAL FIELD 15-Apr-24
CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX Sampling FINAL FIELD 18-Apr-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
Eset #
T38800
T38801
T38802
T38803
T38816
T38817
T38818
T38819
T38820
T38821
T38822
T38824
T38823
T38825
MT7-03A 50-103-20830-00-10 223-084 Greater Mooses Tooth WL PPROF FINAL FIELD 29-Feb-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.20 12:41:13 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, April 4, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT7-03A
GMTU MT7-03A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 04/04/2024
MT7-03A
50-103-20830-01-00
223-084-0
W
SPT
8255
2230840 2064
1257 1258 1250 1255
480 510 510 510
INITAL P
Kam StJohn
2/9/2024
Initial MITIA post rig workover
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:GMTU MT7-03A
Inspection Date:
Tubing
OA
Packer Depth
610 2480 2440 2400IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS240210123107
BBL Pumped:2.5 BBL Returned:2.5
Thursday, April 4, 2024 Page 1 of 1
TT RR AA NN SS MM II TT TT AA LL
FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 330 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: Schlumberger COPA Wireline Backlog – Batch 2
DATE: 03/01/2024
Transmitted:
North Slope, GGMT
Via SFTP drop - DEVELOPMENT - AOGCC - SCHLUMBERGER
MT7-03A
1 of 1
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
Receipt: Date:
Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
223-084
T38551
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.03.04 09:15:42 -09'00'
1a. Well Status:Other Abandoned SuspendedSPLUGOil 1b. Well Class:
20AAC 25.105 20AAC 25.110 ExploratoryDevelopment
WDSPLGINJ WINJ No. of Completions: ____________________Stratigraphic TestService
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
15. API Number:7. Date Spudded:3. Address:
8. Date TD Reached: 16. Well Name and Number:4a. Location of Well (Governmental Section):
Surface:
17. Field / Pool(s):9. Ref Elevations: KB:
GL:100.8 BF:
10.Plug Back Depth MD/TVD: 18. Property Designation:Total Depth:
11. Total Depth MD/TVD: 19. DNR Approval Number:4b. Location of Well (State Base Plane Coordinates, NAD 27):
Zone- 4y-x-Surface:
12. SSSV Depth MD/TVD:Zone- 4y-x-TPI:
Zone- 4y-x-Total Depth:
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
N/A (ft MSL)Submit electronic information per 20 AAC 25.050
22. Logs Obtained:
23.
BOTTOM
120H-4020"10 yrds
3056'L-8013.375"
8304'L-807.625'
8289'L-804.5"
25.No24. Open to production or injection? Yes
26.
NoWas hydraulic fracturing used during completion? Yes
AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD)
27.
Method of Operation (Flowing, gas lift, etc.):Date First Production:
Gas-MCF:Production forHours Tested:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
39.8
AMOUNT
PULLED
16"
42"
BOTTOM
Tail: 308bbls of 15.3 Blend
39.8
11452'4.5"
DEPTH SET (MD)SIZE
11396'MD/8228'TVD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
12/10/2023 223-084
50-103-20830-01-00
285683
GMTU MT7-03A
AA081800, AA081781, AA081803
996' FSL, 1912' FWL, S32 T10N R2E UM
11/24/2023
19100'MD/8300'TVD
P.O. Box 100360, Anchorage, AK 99510-0360
5915818
CASING WT. PER
FT.
289990
Top of Productive Interval:
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,
12/3/2023
SETTING DEPTH TVD
TOP
Directional, GR, RES, NEU, DEN
11720'MD/8326'TVD
68
120'
39.9
282442
TOP
SETTING DEPTH MD
39.839.8
5911477
5918102
94
CASING, LINER AND CEMENTING RECORD
11447' 19095'
GRADE
PRODUCTION TEST
HOLE SIZE
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Lead: 483 bbls of 11ppg
DeepCRETE
Tail: 72bbls of 15.8ppg Class G
175bbls 11.0ppg cement
CEMENTING RECORD
11447'MD/8244'TVD
Injector
Oil-Bbl:Date of Test:
Per 20 AAC 25.283 (i)(2) attach electronic information
8255'12.6
PACKER SET (MD/TVD)
TUBING RECORD
6-1/2"
Flow Tubing
Liner ran on: 12/6/2023 - 11447' to19095' MD/ 8255' to 8289'TVD
Gas-Oil Ratio:Choke Size:Water-Bbl:
1817' FSL, 2875' FWL, S6 T9N R2E UM
Sr Res EngSr Pet GeoSr Pet Eng
Greater Mooses Tooth/Rendevous Pool
None
Oil-Bbl: Water-Bbl:
112.3bbls of 15.8 Class G11"37.111624'37.129.7
Submit within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 3/2020
3553'
3067' FSL,4725' FWL S36 T10N R1E UM
932535000, 932516000, 932538000
20. Thickness of Permafrost MD/TVD:
978'MD/977'TVD
By Grace Christianson at 8:29 am, Jan 04, 2024
Completed
12/10/2023
JSB
RBDMS JSB 011024
G
DSR-2/13/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
978 977
C40 1407 1400
1667 1649
2045 1993
3439 3003
4354 3616
4633 3807
HRZ 9937 7459 N/A
10027 7521
LCU/Miluveach 10203 7640
Top of Productive Interval
(Alpine C):11699 8321
Formation at total depth
(TD):19100 8300
31. List of Attachments:
Cement Report, Directional Survey, Well Schematic, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Longo
Contact Email:joseph.j.longo@conocophillips.com
Authorized Contact Phone:907-947-4323
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:
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.
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
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
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.
C30
Albian 97
Kalubik
C10
K-3
INSTRUCTIONS
Authorized Name:
Authorized Title:
Signature w/Date:
Joe Longo
Drilling Engineer
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.
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.
Albian 96
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).
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.
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 inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
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).
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Alpine C JSB
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Page 1/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/10/2023
00:00
11/11/2023
00:00
24.00 MIRU, MOVE MOB T Phase 3 condition. Wait on weather 0.0 0.0
11/11/2023
00:00
11/12/2023
00:00
24.00 MIRU, MOVE MOB T Phase 3 condition. Wait on weather 0.0 0.0
11/12/2023
00:00
11/12/2023
06:30
6.50 MIRU, MOVE MOB P Prep pad around MT7-03. Spot matting
boards.Un hook interconnects. BD
steam lines. Move ball mill.
0.0 0.0
11/12/2023
06:30
11/12/2023
14:00
7.50 MIRU, MOVE MOB P Lower cattle chute. Skid rig floor. LD
derrick. Stomp modules back and ose
trucks to pull down well row.
0.0 0.0
11/12/2023
14:00
11/13/2023
00:00
10.00 MIRU, MOVE MOB P Stomp out sub. Hook up jeep. Pull sub
to MT7-03 and spot on rig mats. Stomp
sub into position over MT7-03.
0.0 0.0
11/13/2023
00:00
11/13/2023
06:30
6.50 MIRU, MOVE MOB P Turn pipeshed. Spot in place.Pin pipe
shed. Lay mats for csg shed. Spot csg
shed. Spot pit module. Connect
interconnects.
0.0 0.0
11/13/2023
06:30
11/13/2023
12:00
5.50 MIRU, MOVE MOB P Stomp pump module and motor module
into place. Raise derrick. Skid rig floor.
Spot ball mill. Hook up modules.
Energize steam.
0.0 0.0
11/13/2023
12:00
11/13/2023
17:30
5.50 MIRU, MOVE MOB P Change out cable on cattle chute. Raise
cattle chute. Raise chutes in pipe shed.
Spool on drill line. Scope up derrick.
0.0 0.0
11/13/2023
17:30
11/13/2023
21:00
3.50 MIRU, MOVE MOB P Work on rig acceptance checklist. Test
Gen/Hiline sync. Troubleshoot Amphion
alarms. Test gas alarms.
Accept rig @ 21:00hrs 11/13/23
0.0 0.0
11/13/2023
21:00
11/14/2023
00:00
3.00 MIRU, WELCTL RURD P Build hooch around cellar. Take on fluid
to pis. C/O saver sub. Install belt guard
on mud pump.
0.0 0.0
11/14/2023
00:00
11/14/2023
05:00
5.00 MIRU, WELCTL RURD P Change out saver sub.Install
bails/clamps. Take on 8.8ppg VisBrine.
MU squeeze manifold in celllar. line up
to Frac tank.
Initial pressures:
IA - 640psi
TBG - 640psi
OA - 0psi
0.0 0.0
11/14/2023
05:00
11/14/2023
07:00
2.00 MIRU, WELCTL OWFF P Open IA to frac tank. Bleed off 100bbls
(diesel) to frac tank. Final pressure
750psi.
Line up TBG to frac tank. Bled from
720psi to 640psi.
0.0 0.0
11/14/2023
07:00
11/14/2023
10:00
3.00 MIRU, WELCTL CIRC P Line up and pump 275bbls 8.8ppg Vis
Brine down TBG. Stage up to 6 BPM.
Initial pressure: IA-1015psi/TBG-630psi
Final pressure: IA-1620pis/TBG-365psi
0.0 0.0
11/14/2023
10:00
11/14/2023
12:00
2.00 MIRU, WELCTL CIRC P Line up and pump 325bbls 8.8ppg Vis
Brine down IA. Stage up to 4 BPM.
Initial pressure:IA-1160psi/TBG-vac.
Final pressure: IA 620psi/TBG-220psi.
0.0 0.0
11/14/2023
12:00
11/14/2023
12:30
0.50 MIRU, WELCTL RURD P Flowcheck tubing and IA. Both on vac.
Install BPV.
0.0 0.0
11/14/2023
12:30
11/14/2023
13:00
0.50 MIRU, WELCTL PRTS P Perform rolling test on BPV. 4 BPM final
circulating pressure 550psi. No leaks
observed.
0.0 0.0
11/14/2023
13:00
11/14/2023
15:00
2.00 COMPZN, WHDBOP NUND P ND tree and tbg head adapter, Install
blanking plug in tbg hanger.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 2/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/14/2023
15:00
11/14/2023
22:00
7.00 COMPZN, WHDBOP NUND P NU BOPE and MPD equipment. 0.0 0.0
11/14/2023
22:00
11/15/2023
00:00
2.00 COMPZN, WHDBOP RURD P Install trip nipple. MU blank plug and
XO. Perform BOP break in procedure.
0.0 0.0
11/15/2023
00:00
11/15/2023
02:00
2.00 COMPZN, WHDBOP RURD P Pull test joint. Remove master bushings.
Seal up flow box.
0.0 0.0
11/15/2023
02:00
11/15/2023
02:45
0.75 COMPZN, WHDBOP RURD P MU BPA. Stage spooler to rig floor.
Hook up super sucker and retrieve
flashlight in BOPE stack.
0.0 0.0
11/15/2023
02:45
11/15/2023
04:45
2.00 COMPZN, WHDBOP BOPE P Attempt shell test. Observed leak. CO
ring gasket in choke line. Shell test.
Good.
0.0 0.0
11/15/2023
04:45
11/15/2023
06:00
1.25 COMPZN, WHDBOP BOPE P Testing BOPE. 0.0 0.0
11/15/2023
06:00
11/15/2023
14:45
8.75 COMPZN, WHDBOP BOPE T Test BOPE all test T/ 250 low for 5 min
and 5,000 high for 10 min charted. W/
exception of annular T/ 250 low for 5
min and 3,500 high for 10 min. Manual
operated & super choke tested T/2,000
psi charted, Test w/ 3 1/2" and 4 1/2"
test joint.Test choke valves 1-15,
manual operated & super choke, Choke
& kill manuals, HCR's, 4" valves on kill
line, 4" FOSV, 4" Dart valve, Upper and
lower IBOP on TD; Blind/shear rams;
Perform KOOMEY drawdown, ACC =
3000 PSI. MANIF. = 1500 PSI. ACC =
1800 PSI After all functions on bottles,
15 sec for 200 psi. Build W/ 2 Elec.
pumps, 97 sec T/ Build full system.
Pressure W/ 2 Elec. & 2 Air pumps,
Closing times, Annular = 26 sec. UPR =
14 sec. Blind / Shears = 6 sec. LPR = 5
sec. Choke HCR = 2 sec. Kill HCR = 2
sec; Test PVT G/L and flow out alarms,
Test LEL and H2S alarms.
Witnessed by AOGCC Cam St John.
BLM waived witness per Quinn Sawyer.
0.0 0.0
11/15/2023
14:45
11/15/2023
17:00
2.25 COMPZN, WHDBOP MPDA P RU and test MPD. 200psi low/1800psi
high f/ 5/10min ea. Good test.
0.0 0.0
11/15/2023
17:00
11/15/2023
18:00
1.00 COMPZN, WHDBOP RURD P BD choke manifold/Kill line. PU 4.5"
handling equipment, XO's.
0.0 0.0
11/15/2023
18:00
11/15/2023
19:30
1.50 COMPZN, WHDBOP OWFF P RU T-Bar. Check for flow below BPV.
Flow observed. Decision made to Kill
well pumping down tbg.
0.0 0.0
11/15/2023
19:30
11/15/2023
23:00
3.50 COMPZN, WHDBOP CIRC P Line up and pump down tbg @ 75 GPM.
ICP-930psi/FCP 140psi.
4480stks 380bbls pumped.
0.0 0.0
11/15/2023
23:00
11/16/2023
00:00
1.00 COMPZN, WHDBOP OTHR P Drain BOPE stack w/ Super Sucker vac
truck.
0.0 0.0
11/16/2023
00:00
11/16/2023
02:00
2.00 COMPZN, WHDBOP OWFF P Drain stack with Vac truck. Check for
pressure below BPV. Observed flow.
0.0 0.0
11/16/2023
02:00
11/16/2023
05:30
3.50 COMPZN, WHDBOP OTHR P Discuss plan forward with office. 0.0 0.0
11/16/2023
05:30
11/16/2023
08:30
3.00 COMPZN, WHDBOP OTHR P Pump down tbg to kill well. Stage rate to
4 BPM. 7100stks 600bbls
ICPs:
TBG:615psi
IA 235psi
FCP:
TBG: 615psi
IA: 165psi
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 3/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/16/2023
08:30
11/16/2023
10:30
2.00 COMPZN, WHDBOP OTHR P Check for pressure below BPV.No
pressure. Retrieve BPV. Monitor well.
Loss rate at 90 BPH.
0.0 0.0
11/16/2023
10:30
11/16/2023
13:00
2.50 COMPZN, WHDBOP OTHR P Pump down IA and tbg. 1/2 BPM down
tbg and 4 BPM down IA. 450 bbls.
ICP:
IA: 340psi
FCP:
IA: 930psi.
0.0 0.0
11/16/2023
13:00
11/16/2023
15:30
2.50 COMPZN, RPCOMP PULD P Back out lockdown screws. Pull tbg
hanger to rig floor. 216k. LD landing
joint,XOs and hanger.
0.0 0.0
11/16/2023
15:30
11/17/2023
00:00
8.50 COMPZN, RPCOMP PULD P POOH LD 4 1/2" tbg f/ 12376' to 7779'. 12,376.0 7,779.0
11/17/2023
00:00
11/17/2023
13:00
13.00 COMPZN, RPCOMP PULD P POOH LD 4 1/2" tbg f/ 7779' to surface. 7,779.0 0.0
11/17/2023
13:00
11/17/2023
14:30
1.50 COMPZN, WELLPR RURD P RD handling equipment. TEC spool.
Clean and clear rig floor.
0.0 0.0
11/17/2023
14:30
11/17/2023
15:30
1.00 COMPZN, WELLPR RURD P Stage BHA to rig floor. RU 4" handling
equipment.
0.0 0.0
11/17/2023
15:30
11/17/2023
16:15
0.75 COMPZN, WELLPR RURD P Install wear bushing. 0.0 0.0
11/17/2023
16:15
11/17/2023
16:45
0.50 COMPZN, WELLPR BHAH P PJSM. PU BHA 0.0 0.0
11/17/2023
16:45
11/17/2023
17:15
0.50 COMPZN, WELLPR SVRG P Service rig. Adjust link tilts. 0.0 0.0
11/17/2023
17:15
11/17/2023
19:00
1.75 COMPZN, WELLPR BHAH P PU and RIH w/ BHA to 291'. 0.0 291.0
11/17/2023
19:00
11/17/2023
23:00
4.00 COMPZN, WELLPR PULD P RIH w/ 6 1/2" BHA singling in w/ 4" DP f/
291' to 2345'.
291.0 2,345.0
11/17/2023
23:00
11/18/2023
00:00
1.00 COMPZN, WELLPR CIRC P Shallow test MWD. Good test. 2,345.0 2,345.0
11/18/2023
00:00
11/18/2023
13:15
13.25 COMPZN, WELLPR PULD P RIH w/ 6 1/2" BHA singling in w/ 4" DP f/
2345' to 11615'.
