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223-049
T39590
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.09.26 14:58:14 -08'00'
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.
MT7-94
GMTU MT7-94
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2024
MT7-94
50-103-20858-00-00
223-049-0
G
SPT
8079
2230490 2020
3505 3505 3507 3508
50 190 190 190
4YRTST P
Sully Sullivan
7/15/2024
4 year MIT-IA no issues
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 MT7-94
Inspection Date:
Tubing
OA
Packer Depth
1260 2290 2260 2255IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS240717095040
BBL Pumped:3.7 BBL Returned:3.7
Thursday, August 29, 2024 Page 1 of 1
9
9
9
9
9
9
9 9
9 9
9 9 9
9 9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.29 15:35:27 -08'00'
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. 7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: Schlumberger Wireline Backlog – Mooses Tooth
DATE: 12/19/2023
Transmitted:
North Slope, Mooses Tooth Unit
Via hard drive data drop
MT7-07 50-103-20841-00
222052_MT7-07_CBP_15Feb2023
222052_MT7-07_IPROF_14Aug23
222052_MT7-07_IPROF_14Mar23
222052_MT7-07_IPROF_25Nov22
222052_MT7-07_Patch_Setting_28Oct23
222052_MT7-07_PPROF_22Aug2022
222052_MT7-07_WFL_16Mar23
MT7-08 50-103-20846-00
222116_MT7-08_IPROF_17Aug23
222116_MT7-08_TTiX-IPROF_2Oct2023
MT7-09 50-103-20837-00
222011_MT7-09_PPROF_01Nov2022
222011_MT7-09_PPROF_03Jul2022
222011_MT7-09_TTiXPerf_04Oct23
MT7-94 50-103-20858-00
223049_MT7-94_MDT-XLROCK-
GR_10Sep2023
MT7-95 50-103-20854-00
223035_MT7-95_TubingPuncher_12Jun2023
2of 3
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
Receipt: Date:
Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
T38426
T38427
T38428
T38429
T38430
2/29/2024
MT7-94 50-103-20858-00
223049_MT7-94_MDT-XLROCK-
GR_10Sep2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.29
11:00:23 -09'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, January 25, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Josh Hunt
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
MT7-94
GMTU MT7-94
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/25/2024
MT7-94
50-103-20858-00-00
223-049-0
G
SPT
8079
2230490 2020
3424 3424 3424 3424
220 300 300 295
INITAL P
Josh Hunt
12/17/2023
I met with Tom Hills and Matt Miller and traveled to location. Checked the gauges and calibration stickers on the gauges used. They had all the
necessary paperwork needed. Very good test.
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 MT7-94
Inspection Date:
Tubing
OA
Packer Depth
740 2520 2465 2460IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitJDH231217184105
BBL Pumped:7 BBL Returned:7.1
Thursday, January 25, 2024 Page 1 of 1
TTT RR AA NN SS MM II TT TT AA LL
FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl/Kayla Junke ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 330 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: MT7-94
DATE: 12/05/2023
Transmitted:
NPRA, Greater Moose’s Tooth
Via SFTP
____ Geolog Mud log data package
MT7-94
MT7-94 is in a federal oil and gas unit. Only with respect to the zmt7-94 Well Data, CPAI hereby waives its rights to indefinitely
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., AS43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic
Slope Regional Corporation (ASRC).
Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: MT7-94 e-transmittal well folder
Receipt: Date:
Alaska IT Data Support-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 223-049
T38201
12/5/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.12.05
14:52:31 -09'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 2135' FSL, 3600' FEL S25 T10N R1E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 100.6 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" H-40 120'
13-3/8 L-80 3018'
9-5/8" L-80 7365'
7" L-80 8120'
4 1/2" L-80 8118'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Tail: 128ppg 15.8ppg Class G8.5"x9-7/8"
TUBING RECORD
26984'
Lead: 254.2bbl 13.0ppg Class G
Tail: 152bbl 15.8ppg Class G
8079
12-1/4"
6-1/8"
15352'5.5 15295'MD/8065' TVD
15352'MD/8079' TVD
BOTTOM
16" Lead: 456bbl 11.0ppg Blend
Tail: 70bbl 15.8 Class G
CASING
50-103-20858-00-00
GMT MT7-94
8/23/2023
26989'MD/8117'TVD
N/A
139.8
P.O.Box 100360, Anchorage, AK 99510-0360
290133
1073' FSL, 3227' FEL S32 T10N R2E
1647' FSL, 3445' FEL S14 T10N R1E
10/9/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
10/13/2023 223-049
985'MD/985'TVD
SETTING DEPTH TVD
5932755
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER
PACKER SET (MD/TVD)
15352'
42"
12.6
5915890
Greater Mooses Tooth/Rendezvous
AA081800, AA081803, AA081805
932535000, 932538000, 932540000
39'
29
39'
13397'
4086'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
279523
274690
CEMENTING RECORD
5922536
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner (10/9/2023): 15352'MD/8079'TVD - 26984'MD/8118'TVD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
39'
39'
Per 20 AAC 25.283 (i)(2) attach electronic information
43.5
15526'
39'
7296'
94
68
120'
39' 13549'
SIZE DEPTH SET (MD)
10 Yards
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
Injection Well
Date of Test: Oil-Bbl:
Flow Tubing
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 1:16 pm, Nov 15, 2023
Completed
10/13/2023
JSB
RBDMS JSB 111723
GDSR-11/22/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
985 985
C-30 1441 1441
2113 2113
4040 4040
K-2 4743 3315
Albian 97 5287 5287
Albian 96 5713 5713
HRZ 13486 7337
Kalubik 13678 7424
Kuparuk C 13925 7537
13932 7540
15677 8150
26989 8117
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Brad Gorham
Digital Signature with Date:
Contact Phone:907-265-6487
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: 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.
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.
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; or 90 days after log acquisition, 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.
LCU/Miluveach
C-10
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.
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).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, 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).
Authorized Name and
INSTRUCTIONS
Contact Email:brad.gorham@conocophillips.com
Authorized Title: Drilling Engineer
K-3
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Attached Seperately
Formation Name at TD:
Alpine C
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Top of Productive Interval:
Alpine C
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Page 1/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/22/2023
06:00
8/22/2023
07:30
1.50 MIRU, MOVE RURD P Prepare, and skid rig floor into rig move
position. Disconnect electrical from Pit
complex to the pump complex.
0.0 0.0
8/22/2023
07:30
8/22/2023
08:30
1.00 MIRU, MOVE RURD P Lower mast. Disconnect electrical from
pump complex to motors complex.