SimOps: Test MPD lines.
2,345.0 11,202.0
11/18/2023
13:15
11/18/2023
14:30
1.25 COMPZN, WELLPR SLPC P Slip/Cut drill line. 11,202.0 11,202.0
11/18/2023
14:30
11/18/2023
15:00
0.50 COMPZN, WELLPR SVRG P Service Top Drive. 11,202.0 11,615.0
11/18/2023
15:00
11/18/2023
16:00
1.00 COMPZN, WELLPR MPDA P Retrieve trip nipple and install RCD
bearing assembly.
11,615.0 11,615.0
11/18/2023
16:00
11/18/2023
16:45
0.75 COMPZN, WELLPR CIRC P Break circulation. Stage up pumps to
220 GPM/830 PSI. 40 RPM/10k TQ.
255k PU
125 SO
183k ROT
11,615.0 11,615.0
11/18/2023
16:45
11/18/2023
17:00
0.25 COMPZN, WELLPR PULD P RIH w/ 6 1/2" BHA singling in w/ 4" DP f/
11615' to 11678'.
Set down 25k @ 11678'.
11,615.0 11,678.0
11/18/2023
17:00
11/18/2023
19:00
2.00 COMPZN, WELLPR WASH P Wash down f/ 11678' to 12032'.
175 GPM
600PSI
11,678.0 12,032.0
11/18/2023
19:00
11/18/2023
21:00
2.00 COMPZN, WELLPR PULD P RIH w/ 6 1/2" BHA singling in w/ 4" DP f/
12032' to 13171'.
Obstruction encountered @ 13161'.
12,032.0 13,171.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 4/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/18/2023
21:00
11/18/2023
23:00
2.00 COMPZN, WELLPR REAM P Wash/Ream f/ 13171' to 13252'.
175 GPM
700 PSi
40 RPM
12k TQ
4-10k WOB
Observed PSI spike and hi TQ. Decide
to circulate BU.
13,171.0 13,251.0
11/18/2023
23:00
11/19/2023
00:00
1.00 COMPZN, WELLPR CIRC P Reciprocate string while CBU.
200 GPM
810 PSI
40 RPM
12k TQ
13,251.0 13,251.0
11/19/2023
00:00
11/19/2023
01:00
1.00 COMPZN, WELLPR CIRC P Reciprocate string while CBU.
200 GPM
810 PSI
40 RPM
12k TQ
13,251.0 13,251.0
11/19/2023
01:00
11/19/2023
05:00
4.00 COMPZN, WELLPR REAM P Wash/Ream f/ 13251' to 13350'.
200 GPM
800 PSi
40 RPM
14k TQ
185k ROT
13,251.0 13,350.0
11/19/2023
05:00
11/19/2023
07:30
2.50 COMPZN, WELLPR BKRM P Pack off @ 13350'. Work pipe. Re-
establish circulation. Stage pumps back
to 200 GPM. Unable to BROOH
continuing to packoff.
13,350.0 13,350.0
11/19/2023
07:30
11/19/2023
10:00
2.50 COMPZN, WELLPR BKRM P Reduce pump rate to 84 GPM/300 PSI.
BROOH to 13065'. Attempt to pull on
elevators. Observed 30k OP.
13,350.0 13,065.0
11/19/2023
10:00
11/19/2023
13:00
3.00 COMPZN, WELLPR BKRM P BROOH f/ 13065' to 12573'. 13,065.0 12,573.0
11/19/2023
13:00
11/19/2023
14:30
1.50 COMPZN, WELLPR SMPD P SOOH f/ 12573' to 11615'. 12,573.0 11,615.0
11/19/2023
14:30
11/19/2023
15:15
0.75 COMPZN, WELLPR RURD P RU cementing line pump in assembly. 12,573.0 11,615.0
11/19/2023
15:15
11/19/2023
16:30
1.25 COMPZN, WELLPR CIRC P CBU. 220 GPM. 870 PSI. 12,573.0 11,615.0
11/19/2023
16:30
11/19/2023
17:00
0.50 COMPZN, WELLPR CIRC P Establish injection rates @ 2/3/4 BPM.
2BPM - 430psi SPP/182psi ANN
3BPM - 550psi SPP/210psi ANN
4BPM - 720psi SPP/260psi ANN
11,615.0 11,615.0
11/19/2023
17:00
11/19/2023
20:00
3.00 COMPZN, WELLPR CIRC P PJSM. Test lines to 4000psi. Pump
35bbls 11.0ppg spacer + 110bbls
14.5ppg Thixotropic cement + 60bbls
14.0ppg Thixotropic cement + 20bbls
11.0ppg spacer and 20bbls FW. Closed
chokes as spacer exited bit and bull
head to loss zone. Swap over to rig
pumps and displace/bullhead 119bbls of
8.8ppg Vis Brine. 3 BPM FCP 1000psi
on IA/614psi SPP
11,615.0 11,615.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 5/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/19/2023
20:00
11/19/2023
21:15
1.25 COMPZN, WELLPR SQEZ P SD f/ 5 minutes
Squeeze 10bbls @ 1BPM - SPP
520psi/IA 380psi
SD f/ 10 minutes.
Squeeze 10bbls @ 1 BPM - SPP
375psi/IA 230psi
SD f/ 10 minutes.
Squeeze 10bbls @ 1 BPM - SPP
195psi/IA 4psi.
SD f/ 10 minutes.
Cement in place @ 21:15hrs 11/19/23
11,615.0 11,615.0
11/19/2023
21:15
11/19/2023
21:45
0.50 COMPZN, WELLPR SMPD P SOOH 5 stds to 11170'. 11,615.0 11,170.0
11/19/2023
21:45
11/20/2023
00:00
2.25 COMPZN, WELLPR CIRC P Stage up rates to 5 BPM. Check tools.
All good.
Pump 40bbl sugar water pill + 30 bbl
HiVis pill.
Chase pills w/ DS volume.
loss rate:
2 BPM 35 BPH
4 BPM 75 BPH.
11,170.0 11,170.0
11/20/2023
00:00
11/20/2023
06:00
6.00 COMPZN, WELLPR WOC P Waiting on cement. Circulate across top
of hole. Losses 25-30 BPH.
SimOPs: Adjust link tilt. Grease crown
and blocks. Troubleshoot electrical issue
from rig maintenance.
11,170.0 11,170.0
11/20/2023
06:00
11/20/2023
09:00
3.00 COMPZN, WELLPR WOC P Waiting on cement. Break circulation
and stage up to 200 GPM. Tools all
working.
Static losses 25-30 BPH.
11,170.0 11,170.0
11/20/2023
09:00
11/20/2023
10:00
1.00 COMPZN, WELLPR SMPD P Strip in hole to 11645'. 11,170.0 11,645.0
11/20/2023
10:00
11/20/2023
13:30
3.50 COMPZN, WELLPR RGRP T Troubleshoot VFD Chopper Issues. 11,645.0 11,645.0
11/20/2023
13:30
11/20/2023
15:45
2.25 COMPZN, WELLPR REAM P Ream in hole f/ 11645' to 12212'.
48 GPM
310 PSI
20 RPM
13k TQ
11,645.0 12,212.0
11/20/2023
15:45
11/20/2023
17:00
1.25 COMPZN, WELLPR CIRC P Circulate BU
200 GPM
840 PSI
40 RPM
14k TQ
12,212.0 12,212.0
11/20/2023
17:00
11/20/2023
21:30
4.50 COMPZN, WELLPR CIRC P Circulate
84 GPM
260 PSI
20 RPM
16k TQ
12,212.0 12,212.0
11/20/2023
21:30
11/21/2023
00:00
2.50 COMPZN, WELLPR CIRC T Take baseline parameters for opening
well commander. Drop 1.75" openng
ball. Pump down @ 2 BPM. No
indications of ball landing in seat after
pumping 50bbls over calculated strokes.
Continue pumping. Work drill pipe. Vary
RPMs. No indications ball seated.
12,212.0 12,212.0
11/21/2023
00:00
11/21/2023
01:30
1.50 COMPZN, WELLPR CIRC T Continue Adjusting parameters to shift
well commander open. No success.
Ream back down to 12212'
12,212.0 12,212.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 6/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/21/2023
01:30
11/21/2023
03:00
1.50 COMPZN, WELLPR CIRC P Pump 10 bbls spacer + 20 bbls 16.5ppg
Gel pill + 10 bbls spacer. Displace with
130bbls 8.8 Vis Brine. Close chokes and
bullhead into OH. Final circulating
pressure SPP 1177 psi/IA 675 psi.
12,212.0 12,212.0
11/21/2023
03:00
11/21/2023
04:15
1.25 COMPZN, WELLPR SMPD P SOOH to inside casing @ 11568'. 12,212.0 11,568.0
11/21/2023
04:15
11/21/2023
05:00
0.75 COMPZN, WELLPR MPDA P Flow check. Retrieve RCD bearing
assembly and install trip nipple.
12,212.0 11,568.0
11/21/2023
05:00
11/21/2023
05:30
0.50 COMPZN, WELLPR OWFF P Establish static loss rate.
15 BPH
11,568.0 11,568.0
11/21/2023
05:30
11/21/2023
06:00
0.50 COMPZN, WELLPR CIRC P Pump slug and blow down top drive. 11,568.0 11,568.0
11/21/2023
06:00
11/21/2023
08:30
2.50 COMPZN, WELLPR TRIP P Drop 2.5" drift w/ tail. POOH f/ 11568' to
7196'.
11,568.0 7,196.0
11/21/2023
08:30
11/21/2023
09:00
0.50 COMPZN, WELLPR RURD P Found 2.50" drift tail in Std #73. LD
singles and retrieved drift in top of Std
#72. Observed residual cement in STD.
MU singles and drop 2.14" drift w/ tail in
string.
7,196.0 7,196.0
11/21/2023
09:00
11/21/2023
12:00
3.00 COMPZN, WELLPR P POOH f/ 7196' to 1945' 7,196.0 1,945.0
11/21/2023
12:00
11/21/2023
12:30
0.50 COMPZN, WELLPR OWFF P Establish static loss rate.
21 BPH
1,945.0 1,945.0
11/21/2023
12:30
11/21/2023
14:00
1.50 COMPZN, WELLPR TRIP P TOOH f/ 1945' to 200'. 1,945.0 200.0
11/21/2023
14:00
11/21/2023
14:15
0.25 COMPZN, WELLPR OWFF P Flow check. Slow loss. PJSM f/ BHA 200.0 200.0
11/21/2023
14:15
11/21/2023
15:30
1.25 COMPZN, WELLPR BHAH P LD BHA. 200.0 0.0
11/21/2023
15:30
11/21/2023
16:00
0.50 COMPZN, WELLPR CLEN P Clean and clear rig floor. Stage Tbg
handling equipment.
0.0 0.0
11/21/2023
16:00
11/21/2023
17:00
1.00 COMPZN, WELLPR RURD P RU 3 1/2" Tbg handling equipment. 0.0 0.0
11/21/2023
17:00
11/21/2023
19:00
2.00 COMPZN, WELLPR PULD P PJSM. RIH w/ 3 1/2" cementing stinger. 0.0 1,230.0
11/21/2023
19:00
11/21/2023
19:45
0.75 COMPZN, WELLPR RURD P MU XO. RD tbg handling equipment. 1,230.0 1,230.0
11/21/2023
19:45
11/22/2023
00:00
4.25 COMPZN, WELLPR TRIP P RIH w/ 3 1/2" cement stinger on 4" DP f/
1230' to 10219'.
1,230.0 10,219.0
11/22/2023
00:00
11/22/2023
00:45
0.75 COMPZN, WELLPR TRIP P RIH f/ 10219' to 11546'. 10,219.0 11,546.0
11/22/2023
00:45
11/22/2023
01:15
0.50 COMPZN, WELLPR RURD P Flow check. Retrieve trip nipple. Install
RCD bearing assembly.
11,546.0 11,546.0
11/22/2023
01:15
11/22/2023
03:00
1.75 COMPZN, WELLPR CIRC P Establish loss rates @ 4 BPM. 24 BPH.
Obtain baseline parameters @ 2BPM.
257k PU
145k SO
182k ROT
10.5k TQ @ 10 RPM
11.5k TQ @ 15 RPM
11.7k TQ @ 20 RPM
11,546.0 11,546.0
11/22/2023
03:00
11/22/2023
03:30
0.50 COMPZN, WELLPR TRIP P RIH f/ 11546' to 12205' 11,546.0 12,205.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 7/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/22/2023
03:30
11/22/2023
05:45
2.25 COMPZN, WELLPR REAM P Wash/Ream in hole f/ 12205' to 12405'.
Observe taking weight @ 12405'. Work
string and wash down to 12492'.
84 GPM
200 PSI
20 RPM
13/14k TQ
180k ROT
12,205.0 12,492.0
11/22/2023
05:45
11/22/2023
10:00
4.25 COMPZN, WELLPR CIRC P Stage pumps to 210 GPM and circulate
3 BU. Rotate and reciprocate pipe.
210 GPM
491 PSI
12,492.0 12,492.0
11/22/2023
10:00
11/22/2023
12:00
2.00 COMPZN, WELLPR CIRC P Establish injection rates. Pump 100bbl
LCM pill + 10bbl spacer + 20bbls
16.5ppg Gel pill + 10bbls spacer. Chase
w/ 116bbls 8.8ppg Vis Brine. Close
chokes and bullhead as LCM pill exits
bit.
FCP:
SPP - 750psi
IA - 1060psi
12,492.0 12,492.0
11/22/2023
12:00
11/22/2023
13:30
1.50 COMPZN, WELLPR RURD P RU cementing assembly. PJSM.
Circulate @ 1 BPM/55PSI.
12,492.0 12,492.0
11/22/2023
13:30
11/22/2023
15:00
1.50 COMPZN, WELLPR CMNT P Flood lines and test to 3800psi. Good
test. Pump 30bbls 13.0ppg mudpush
spacer + 43bbls 16.5ppg G cement +
11bbls 13.0ppg mud push spacer.
Displace w/ 99 bbls 8.8ppg Vis Brine.
12,492.0 12,492.0
11/22/2023
15:00
11/22/2023
15:30
0.50 COMPZN, WELLPR RURD P RD cementing assembly and BD lines. 12,492.0 12,492.0
11/22/2023
15:30
11/22/2023
17:30
2.00 COMPZN, WELLPR BKRM P BROOH f/ 12492' to 11357'. Observed
several overpulls. Worked through.
1/4 BPM
10 RPM
8k TQ
12,492.0 11,357.0
11/22/2023
17:30
11/22/2023
20:00
2.50 COMPZN, WELLPR CIRC P Load nerf ball in DS. Circulate BU x 2.
Observed soft cement/Gel/LCM across
shakers at 1/3 of first BU. Dumped a
total of 387 bbls of contaminated
returns.
Established loss rate after circulating
BU. 6 BPH.
168 GPM
600 PSI
20 RPM
10k TQ.
11,357.0 11,357.0
11/22/2023
20:00
11/22/2023
20:45
0.75 COMPZN, WELLPR MPDA P Retrieve RCD bearing assembly and
install trip nipple.
11,357.0 11,357.0
11/22/2023
20:45
11/23/2023
00:00
3.25 COMPZN, WELLPR TRIP P POOH f/ 11357' to 6716'. 11,357.0 6,716.0
11/23/2023
00:00
11/23/2023
03:00
3.00 COMPZN, WELLPR TRIP P POOH f/ 6716' to 1230' 6,716.0 1,230.0
11/23/2023
03:00
11/23/2023
03:30
0.50 COMPZN, WELLPR RURD P Flow check. RU tbg handling equipment. 1,230.0 1,230.0
11/23/2023
03:30
11/23/2023
06:00
2.50 COMPZN, WELLPR PULD P POOH LD 3 1/2" tbg f/ 1230' to surface. 1,230.0 0.0
11/23/2023
06:00
11/23/2023
06:45
0.75 COMPZN, WELLPR RURD P RD tbg handling equipment. Clean and
clear rig floor.
0.0 0.0
11/23/2023
06:45
11/23/2023
09:00
2.25 COMPZN, DRILLOUT BHAH P PJSM. MU and RIH w/ 6 1/2" kick off
BHA.
0.0 318.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 8/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/23/2023
09:00
11/23/2023
11:00
2.00 COMPZN, DRILLOUT TRIP P RIH w/ 6 1/2" kick off BHA to 2633'. 318.0 2,633.0
11/23/2023
11:00
11/23/2023
11:30
0.50 COMPZN, DRILLOUT SVRG P Service Rig. 2,633.0 2,633.0
11/23/2023
11:30
11/23/2023
13:00
1.50 COMPZN, DRILLOUT RGRP T Change out switch on Top drive. 2,633.0 2,633.0
11/23/2023
13:00
11/23/2023
18:00
5.00 COMPZN, DRILLOUT TRIP P RIH w/ 6 1/2" kick off f/ 2633' to 11340'. 2,633.0 11,340.0
11/23/2023
18:00
11/23/2023
19:00
1.00 COMPZN, DRILLOUT SLPC P Slip/Cut drillline. 11,340.0 11,340.0
11/23/2023
19:00
11/23/2023
19:30
0.50 COMPZN, DRILLOUT SVRG P Service rig. 11,340.0 11,340.0
11/23/2023
19:30
11/23/2023
20:30
1.00 COMPZN, DRILLOUT WASH P Break circulation and wash down f/
11340'. Set down 15k @ 11469'.
200 GPM
1550PSI
11,340.0 11,469.0
11/23/2023
20:30
11/23/2023
22:00
1.50 COMPZN, DRILLOUT REAM P Wash/Ream f/ 11469' to 11644'. (20'
below shoe).
200 GPM
1550PSI
XX RPM
14-15k TQ.
11,469.0 11,644.0
11/23/2023
22:00
11/24/2023
00:00
2.00 COMPZN, DRILLOUT CIRC P Circulate BU and back ream into shoe to
11626'
200 GPM
1480 PSI
60 RPM
13k TQ.
11,644.0 11,626.0
11/24/2023
00:00
11/24/2023
00:30
0.50 COMPZN, DRILLOUT CIRC T Circulate BU and back ream into shoe to
11626' 200 GPM 1480 PSI 60 RPM 13k
TQ.
11,626.0 11,626.0
11/24/2023
00:30
11/24/2023
02:15
1.75 COMPZN, DRILLOUT FIT P RU and perform shoe test to 12.1ppg
EMW. RD test equipment.
11,626.0 11,626.0
11/24/2023
02:15
11/24/2023
03:15
1.00 COMPZN, DRILLOUT REAM P Wash/Ream f/ 11626' to 11720'.
200 GPM
1550 PSI
60 RPM
13k TQ
182k ROT
11,626.0 11,720.0
11/24/2023
03:15
11/24/2023
09:00
5.75 COMPZN, DRILLOUT DRLG P Reciprocate and ream to build trough for
side track. 11720' to 11682'.
200 GPM
1550 PSi
60-80 RPM
13k TQ
182k ROT
11,720.0 11,720.0
11/24/2023
09:00
11/24/2023
18:00
9.00 COMPZN, DRILLOUT DRLG P Time driill f/ 11720' to 11731'.
200 GPM
1550 PSI
80 RPM
13-14k TQ
188 ROT
11,720.0 11,731.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 9/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/24/2023
18:00
11/25/2023
00:00
6.00 COMPZN, DRILLOUT DRLG P Time driill f/ 11731' to 11758'.
200 GPM
1550 PSI
80 RPM
13-14k TQ
188 ROT
11,731.0 11,758.0
11/25/2023
00:00
11/25/2023
02:30
2.50 COMPZN, DRILLOUT DDRL P Time drill f/ 11758' to 11806'.
200 GPM
1530 PSI
80 RPM
13-14k TQ.
11,758.0 11,806.0
11/25/2023
02:30
11/25/2023
03:00
0.50 COMPZN, DRILLOUT CIRC P Take survey. Drift Sidetrack f/ 11720' to
11806'. Set down 15k to confirm new
hole.
11,806.0 11,806.0
11/25/2023
03:00
11/25/2023
05:00
2.00 COMPZN, DRILLOUT CIRC P Pump out of hole to 11695'. BROOH f/
11695' to 11622' while circulating BU.
200 GPM
1530 PSI
20 RPM
13-14k TQ
188k ROT
11,806.0 11,622.0
11/25/2023
05:00
11/25/2023
05:30
0.50 COMPZN, DRILLOUT OWFF P Flow check. Static. Pump slug. Blow
down Top Drive.
11,622.0 11,622.0
11/25/2023
05:30
11/25/2023
11:45
6.25 COMPZN, DRILLOUT TRIP P POOH to BHA at 270'. 11,622.0 270.0
11/25/2023
11:45
11/25/2023
12:30
0.75 COMPZN, DRILLOUT OWFF P Flow check. Static. Pull PS-21s and
install master bushings.
270.0 270.0
11/25/2023
12:30
11/25/2023
14:00
1.50 COMPZN, DRILLOUT BHAH P LD BHA. 270.0 0.0
11/25/2023
14:00
11/25/2023
15:00
1.00 COMPZN, DRILLOUT CIRC P Function rams and jet BOPE. 0.0 0.0
11/25/2023
15:00
11/25/2023
15:30
0.50 COMPZN, DRILLOUT CLEN P Clean and clear rig floor. 0.0 0.0
11/25/2023
15:30
11/26/2023
00:00
8.50 COMPZN, DRILLOUT BOPE P Test BOPE all test T/ 250 low for 5 min
and 5,000 high for 10 min charted. W/
exception of annular T/ 250 low for 5
min and 2,500 high for 10 min w/ 4" test
joint. Manual operated & super choke
tested T/2,000 psi charted, Test w/ 4"
and 4 1/2" test joint.Test choke valves 1-
15, manual operated & super choke,
Choke & kill manuals, HCR's, 4" valves
on kill line, 4" FOSV, 4" Dart valve,
Upper and lower IBOP on TD;
Blind/shear rams; Perform KOOMEY
drawdown, ACC = 3000 PSI. MANIF. =
1500 PSI. ACC = 1800 PSI After all
functions on bottles, 17 sec for 200 psi.
Build W/ 2 Elec. pumps, 97 sec T/ Build
full system. Pressure W/ 2 Elec. & 2 Air
pumps, Closing times, Annular = 27 sec.
UPR = 6 sec. Blind / Shears = 5 sec.
LPR = 5 sec. Choke HCR = 2 sec. Kill
HCR = 2 sec; Test PVT G/L and flow out
alarms, Test LEL and H2S alarms.
Witnessed by AOGCC Sean Sullivan .
BLM waived witness per Quinn Sawyer.
0.0 0.0
11/26/2023
00:00
11/26/2023
01:00
1.00 COMPZN, DRILLOUT BOPE P Test LPRs and manual chokes.
250/5000 PSI 5min low/10min high.
0.0 0.0
11/26/2023
01:00
11/26/2023
02:00
1.00 COMPZN, DRILLOUT RURD P Pull test plug/RD test equipment. Install
wear bushing and lock down.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 10/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/26/2023
02:00
11/26/2023
05:00
3.00 COMPZN, DRILLOUT BHAH P MU and RIH w/ 6 1/2" production BHA. 0.0 318.0
11/26/2023
05:00
11/26/2023
06:30
1.50 COMPZN, DRILLOUT TRIP P RIH f/ 318' to 790'. Rattling DP to
remove cement. Decision made to
POOH.
318.0 790.0
11/26/2023
06:30
11/26/2023
07:00
0.50 COMPZN, DRILLOUT TRIP T POOH to BHA. 790.0 318.0
11/26/2023
07:00
11/26/2023
08:30
1.50 COMPZN, DRILLOUT BHAH T Rack back majority of BHA. Remove
source.
318.0 0.0
11/26/2023
08:30
11/26/2023
12:00
3.50 COMPZN, DRILLOUT TRIP T MU open ended 4" mule shoe and RIH
w/ 4" DP to 6146'. Rattling each joint
with hammer to dislodge cement.
Observed cement coming out stds 1-13.
0.0 6,146.0
11/26/2023
12:00
11/26/2023
12:30
0.50 COMPZN, DRILLOUT SVRG T Service rig. (Power surge blacked out
rig trounbleshoot).
6,146.0 6,146.0
11/26/2023
12:30
11/26/2023
13:00
0.50 COMPZN, DRILLOUT RGRP T Troubleshoot power surge that blacked
out rig.
6,146.0 6,146.0
11/26/2023
13:00
11/26/2023
16:00
3.00 COMPZN, DRILLOUT TRIP T RIH w/ 4" DP f/ 6146' to 11542'. 6,146.0 11,542.0
11/26/2023
16:00
11/26/2023
17:30
1.50 COMPZN, DRILLOUT CIRC T Pump 50 bbl 8.8ppg BiCarb pill and
circulate surface to surface to clean drill
pipe.
500 GPM
1920 PSI
11,542.0 11,542.0
11/26/2023
17:30
11/26/2023
18:00
0.50 COMPZN, DRILLOUT OWFF T Flow check and blow down Top drive. 11,542.0 11,542.0
11/26/2023
18:00
11/27/2023
00:00
6.00 COMPZN, DRILLOUT TRIP T POOH f/ 11542' to 3200'. 11,542.0 3,200.0
11/27/2023
00:00
11/27/2023
00:30
0.50 COMPZN, DRILLOUT TRIP T POOH f/ 3200' to 2076'. 3,200.0 2,076.0
11/27/2023
00:30
11/27/2023
03:30
3.00 COMPZN, DRILLOUT PULD T POOH LD 4" DP f/ 2076' to HWDP. 3,200.0 180.0
11/27/2023
03:30
11/27/2023
04:30
1.00 COMPZN, DRILLOUT PULD T POOH LD 4" HWDP. Inspect and drift.
MU and rack back.
180.0 0.0
11/27/2023
04:30
11/27/2023
06:30
2.00 PROD1, DRILL BHAH T RIH w/ 6 1/2" production BHA. 0.0 318.0
11/27/2023
06:30
11/27/2023
10:00
3.50 PROD1, DRILL TRIP P RIH w/ 6 1/2" production BHA f/ 318' to
2211'.
318.0 2,211.0
11/27/2023
10:00
11/27/2023
10:30
0.50 PROD1, DRILL CIRC P Shallow test smart tools. Good test. 2,211.0 2,210.0
11/27/2023
10:30
11/27/2023
16:30
6.00 PROD1, DRILL TRIP P RIH f/ 2210' to 11487'. 2,210.0 11,487.0
11/27/2023
16:30
11/27/2023
18:00
1.50 PROD1, DRILL SLPC P Slip/Cut drill line.
SimOps: Circulate at 100 GPM.
11,487.0 11,487.0
11/27/2023
18:00
11/27/2023
18:30
0.50 PROD1, DRILL SVRG P Service top drive. 11,487.0 11,487.0
11/27/2023
18:30
11/27/2023
19:00
0.50 PROD1, DRILL CIRC P Bring pumps up to drilling rate and
check tools. All good.
11,487.0 11,487.0
11/27/2023
19:00
11/27/2023
20:00
1.00 PROD1, DRILL SMPD P Retrieve trip nipple and install RCD
bearing assembly.
11,487.0 11,487.0
11/27/2023
20:00
11/27/2023
21:00
1.00 PROD1, DRILL REAM P Wash/Ream f/ 11487' to 11806'.
100-200 GPM
370-1000 PSI
30-100 RPM
12-15k TQ.
11,487.0 11,806.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 11/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/27/2023
21:00
11/28/2023
00:00
3.00 PROD1, DRILL DDRL P Drill 11806' to 11887'. Displace to
8.8ppg FloPro Lite while drilling.
5-10k WOB
200 GPM
950 PSI
100-120 RPM
7k TQ
9.3ppg ECD
217k PU
160k SO
190k ROT
11,806.0 11,887.0
11/28/2023
00:00
11/28/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 11887' to 12438'.
15k WOB
230 GPM
1187 PSI
120 RPM
8k TQ
9.5ppg ECD
203k PU
167k SO
180k ROT
11,806.0 12,438.0
11/28/2023
06:00
11/28/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 12438' to 13005 MD'/ 8413' TVD.
15k WOB
230 GPM
1250 PSI
130 RPM
7k TQ
9.5ppg ECD
204k PU
164k SO
183k ROT
12,438.0 13,005.0
11/28/2023
12:00
11/28/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 13005' to 13628' MD'/ 8396' TVD.
Observed losses @ 13570'.
15k WOB
230 GPM
1187 PSI
130 RPM
7k TQ
9.6ppg ECD
205k PU
160k SO
185k ROT
13,005.0 13,628.0
11/28/2023
18:00
11/28/2023
19:00
1.00 PROD1, DRILL CIRC P Initial loss rate 130-140 BPH. Pump 50
bbls of 35 ppb LCM pill. Loses
decreased to 60-70 BPH before LCM
exited bit and then decreased to 20-30
BPH.
Note: Slow pump rate and turn off tools
before pill made it to smart tools.
13,628.0 13,628.0
11/28/2023
19:00
11/29/2023
00:00
5.00 PROD1, DRILL DDRL P Drill 13628' to 14184' MD'/ 8396' TVD.
Adding 10bbls of 35ppb per std to active
as background LCM. Losses 25-40
BPH
15k WOB
230 GPM
1345 PSI
120 RPM
7k TQ
9.7ppg ECD
205k PU
160k SO
190k ROT
13,628.0 14,184.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 12/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/29/2023
00:00
11/29/2023
03:30
3.50 PROD1, DRILL DDRL P Drill 14184' to 14592' MD'/ 8427' TVD.
Went on 70-90 BPH losses @ 14483'.
Pump 50bbls of 35ppb LCM pill.
15k WOB
230 GPM
1345 PSI
120 RPM
7k TQ
9.7ppg ECD
205k PU
160k SO
190k ROT
14,184.0 14,592.0
11/29/2023
03:30
11/29/2023
04:15
0.75 PROD1, DRILL CIRC P PU off bottom and slow rates to keep
tools off as LCM passed through BHA.
Losses decreasing to 40-50 BPH.
130 GPM
570 PSI
80 RPM
5k TQ
14,592.0 14,592.0
11/29/2023
04:15
11/29/2023
06:30
2.25 PROD1, DRILL DDRL P Drill 14592' to 14803' MD'/ 8363' TVD.
Went on total losses @ 14625'.Line up
pump on annulus @ 1bpm to keep hole
full.
15k WOB
230 GPM
1345 PSI
120 RPM
7k TQ
9.4ppg ECD
205k PU
160k SO
190k ROT
SimOps: Building LCM pill.
14,592.0 14,803.0
11/29/2023
06:30
11/29/2023
08:00
1.50 PROD1, DRILL BKRM T BROOH f/ 14803' to 14517'. Pumping
down annulus @ 3 BPM to keep hole
full.
200 GPM
930 PSI
80 RPM
4k TQ
SimOps: Building LCM pill.
14,803.0 14,517.0
11/29/2023
08:00
11/29/2023
10:15
2.25 PROD1, DRILL CIRC T Drop 1.75" WC opening ball and pump
down at 2 BPM. Landed @ 980 stks.
Shifted open @ 1357 PSI. Drop
Isolation ball and pump down @ 2 BPM.
SimOps: Building LCM pill.
14,517.0 14,517.0
11/29/2023
10:15
11/29/2023
14:00
3.75 PROD1, DRILL CIRC T Pump 100 BBLs of 100 PPB LCM pill.
With 30 BBLs of pill out of WC observed
returns. Start applying back pressure w/
MPD chokes. 200 PSI backpressure
and 400 PSI on DP @ 2 BPM. Continue
squeezing LCM pill. Losses deceased to
40 BPH. Drop 1.75" WC closing ball and
pump down @ 2 BPM/240 PSI. Ball
landed @ 965 STKs and shifted close
@ 1432 PSI. Stage up rates and verify
tools on.
14,517.0 14,517.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 13/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/29/2023
14:00
11/29/2023
15:00
1.00 PROD1, DRILL WASH T Wash in hole f/ 14517' to 14803'.
160-230 GPM
790-1300 PSI
14,517.0 14,803.0
11/29/2023
15:00
11/29/2023
19:00
4.00 PROD1, DRILL DDRL P Drill 14803' to 15182' MD'/ 8358' TVD.
Closing choke on connections. 0 PSI
build.
15k WOB
230 GPM
1345 PSI
120 RPM
7k TQ
9.4ppg ECD
205k PU
160k SO
190k ROT
Losses: 70-120 BPH
14,803.0 15,182.0
11/29/2023
19:00
11/29/2023
21:00
2.00 PROD1, DRILL BKRM T BROOH f/ 15182' to 14517'
185 GPM
1150 PSI
80 RPM
6k TQ
15,182.0 14,517.0
11/29/2023
21:00
11/29/2023
23:00
2.00 PROD1, DRILL CIRC T Obtain base parameters. Drop 1.75"
WC opening ball. Pump down @ 2
BPM/315 PSI. Landed @ 847stks.
Shifted @ 1733 PSI. Stage up rates and
confirm WC open. Drop 1.698" Isolation
ball and pump down @ 3 BPM 375 PSI.
14,517.0 14,517.0
11/29/2023
23:00
11/30/2023
00:00
1.00 PROD1, DRILL CIRC T Pump 100 BBLs 25 ppb Gel pill followed
by 100 BBLs of 100ppb LCM pill.