0.0 0.0
8/22/2023
08:30
8/22/2023
10:30
2.00 MIRU, MOVE RURD P Unpin pipe shed complex from sub.
Raise the sub, and stomp pipe shed
away from sub. Stomp motors and
pump complexes away from the rig. Put
motors, and pump complexes on
suspension. Stomp pit complex away
from sub.
0.0 0.0
8/22/2023
10:30
8/22/2023
15:00
4.50 MIRU, MOVE RURD P Stomp sub away from the well (MT7-
14). Stomp pipe shed, and sub into tow
position. Hook up jeep to the sub.
0.0 0.0
8/22/2023
15:00
8/22/2023
18:00
3.00 MIRU, MOVE RURD P Hook truck up to sub, move sub over
MT7-94. Unhook truck, and jeep from
sub. Stomp pipe shed into tow position.
Hook up truck to pipe shed and move to
MT7 94.
0.0 0.0
8/22/2023
18:00
8/22/2023
21:00
3.00 MIRU, MOVE RURD P Stomp pipe shed into sub. Pin pipe
shed to sub. Shim sub and pipe shed.
Spot motor complex with truck. Move
pit and pump complex to the sub.
0.0 0.0
8/22/2023
21:00
8/23/2023
00:00
3.00 MIRU, MOVE RURD P Raise mast. Skid rig floor into drilling
position. Spot and shim pit, and pump
complexes.
0.0 0.0
8/23/2023
00:00
8/23/2023
01:30
1.50 MIRU, MOVE RURD P Set pump complex. Hook up
interconnects and lower stairs. Stomp
CSG complex and shim. Set pipe
conveyors, and lower stairs.
0.0 0.0
8/23/2023
01:30
8/23/2023
03:00
1.50 MIRU, MOVE RURD P Stomp motor complex into place, and
set stairs. Shim and set cellar. Hook-up
pit and pump complex electrical lines.
0.0 0.0
8/23/2023
03:00
8/23/2023
04:00
1.00 MIRU, MOVE RURD P Hook-up pits interconnects. Lower C-
section. Hook-up mud and cement lines
on the rig floor. Remove energy track
straps, hook-up electrical lines on the rig
floor and in the pit complex.
0.0 0.0
8/23/2023
04:00
8/23/2023
06:30
2.50 MIRU, MOVE RURD P Hook-up hydraulic lines, and raise cattle
-shoot. Install cattle-shoot hatches.
Hook-up CSG and pipe shed complex
electrical lines. Hook-up geronimo and
derrick assist lines.
0.0 0.0
8/23/2023
06:30
8/23/2023
08:00
1.50 MIRU, MOVE RURD P Hook-up elecrtrical from motor to pump
complexes. Begin working on rig
acceptance check list.
0.0 0.0
8/23/2023
08:00
8/23/2023
09:00
1.00 MIRU, MOVE RURD P Swap from cold start gens to rig power
on all complexes. Start Amphion. Spool
drilling line onto the draw-works.
Remove shipping pins on the top drive.
Install bridal lines and scope derrick up.
0.0 0.0
8/23/2023
09:00
8/23/2023
09:30
0.50 MIRU, MOVE RURD P Lower derrick ladder. Install SRL's and
pull derrick counter weight line to the rig
floor. Make up kelly hose to top drive.
Obtain RKB's.
RKB:
38.7' to load shoulder.
39.2' to ground level.
RIG ACCEPTED 09:30 ON 08/23/2023.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 2/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/23/2023
09:30
8/23/2023
12:00
2.50 MIRU, MOVE NUND P N/U surface riser. Rig down ST-80 and
remove from rig floor. Start to bring on
drilling mud into the pits.
0.0 0.0
8/23/2023
12:00
8/23/2023
16:00
4.00 MIRU, MOVE NUND P M/U flow line flange to riser. M/U flow
line dresser sleeve. Move Joe's box in
place, and seal. Install surface riser
flow nipple. Air up air boots on flow line.
RIG ON HIGH LINE POWER 1530 HRS
ON 08/23/2023.
0.0 0.0
8/23/2023
16:00
8/23/2023
17:00
1.00 MIRU, MOVE BHAH P Bring short BHA components to the rig
floor. Load long BHA components and
HWDP into the pipe shed.
0.0 0.0
8/23/2023
17:00
8/23/2023
18:30
1.50 MIRU, MOVE BHAH P P/U and rack back 4 stands of HWDP.
Check that 90' mouse hole is clear.
0.0 0.0
8/23/2023
18:30
8/23/2023
19:00
0.50 MIRU, MOVE CIRC P Flood lines and fill up conductor. Check
for leaks.
0.0 0.0
8/23/2023
19:00
8/23/2023
20:30
1.50 MIRU, MOVE BHAH P P/U Conductor clean out BHA to 65' per
Baker DD.
0.0 65.0
8/23/2023
20:30
8/23/2023
21:00
0.50 MIRU, MOVE SEQP P Test surface lines to 3500 PSI: GOOD. 65.0 65.0
8/23/2023
21:00
8/23/2023
21:15
0.25 MIRU, MOVE WASH P Wash down F/ 65' to 106'. Tag bottom
@ 106'.
150 GPM @ 180 PSI.
65.0 106.0
8/23/2023
21:15
8/23/2023
22:30
1.25 SURFAC, DRILL DDRL P Drill F/ 106' to 270' leaving enough room
to P/U the next BHA.
575 GPM @ 905 PSI
40 RPM @ 5 K TQ
8 K WOB.
106.0 270.0
8/23/2023
22:30
8/24/2023
00:00
1.50 SURFAC, DRILL BKRM P Back ream out of the hole F/ 270' to 65'.
575 GPM @ 700 PSI
40 RPM @ 2 K TQ
ROTWT: 60 K.
270.0 65.0
8/24/2023
00:00
8/24/2023
02:45
2.75 SURFAC, DRILL BHAH P P/U surface BHA and Make up as per
Baker DD. Trip in to 206' MD. Plug in
and test MWD tools .
65.0 206.0
8/24/2023
02:45
8/24/2023
03:45
1.00 SURFAC, DRILL PULD P P/U stand of HWDP shallow test MWD
tools and obtain survey at 206' MD ,
Mouse hole stand and P/U last joint of
drill collars to 245' MD
206.0 245.0
8/24/2023
03:45
8/24/2023
06:00
2.25 SURFAC, DRILL DDRL P Wash in hole from 245' MD to 270' MD
survey with Gyro and drill 16" surface
hole section from 270' MD to 390'
MD/TVD.