3 BPM
375 PSI
5 RPM
6k TQ.
14,517.0 14,517.0
11/30/2023
00:00
11/30/2023
01:30
1.50 PROD1, DRILL CIRC T Continue pumping pills. Close chokes
as pill exits WC. Bullhead pills below bit
decreasing rate from 120 GPM to 80
GPM as pressure increases. SD and
monitor pressures. Bled down to 0 PSI.
120-80 GPM
340 PSI final MPD pressure.
545 PSI final SPP
14,517.0 14,517.0
11/30/2023
01:30
11/30/2023
03:30
2.00 PROD1, DRILL OWFF T BROOH one std to 14422'. Pump
across top of hole and establish static
loss rate. 45 BPH.
14,517.0 14,422.0
11/30/2023
03:30
11/30/2023
04:00
0.50 PROD1, DRILL CIRC T Pump 1.75" WC closing ball down @ 2
BPM. Landed @ 930 STKS. Shifted
close @ 1460 PSI.
14,422.0 14,422.0
11/30/2023
04:00
11/30/2023
06:00
2.00 PROD1, DRILL CIRC T Stage pumps up to 200 GPM and
confirm tools working. Establish
dynamic loss rate. 72 BPH. SD and
pump across top of hole monitoring loss
rates.
14,422.0 14,422.0
11/30/2023
06:00
11/30/2023
09:30
3.50 PROD1, DRILL WAIT T Circulate across top of hole monitoring
losses while waiting on cement swivel to
arrive.
14,422.0 14,422.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 14/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/30/2023
09:30
11/30/2023
13:30
4.00 PROD1, DRILL BKRM T BROOH f/ 14422' to 13000'.
190 GPM
930 PSI
40 RPM
6k TQ
180k ROT
14,422.0 13,000.0
11/30/2023
13:30
11/30/2023
14:00
0.50 PROD1, DRILL CIRC T Stage up to 200 GPM and establish loss
rates. 84 BPH
200 GPM
990 PSI
5 RPM
5k TQ
13,000.0 13,000.0
11/30/2023
14:00
11/30/2023
14:30
0.50 PROD1, DRILL RURD T RU cement swivel and cement line. 13,000.0 13,000.0
11/30/2023
14:30
11/30/2023
15:00
0.50 PROD1, DRILL CIRC T Establish injection rates.
2 BPM - 300 PSI SPP/0PSI IA
3 BPM - 598 PSI SPP/300 PSI IA.
4 BPM - 930 PSi SPP/345 PSI IA
13,000.0 13,000.0
11/30/2023
15:00
11/30/2023
17:30
2.50 PROD1, DRILL CMNT T PJSM. Pump 5 BBLs FW. Test lines to
3500 PSI. Mix and pump 30 BBLs 11.0
PPG Mud Push spacer + 125 BBLs 14.0
PPG Thixotropic cement + 21 BBLs 11.0
PPG Mud Push spacer. Chase w/ 20
BBLs FW. (Closed chokes and bullhead
at 100 BBLs away). Swap over to rig
pumps and bullhead w/ 115 BBLs 8.8
PPG FloPro. SD and monitor pressure.
Bled to 0 PSI.
Cement in place @ 17:30 hrs 11/30/23
3 BPM
38-945 PSI SPP
320-472 PSI IA
13,000.0 13,000.0
11/30/2023
17:30
11/30/2023
18:00
0.50 PROD1, DRILL RURD T RD Cement line and LD swivel.
Establish static los rates. 58 BPH.
13,000.0 13,000.0
11/30/2023
18:00
11/30/2023
20:30
2.50 PROD1, DRILL SMPD T SOOH f/ 13000' to 11586'. Holding
8.8ppg EMW w/ MPD
13,000.0 11,568.0
11/30/2023
20:30
11/30/2023
21:00
0.50 PROD1, DRILL OWFF T Establish Static loss rate. 48 BPH. 11,568.0 11,568.0
11/30/2023
21:00
11/30/2023
23:00
2.00 PROD1, DRILL CIRC T Circulate down drillstring at 120 GPM
(below tool rate) for 10 minutes. Pump
50 BBLs sugar water and stage rates up
to 200 GPM. Confirm tools working.
Pump sugar surface to surface to scour
drillstring and clean tools. Dynamic loss
rate 65 BPH.
200 GPM
1100 PSI
9.4ppg ECD
10 RPM 4k TQ
11,568.0 11,568.0
11/30/2023
23:00
12/1/2023
00:00
1.00 PROD1, DRILL OWFF T Circulate across top of hole. WOC and
monitor loss rate. Static loss rate 48
BPH.
11,568.0 11,568.0
12/1/2023
00:00
12/1/2023
08:30
8.50 PROD1, DRILL OWFF T Circulate across top of hole. WOC and
monitor loss rate. Static loss rate 48
BPH.
11,568.0 11,568.0
12/1/2023
08:30
12/1/2023
10:00
1.50 PROD1, DRILL SMPD T Install RCD bearing and SIH to 13000'
while WOC.
11,568.0 13,000.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 15/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/1/2023
10:00
12/1/2023
16:30
6.50 PROD1, DRILL REAM T Wash/Ream f/ 13000' to 15183'.
150-180 GPM
500-1100 PSI
40-70 RPM
6-14k TQ
Loss rate- 20-30 BPH
13,000.0 15,183.0
12/1/2023
16:30
12/1/2023
18:45
2.25 PROD1, DRILL CIRC T Tools stopped pulsing. Recycle pumps.
Troubleshoot. Pumped 30 BBL FW pill.
Tools came back on.
15,183.0 15,183.0
12/1/2023
18:45
12/2/2023
00:00
5.25 PROD1, DRILL DDRL P Drill 15182' to 15714' MD'/ 8351' TVD.
Closing choke on connections. 0 PSI
build.
18k WOB
230 GPM
1600 PSI
130 RPM
16k TQ
9.7ppg ECD
258k PU
128k SO
182k ROT
Losses: 60 BPH
15,183.0 15,714.0
12/2/2023
00:00
12/2/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 15714' to 16316' MD'/ 8341' TVD.
Closing choke on connections. 0 PSI
build.
9k WOB
230 GPM
1514 PSI
130 RPM
19k TQ
9.7ppg ECD
259k PU
118k SO
187k ROT
340 units Max gas
50.7 TTL bit hrs
Losses: 50 BPH
15,714.0 16,316.0
12/2/2023
06:00
12/2/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 16316' to 16953' MD'/ 8330' TVD.
Closing choke on connections. 0 PSI
build.
9k WOB
230 GPM
1480 PSI
130 RPM
18k TQ
9.6ppg ECD
258k PU
118k SO
189k ROT
240 units Max gas
55.1 TTL bit hrs
Losses: 50 BPH
16,316.0 16,953.0
12/2/2023
12:00
12/2/2023
13:00
1.00 PROD1, DRILL CIRC T Circulate and condition mud while
cleaning up flow line and shakers due to
cement contamination. Blinding shaker
screens. Install various sizes to mitigate
shakers blinding.
16,953.0 16,953.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 16/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/2/2023
13:00
12/2/2023
18:00
5.00 PROD1, DRILL DDRL P Drill 16953' to 17435' MD'/ 8322' TVD.
Closing choke on connections. 0 PSI
build.
13k WOB
230 GPM
1400 PSI
130 RPM
15k TQ
9.6ppg ECD
251k PU
122k SO
190k ROT
500 units Max gax
55.1 TTL bit hrs
Losses: 60 BPH
16,953.0 17,435.0
12/2/2023
18:00
12/3/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 17435' to 18050' MD'/ 8312' TVD.
Closing choke on connections. 0 PSI
build.
10k WOB
200 GPM
1250 PSI
130 RPM
14k TQ
9.6ppg ECD
229k PU
140k SO
181k ROT
731 units Max gax
62.8 TTL bit hrs
Losses: 65-70 BPH. Started adding
background LCM at 17650'.
17,435.0 18,050.0
12/3/2023
00:00
12/3/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 18050' to 18715' MD/ 8312' TVD.
Closing choke on connections. 0 PSI
build.
6k WOB
200 GPM
1230 PSI
130 RPM
7k TQ
9.4ppg ECD
227k PU
142k SO
184k ROT
2010 units Max gax
67.4 TTL bit hrs
Losses: 65-70 BPH. Started adding
background LCM at 17650'.
18,050.0 18,715.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 17/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/3/2023
06:00
12/3/2023
10:00
4.00 PROD1, DRILL DDRL P Drill 18715' to 19100' MD/ 8300' TVD.
TD section. Closing choke on
connections. 0 PSI build.
2k WOB
200 GPM
1300 PSI
120 RPM
5k TQ
9.6ppg ECD
232k PU
133k SO
184k ROT
550 units Max gax
70.1 TTL bit hrs
Losses: 65-70 BPH. Started adding
background LCM at 17650'.
18,715.0 19,100.0
12/3/2023
10:00
12/3/2023
12:00
2.00 PROD1, TRIPCAS CIRC P Take final survey. Downlink and turn
tools off. Circulate BU.
230 GPM
1500 PSi
80 RPM
6k TQ
9.6ppg ECD
19,100.0 19,100.0
12/3/2023
12:00
12/3/2023
12:30
0.50 PROD1, TRIPCAS OWFF P Attempt to fingerprint well - on static
losses.
Flow check. Static losses = 48 BPH.
19,100.0 19,100.0
12/3/2023
12:30
12/4/2023
00:00
11.50 PROD1, TRIPCAS CIRC P Circulate Hole clean. Rotate and
reciprocate drillstring from 19100' to
19020'.
200 GPM
1280 PSI
80 RPM
7k TQ.
Static losses- 50 BPH
Dynamic losses 75 BPH
Note: Extended circulating due to
waiting on Brine from mud plant.
19,100.0 19,100.0
12/4/2023
00:00
12/4/2023
01:00
1.00 PROD1, TRIPCAS CIRC P Circulate and prep to displace well.
Rotate and reciprocate drillstring 19100'
to 19020'.
200 GPM
1280 PSI
80 RPM
7k TQ.
Static losses- 50 BPH
Dynamic losses 75 BPH
Note: Extended circulating due to
waiting on Brine from mud plant.
19,100.0 19,100.0
12/4/2023
01:00
12/4/2023
05:00
4.00 PROD1, TRIPCAS CIRC P Displace hole to 8.8ppg Vis Brine.
200 GPM
1120 PSI
120 RPM
7k TQ
19,100.0 19,100.0
12/4/2023
05:00
12/4/2023
05:30
0.50 PROD1, TRIPCAS OWFF P Flow check. Static losses = 27 BPH 19,100.0 19,100.0
12/4/2023
05:30
12/4/2023
14:00
8.50 PROD1, TRIPCAS SMPD P SOOH f/ 19100' to 11856'. 0 PSI in
slips/30 PSI out with MPD.
19,100.0 11,586.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 18/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2023
14:00
12/4/2023
17:00
3.00 PROD1, TRIPCAS CIRC P Circulate casing clean.
230 GPM
1000 PSI
30 RPM
4k TQ
200k PU
173k SO
182k ROT
11,586.0 11,586.0
12/4/2023
17:00
12/4/2023
18:00
1.00 PROD1, TRIPCAS MPDA P Retrieve RCD bearing assembly and
install trip nipple. Static loss rate 48
BPH. Drop 2.15" hollow drift w/ tail
11,586.0 11,586.0
12/4/2023
18:00
12/5/2023
00:00
6.00 PROD1, TRIPCAS TRIP P POOH f/ 11586' to 412'. Several
overtorqued connections.
11,586.0 412.0
12/5/2023
00:00
12/5/2023
00:30
0.50 PROD1, TRIPCAS OWFF P Rack back last std of 4" DP. Flow check.
Static loss rate 55 BPH.
412.0 315.0
12/5/2023
00:30
12/5/2023
02:30
2.00 PROD1, TRIPCAS BHAH P LD HWDP and BHA. 315.0 0.0
12/5/2023
02:30
12/5/2023
03:00
0.50 PROD1, TRIPCAS CLEN P Clean and clear rig floor. 0.0 0.0
12/5/2023
03:00
12/5/2023
04:00
1.00 COMPZN, CASING RURD P RU tbg handling equipment. 0.0 0.0
12/5/2023
04:00
12/5/2023
12:30
8.50 COMPZN, CASING PUTB P MU float shoe and visually check float.
RIH w/ 4 1/2" 12.6# H563 tbg as per
tally to 7618'.
0.0 7,618.0
12/5/2023
12:30
12/5/2023
13:30
1.00 COMPZN, CASING PUTB P MU liner hanger/packer. RIH. 7,618.0 7,664.0
12/5/2023
13:30
12/5/2023
23:00
9.50 COMPZN, CASING RUNL P RIH w/ liner on 4" DP f/ 7664' to 19100'.
Filling pipe w/ fillup hose. Did not fill on
last 10 stds. Set down 5k @ 19100'.
At shoe -
140k PU
132k SO
15k ROT
20 RPM
3k TQ
7,664.0 19,100.0
12/5/2023
23:00
12/5/2023
23:30
0.50 COMPZN, CASING RURD P MU cement swivel and set liner on
depth.
19,100.0 19,100.0
12/5/2023
23:30
12/6/2023
00:00
0.50 COMPZN, CEMENT CIRC P Attempt to shear flotation sub. 1/2 BPM
1st - 1200 PSI. Bleed off.
2nd - 1200 PSI. Bleed off.
19,100.0 19,100.0
12/6/2023
00:00
12/6/2023
00:30
0.50 COMPZN, CEMENT CIRC P Attempt to shear flotation sub. 1/2 BPM
3rd - 1300 PSI. Bleed off
4th - 1400 PSi. Hold and sheared at
1400psi.
Stage rate up to 5 BPM. Fill liner.
Decrease rate when catching pressure
to 3 BPM. 450psi, pumped 135bbls to
catch pressure.
19,095.0 19,095.0
12/6/2023
00:30
12/6/2023
03:30
3.00 COMPZN, CEMENT CIRC P Circulate surface to surface volume. 5
BPM/ 860 PSI. 85-90 BPH loss rate.
PJSM. Pumped 8950stks (757bbls)
19,095.0 19,095.0
12/6/2023
03:30
12/6/2023
04:00
0.50 COMPZN, CEMENT RURD P SD. Swap over to cementers. RU
bleeder liner to wash up cementers.
Pump 10bbls water, Test lines to
4600psi.
19,095.0 19,095.0
12/6/2023
04:00
12/6/2023
06:00
2.00 COMPZN, CEMENT CMNT P Pump 37bbls 13.0ppg mud push, mix
and pump 308bbls 15.3ppg CTD slim
hole slurry. Cement wet at 04:24hrs.
19,095.0 19,095.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 19/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/6/2023
06:00
12/6/2023
07:00
1.00 COMPZN, CEMENT CMNT P Open bleeder. SLB pump 10bbls water,
Line up to displace , Drop dart, Pump at
250gpm (caught pressre @ 510stks)
reduce rate to 130gpm 600psi top dart
land at 1320stks and sheared at
1132psi, @ 2350stks lower rate and
bump at 2683stks 1,280psi, pressure up
to 1,780psi, Hole 5min (All good)
19,095.0 19,095.0
12/6/2023
07:00
12/6/2023
07:45
0.75 COMPZN, CEMENT PRTS P Set hanger, Pressure up to 2500psi and
hold 2 min, Slack off to 43k, Pressure up
to 3,970psi to release hanger, Bled off to
0psi, P/U to 210k, P/U 6' and expose
dog sub, S/O 50k, P/U, rotate 20rpm
set down to130k confirm packer set.
TOL at 11,446' MD
Shoe at 19,095' MD
19,095.0 19,095.0
12/6/2023
07:45
12/6/2023
08:15
0.50 COMPZN, CEMENT RURD P R/D Cement swivel and lines. 19,095.0 19,095.0
12/6/2023
08:15
12/6/2023
09:00
0.75 COMPZN, WELLPR CIRC P Pressure up to 500psi, Pull out liner top
without pressure drop, P/U and
observed returns, Circulate BU at
10bpm 427gpm 1060 - 1550psi. Mud
push at surface at 4640stks at 3200stks
dump cement (37bbls cement return)
11,446.0 11,426.0
12/6/2023
09:00
12/6/2023
10:30
1.50 COMPZN, WELLPR CIRC P Install and pump wipper ball at 430gpm
920-1050psi
11,426.0 11,404.0
12/6/2023
10:30
12/6/2023
12:00
1.50 COMPZN, WELLPR SLPC P Slip and cut 126' drill line, Set block
hight and COM
11,404.0 11,404.0
12/6/2023
12:00
12/6/2023
15:00
3.00 COMPZN, WELLPR TRIP P POOH from 11,404' MD racking back 4"
drill pipe.