7k WOB
650 GPM
1205 PSI
60 RPM
4.5 k TQ on bttm
2.5 k TQ off bttm
41% FO
2.2 hrs ADT
2.2 hrs ART
2.2 hrs TBH
0 hrs TJH
245.0 390.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 3/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/24/2023
06:00
8/24/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill/Slide f/ 390' to 1686' MD/ 990' TVD.
8 k WOB
850 GPM
1950 PSI
60 RPM
6k TQ on bttm
2.5k TQ off bttm
50% FO
11.4 ppg ECD
85k PUW
85k SOW
85k ROT
1.1 hrs AST
2.4 hrs ART
5.7 hrs TBH
2.1 hrs TJH
390.0 990.0
8/24/2023
12:00
8/24/2023
18:00
6.00 SURFAC, DRILL DDRL P Drill/Slide f/ 990' to 1686' MD/ 1646'
TVD.
12k WOB
900 GPM
2330 PSI
60 RPM
7k TQ on bttm
3k TQ off bttm
50% FO
11.6ppg ECD
98k SO
94k ROT
2.1 hrs AST
2.3 hrs ART
4.3 hrs ADT
6.2 hrs TJH
990.0 1,646.0
8/24/2023
18:00
8/24/2023
23:30
5.50 SURFAC, DRILL DDRL P Drill/Slide f/ 1686' to 2350' MD/ 2152'
TVD.
9k WOB
900 GPM
2310 PSI
60 RPM
8k TQ on bttm
4k TQ off bttm
50% FO
11.6ppg ECD
98k SO
100k ROT
2.5 hrs AST
1.6 hrs ART
4.1 hrs ADT
10.5 hrs TJH
14.1 Bit hours
1,646.0 2,350.0
8/24/2023
23:30
8/25/2023
00:00
0.50 SURFAC, DRILL SVRG P Rig service replace breaker for pipe
shed power supply.
2,350.0 2,350.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 4/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/25/2023
00:00
8/25/2023
03:00
3.00 SURFAC, DRILL DDRL P Drill/Slide f/ 2350' to 2700' MD/ 2367'
TVD.
9k WOB
900 GPM
2310 PSI
60 RPM
8k TQ on bttm
4k TQ off bttm
50% FO
11.6ppg ECD
98k SO
100k ROT
2.5 hrs AST
1.6 hrs ART
4.1 hrs ADT
10.5 hrs TJH
14.1 Bit hours
2,350.0 2,700.0
8/25/2023
03:00
8/25/2023
04:00
1.00 SURFAC, DRILL DDRL T Trouble shoot MWD signal loss, try
different pump rates and several cycles.
Pump 10 bbl sweep fresh water to try
and clear tools.
2,700.0 2,700.0
8/25/2023
04:00
8/25/2023
05:15
1.25 SURFAC, DRILL CIRC T Unable to regain comms with MWD.
Rack back a stand and cycle pumps
from 800 to 1000 GPM attempting to
establish connection. Pump 10 bbl water
sweep to try and clear tools of potential
debris. Unable to regain connectivity
with MWD.
2,700.0 2,700.0
8/25/2023
05:15
8/25/2023
12:00
6.75 SURFAC, DRILL BKRM T BROOH from 2686' MD to 578' MD
900 GPM
2150 PSI
40 RPM
5k TQ
49% flow out
80k ROT
2,700.0 2,700.0
8/25/2023
12:00
8/25/2023
12:15
0.25 SURFAC, DRILL CIRC T Pump 80 bbl sweep and observe
increae of large cuttings.
2,700.0 2,700.0
8/25/2023
12:15
8/25/2023
12:30
0.25 SURFAC, DRILL OWFF T Open well flow check and observe minor
losses
2,700.0 2,700.0
8/25/2023
12:30
8/25/2023
13:00
0.50 SURFAC, DRILL TRIP T POOH from 578' MD to 242' MD racking
back stands of HWDP.
2,700.0 2,700.0
8/25/2023
13:00
8/25/2023
14:30
1.50 SURFAC, DRILL BHAH T L/D BHA from 242' MD to 0' as per
Baker DD
2,700.0 2,700.0
8/25/2023
14:30
8/25/2023
16:00
1.50 SURFAC, DRILL BHAH T P/u and M/U 16" BHA #2 as per Baker
DD/MWD scribe, Plug in tools and test
tools. 242' MD.
2,700.0 2,700.0
8/25/2023
16:00
8/25/2023
17:30
1.50 SURFAC, DRILL TRIP T Trip in hole from 242' MD to 2670' MD
89k SO
2,700.0 2,700.0
8/25/2023
17:30
8/25/2023
18:00
0.50 SURFAC, DRILL REAM T Wash in hole from 2670' MD to 2700'
MD
900 GPM
2550 PSI
60 RPM
4k TQ
2,700.0 2,700.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 5/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/25/2023
18:00
8/25/2023
23:15
5.25 SURFAC, DRILL DDRL P Drill/Slide f/ 2700' to 3264' MD/ 2644'
TVD.
23k WOB
900 GPM
3020 PSI
60 RPM
10k TQ on bttm
49% FO
11.8ppg ECD
106k ROT
1.4 hrs AST
3.3 hrs ART
4.7 hrs ADT
18.09 hrs TJH
21.69 Bit hours
2,700.0 3,264.0
8/25/2023
23:15
8/26/2023
00:00
0.75 SURFAC, DRILL DDRL T Plugged flowbox from hole unloading
after sliding.
3,264.0 3,264.0
8/26/2023
00:00
8/26/2023
05:00
5.00 SURFAC, DRILL DDRL P Drill/Slide f/ 3264' to 3726' MD/ 2861'
TVD.
28k WOB
900 GPM
3060 PSI
60 RPM
11k TQ on bttm
6k TQ off Bttm
65% FO
12.1ppg ECD
110k ROT
3,264.0 3,726.0
8/26/2023
05:00
8/26/2023
05:30
0.50 SURFAC, DRILL DDRL T Hole unloaded and plugged flowbox.
Shut down pull master bushings and
clean out Joes box.
3,726.0 3,726.0
8/26/2023
05:30
8/26/2023
08:30
3.00 SURFAC, DRILL DDRL P Drill/Slide f/ 3726' to 4020' MD/ 2997'
TVD.
35k WOB
900 GPM
2960 PSI
60 RPM
11k TQ on bttm
6k TQ off Bttm
68% FO
12.2ppg ECD
110k ROT
3,726.0 4,020.0
8/26/2023
08:30
8/26/2023
09:45
1.25 SURFAC, DRILL CIRC T Observed sudden increase uin ECD
from 11.8 ppg to 12.2 ppg, Picked up off
bottm and work pipe, pull master
bushings and work pipe until hole cleans
up.
4,020.0 4,020.0
8/26/2023
09:45
8/26/2023
10:30
0.75 SURFAC, DRILL DDRL P Drill/Slide f/ 4020' to 4096' MD/ 3022'
TVD. TD called at 4096'
28k WOB
900 GPM
3215 PSI
60 RPM
11k TQ on bttm
7k TQ off Bttm
68% FO
11.6 ppg ECD
110k ROT
4,020.0 4,096.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 6/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/26/2023
10:30
8/26/2023
13:00
2.50 SURFAC, TRIPCAS CIRC P Take final survey, pump 40 bbl HIVIS
sweep.
Minimal increase in cuttings from
sweep.
900 GPM
3215 PSI
60 RPM
11k TQ on bttm
7k TQ off Bttm
68% FO
11.6 ppg ECD
4,096.0 4,096.0
8/26/2023
13:00
8/26/2023
13:15
0.25 SURFAC, TRIPCAS OWFF P Open well flow check , slight losses
observed.
4,096.0 4,096.0
8/26/2023
13:15
8/26/2023
18:00
4.75 SURFAC, TRIPCAS BKRM P Backream out of hole from 3893' MD to
2586' MD.
900 GPM
2700 PSI
40 RPM
5k TQ
4,096.0 4,096.0
8/26/2023
18:00
8/27/2023
00:00
6.00 SURFAC, TRIPCAS BKRM P Backream out of hole from 2586' MD to
807' MD.
900 GPM
2200 PSI
40 RPM
Slow pump rate at 1000' MD to 750
GPM.
750 GPM 1700 PSI
4,096.0 4,096.0
8/27/2023
00:00
8/27/2023
00:45
0.75 SURFAC, TRIPCAS BKRM P Back rem from 807' MD to 784'
750 GPM
40 RPM
4,096.0 4,096.0
8/27/2023
00:45
8/27/2023
01:45
1.00 SURFAC, TRIPCAS CIRC P Pump 40 bbl HiVis sweep on last stand
of drill pipe and Back ream until sweep
is out, moderate increase in cuttings
from sweep. Rack back stand and pump
second 40 bbl HiVis sweep on first
stand of HWDP and Backream while
circulating out sweep Heavy increase in
cuttings observed fro second sweep.
4,096.0 4,096.0
8/27/2023
01:45
8/27/2023
02:00
0.25 SURFAC, TRIPCAS OWFF P Flow check well for 15 minutes, well
static.
4,096.0 4,096.0
8/27/2023
02:00
8/27/2023
05:00
3.00 SURFAC, TRIPCAS BHAH P Rack back HWDP and L/D BHA as per
Baker DD.
4,096.0 4,096.0
8/27/2023
05:00
8/27/2023
06:00
1.00 SURFAC, CASING BHAH P Clean and clear rig floor remove BHA
components
4,096.0 4,096.0
8/27/2023
06:00
8/27/2023
07:00
1.00 SURFAC, CASING RURD P R/U Volant , power tongs, Bail
extensions, Elevators and Spiders.
4,096.0 4,096.0
8/27/2023
07:00
8/27/2023
07:30
0.50 SURFAC, CASING PUTB P M/U 13-3/8" Shoe track Backer Lock
pins through joint #4. Pump through
shoe track to check floats.
4,096.0 4,096.0
8/27/2023
07:30
8/27/2023
10:00
2.50 SURFAC, CASING PUTB P Run in hole with 13-3/8" Surface casing
as per modeled trip speeds. to 1037'
MD
30K M/U TQ
98k SOW
4,096.0 4,096.0
8/27/2023
10:00
8/27/2023
10:30
0.50 SURFAC, CASING CIRC P Circulate bottoms up at 1037' MD
stagging pumps up to 8 BPM.
148 PSI
21% FO
4,096.0 4,096.0
8/27/2023
10:30
8/27/2023
12:00
1.50 SURFAC, CASING PUTB P Run in hole with 13-3/8" surface casing
from 1037' MD to 1764' MD as per
modeled tripping speeds.
Install Centek centralizers as per tally.
30K M/U TQ
130k SOW
4,096.0 4,096.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 7/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/27/2023
12:00
8/27/2023
18:30
6.50 SURFAC, CASING PUTB P Run in hole with 13-3/8" surface casing
from 1764' MD to 4043' MD as per
modeled tripping speeds.
Install centralizers Centek centralizers
as per tally.
32K M/U TQ
172k SOW
4,096.0 4,096.0
8/27/2023
18:30
8/27/2023
19:00
0.50 SURFAC, CASING PUTB P 4043' MD M/U hanger and RIH to 4085' 4,096.0 4,096.0
8/27/2023
19:00
8/27/2023
20:00
1.00 SURFAC, CASING CIRC P 4085' MD Stage up pumps to 8 BPM
and CBU
FCP at 8 BPM 241 PSI
PUW 226k
SOW 176k
4,096.0 4,096.0
8/27/2023
20:00
8/27/2023
20:30
0.50 SURFAC, CASING RURD P Blow down top drive rig up cement hose
to Volant break circulation at 4 BPM,
simps PJSM for cement job.
4,096.0 4,096.0
8/27/2023
20:30
8/28/2023
00:00
3.50 SURFAC, CEMENT CMNT P Line up to SLB cement unit pressure
test lines to 4500 psi. Pump 103 bbl's
mudpush2, FCP at 4.8 BPM 292 psi.
Spot 2 gallons of red dye and drop
bottom plug. Pump 461 bbl's of 11 ppg
DeepCrete cmt FCP at 5 BPM 803 psi.
Pump 73 bbl's 15.8 ppg class G tail cmt
at 5 BPM, 510 FCP at 4.1 BPM. Drop
top plug and chase with 20 bbl's water
from cement unit and line up on mud
pump and pump 1560 strokes observe
bottom plug land at 576 stokes shear at
374 psi.
4,096.0 4,096.0
8/28/2023
00:00
8/28/2023
01:30
1.50 SURFAC, CEMENT CMNT P Continue displacing cement with rig mud
pumps at 8 BPM Observed cement back
to surface at 3600 strokes. Reduced
rate to 3 BPM, 480 PSI at 4800 strokes,
Bump plugs at 4930 strokes and
pressure up to 900 PSI 500 psi over
FCP. Hold for 5 minutes. Bleed off
pressure and check flow for floats
holding, floats good. Drain riser and
flush with black water. 198 Cement
returns.