11,404.0 7,328.0
12/6/2023
15:00
12/6/2023
20:30
5.50 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe singles from
7,328' MD to 3,927' MD.
7,328.0 3,927.0
12/6/2023
20:30
12/6/2023
21:00
0.50 COMPZN, WELLPR SVRG P Service rig and pipe skate 3,927.0 3,927.0
12/6/2023
21:00
12/7/2023
00:00
3.00 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe singles from
3,927' MD to 2,176' MD. (high torque
connections)
3,927.0 2,176.0
12/7/2023
00:00
12/7/2023
03:30
3.50 COMPZN, WELLPR PULD P Continue L/D 4" drill pipe from 2,176'
MD to Surface, (high torque
connections) L/D running tools (good
shear on dog sub).
2,176.0 0.0
12/7/2023
03:30
12/7/2023
04:30
1.00 COMPZN, WELLPR BHAH P M/U Baker 7-5/8" scrapper assy 60.80'. 0.0 60.0
12/7/2023
04:30
12/7/2023
10:45
6.25 COMPZN, WELLPR TRIP P Continue TIH from 60' MD to 11,038'
MD.
60.0 11,038.0
12/7/2023
10:45
12/7/2023
13:00
2.25 COMPZN, WELLPR WASH P Wash in hole from 11,038' MD to 11,442'
MD. Tagged 3X with 5k at 11,442' MD.
GPM: 420
PSI: 1230
PU: 185k
SO: 160
ROT: 176k
TRQ: 3k
11,038.0 11,442.0
12/7/2023
13:00
12/7/2023
14:00
1.00 COMPZN, WELLPR CIRC P Circulate BTM's up at 11,442' MD,
Pump 50bbls spacer and displace well
to 8.8ppg corrosion inhibited brine.
GPM: 420
PSI: 1620
PU: 195k
SO: 155
11,442.0 11,442.0
12/7/2023
14:00
12/7/2023
15:00
1.00 COMPZN, WELLPR OWFF P OWFF 30min (static). Prep to L/D
doubles. CO PSI reg on Shot Pin Assy.
11,442.0 11,442.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 20/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/7/2023
15:00
12/8/2023
00:00
9.00 COMPZN, WELLPR PULD P POOH from 11,442' MD to 2,901' MD,
L/D 102 / 4" drill pipe in doubles.
Continue L/D singles.
11,442.0 2,901.0
12/8/2023
00:00
12/8/2023
03:45
3.75 COMPZN, WELLPR PULD P Continue POOH and L/D 4" DP singles
from 2,901' MD to surface.
2,901.0 0.0
12/8/2023
03:45
12/8/2023
04:30
0.75 COMPZN, WELLPR OWFF P OWFF (Static). L/D Scrapper assy.
(Very little material on magnets and
nothing in bootbaskets). No cement
observed on tools.
0.0 0.0
12/8/2023
04:30
12/8/2023
05:45
1.25 COMPZN, WELLPR WWWH P Blow down top drive and equipment.
Pull wear ring and jet stack.
0.0 0.0
12/8/2023
05:45
12/8/2023
07:00
1.25 COMPZN, WELLPR PRTS P Test liner top to 3,500psi for 30min
(good test).
0.0 0.0
12/8/2023
07:00
12/8/2023
07:30
0.50 COMPZN, RPCOMP RURD P R/U to run 4.5" 12.6ppf, L80, H563
upper completion.
0.0 0.0
12/8/2023
07:30
12/8/2023
09:00
1.50 COMPZN, RPCOMP PUTB P PJSM. RIH w/ upper completion. P/U
HES downhole gauge assembly & test
to 9,500psi for 5min - Good test. CPAI
witness.
0.0 120.0
12/8/2023
09:00
12/8/2023
12:00
3.00 COMPZN, RPCOMP PUTB P RIH w/4.5" 12.6ppf, L80, H563 upper
completion to 2,417' MD. Running TEC
line and installing Cannon clamps every
joint. Checking control line every 1000'
MD.
120.0 2,417.0
12/8/2023
12:00
12/8/2023
18:00
6.00 COMPZN, RPCOMP PUTB P Continue RIH w/4.5" 12.6ppf, L80, H563
upper completion to 7,900' MD. Running
TEC line and installing Cannon clamps
every joint. Checking control line every
1000' MD.
2,417.0 7,900.0
12/8/2023
18:00
12/8/2023
22:00
4.00 COMPZN, RPCOMP PUTB P Continue RIH w/4.5" 12.6ppf, L80, H563
upper completion to 11,451' MD.
Running TEC line and installing Cannon
clamps every joint. Checking control line
every 1000' MD. Land tubing at 11,451'
MD, Witness locater sheared with 12k.
PU: 175k
SO: 138k
Down hole pressure: 3764psi
Down hole temp: 157°
7,900.0 11,451.0
12/8/2023
22:00
12/9/2023
00:00
2.00 COMPZN, RPCOMP OTHR P MU pup joints - 9.9', 9.8', 8.08', 5.78'
and rerun joint #272. MU hanger and
landing joint. Terminate line through
hanger and test to 5,000psi - Good test.
Land hanger with 138k. RILD. (3.36'
above full located). Fill stack and flood
lines.
11,411.0 11,451.0
12/9/2023
00:00
12/9/2023
00:30
0.50 COMPZN, RPCOMP PRTS P RU test equipment. Test hanger seals to
3000 psi for 5 min - Good test.
0.0 0.0
12/9/2023
00:30
12/9/2023
01:00
0.50 COMPZN, RPCOMP OTHR P Drop 1-5/16" ball and rod. 0.0 0.0
12/9/2023
01:00
12/9/2023
03:30
2.50 COMPZN, RPCOMP PRTS P RU test lines. Pressure up tubing, set
packer and test tubing to 4,200 psi for
30 min. Bleed tubing down to 3,000 psi,
bring pressure on IA to 4,200 psi and
hold pressure for 30 min. Bleed tubing
to 0 psi, shear SOV. Tubing and IA
equalized and bled to 0 psi. Observed IA
for flow for 30 min - No flow.
0.0 0.0
12/9/2023
03:30
12/9/2023
06:00
2.50 COMPZN, RPCOMP OTHR P Vac out BOP stack. Pull landing joint
and install BPV. Pump down IA. Test
BPV in direction of flow to 3,000 psi for
10 min
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 21/21
MT7-03
Report Printed: 1/9/2026
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/9/2023
06:00
12/9/2023
06:30
0.50 COMPZN, RPCOMP OTHR P Blow down all surface equipment. 0.0 0.0
12/9/2023
06:30
12/9/2023
07:30
1.00 COMPZN, RPCOMP RURD P De-Energize KOOMEY, Clean flow box
and L/D mouse hole.
0.0 0.0
12/9/2023
07:30
12/9/2023
09:30
2.00 COMPZN, WHDBOP NUND P Remove trip nipple, break bolts on stack
and remove choke and kill lines. Skid
BOP's into STOW position. Remove
risers.
0.0 0.0
12/9/2023
09:30
12/9/2023
12:00
2.50 COMPZN, WHDBOP NUND P HES terminate TEC line and install 10k
adaptor flange. Torque adaptor, (test to
5k 10 min). Stage 10k tree in cellar.
0.0 0.0
12/9/2023
12:00
12/9/2023
14:00
2.00 COMPZN, WHDBOP NUND P N/U 10k frac tree and test to 9,600psi
(good test).
0.0 0.0
12/9/2023
14:00
12/9/2023
18:00
4.00 COMPZN, WHDBOP FRZP P Pull BPV, R/U LRS, test lines to 3500
psi, Pump 50 bbls diesel down IA taking
returns up tubing. Shut down and let U-
Tube for one hour.
IA: 0psi
OA: 0psi
TBG: 0psi
0.0 0.0
12/9/2023
18:00
12/9/2023
21:00
3.00 DEMOB, MOVE RURD P R/D all service lines and equipment.
Secure well for MOB.
0.0 0.0
12/9/2023
21:00
12/10/2023
00:00
3.00 DEMOB, MOVE RURD P Clean pits and cellar area and tree,
Install companion flanges and gauges.
Clear 5k tree from rig floor.
SIMOPS: Scope down derrick, Secure
top drive, Unspool drill line, Blow down
steam system and lower cattle chute.
Rig release from MT7-03 RWO at 00:00
hrs 12-10-23.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 12/10/2023
Page 1/1
MT7-03
Report Printed: 12/21/2023
Cement Detail Report
Cement Details
Description
Production String 1 Cement
Cementing Start Date
12/6/2023 04:00
Cementing End Date
12/6/2023 07:00
Wellbore Name
MT7-03
Comment
Pump 37bbls 13.0ppg mud push, mix and pump 308bbls 15.3ppg CTD slim hole slurry. Cement wet at 04:24hrs. Open bleeder. SLB pump 10bbls water, Line up
to displace , Drop dart, Pump at 250gpm (caught pressre @ 510stks) reduce rate to 130gpm 600psi top dart land at 1320stks and sheared at 1132psi, @
2350stks lower rate and bump at 2683stks 1,280psi, pressure up to 1,780psi, Hole 5min (All good)
Cement Stages
Stage # 1
Description
Production String 1
Cement
Objective Top Depth (ftKB)
11,446.0
Bottom Depth (ftKB)
19,095.0
Full Return?
No
Vol Cement …
37.0
Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
4
P Pump Final (psi)
1,280.0
P Plug Bump (psi)
1,780.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
11,446.0
Est Btm (ftKB)
19,095.0
Amount (sacks) Class
Blend
Volume Pumped (bbl)
308.0
Yield (ft³/sack)
1.32
Mix H20 Ratio (gal/sa…
3.91
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Production String 1 Cement
Job: RECOMPLETION-<jobsubtyp> 11/10/2023 …
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'!4 )(+) .+(+ +.(') 4+ :()/ /4+"+( / "4/+!( : 4)":("/ .4+'!4+ (!' ):4":"()+ (.' 4!:)(:/ *=B**&",
'!4) (+' :!(): + (". )4!"( ! /4+!"( ' "4.:"( . 4))"(! .4+''4!'.(!. ):4+'(+/ (:' 4'/)(./ *=B**&",
'!4+: (" :(/+ ++(!+ )4!:)(. /4):/(") "4:" (!' 4+)(! .4+''4!.:("+ ):4'+()! (" 4+(.: *=B**&",
''4!:'(" :/('/ "!'(!" )4''!( ' /4)("" "4 !+(:. 4+ !(' .4+''4'!!(// ):4'/)(": (.. 4"'!( ! *=B**&",
''4'..(:. :.(+ "!( )4'.!(.! /4 (': "4 )( )4!'!(!! .4+''4'/ (:' ):4! (!" (." 4"+(:/ *=B**&",
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''4"//( ' :+( " "!:("" )4'(:" /4: ( + "4+:(//)4!)'('" .4+''4.!(+/ ).4+".(:) (./ 4.. () *=B**&",
''4/"+(/ '(+. "!)(". )4.( /4:"(. "4++ (..)4''( .4+''4"! (': ).4)::('! "(!+ 4:/!( . *=B**&",
''4."/(' "(+) "'!(' )4)!(/: /4.::( /4!: (:/)4'"+(+: .4+''4"::(") ).4 + (:" () 4 "(/. *=B**&",
''4:'+(!' .( ! "'("" )4"!(:: /4.'(! /4'+(/)4':(': .4+''4/(!+ ).4 " (.: "(') 4 + (!+ *=B**&",
''4:)+("" :( ! "'.(" )4"'+(// /4/:/(+. /4' )(.")4' )(+/ .4+''4/ !(:) ).4:)+(:! /(. 4). (! *=B**&/,
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''4)"+(+ ('' "'/( . )4"./('/ /4":'(! /4)'(+.)4'"(:/ .4+''4. ("+ ).4.)+('' '(+) 4+)/(' *=B**&.,
) *
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''4+"/(' +( "'+(.. )4" "(/ /4+"(. /4"//(.+)4"(+ .4+''4:/:(:. ).4.)(" .(/+ "4!:(" *=B**&.,
'4!+(+" )'(!) ""( . )4")+( /4'+(.! /4/!"('/)4/+( .4+''4 (: ).4/ '(+! /( ' "4'")("" *=B**&.,
'4'/()/ )( ".(): )4/!"('. /4'/( /4/. (+)4:(:. .4+''4)!!(.' ).4/'+(+' ()! "4'!( *=B**&.,
'4'+(: )/( ! ")(' )4/'"(." /4!:"( /4.!)(:!)4 "(!" .4+''4))!(+! ).4" !()' "(': "4)'(!. *=B**&.,
'4"'.(": ):(": ""!(!/ )4/!(++ "4+)'()/ /4.. (:/)4)!(/+ .4+''4+:/('! ).4"/(!: (:. "4"/+(+! *=B**&.,
'4/''("/ ) ()/ """( ! )4/.(). "4)+ (" /4:!()")4).(". .4+'4!/+()/ ).4)'(/ /('' "4/'.( *=B**&.,
'4.!.(:: +!(:/ ""/(.! )4/ ('! "4)'(.! /4://(!)4):(:! .4+'4'".( ).4/(/" "(!+ "4/ ( *=B**&.,
'4.++(." +'()! "".(." )4/.('! "4 (/" /4:)"(::)4)/(:! .4+'4'(+! ).4!.(': '(:. "4.")("+ *=B**&.,
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'4 )+(!' +'(.. "/!(! )4/!()) "4..(+/ /4 . (:)4)!(") .4+'4"+)(": ).4'":(// "()! "4:..(+ *=B**&.,
'4))( : +(!) ""+(.: )4/' (+' "4/:.(!' /4 )+(:")4 (/' .4+'4/) ('. ).4'!:(. !( . "4 !+(:. *=B**&.,
'4+ ( ! +'(.. "".( + )4/'/(+! "4" (/ /4).(: )4 /(/! .4+'4. .() ).4! (+" /(!' "4 : (.' *=B**&.,
'"4! (! +'()+ ""/(+ )4/'(! "4+'(:' /4):.(.")4 '(. .4+'4::(.) ).4!".(/ '(:" "4))(/) *=B**&.,
'"4'::("+ +'(+ """() )4/!)(+" "4! (': /4+! ('')4:)(/" .4+'4 /)('. )/4++:(. '(! "4)+!() *=B**&.,
'"4:!(.. +'(.. ""(': )4/!:(!) "4'"(.' /4+.!(.)4:.(.) .4+'4)"(+: )/4+..(/. '(. "4+./(// *=B**&.,
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'"4//+(+ +'("/ ""( / )4/!'(' 4+.:('' .4!")(:/)4:!(: .4+'"4!!( / )/4) '( / !(+/ /4!)"( / *=B**&.,
'"4./"(// +'(.! """("" )4"+)()! 4) ( ) .4!)'(!")4.)("! .4+'"4!) (! )/4)"'(:) !(:. /4'/:(.: *=B**&.,
'"4:")(/) +'(.: """(: )4"+:(: 4 ) ( : .4'"(/)4..( : .4+'"4' "(" )/4 +'(: !(": /4!+() *=B**&.,
'"4 ""(.! +'(/ """(. )4"+"( . 4 !( ) .4':.() )4."(. .4+'"4.+(/) )/4 .'(:! !(/. /4 "(' *=B**&.,
'"4))("+ +'(.: """(:+ )4"+'(/ 4:' (+' .4!)(/)4.!( / .4+'"4"/.(/+ )/4 ''(:' !(/ /4"":(" *=B**&.,
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'/4"+.(/) +'()/ ""('' )4" "("+ 4''(/ .4/:/(. )4"()+ .4+'"4). ()) )/4/:+(/' !(!: /4 ':(.) *=B**&.,
'/4/+!(.: +'()/ ""(. )4" !("/ 4!)(. .4.!)(:))4+()/ .4+'"4+/"(" )/4/ (:. !(/) /4 )'() *=B**&.,
'/4.).()/ +'()/ ""( : )4": () '4+/"(:: .4..(/')4:( ) .4+'/4!+(!' )/4"):(+ !(! /4)/.( *=B**&.,
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'/4 .(" +'(!' ""()/ )4":"(" '4 .(". .4:"+(':)4() .4+'/4'++(:. )/4"!/(: !('+ /4+ "(: *=B**&.,
'/4) !("" +!(:: ""(/! )4":'(++ '4:+!(+' .4:)()+)4'(/+ .4+'/4).( )/4:()+ !(.+ .4!")(! *=B**&.,
'/4+:.(/ +!(:+ ""'(! )4":!() '4:! ("/ .4 ():)4!(" .4+'/4" !(!/ )/4!(. '(/. .4'!"(// *=B**&.,
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'.4'./(!! +!(:: """(+ )4".)( '4/"+(:: .4)'/(/ )4')( .4+'/4./!(!: )/4'")("/ '(': .4"'('! *=B**&.,
'.4/)(!! +!(:! ""/('' )4". (:+ '4"..('. .4)..(:')4' ('+ .4+'/4:.(: )/4!++(.: !(': .4+"(!" *=B**&.,
'.4"//(!" +!(:" """(/) )4".:(:. '4:+(!! .4)+)(!)4':('. .4+'/4 '(+ )/4!.+(. !(:: .4".:(:! *=B**&.,
'.4/" (+) +!(). """( + )4"..(// '4')/()" .4+"+( ")4'/(+/ .4+'/4 +)(: )/4!!(! !(/! .4/')(+) *=B**&.,
'.4."(+ +!()) """("' )4"./(!' '4!++( + .4+)(!/)4'"(.' .4+'/4))/(/" )"4+)!( !(.' .4/)(': *=B**&.,
'.4: ('' +!(+ """(:! )4".(/+ '4!'.(.) :4!/('!)4''(++ .4+'/4+:+( )"4+/!(.: !(" .4.//(+! *=B**&.,
) *
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'.4)':(:. +'(!! ""/(!" )4"/+("! )/.() :4'!)(".)4!)()! .4+'.4'/'( + )"4):'(! !(: .4: !() *=B**&.,
'.4+''( +!(+ """("' )4"/ (: :!(:" :4'.!(.')4! (' .4+'.4)(' )"4)'(+ !( : .4 ""(+! *=B**&.,
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':4))(+ +!(+) ""(" )4"/'(/ /.(/ :4"'(. )4!!(+ .4+'.4.:)('' )"4:.+(:' !(!. .4+) (': *=B**&.,
':4")(): +!(+ ""(:/ )4""+(). "/'(": :4":.(")4'++(". .4+'.4:."(': )"4:')("! !(+ :4!.'("/ *=B**&.,
':4/ )(' +!(+. ""(/' )4"")(+ .:( ) :4/!+(')4'+ ( + .4+'.4 ")(+" )"4. :(:+ !(/ :4'':(! *=B**&.,
':4. (.+ +!(+) ""( " )4"":( ! ' "(! :4/.(:))4'+:(! .4+'.4)"(): )"4.".(.: !("/ :4' +(++ *=B**&.,
':4:::("' +!(+) ""(" )4"".('! )+(+ :4/+.(+))4'+/(:! .4+'.4+!)('" )"4/+/(.+ !(." :4/"(: *=B**&.,
':4 :'(': +!(+ ""(" )4"""(." .(+. :4./!(!:)4'+"(!" .4+'.4++"() )"4/.(). !(': :4"!)(/ *=B**&.,
':4)..("' +!(+ """(!) )4""'(+ ( :4.)"(!)4'+'(/ .4+':4! )('' )"4/'(!. !( : :4" '(): *=B**&.,
':4+/+(+ +!(+ ""(' )4""!(") ':'(') :4::("))4')+()) .4+':4':( " )"4" '(' !(+" :4/".(/ *=B**&.,
' 4!/"(" +!(+ ""()' )4")( + //(.) :4::+( ))4'))(+ .4+':4/ ("! )"4""!('. !(:/ :4/++() *=B**&.,
' 4'" ()) +'(!" """(/) )4" ('/ ")(+" :4 '(/+)4'):(:/ .4+':4""()! )"4)+()! !( ' :4.:(: *=B**&.,
' 4"(:" +'(!" ""/('. )4".(// /'"(+/ :4 ./(+)4')/(+/ .4+':4/')(+" )"4.!(" !( ' :4:.(": *=B**&.,
' 4":(+ +!(+ """(:+ )4""()" /+)(:: :4 +.( :)4')"("" .4+':4.!/( )"4''( !(.! :4:) (:. *=B**&.,
' 4/(: +!(+) """(+) )4"(. .)/(' :4)" ( )4')'( . .4+':4.+'(/' )"4' '(:. !("' :4 .!(: *=B**&.,
' 4.':(/ +!(+. """(.. )4"!(: ::)(: :4) +("+)4')!(' .4+':4: :(+) )"4'"(/! !(/: :4)'"(!/ *=B**&.,
' 4:!+("" +!(+) """(). )4"'+('! .'(+! :4+!(..)4' )(:! .4+':4 :'(" )"4!+"(. !(" :4) /(:. *=B**&.,
' 4 !/(+! +!(+. """(:" )4"' (/+ )" (:! :4+:()")4' :(++ .4+':4)/)(! )"4!."(:) !(" :4+" (+) *=B**&.,
' 4 ++(/: +!()" ""(+/ )4"':(! +(!. 4!!.("")4' .(. .4+':4+""()! )"4!'"(./ !( / 4!!'(! *=B**&.,
' 4)+/( + +!()! """(. )4"'/(: '4!! (') 4!/)(")4' /(' .4+' 4!!(! )4+ "(!" !(:: 4!:/(+) *=B**&.,