4,096.0 4,096.0
8/28/2023
01:30
8/28/2023
02:30
1.00 SURFAC, CEMENT PRTS P Pressure test surface casing to 3500 psi
for 30 minutes charted , record bleed off
on LOT chart.
4,096.0 4,096.0
8/28/2023
02:30
8/28/2023
04:00
1.50 SURFAC, CEMENT RURD P Back out landing joint , set slips and R/D
Volant and L/D landing joint. Flush riser.
Clean cement line, Demco's and Joes
Box. Blow down hole fill and jet lines.
4,096.0 4,096.0
8/28/2023
04:00
8/28/2023
06:00
2.00 SURFAC, WHDBOP RURD P Nipple down riser and surface
equipment.
4,096.0 4,096.0
8/28/2023
06:00
8/28/2023
07:00
1.00 SURFAC, WHDBOP NUND P Nipple upWell head and orientate as per
Pad operator. test lower seal to 1000
PSi as per FMC rep.
4,096.0 4,096.0
8/28/2023
07:00
8/28/2023
11:30
4.50 SURFAC, WHDBOP NUND P Nipple up BOPS, Riser Flowline, RCD
clamp, Choke and kill lines. Obtain RKB
measurements set mouse hole and
mobilize BHA components to the rig
floor.
4,096.0 4,096.0
8/28/2023
11:30
8/28/2023
12:00
0.50 SURFAC, WHDBOP MPSP P Set test plug, fill BOPS with H2O, set
RCD test cap and purge system of air.
4,096.0 4,096.0
8/28/2023
12:00
8/28/2023
13:00
1.00 SURFAC, WHDBOP RURD P TQ Riser bolts 4,096.0 4,096.0
8/28/2023
13:00
8/28/2023
14:15
1.25 SURFAC, WHDBOP MPDA P Pressure test RCD to 250 low psi and
1800 high psi for 5/10 minutes, rig down
and pull test cap.
4,096.0 4,096.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 8/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/28/2023
14:15
8/28/2023
15:15
1.00 SURFAC, WHDBOP RURD P P/U 9.625 test joint and R/U BOP
testing equipment. Flood lines with H2O
and purge air.
4,096.0 4,096.0
8/28/2023
15:15
8/28/2023
22:30
7.25 SURFAC, WHDBOP 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 3,500 high for 10 min. Manual
operated & super choke tested T/2,000
psi charted, W/ 9-5/8" test JT test
annular, 9-5/8" UPR, Test choke valves
1-15, manual operated & super choke,
Choke & kill manuals, HCR's, 4" valves
on kill line, 5" FOSV, 5" Dart valve,
Upper and lower IBOP on TD;
Blind/shear rams; Perform KOOMEY
drawdown, ACC = 3050 PSI. MANIF. =
1500 PSI. ACC = 1650 PSI After all
functions on bottles, 14 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 = 14 sec. Blind / Shears = 15 sec.
LPR = 14 sec. Choke HCR = 2 sec. Kill
HCR = 2 sec; Test PVT G/L and flow out
alarms, Test LEL and H2S alarms.
AOGCC and BLM witness waived.
4,096.0 4,096.0
8/28/2023
22:30
8/28/2023
23:00
0.50 SURFAC, WHDBOP RURD P Blow down and rig down test equipment. 4,096.0 4,096.0
8/28/2023
23:00
8/29/2023
00:00
1.00 SURFAC, DRILLOUT SLPC P Hang off blocks and Slip and cut drilling
line. replace spool.
4,096.0 4,096.0
8/29/2023
00:00
8/29/2023
02:30
2.50 SURFAC, DRILLOUT SLPC P Hang off blocks and Slip and cut drilling
line. replace spool.
4,096.0 4,096.0
8/29/2023
02:30
8/29/2023
03:00
0.50 SURFAC, DRILLOUT RURD P Install wear ring as per FMC rep. 4,096.0 4,096.0
8/29/2023
03:00
8/29/2023
08:15
5.25 SURFAC, DRILLOUT BHAH P PJSM and P/U and M/U 12-1/4" INT 1
BHA as per Baker DD.
4,096.0 4,096.0
8/29/2023
08:15
8/29/2023
11:15
3.00 SURFAC, DRILLOUT TRIP P Run in hole to 3788' MD with 12-1/4"
INT #1 BHA with stands of drill pipe from
derrick.
Monitor displacement on pit #7
Shallow test MWD at 2500' MD with 770
GPM 3500 PSI.
4,096.0 4,096.0
8/29/2023
11:15
8/29/2023
11:45
0.50 SURFAC, DRILLOUT SFTY P Fill pipe , space out and shut in well for
choke drill.
4,096.0 4,096.0
8/29/2023
11:45
8/29/2023
13:45
2.00 SURFAC, DRILLOUT COCF P Wash in hole fro 3611' MD to 3981'
126 GPM
189 PSI
Drill cement stringers from to 3993' MD
3993'MD tag FC
4,096.0 4,096.0
8/29/2023
13:45
8/29/2023
17:30
3.75 SURFAC, DRILLOUT DRLG P 3993' MD drill plugs, FC and Shoe track
to 4085' MD wash down to 4096'
640 GPM
1460 PSI
50-80 RPM
10 to 16K TQ
4,096.0 4,096.0
8/29/2023
17:30
8/29/2023
18:00
0.50 SURFAC, DRILLOUT DDRL P Drill ahead from 4096 to 4116' for 20'
new formation to FIT test depth.
640 GPM
1430 PSI
10-13K TQ
4,096.0 4,116.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 9/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/29/2023
18:00
8/29/2023
19:00
1.00 SURFAC, DRILLOUT CIRC P 4116' MD circulate and condition mud
for FIT test.
640 GPM
1430 PSI
60 RPM
10-13k TQ
4,116.0 4,116.0
8/29/2023
19:00
8/29/2023
19:30
0.50 SURFAC, DRILLOUT FIT P Pull back into casing shoe RB stand and
R/U for FIT test flood lines and perform
FIT test with 10.9 ppg MDWT and 759
PSI for a 15.7 ppg EQV.
3.2 bbl's pumped and 3.0 bbl's bled
back.
4,116.0 4,116.0
8/29/2023
19:30
8/30/2023
00:00
4.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4116' MD to
4155'' MD , make connection and
resume drilling ahead from 4155' MD to
4446' MD 3179' TVD while displacing
mud to 11.0 ppg FWP. Finish
displacement before connection is made
and continue drilling ahead down linking
as needed.