' 4+))( + +!(): ""/(!: )4"'"("' '4!+'(. 4!)+( !)4' ()' .4+' 4'!.(." )4+""(+' !(." 4' (' *=B**&.,
')4!)"(.. +!() """(': )4"''(+ '4' :("+ 4'"'())4' '(/ .4+' 4'+'(./ )4)+/(' !(+. 4'+!('" *=B**&.,
')4' (). +!( ""'(/. )4"'!(:' '4.+()) 4' .(:/)4' !('' .4+' 4 :(! )4).(:+ '()' 4./(": *=B**&.,
')4 (:) +!(.) ""( )4"!+(/+ '4"/"(/ 4!(/!)4':)(++ .4+' 4":'(!! )4)'!( !()/ 4"'+(." *=B**&.,
')4":.(:/ +!(.) ""'() )4"!)(.. '4/.(.: 4:/(!')4':)(!. .4+' 4///( )4 :)(+. !(/" 4")"(! *=B**&.,
')4/:!()/ +!(. ""'( ! )4"! (:/ '4.!+(/" 4"!+(!.)4': ('/ .4+' 4.+(". )4 :(: !('/ 4//)( ' *=B**&.,
')4..:(!' +!(.. ""'(+. )4"!:( . '4.+"(" 4"."(+))4'::(. .4+' 4:'/(/. )4:)"(: !(: 4.'/('" *=B**&.,
')4:.!(! +'( ""()) )4"!.(+ '4: :(:) 4"+ (.")4':/( + .4+' 4:+)(+ )4:/(/. '( 4. )(! *=B**&.,
')4 //('+ +!(:! ""("+ )4"!"()! '4 :!(. 4//!( +)4':"("! .4+' 4 )"( ' )4:!'(." !()/ 4:/'( + *=B**&.,
')4)")('/ +!()+ ""(/ )4"!(.) '4)/"(." 4/)/( )4':(!) .4+' 4):)(': )4.:!("+ !(" 4 !.(:/ *=B**&.,
')4+"(.+ +!(/) ""!(/ )4"!'(/. '4+:(.! 4.+("))4':!(+. .4+' 4+.(". )4.' (:! (': 4 !(+) *=B**&.,
'+4!)('" +!(/ ""'(. )4"!!( ! 4!'!(! 4. .(::)4':!(! .4+')4!" (' )4/ "(:. '('. 4)" (: *=B**&.,
'+4! (+! +!(/) """(:: )4"!!(". 4!/+() 4.+:(.)4'.+(). .4+')4! (/ )4/./(') /(: 4): (+/ *=B**&.,
'+4'!!(!! +!(/) """(:: )4"!!(' 4! /('! 4:!)())4'.+(: .4+')4'!(!) )4//()" !(!! 4)).(+ #E00
From:Taylor, Jenna
To:Brooks, James S (OGC)
Subject:RE: [EXTERNAL]FW: MT7-03 10-407 & MT7-03A 10-407
Date:Monday, January 22, 2024 2:14:13 PM
Alpine C
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Monday, January 22, 2024 2:12 PM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]FW: MT7-03 10-407 & MT7-03A 10-407
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Hi,
What is the Formation at total depth name ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Thursday, January 4, 2024 8:31 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW:MT7-03 10-407 & MT7-03A 10-407
Hi James,
Attached is stamped 10-407 for GMT MT7-03 and GMT MT7-03A; it is logged in the 10-407 Excel
spreadsheet.
Thank you,
Grace Christianson
Executive Assistant,
Alaska Oil & Gas Conservation Commission
(907) 793-1230
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
Sent: Wednesday, January 3, 2024 11:42 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>
Subject: MT7-03 10-407 & MT7-03A 10-407
Hello – See attached 10-407s for MT7-03 and MT7-03A. Please let me know if you need additional
information.
Thank you,
Jenna
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Dec 15, 2023
AOGCC
Attention: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
MT7-03A
Greater Mooses Tooth
API #: 50-103-20830-01
Permit No: 223-084
Rig: Doyon 25
The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well.
Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files.
MT7-03A is located in a federal oil and gas unit. Only with respect to the MT7-03A Well Data, CPAI hereby waives
its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be
construed as a waiver of indefinite confidentiality on any other wells.
Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the
release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of
Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC).
Thank you.
Signature of receiver & date received:
Please return transmittal letter to:
Garrett Brown
Garrett.Brown@conocophillips.com
Luis Arismendi
Luis.arismendi@bakerhughes.com
PTD: 223-084
T38223
12/14/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.12.14
11:04:01 -09'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________GMTU MT7-03A
JBR 01/18/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
BOPE test after succesful sidetrack and out of the hole. 4" and 4.5" test joint. Lel audible at drillers cab initially failed , calibrated
and passed retest. No other failures
Test Results
TEST DATA
Rig Rep:R. FrittsOperator:ConocoPhillips Alaska, Inc.Operator Rep:R. Reindhardt
Rig Owner/Rig No.:Doyon 25 PTD#:2230840 DATE:11/26/2023
Type Operation:DRILL Annular:
250/2500Type Test:OTH
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopSTS231201103944
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.75
MASP:
2840
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 2 7/8 x 5 vari P
#2 Rams 1 Blinds P
#3 Rams 1 2 7/8 x 5 vari P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 2 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1900
200 PSI Attained P17
Full Pressure Attained P79
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1920
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P FPMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P27
#1 Rams P6
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9999
9
9
9
9
Lel audible at drillers cab initially failed
FP
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Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Greater Mooses Tooth Field, Rendezvous Oil Pool, GMT MT7-03A
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-084
Surface Location: 992’ FSL, 1908’ FWL, S32 T10N R2E, UM
Bottomhole Location: 463’ FNL, 1396’ FEL, S36 T10N R1E, UM
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
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,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of November 2023.
.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.14 14:30:48 -09'00'
14
1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 21,040 TVD: 8280
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 140.7 15. Distance to Nearest Well Open
Surface: x-289990 y- 5915818 Zone- 4 100.8 to Same Pool: 115' to MT7-03
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90° degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
6-1/2" 4-1/2" 12.6# L80 H563 9591 11449 8256 21040 8280
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
N/A
TVD
120
3076
8304
8405
Hydraulic Fracture planned?Yes No
20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name:
David Lee Contact Email:joseph.j.longo@conocophillips.com
Drilling Engineering Supervisor Contact Phone: (907) 947-4323
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval :
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
If checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.Joseph Longo
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Perforation Depth MD (ft):N/A Perforation Depth TVD (ft):N/A
Intermediate 11624 7-5/8"Stage 1 - 61 bbls 15.8 ppg Class G
Stage 2 - 52 bbls 15.8 ppg Class G 11624
Production 12375 4-1/2"12375
Liner
Conductor/Structural 80 20"Cement to surface with 10 yds slurry 120
Surface 3553 13-3/8"483 bbls 11 ppg DeepCRETE
72 bbls 15.8 ppg Class G 3553
21040 8280 N/A 21040 8280
Casing Length Size Cement Volume MD
1189 sx of 15.3 ppg GASBLOK CTD
Total Depth MD (ft):Total Depth TVD (ft):Plugs (measured):Effect. Depth MD (ft):Effect. Depth TVD (ft):
463 FNL, 1396 FEL, S36 T10N R1E, UM 3776, 5756, 5720 1396' to AA081800
GL / BF Elevation above MSL (ft):
3670 2840
18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
(including stage data)
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Greater Mooses Tooth
Rendezvous992 FSL, 1908 FWL, S32 T10N R2E, UM AA081800, AA081803, AA081781
1766 FSL, 2237 FEL, S06 T9N R2E, UM 932535000, 932538000, 932516000 9/18/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 MT7-03A
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Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 2:30 pm, Sep 08, 2023
11/20/23
A.Dewhurst 20SEP23
BOP test to 5000 psig
Annular preventer test to 2500 psig
VTL 11/14/2023
50-103-20830-01-00223-084
X
10/15/2023
DSR-9/12/23*&:JLC 11/14/2023
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.11.14 14:31:08 -09'00'11/14/23
11/14/23
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, AK 99510-0360
Telephone 907-276-1215
August 31, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Permit to Drill MT7-03A
Dear Sir or Madam,
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C Sand - Single Lateral Injector
from the MT7 drilling pad. The intended spud date for this well is October 15, 2023. It is intended that Doyon 25
be used to drill the well.
Prior to this re-drill an attempt will be made to re-enter the existing MT7-03 lateral with the intent of running and
cementing a 4-1/2” liner in place. If this is unsuccessful MT7-03A will re-drill a 6-1/2” production interval
horizontally and geo-steered within the Alpine C sand. The production section will be sidetracked out of the
existing 7-5/8” intermediate casing after setting a cement kick off plug in the existing MT7-03 6-1/2” lateral
section, currently completed barefoot.
The MT7-03A well will be completed with a 4-1/2" cemented liner including frac sleeves and potentially swell
packers. The upper completion run from surface will include a production packer and GLM’s.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a)
2. Proposed drilling program
3. Proposed drilling fluids program summary
4. Proposed completion diagram
5. Pressure information as required by 20 ACC 25.005 (c) (4) (a-c)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
7. Area of Review
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Joseph Longo at (907) 947-4323
(joseph.j.longo@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com).
Regards,
Joseph Longo
Staff Drilling Engineer
cc:
MT7-03A Well File / Jenna Taylor ATO 1732
David Lee ATO 1552
Chris Brillon ATO 1548
Andy Mack Kuukpik Corp
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MT7-03A Well Plan
Application for Permit to Drill
Table of Contents
1. Well Name ............................................................................................................................................. 2
2. Location Summary ................................................................................................................................. 2
3. Proposed Drilling Program ..................................................................................................................... 5
4. Diverter and BOP Information ................................................................................................................ 6
5. MASP Calculations ................................................................................................................................. 6
6. Procedure for Conducting Formation Integrity Tests ............................................................................... 7
7. Casing and Cementing Program .............................................................................................................. 7
8. Drilling Fluid Program ............................................................................................................................ 9
9. Abnormally Pressured Formation Information ........................................................................................ 9
10. Seismic Analysis ..................................................................................................................................... 9
11. Seabed Condition Analysis ..................................................................................................................... 9
12. Evidence of Bonding ............................................................................................................................... 9
13. Discussion of Mud and Cuttings Disposal and Annular Disposal ............................................................ 10
14. Drilling Hazards Summary .................................................................................................................... 10
15. Present Well Schematic ........................................................................................................................ 11
16. Proposed Completion Schematic .......................................................................................................... 12
17. Area of Review..................................................................................................................................... 13
18. Intermediate Bond Log Review – ConocoPhillips Cementing SME Evaluation ........................................ 14
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1. Well Name
Requirements of 20 AAC 25.005 (f)
The well for which this application is submitted will be designated as MT7-03A
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
Location at Surface 992 FSL, 1908 FWL, S32 T10N R2E, UM
NAD27
Northing: 5915817.71
Easting: 289990.39
RKB Elevation 39.9’ AMSL
Pad Elevation 100.8’ AMSL
Top of Productive Horizon (Heel) 1766 FSL, 2237 FEL, S06 T9N R2E, UM
NAD27
Northing: 5911425.82
Easting: 285734.05
Measured Depth, RKB: 11624‘ MD
True Vertical Depth, RKB: 8304‘ TVD
True Vertical Depth, SS: 8163‘ TVDss
Total Depth (Toe) 463 FNL, 1396 FEL, S36 T10N R1E, UM
NAD27
Northing: 281520.49
Easting: 5919813.08
Measured Depth, RKB: 21040‘ MD
True Vertical Depth, RKB: 8280‘ TVD
True Vertical Depth, SS: 8139‘ TVDss
Please see attached well stick diagram for the current planned development of the pad.
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Pad Layout
Well Stick Diagram
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Well Plat
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3. Proposed Drilling Program
- For re-entry operations see MT7-03 Sundry -
1. Spot and rig up wireline unit
2. Set tubing tail plug in lower nipple.
3. Pull dummy in lower GLM and leave pocket open to allow for a circulation point.
4. Cut packer mandrel on Baker Premier Production Packer.
5. Circulate KWF around and set BPV.
6. MIRU Doyon 25 onto MT7-03.
7. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 2-7/8” x 5-1/2”
VBR’s, blind ram and 2-7/8” x 5-1/2” VBR’s.