1048 GPM
2333 PSI
140 RPM
15k WOB
15k TQ on bttm
10k TQ off Bttm
54% FO
11.8 ppg ECD
140k PUW
104 SOW
119k RTW
ADT 2.8
Bit hours 3.25
Jar hours 31.1
4,116.0 4,446.0
8/30/2023
00:00
8/30/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4446' MD to 4998'
MD
1040 GPM
2470 PSI
150 RPM
16k WOB
10k TQ on bttm
6k TQ off Bttm
55% FO
11.9 ppg ECD
140k PUW
110 SOW
126k RTW
ADT 4.1
Bit hours 4.1
Jar hours 35.2
4,446.0 4,998.0
8/30/2023
06:00
8/30/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 4998' MD to 5684'
MD
1040 GPM
2790 PSI
150 RPM
16k WOB
11k TQ on bttm
6k TQ off Bttm
55% FO
12.2 ppg ECD
146k PUW
118 SOW
131k RTW
ADT 4.4
Bit hours 11.8
Jars 35.6
4,998.0 5,684.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 10/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/30/2023
12:00
8/30/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 5684' MD to 6436'
MD 4096 TVD
1040 GPM
3060 PSI
150 RPM
22k WOB
12k TQ on bttm
8k TQ off Bttm
57% FO
12.4 ppg ECD
160k PUW
121 SOW
137k RTW
ADT 4.4
Bit hours 16.2
Jars 44
Note:
At 5900' suspend NOVOS T&D due to
inability to properly configure settings.
Rotary randomly turning on at 120rpm
while slacking off.
5,684.0 6,436.0
8/30/2023
18:00
8/31/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 6436' MD to 7262'
MD 4477' TVD
1040 GPM
3400 PSI
150 RPM
20k WOB
13k TQ on bttm
10k TQ off Bttm
57% FO
12.8 ppg ECD
165k PUW
123 SOW
143k RTW
ADT 4.5
Bit hours 20.7
Jars 48.5
6,436.0 7,262.0
8/31/2023
00:00
8/31/2023
06:30
6.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 7262' MD to 8002'
MD 4810' TVD
1040 GPM
3546 PSI
150 RPM
20k WOB
15k TQ on bttm
8k TQ off Bttm
55% FO
12.9 ppg ECD
183k PUW
128 SOW
145k RTW
ADT 4.3
Bit hours 25.1
Jars 52.9
7,262.0 8,002.0
8/31/2023
06:30
8/31/2023
07:30
1.00 INTRM1, DRILL CIRC P Pomp 50 bbl LowVis nut plug sweep
circulate and reciprocate.
1040 GPM
3600 PSI
11k TQ on bttm
6k TQ off Bttm
55% FO
12.7 ppg ECD
183k PUW
128 SOW
145k RTW
8,002.0 8,002.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 11/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/31/2023
07:30
8/31/2023
12:00
4.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8002' MD to 8510'
MD 5051' TVD
1040 GPM
3710 PSI
150 RPM
16k WOB
16k TQ on bttm
9k TQ off Bttm
55% FO
12.9 ppg ECD
183k PUW
128 SOW
145k RTW
ADT 3.5
Bit hours 28.6
Jars 56.4
8,002.0 8,510.0
8/31/2023
12:00
8/31/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8510' MD to 8781'
MD
1040 GPM
3440 PSI
120 RPM
12k WOB
16k TQ on bttm
9k TQ off Bttm
58% FO
12.4 ppg ECD
184k PUW
137 SOW
154k RTW
ADT 5.5
Bit hours 34.1
Jars 61.9
8,510.0 8,781.0
8/31/2023
18:00
9/1/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 8510' MD to 9047'
MD 5298' TVD, Increased gas at 8873'
MD 5219' TVD
1040 GPM
3400 PSI
120 RPM
14k WOB
13k TQ on bttm
7k TQ off Bttm
58% FO
12.2 ppg ECD
184k PUW
137 SOW
154k RTW
ADT 5.3
Bit hours 39.1
Jars 67.9
Gas units peak 182
8,781.0 9,047.0
9/1/2023
00:00
9/1/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9047' MD to 9300'
MD 5416' TVD, Increased gas at 8873'
MD 5219' TVD
1040 GPM
3712 PSI
120 RPM
18k WOB
15k TQ on bttm
9k TQ off Bttm
58% FO
12.1 ppg ECD
190k PUW
140 SOW
159k RTW
ADT 5.2
Bit hours 44.6
Jars 72.4
Gas units peak 167
9,047.0 9,300.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 12/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/1/2023
06:00
9/1/2023
09:15
3.25 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9300' MD to 9554'
MD 5486' TVD,
1040 GPM
3500 PSI
120 RPM
18k WOB
15k TQ on bttm
9k TQ off Bttm
58% FO
12.1 ppg ECD
184k PUW
137 SOW
155k RTW
9,300.0 9,454.0
9/1/2023
09:15
9/1/2023
09:45
0.50 INTRM1, DRILL SVRG P Rig service, replace pin connection on
mud pump #2
9,454.0 9,454.0
9/1/2023
09:45
9/1/2023
10:30
0.75 INTRM1, DRILL CIRC T Continue replacing pin connector on
mud pump#2
9,454.0 9,454.0
9/1/2023
10:30
9/1/2023
12:00
1.50 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9454' MD to 9514'
MD 5514' TVD,
1040 GPM
3700 PSI
120 RPM
25k WOB
15k TQ on bttm
11k TQ off Bttm
58% FO
12.1 ppg ECD
184k PUW
137 SOW
155k RTW
ADT 4.3
Bit hours 48.9
Jars 76.7
9,454.0 9,514.0
9/1/2023
12:00
9/1/2023
16:00
4.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9514' MD to 9679'
MD 5589' TVD,
1040 GPM
3730 PSI
120 RPM
25k WOB
15k TQ on bttm
11k TQ off Bttm
58% FO
12.1 ppg ECD
184k PUW
137 SOW
155k RTW
ADT 3.4
Bit hours 52.3
Jars 80.1
9,514.0 9,679.0
9/1/2023
16:00
9/1/2023
17:00
1.00 INTRM1, DRILL CIRC T Circullate and condition while replace
gasket on mud pump #2
500 GPM
1190 PSI
100 RPM
10K TQ
9,679.0 9,679.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 13/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/1/2023
17:00
9/2/2023
00:00
7.00 INTRM1, DRILL DRLG P Drill 12-1/4" hole from 9679' MD to 9979'
MD 5727' TVD,
1040 GPM
3750 PSI
120 RPM
25k WOB
17k TQ on bttm
11k TQ off Bttm
58% FO
12.1 ppg ECD
184k PUW
137 SOW
155k RTW
ADT 6
Bit hours 58.3
Jars 86.1
9,679.0 9,979.0
9/2/2023
00:00
9/2/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 9979' MD to
10,238' MD ' 5846 TVD,
1025 GPM
3750 PSI
120 RPM
25k WOB
17k TQ on bttm
11k TQ off Bttm
58% FO
12.1 ppg ECD
208k PUW
150 SOW
170k RTW
ADT 5.4
Bit hours 68.4
Jars 91.3
9,979.0 10,230.0
9/2/2023
06:00
9/2/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 10238' MD to
10,585' MD ' 6,006' TVD,
1025 GPM
3675 PSI
140 RPM
22k WOB
18k TQ on bttm
14k TQ off Bttm
58% FO
12.0 ppg ECD
220k PUW
150 SOW
170k RTW
ADT 4.9
Bit hours 68.4
Jars 96.2
10,230.0 10,585.0
9/2/2023
12:00
9/2/2023
16:00
4.00 INTRM1, DRILL DDRL P Drill 12-1/4" hole from 10585' MD to
10,930' MD ' 6,165' TVD,
1020 GPM
3620 PSI
140 RPM
22k WOB
19k TQ on bttm
14k TQ off Bttm
58% FO
12.0 ppg ECD
220k PUW
150 SOW
170k RTW
ADT 4.9
Bit hours 68.4
Jars 96.2
10,585.0 10,930.0
9/2/2023
16:00
9/2/2023
19:30
3.50 INTRM1, DRILL CIRC P Circulate bottoms up racking back pne
stand per bottoms up. from 10,930' MD
to 10,684' MD.
10,930.0 10,930.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 14/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/2/2023
19:30
9/2/2023
20:00
0.50 INTRM1, DRILL OWFF P Conduct 30 minute flow check
well,observe alight drop in fluid level.
10,930.0 10,930.0
9/2/2023
20:00
9/3/2023
00:00
4.00 INTRM1, DRILL BKRM P Back ream out of hole from 10,684' MD
to 10,215' MD
1000 GPM
3410 PSI
120 RPM
18k TQ
58% FO
11.9 ppg ECD
165k RTW
10,930.0 10,930.0
9/3/2023
00:00
9/3/2023
06:00
6.00 INTRM1, DRILL BKRM P Back ream out of hole from 10,215' MD
to 9100' MD Pumping sweeps and
adding dilution fluid as needed to
maintain mud properties.
1000 GPM
3340 PSI
120 RPM
14k TQ
58% FO
11.9 ppg ECD
152k RTW
10,930.0 10,930.0
9/3/2023
06:00
9/3/2023
12:00
6.00 INTRM1, DRILL BKRM P Back ream out of hole from 9,100' MD to
7,675' MD, Pumping sweeps and adding
dilution fluid as needed to maintain mud
properties.
1000 GPM
3108 PSI
120 RPM
11k TQ
58% FO
12.2 ppg ECD
140k RTW
10,930.0 10,930.0
9/3/2023
12:00
9/3/2023
18:00
6.00 INTRM1, DRILL BKRM P Back ream out of hole from 9,100' MD to
7,675' MD, Pumping sweeps and adding
dilution fluid as needed to maintain mud
properties.
1000 GPM
3108 PSI
120 RPM
11k TQ
58% FO
12.2 ppg ECD
140k RTW
10,930.0 10,930.0
9/3/2023
18:00
9/4/2023
00:00
6.00 INTRM1, DRILL BKRM P Back ream out of hole from 7,675' MD to
5688' MD, Pumping sweeps and adding
dilution fluid as needed to maintain mud
properties.
Tight spots encountered at 7400' to
5780'.
1000 GPM
2724 PSI
120 RPM
12k TQ
56% FO
12.0 ppg ECD
125k RTW
10,930.0 10,930.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 15/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/4/2023
00:00
9/4/2023
06:00
6.00 INTRM1, DRILL BKRM P Back ream out of hole from 5,688' MD to
4774' MD, Pumping sweeps and adding
dilution fluid as needed to maintain mud
properties.
Tight spots encountered at 7400' to
4774'.
1000 GPM
2724 PSI
120 RPM
12k TQ
56% FO
12.0 ppg ECD
125k RTW
5,688.0 4,774.0
9/4/2023
06:00
9/4/2023
10:00
4.00 INTRM1, DRILL BKRM P Back ream out of hole from 4774' MD to
4080' MD, Pumping sweeps and adding
dilution fluid as needed to maintain mud
properties.
Tight spots encountered up to 4500'.
4450' MD Perform 540 bbl dilution.
1000 GPM
2500 PSI
120 RPM
12k TQ
56% FO
11.8 ppg ECD
116k RTW
4,774.0 4,080.0
9/4/2023
10:00
9/4/2023
11:15
1.25 INTRM1, DRILL CIRC P Pump 40 bbl LoVis and 40 bbl HiVis
sweep Nut plug sweep
Large increase in cuttings from sweeps.
1000 GPM
2230 PSI
60 RPM
7K TQ
55% FO
RTW 120K
4,080.0 4,080.0
9/4/2023
11:15
9/4/2023
12:00
0.75 INTRM1, DRILL TRIP P Trip in hole from 4080' to 5027' MD.
112K SOW
132K PUW
4,080.0 5,027.0
9/4/2023
12:00
9/4/2023
16:00
4.00 INTRM1, DRILL TRIP P Trip in hole from 5027' to 9833' MD.
112K SOW
132K PUW
5,027.0 9,833.0
9/4/2023
16:00
9/4/2023
19:30
3.50 INTRM1, DRILL CIRC P Circulate bottoms up X3 and pump 40
bbl LoVis and 40 bbl HiVis sweeps to
clean hole and pump 550 bbl dilution.
1000 GPM
3071 PSI
120 RPM
16K TQ
11.60 ECD
PUW 200k
SOW 147k
RTW 165k
9,833.0 9,833.0
9/4/2023
19:30
9/4/2023
20:00
0.50 INTRM1, DRILL OWFF P Perform flow check well, Observe slight
drop in fluid level.
9,833.0 9,833.0
9/4/2023
20:00
9/5/2023
00:00
4.00 INTRM1, DRILL TRIP P Trip out of hole fro 9833' MD to 5700'
MD with 12-1/4" BHA while monitor
displacement on Pit #2.