8. Test BOPE to 250 psi low / 5000 psi high (24-48 hr. regulatory notice)
9. Pull and lay down 4-1/2” tubing.
10. Pick up 6-1/2” clean out assembly and trip in hole to the 7-5/8” intermediate casing shoe.
11. Displace to 9 ppg WBM.
12. Attempt to clean out existing 6-1/2” lateral
13. If unsuccessful – set Kick off plug
-Start of MT7-03A Permit to Drill -
14. Pick up and RIH with 6-1/2” drilling assembly.
15. Tag and confirm kick off plug
16. Sidetrack out of existing 7-5/8” intermediate casing.
17. Drill 6-1/2" horizontal hole to section TD.
18. Circulate the hole clean and POOH.
19. Run 4-1/2” liner on 4” DP.
20. Cement 4-1/2” Liner.
21. Set liner hanger and packer. Chart casing pressure test 3,500 psi. POOH LD DP.
22. Run 4-1/2” tubing with production packer, DHG, GLMs and 2x landing nipples. Locate and space out
tubing. Terminate TEC wire and land tubing hanger.
23. Pressure test hanger seals to 2500 psi.
24. Drop ball & rod, pressure up and set production packer.
25. Pressure test tubing and IA and shear SOV.
26. Install BPV. ND BOPE and install tubing head adapter. Pressure test adapter to 5000 psi.
27. Install 10k frac tree and test.
28. Remove BPV and freeze protect well.
29. Secure well and RDMO.
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4. Diverter and BOP Information
Requirements of 20 AAC 25.005(c)(3 & 7)
Please reference BOP and diverter schematics on file for Doyon 25
5. MASP Calculations
Requirements of 20 AAC 25.005(c)(4)
(A) maximum downhole pressure and maximum potential surface pressure;
Maximum Potential Surface Pressure (MPSP) is determined as the lesser of:
Method 1: surface pressure at breakdown of the formation casing seat with a gas gradient to the surface
Method 2: formation pore pressure at the next casing point less a gas gradient to the surface
Method 1 Method 2
ܯܲܵܲ = [(ܨܩ × 0.052 )െܩܽݏ ܩݎܽ݀݅݁݊ݐ] × ܸܶܦ ܯܲܵܲ = ܨܲܲ െ (ܩܽݏ ܩݎܽ݀݅݁݊ݐ) × ܸܶܦ
Where:
FG – Fracture gradient at the casing seat in lb/gal
0.052 – Conversion from lb/gal to psi/ft
Gas Gradient – 0.1 psi/ft
TVD – True Vertical Depth of casing seat in ft RKB
Where:
FPP – Formation Pore Pressure at the next casing point
Gas Gradient – 0.1 psi/ft
The following presents data used for calculation of Maximum Potential Surface Pressure (MPSP) while
drilling:
Section Hole Size
Previous CSG Section TD MPSP
psi
MPSP MPSP
Size MD TVD FG
ppg
Pore Pressure
ppg | psi MD TVD Pore Pressure
ppg | psi
Method 1
psi
Method 2
psi
PROD 6-1/2" 7-5/8" 11624 8304 12.5 8.7 3,757 21040 8280 8.7 3,746 2,918 4,567 2,918
*Maximum potential pore pressure in the Susitna Sand if present
(B) data on potential gas zones;
The planned wellbore is expected to enter the gas cap and the area is expected to be normally pressured
(8.5-8.9 ppg).
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost
circulation zones, and zones that have a propensity for differential sticking;
Please see Drilling Hazards Summary
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6. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
Drill out casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that
ConocoPhillips Alaska has on file with the Commission.
7. Casing and Cementing Program
Requirements of 20 AAC 25.005 (c)(6)
Casing and Cementing Program
OD
(in)
Hole Size
(in)
Weight
(lb/ft) Grade Conn. Cement Program
20 42 94 H40 Welded Cemented to surface with
10 yds slurry
13-3/8" 16" 68# L80 H563 Previously Cemented – See Below
7-5/8" 9-7/8" x 11 29.7# /
33.7# L80 H563 /
TXPM Previously Cemented – See Below
4-1/2" 6-1/2” 12.6# L80 H563 4-1/2" cemented liner including frac sleeves and
potentially swell packers
13-3/8" Surface Casing run to 3553' MD/ 3076' TVD Cement Plan:
Previously cement from 3553’ MD to 3053’ (500’ of tail) with DeepCRETE + Adds @ 15.8 ppg, and from
3053' to surface with 11.0 ppg DeepCRETE. 175 bbls returned to surface
Lead 483 bbls => 1412 sx of 11.0 ppg DeepCRETE + Add's @ 1.92 ft³/sk
Tail 72 bbls => 350 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
7-5/8" Intermediate Casing run to 11624' MD/ 8304' TVD Cement Plan:
Previously cemented with a dual stage cement job. Primary stage was cemented from 11624’ MD with 61
bbls 15.8 ppg Class G to cover the Alpine C. The second stage collar was pumped thru the stage collar at
8748’ MD and consisted of 52 bbls 15.8 ppg Class G. TOC on the primary was confirmed at 11065’ MD
(559’ of coverage). TOC on the secondary cement job was inconclusive. See bond log interpretation
attached.
Stage 1 61 bbls => 295 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
Stage 2 52 bbls => 252 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
4-1/2” Production Liner run to Cement Plan:
Top of slurry is designed to be at 11124’ MD, which is 500' above 7-5/8'' intermediate shoe. Assume 30%
excess annular volume.
Tail 278 bbls => 1190 sx of 15.3 ppg GASBLOK CTD + Add's @ 1.31 ft³/sk
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Weight Yield
ft3 bbls ft3 bbls ft3 bbls ft3 bbls ppg ft3/ Sack
Lateral Length + 500' 11124' - 21040' 9916 0.021 30% 1190 211.92 357 63.58 0 0 1547 275.50 1181 15.3 ppg GASBLOK CTD 1.31
Shoe Track 20920' - 21040' 120 0.015 0% 10 1.83 0 0.00 0 0 10 1.83 8 15.3 ppg GASBLOK CTD 1.31
1200 213.75 357 63.58 0 0 1557 277.32 1189 15.3 ppg GASBLOK CTD 1.31
Total Tail Volume = 275.50 + 1.83 bbls = 277.32 bbls => 1,189 sx of 15.3 ppg GASBLOK CTD @ 1.31 ft³/sk
Additional bbls Total Volume Sacks Blend
Tail
FootagePlacement bbl/ft % Excess Volume XS Volume
Production Liner
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8. Drilling Fluid Program
(Requirements of 20 AAC 25.005(c)(8))
Production
Hole Size in 6-1/2"
Casing Size in 4-1/2"
Density ppg 8.8 – 9.5
PV cP 15
YP lb./100 ft2 15 - 20
Funnel Viscosity s/qt 60 - 80
Initial Gels lb./100 ft2 10
10 Minute Gels lb./100 ft2 15
API Fluid Loss cc/30 min 4
HPHT Fluid Loss cc/30 min 10.0
pH 9.0 – 9.5
Production Hole:
The horizontal production interval will be drilled with water-based mud drill-in fluid weighted to 8.8-9.5
ppg. MPD will be used to hold back pressure, keeping the well dynamically balanced.
Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate
regulations.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
N/A - Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
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13. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
Incidental fluids developed from drilling operations on well MT7-03A will be disposed of into a permitted
annulus on the MT7 pad or hauled to the Class 1 disposal well on CD1.
14. Drilling Hazards Summary
6-1/2" Hole | 4-1/2" Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add
lost circulation material
Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real
time ECD monitoring
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight
Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight
Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers
To be posted in Rig Floor Doghouse Prior to Spud
Well Proximity Risks:
MT7 will be a multi-well pad, containing an original plan of 36 wells. Directional drilling / collision
avoidance information is provided in the following attachments.
Drilling Area Risks:
x Reservoir Pressure:
Offset injection has the potential to increase reservoir pressure over predicted. Although this is
unlikely, the rig will be prepared to weight up if required.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in
losses in the intermediate section.
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15. Present Well Schematic
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16. Proposed Completion Schematic
MT7-03A
Single Lateral Injector
UPPER COMPLETION:
1. 4-½” X Landing Nipple (3.813" ID)
2. 4-½” x 1" KBG 4-5 (3x – 1 SOV, 2 DV)
3. 4-½” X Landing Nipple (3.813" ID)
4. HES Opsis Downhole Gauge
5. HES TNT Packer
6. 4-½” DB Landing Nipple (3.75" ID)
DRAFT -WP02
RKB = 140.7’ AMSL
JJLONGO - 7/11/2023
Surface Casing
13-3/8" 68# L80 H563
3553' MD/ 3076' TVD
Cemented to Surface
Lead: 11.0 ppg DeepCRETE | Tail: 15.8 ppg Class G
4-1/2" 12.6# L80 H563 Production Tubing
Intermediate I Casing
7-5/8" 29.7# L80 H563 x 7-5/8" 33.7# L80 TXPM
11624' MD/ 8304' TVD
4-1/2" 12.6# L80 H563
21035' MD / 8280' TVD
6-1/2" Production Hole
21040' MD/ 8280' TVD
4-1/2" 12.6# L80 H563
Swell Packer and sleeve positioning will be optimized based on as-drilled data
MT7-03 Abandoned Lateral
7-5/8" x 4-1/2" Production Packer
11329' MD / 8216' TVD
HRDE ZXHD Liner Top PKR
11449' MD / 8256' TVD
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17. Area of Review
Casing and Cementing Program
Well
Name Status Top Alpine
MD / TVD
TOC
MD / TVD
TOC
Method
Reservoir
Status Zonal Isolation Cement Ops Summary
MT7-05 Producing 12303’ / 8310’ 11900’ / 8185’ Sonic LWD Liner TOC & Packer 52 bbls 15.8 ppg Class G
MT7-01 Producing 10802’ / 8337’ 9994’ / 7974’ Sonic LWD Liner TOC & Packer 50 bbls 15.8 ppg Class G
MT7-05 intermediate 2 section was drilled and cased with 7” liner down to 12252’ MD in the Alpine D. The
Alpine C zone was penetrated at 12303’ MD. The intermediate casing was cemented to isolate the Alpine pool
with 52 bbls of Class G cement (plugs bumped and floats held) and top of cement was measured via Sonic
LWD at 11900’ MD. A horizontal production section was drilled in the Alpine C to 21916’ MD and completed
with a liner.
MT7-01 intermediate 2 section was drilled and cased with 7” liner down to 10727’ MD in the Alpine D. The
Alpine C zone was penetrated at 10802’ MD. The intermediate casing was cemented to isolate the Alpine pool
with 50 bbls of Class G cement (plugs bumped and floats held) and top of cement was measured with a Sonic
LWD at 9994’. A horizontal production section was drilled in the Alpine C to 19645’ MD and completed with a
liner.
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18. Intermediate Bond Log Review – ConocoPhillips Cementing SME Evaluation
Stage 1:
We appear to have near pristine cement
to at least 11,050’ based on the very low
amplitude. Based on the response this
looks like very high quality cement
capable of reliable isolation. Due to the
loss of returns it now becomes difficult
to ascertain the exact nature of the
materials above this, although we can
see differences in the materials behind
pipe. Lift pressure analysis and fluid
displacement predictions are not
reliable when lost circulation events
occur.
Due to the amount and apparent high
quality of the cement around the shoe I
would consider it risky, if not hazardous,
to attempt any type of remediation by
way of perforations for an additional
100’ of isolation.
Stage 2
I have reviewed the lift pressure analysis
for stage II, along with the pre-job
predictions. When I look at the pre-job
predictions I look closely at the fluid
friction pressure hierarchy chart. This
chart tells if the fluids exert enough
shear stress to displace the fluid(s) in front of it. In our case this is a very positive indicator that the fluid
regime was in proper alignment for a good displacement. This if further enforced by the mud removal
predictions and fluid concentration charts which predict a high percentage of cement in the annulus
above the stage tool. Although not the best Cement Evaluation Log we have seen there are indications of
a change in material in the annulus upward to 8,000’. This would be very close to the predicted top of
spacer at 8400’.
Additionally we did not lose returns and the job was executed properly. Based on previous logs reviewed
on the stage II operation I feel confident that our cement job is place as expected and will meet our
expectations.
-10500
-8750
-7000
-5250
-3500
-1750
0
1750
3500
5250
7000
8750
10500
12250
So
u
t
h
(
-
)
/
N
o
r
t
h
(
+
)
(
3
5
0
0
u
s
f
t
/
i
n
)
-15750 -14000 -12250 -10500 -8750 -7000 -5250 -3500 -1750 0 1750 3500 5250 7000 8750 10500 12250 14000 15750 17500
West(-)/East(+) (3500 usft/in)
MT7-03 RWO Redrill Heel
MT7-03 RWO Redrill Toe
MT7-14_wp09
MT7-14 Actual
MT7-08PB1MT7-08
MT7-07
MT7-11
MT7-02
MT7-09
MT7-94_wp03
MT7-04
MT7-03
MT7-06A
MT7-93_wp08
MT7-95
MT7-99
MT7-01
MT7-98 MT7-96
MT7-05
MT7-97MT7-06
MT7-03 RWO Redrill wp01
MT7-03 RWO Redrill wp01 PLAN VIEW
MT7-03 RWO Redrill wp01 SECTION VIEW
0
3000
6000
9000
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
-3000 0 3000 6000 9000 12000
Vertical Section at 294.38°
12
0
0
0
13
000
14
0
00
15
0
00
16
0
00
17
0
00
18
00
0
1900
0
20
000
21
0
00
MT7-03 RWO Redrill wp01
SURVEY PROGRAM
Date: 2023-06-20T00:00:00 Validated: Yes Version:
MD From MD To Survey / Plan
Tool
11624.00 21040.03 MT7-03 RWO Redrill wp01 (MT7-03_RWO Redrill)MWD+IFR2+SAG+MS
0
75
150
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 2750 5500 8250 11000 13750 16500 19250
Measured Depth
Equivalent Magnetic Distance
0
2
4
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 2750 5500 8250 11000 13750 16500 19250 22000
Measured Depth
MT7-03 RWO Redrill wp01
MT7-14_wp09MT7-14 Actual
MT7-08PB1 MT7-08
MT7-07
MT7-11
MT7-02
MT7-09
MT7-94_wp03
MT7-04
MT7-03
MT7-06AMT7-06PB1
MT7-93_wp08
MT7-95MT7-99
MT7-10_
MT7-01
MT7-98
MT7-96
MT7-05
MT7-97
MT7-06
Plan Summary
8325
8400
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
2000 3000 4000 5000 6000 7000 8000 9000
Vertical Section at 294.38°
Mag Model & Date:BGGM2023 20-Jun-23
Magnetic North is 14.00° East of True North (Magnetic Declination)
Mag Dip & Field Strength:80.36°57098.06nT
CASING DETAILS
No casing data is available
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation
1 11624.00 75.77 312.53 8304.04 -4509.06 -4132.66 0.00 0.00 1902.78
2 11654.00 75.77 312.53 8311.42 -4489.40 -4154.09 0.00 0.00 1930.41
3 11704.00 75.55 313.80 8323.80 -4456.27 -4189.42 2.50 100.00 1976.27
412127.71 78.00 333.23 8421.60 -4126.21 -4433.09 4.50 84.94 2334.45
5 12419.30 91.12 333.23 8449.18 -3867.61 -4563.54 4.50 0.00 2560.03
6 21040.03 91.12 333.23 8280.45 3827.71 -8445.64 0.00 0.00 9272.55
FORMATION TOP DETAILS
No formation data is available
75
75
0
90
180
270
30
210
60
240 120
300
150
330
MT7-03
DDI 6.441MT7-03 RWO Redrill wp01
0501
501 1001
1001 1501
1501 2001
2001 2501
2501 3001
3001 5001
5001 8001
8001 12001
12001 17001
17001 22301
From To MD
Standard Proposal Report
11 July, 2023
Plan: MT7-03 RWO Redrill wp01
ConocoPhillips Alaska Inc_WNS
Western North Slope
GMT2 Rendezvous Pad
MT7-03
501032083000
MT7-03_RWO Redrill
ConocoPhillips
Standard Proposal Report
Well MT7-03Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Actual 100.8+39.9 @ 140.70usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Actual 100.8+39.9 @ 140.70usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-03Well:
MT7-03_RWO RedrillWellbore:
MT7-03 RWO Redrill wp01Design:
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1983
North American Datum 1983
Western North Slope, North Slope Alaska, United States
Alaska Zone 4
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Site Position:
From:
Site
Latitude:
Longitude:
Position Uncertainty:
Northing:
Easting:
Grid Convergence:
GMT2 Rendezvous Pad
Map
-1.59 °Slot Radius:13.200 in
5,915,580.00 usft
1,430,062.00 usft
0.00 usft
70° 10' 22.674 N
151° 41' 36.331 W
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
+E/-W
+N/-S
Position Uncertainty Ground Level:
MT7-03, GMT2 SW03-108
5,915,561.84 usft
1,430,026.36 usft
100.80 usftWellhead Elevation:0.00 usft0.00 usft
70° 10' 22.486 N
151° 41' 37.349 W
-19.14 usft
-35.12 usft
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MT7-03_RWO Redrill
Model NameMagnetics
BGGM2023 6/20/2023 14.00 80.36 57,098.06
Phase:Version:
Audit Notes:
Design MT7-03 RWO Redrill wp01
PLAN
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:11,624.00
294.380.000.0039.90
Depth From
(usft)
Plan Survey Tool Program
RemarksTool NameSurvey (Wellbore)
Depth To
(usft)
Date 6/20/2023
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag
MT7-03 RWO Redrill wp01 (MT711,624.00 21,040.031
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
TFO
(°)
+N/-S
(usft)
Measured
Depth
(usft)
Vertical
Depth
(usft)
Dogleg
Rate
(°/100usft)
Build
Rate
(°/100usft)
Turn
Rate
(°/100usft)
Plan Sections
Target
0.000.000.000.00-4,132.66-4,509.068,304.04312.5375.7711,624.00
0.000.000.000.00-4,154.09-4,489.408,311.42312.5375.7711,654.00
100.002.54-0.432.50-4,189.42-4,456.278,323.80313.8075.5511,704.00
84.944.590.584.50-4,433.09-4,126.218,421.60333.2378.0012,127.71
0.000.004.504.50-4,563.54-3,867.618,449.18333.2391.1212,419.30
0.000.000.000.00-8,445.643,827.718,280.45333.2391.1221,040.03 MT7-03 RWO Redr
7/11/2023 3:53:59PM COMPASS 5000.17 Build Page 2
ConocoPhillips
Standard Proposal Report
Well MT7-03Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Actual 100.8+39.9 @ 140.70usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Actual 100.8+39.9 @ 140.70usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-03Well:
MT7-03_RWO RedrillWellbore:
MT7-03 RWO Redrill wp01Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Vertical
Section
(usft)
Dogleg
Rate
(°/100usft)
+N/-S
(usft)
Build
Rate
(°/100usft)
Turn
Rate
(°/100usft)
Planned Survey
Vertical
Depth
(usft)
11,624.00 75.77 312.53 8,304.04 1,902.78 0.00-4,509.06 -4,132.66 0.00 0.00
11,654.00 75.77 312.53 8,311.42 1,930.41 0.00-4,489.40 -4,154.09 0.00 0.00
11,704.00 75.55 313.80 8,323.80 1,976.27 2.50-4,456.27 -4,189.42 -0.43 2.54
11,800.00 75.98 318.23 8,347.42 2,062.74 4.50-4,389.33 -4,254.02 0.44 4.62
11,900.00 76.50 322.84 8,371.22 2,149.90 4.50-4,314.36 -4,315.74 0.52 4.60
12,000.00 77.11 327.42 8,394.06 2,233.54 4.50-4,234.51 -4,371.38 0.61 4.58
12,100.00 77.80 331.97 8,415.80 2,313.17 4.50-4,150.26 -4,420.62 0.69 4.56
12,127.71 78.00 333.23 8,421.60 2,334.45 4.50-4,126.21 -4,433.09 0.74 4.54
12,200.00 81.25 333.23 8,434.62 2,389.83 4.50-4,062.73 -4,465.11 4.50 0.00
12,300.00 85.75 333.23 8,445.93 2,467.19 4.50-3,974.04 -4,509.85 4.50 0.00
12,400.00 90.25 333.23 8,449.41 2,545.00 4.50-3,884.83 -4,554.85 4.50 0.00
12,419.30 91.12 333.23 8,449.18 2,560.03 4.50-3,867.61 -4,563.54 4.50 0.00
12,500.00 91.12 333.23 8,447.60 2,622.87 0.00-3,795.57 -4,599.89 0.00 0.00
12,600.00 91.12 333.23 8,445.65 2,700.73 0.00-3,706.30 -4,644.92 0.00 0.00
12,700.00 91.12 333.23 8,443.69 2,778.60 0.00-3,617.04 -4,689.95 0.00 0.00
12,800.00 91.12 333.23 8,441.73 2,856.46 0.00-3,527.77 -4,734.98 0.00 0.00
12,900.00 91.12 333.23 8,439.77 2,934.33 0.00-3,438.51 -4,780.01 0.00 0.00
13,000.00 91.12 333.23 8,437.82 3,012.19 0.00-3,349.24 -4,825.05 0.00 0.00
13,100.00 91.12 333.23 8,435.86 3,090.06 0.00-3,259.98 -4,870.08 0.00 0.00
13,200.00 91.12 333.23 8,433.90 3,167.92 0.00-3,170.71 -4,915.11 0.00 0.00
13,300.00 91.12 333.23 8,431.95 3,245.79 0.00-3,081.45 -4,960.14 0.00 0.00
13,400.00 91.12 333.23 8,429.99 3,323.65 0.00-2,992.18 -5,005.18 0.00 0.00
13,500.00 91.12 333.23 8,428.03 3,401.52 0.00-2,902.91 -5,050.21 0.00 0.00
13,600.00 91.12 333.23 8,426.07 3,479.38 0.00-2,813.65 -5,095.24 0.00 0.00
13,700.00 91.12 333.23 8,424.12 3,557.25 0.00-2,724.38 -5,140.27 0.00 0.00
13,800.00 91.12 333.23 8,422.16 3,635.11 0.00-2,635.12 -5,185.30 0.00 0.00
13,900.00 91.12 333.23 8,420.20 3,712.98 0.00-2,545.85 -5,230.34 0.00 0.00
14,000.00 91.12 333.23 8,418.24 3,790.84 0.00-2,456.59 -5,275.37 0.00 0.00
14,100.00 91.12 333.23 8,416.29 3,868.71 0.00-2,367.32 -5,320.40 0.00 0.00
14,200.00 91.12 333.23 8,414.33 3,946.57 0.00-2,278.06 -5,365.43 0.00 0.00
14,300.00 91.12 333.23 8,412.37 4,024.44 0.00-2,188.79 -5,410.46 0.00 0.00
14,400.00 91.12 333.23 8,410.42 4,102.30 0.00-2,099.53 -5,455.50 0.00 0.00
14,500.00 91.12 333.23 8,408.46 4,180.16 0.00-2,010.26 -5,500.53 0.00 0.00
14,600.00 91.12 333.23 8,406.50 4,258.03 0.00-1,921.00 -5,545.56 0.00 0.00
14,700.00 91.12 333.23 8,404.54 4,335.89 0.00-1,831.73 -5,590.59 0.00 0.00
14,800.00 91.12 333.23 8,402.59 4,413.76 0.00-1,742.47 -5,635.63 0.00 0.00
14,900.00 91.12 333.23 8,400.63 4,491.62 0.00-1,653.20 -5,680.66 0.00 0.00
15,000.00 91.12 333.23 8,398.67 4,569.49 0.00-1,563.94 -5,725.69 0.00 0.00
15,100.00 91.12 333.23 8,396.71 4,647.35 0.00-1,474.67 -5,770.72 0.00 0.00
15,200.00 91.12 333.23 8,394.76 4,725.22 0.00-1,385.41 -5,815.75 0.00 0.00
15,300.00 91.12 333.23 8,392.80 4,803.08 0.00-1,296.14 -5,860.79 0.00 0.00
15,400.00 91.12 333.23 8,390.84 4,880.95 0.00-1,206.88 -5,905.82 0.00 0.00
15,500.00 91.12 333.23 8,388.88 4,958.81 0.00-1,117.61 -5,950.85 0.00 0.00
15,600.00 91.12 333.23 8,386.93 5,036.68 0.00-1,028.35 -5,995.88 0.00 0.00
15,700.00 91.12 333.23 8,384.97 5,114.54 0.00-939.08 -6,040.91 0.00 0.00
15,800.00 91.12 333.23 8,383.01 5,192.41 0.00-849.82 -6,085.95 0.00 0.00
15,900.00 91.12 333.23 8,381.06 5,270.27 0.00-760.55 -6,130.98 0.00 0.00
16,000.00 91.12 333.23 8,379.10 5,348.14 0.00-671.28 -6,176.01 0.00 0.00
16,100.00 91.12 333.23 8,377.14 5,426.00 0.00-582.02 -6,221.04 0.00 0.00
16,200.00 91.12 333.23 8,375.18 5,503.87 0.00-492.75 -6,266.08 0.00 0.00
16,300.00 91.12 333.23 8,373.23 5,581.73 0.00-403.49 -6,311.11 0.00 0.00
16,400.00 91.12 333.23 8,371.27 5,659.60 0.00-314.22 -6,356.14 0.00 0.00
16,500.00 91.12 333.23 8,369.31 5,737.46 0.00-224.96 -6,401.17 0.00 0.00
16,600.00 91.12 333.23 8,367.35 5,815.33 0.00-135.69 -6,446.20 0.00 0.00
7/11/2023 3:53:59PM COMPASS 5000.17 Build Page 3
ConocoPhillips
Standard Proposal Report
Well MT7-03Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Actual 100.8+39.9 @ 140.70usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Actual 100.8+39.9 @ 140.70usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-03Well:
MT7-03_RWO RedrillWellbore:
MT7-03 RWO Redrill wp01Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Vertical
Section
(usft)
Dogleg
Rate
(°/100usft)
+N/-S
(usft)
Build
Rate
(°/100usft)
Turn
Rate
(°/100usft)
Planned Survey
Vertical
Depth
(usft)
16,700.00 91.12 333.23 8,365.40 5,893.19 0.00-46.43 -6,491.24 0.00 0.00
16,800.00 91.12 333.23 8,363.44 5,971.06 0.0042.84 -6,536.27 0.00 0.00
16,900.00 91.12 333.23 8,361.48 6,048.92 0.00132.10 -6,581.30 0.00 0.00
17,000.00 91.12 333.23 8,359.53 6,126.79 0.00221.37 -6,626.33 0.00 0.00
17,100.00 91.12 333.23 8,357.57 6,204.65 0.00310.63 -6,671.36 0.00 0.00
17,200.00 91.12 333.23 8,355.61 6,282.52 0.00399.90 -6,716.40 0.00 0.00
17,300.00 91.12 333.23 8,353.65 6,360.38 0.00489.16 -6,761.43 0.00 0.00
17,400.00 91.12 333.23 8,351.70 6,438.25 0.00578.43 -6,806.46 0.00 0.00
17,500.00 91.12 333.23 8,349.74 6,516.11 0.00667.69 -6,851.49 0.00 0.00
17,600.00 91.12 333.23 8,347.78 6,593.98 0.00756.96 -6,896.52 0.00 0.00
17,700.00 91.12 333.23 8,345.82 6,671.84 0.00846.22 -6,941.56 0.00 0.00
17,800.00 91.12 333.23 8,343.87 6,749.71 0.00935.49 -6,986.59 0.00 0.00
17,900.00 91.12 333.23 8,341.91 6,827.57 0.001,024.75 -7,031.62 0.00 0.00
18,000.00 91.12 333.23 8,339.95 6,905.44 0.001,114.02 -7,076.65 0.00 0.00
18,100.00 91.12 333.23 8,338.00 6,983.30 0.001,203.28 -7,121.69 0.00 0.00
18,200.00 91.12 333.23 8,336.04 7,061.17 0.001,292.55 -7,166.72 0.00 0.00
18,300.00 91.12 333.23 8,334.08 7,139.03 0.001,381.82 -7,211.75 0.00 0.00
18,400.00 91.12 333.23 8,332.12 7,216.90 0.001,471.08 -7,256.78 0.00 0.00
18,500.00 91.12 333.23 8,330.17 7,294.76 0.001,560.35 -7,301.81 0.00 0.00
18,600.00 91.12 333.23 8,328.21 7,372.63 0.001,649.61 -7,346.85 0.00 0.00
18,700.00 91.12 333.23 8,326.25 7,450.49 0.001,738.88 -7,391.88 0.00 0.00
18,800.00 91.12 333.23 8,324.29 7,528.36 0.001,828.14 -7,436.91 0.00 0.00
18,900.00 91.12 333.23 8,322.34 7,606.22 0.001,917.41 -7,481.94 0.00 0.00
19,000.00 91.12 333.23 8,320.38 7,684.09 0.002,006.67 -7,526.97 0.00 0.00
19,100.00 91.12 333.23 8,318.42 7,761.95 0.002,095.94 -7,572.01 0.00 0.00
19,200.00 91.12 333.23 8,316.47 7,839.82 0.002,185.20 -7,617.04 0.00 0.00
19,300.00 91.12 333.23 8,314.51 7,917.68 0.002,274.47 -7,662.07 0.00 0.00
19,400.00 91.12 333.23 8,312.55 7,995.55 0.002,363.73 -7,707.10 0.00 0.00
19,500.00 91.12 333.23 8,310.59 8,073.41 0.002,453.00 -7,752.14 0.00 0.00
19,600.00 91.12 333.23 8,308.64 8,151.28 0.002,542.26 -7,797.17 0.00 0.00
19,700.00 91.12 333.23 8,306.68 8,229.14 0.002,631.53 -7,842.20 0.00 0.00
19,800.00 91.12 333.23 8,304.72 8,307.01 0.002,720.79 -7,887.23 0.00 0.00
19,900.00 91.12 333.23 8,302.76 8,384.87 0.002,810.06 -7,932.26 0.00 0.00
20,000.00 91.12 333.23 8,300.81 8,462.74 0.002,899.32 -7,977.30 0.00 0.00
20,100.00 91.12 333.23 8,298.85 8,540.60 0.002,988.59 -8,022.33 0.00 0.00
20,200.00 91.12 333.23 8,296.89 8,618.46 0.003,077.85 -8,067.36 0.00 0.00
20,300.00 91.12 333.23 8,294.93 8,696.33 0.003,167.12 -8,112.39 0.00 0.00
20,400.00 91.12 333.23 8,292.98 8,774.19 0.003,256.38 -8,157.42 0.00 0.00
20,500.00 91.12 333.23 8,291.02 8,852.06 0.003,345.65 -8,202.46 0.00 0.00
20,600.00 91.12 333.23 8,289.06 8,929.92 0.003,434.91 -8,247.49 0.00 0.00
20,700.00 91.12 333.23 8,287.11 9,007.79 0.003,524.18 -8,292.52 0.00 0.00
20,800.00 91.12 333.23 8,285.15 9,085.65 0.003,613.45 -8,337.55 0.00 0.00
20,900.00 91.12 333.23 8,283.19 9,163.52 0.003,702.71 -8,382.59 0.00 0.00
21,000.00 91.12 333.23 8,281.23 9,241.38 0.003,791.98 -8,427.62 0.00 0.00
21,040.03 91.12 333.23 8,280.45 9,272.56 0.003,827.71 -8,445.64 0.00 0.00
7/11/2023 3:53:59PM COMPASS 5000.17 Build Page 4
ConocoPhillips
Standard Proposal Report
Well MT7-03Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Actual 100.8+39.9 @ 140.70usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Actual 100.8+39.9 @ 140.70usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-03Well:
MT7-03_RWO RedrillWellbore:
MT7-03 RWO Redrill wp01Design:
Target Name
- hit/miss target
- Shape
TVD
(usft)
Northing
(usft)
Easting
(usft)
+N/-S
(usft)
+E/-W
(usft)
Design Targets
LongitudeLatitude
Dip Angle
(°)
Dip Dir.
(°)
MT7-03 RWO Redrill T 8,280.45 5,919,622.71 1,421,690.833,827.71 -8,445.640.00 0.00 70° 11' 0.086 N 151° 45' 42.184 W
- plan hits target center
- Circle (radius 1,320.00)
MT7-03 RWO Redrill 8,430.40 5,911,823.56 1,425,436.17-3,864.66 -4,484.690.00 0.00 70° 9' 44.462 N 151° 43' 47.226 W
- plan misses target center by 74.20usft at 12385.75usft MD (8449.40 TVD, -3897.56 N, -4548.43 E)
- Circle (radius 1,320.00)
7/11/2023 3:53:59PM COMPASS 5000.17 Build Page 5
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
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 the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
223-084
GMTU MT7-03A
RENDEZVOUS OIL POOLGRTR MOOSES TOOTH
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No
16
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17
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18
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19
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20
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21
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27
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31
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32
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No
33
Is
p
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2
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34
Me
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35
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36
Da
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NA
37
Se
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NA
38
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NA
39
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