150k PUW
9,833.0 5,700.0
9/5/2023
00:00
9/5/2023
01:30
1.50 INTRM1, DRILL TRIP P Trip out of hole fro 5700' MD to 4080'
MD with 12-1/4" BHA while monitor
displacement on Pit #2
150k PUW
5,700.0 4,080.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 16/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/5/2023
01:30
9/5/2023
03:00
1.50 INTRM1, DRILL CIRC P Pump HiVis Low Vis sweep 40 bbl each.
Circulate 2 x bottoms up inside casing
pump HiVis Low Vis sweep 40 bbl each.
1000 GPM
2278 PSI
11.7 ECD
30 RPM
7k TQ
110k RTW
Pump dry job
4,080.0 4,080.0
9/5/2023
03:00
9/5/2023
03:15
0.25 INTRM1, DRILL OWFF P Perform flow check well, Observe slight
drop in fluid level.
4,080.0 4,080.0
9/5/2023
03:15
9/5/2023
04:30
1.25 INTRM1, DRILL TRIP P Trip out of hole from 4080' MD to 2798'
MD with 12-1/4" BHA while monitor
displacement on Pit #2
120k PUW
4,080.0 2,798.0
9/5/2023
04:30
9/5/2023
04:45
0.25 INTRM1, DRILL SVRG P Replace tong dies on ST-80's 2,798.0 2,798.0
9/5/2023
04:45
9/5/2023
06:30
1.75 INTRM1, DRILL TRIP P Trip out of hole from 2798' MD to 690'
MD with 12-1/4" BHA while monitor
displacement on Pit #2
2,798.0 690.0
9/5/2023
06:30
9/5/2023
07:00
0.50 INTRM1, DRILL OWFF P Perform 15 minute flow check, observe
slight drop in fluid level.
690.0 690.0
9/5/2023
07:00
9/5/2023
12:00
5.00 INTRM1, DRILL BHAH P Rack back HWDP, Jars and collars. L/D
BHA as per Baker Rep. Download
MWD, M/U filter float subs and DC and
rack back in derrick.
690.0 0.0
9/5/2023
12:00
9/5/2023
15:30
3.50 INTRM1, EVALFM DLOG P Set up and test E-line tools in pipe shed,
Simops shuffle pipe in derrick and clean
and clear rig floor.
0.0 0.0
9/5/2023
15:30
9/5/2023
17:00
1.50 INTRM1, EVALFM DLOG P M/U E-line BHA and RIH to 161' MD and
test tools as per SLB procedure.
0.0 161.0
9/5/2023
17:00
9/5/2023
20:30
3.50 INTRM1, EVALFM DLOG P RIH with MDT tools from 161' MD to
3917' MD on drill pipe from derrick. Fill
pipe every 10 stands.
161.0 3,917.0
9/5/2023
20:30
9/5/2023
21:00
0.50 INTRM1, EVALFM DLOG P Hang E-line shives in derrick and rope
socket side entry sub.
3,917.0 3,917.0
9/5/2023
21:00
9/6/2023
00:00
3.00 INTRM1, EVALFM DLOG P RIH with MDT tools from 3917' MD to
5800' MD on drill pipe from derrick. Fill
pipe every 10 stands.
120k PUW
108K SOW
3,917.0 5,800.0
9/6/2023
00:00
9/6/2023
03:00
3.00 INTRM1, EVALFM DLOG P RIH with MDT tools from 5800' MD to
7500' MD on drill pipe from derrick. Fill
pipe every 10 stands.
136k PUW
115K SOW
5,800.0 7,500.0
9/6/2023
03:00
9/6/2023
05:30
2.50 INTRM1, EVALFM DLOG P P/U CSES sub above floor and R/U
lower sheave on rig floor, Stab PWCH
into drill pipe. RIH 20' below mud line
and run E-line in hole 300' above
DWCH, latch. Pump E-line cable into
latch at 4 BPM, verify latch and
continuity with BHA. P/U side entry to rig
floor and install cable clamp and cover.
Perform additional tool check and pull
test to 2.5K.
7,500.0 7,500.0
9/6/2023
05:30
9/6/2023
07:30
2.00 INTRM1, EVALFM DLOG P RIH with E-line latched in the DWCH
with drill pipe at 20 FPM.
7,500.0 8,864.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 17/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/6/2023
07:30
9/6/2023
12:00
4.50 INTRM1, EVALFM DLOG P Perform stick test at 5 and 10 minute
intervals, 125K SOW, 160k PUW.
Space out at 8863' MD and begin
pressure sampling at 8845' MD to 8955'
MD as per SLB E-line rep. 126K SOW
and 188K PUW. Monitor well on trip
tank.
8,864.0 8,955.0
9/6/2023
12:00
9/6/2023
18:00
6.00 INTRM1, EVALFM DLOG P Continue pressure sampling from 8845'
MD to 9019' MD as per SLB E-line rep.
8,955.0 9,019.0
9/6/2023
18:00
9/7/2023
00:00
6.00 INTRM1, EVALFM DLOG P Set tooll at 9019' MD and inflate packer
for wellbore sampling.
Conduct formation evaluation as per
engineering team.
9,019.0 9,019.0
9/7/2023
00:00
9/7/2023
01:00
1.00 INTRM1, EVALFM DLOG P Set SLB MDT dual packer tool at 9019'
and inflate packer for wellbore sampling.
Conduct formation evaluation as per
engineering team.
9,019.0 9,019.0
9/7/2023
01:00
9/7/2023
01:15
0.25 INTRM1, EVALFM DLOG P Release packer and stroke pipe 90'
Break over at 257K PUW and stabilize
at 159K PUW
127K SOW
9,019.0 9,019.0
9/7/2023
01:15
9/7/2023
10:30
9.25 INTRM1, EVALFM DLOG P Set SLB MDT dual packer tool at 9019'
and inflate packer for wellbore sampling
(5.2 gallons formation fluid pumped into
wellbore). Release MDT packers.
Conduct formation evaluation as per
engineering team.
9,019.0 9,019.0
9/7/2023
10:30
9/7/2023
11:15
0.75 INTRM1, EVALFM DLOG P P/U 30' confirming pipe free. 286K to
breakover, 165K P/U, 124K S/O.
RIH f/9,019' t/9,482'.
9,019.0 9,482.0
9/7/2023
11:15
9/7/2023
15:00
3.75 INTRM1, EVALFM CIRC P Circulate bottoms up and reciprocate
string. 146 units max gas.
300 GPM
700-800 PSI
165K P/U
130K S/O
9,482.0 9,482.0
9/7/2023
15:00
9/7/2023
17:00
2.00 INTRM1, EVALFM TRIP P POOH f/9,482' t/7,512' with SLB MDT to
CSES.
148K P/U
9,482.0 7,512.0
9/7/2023
17:00
9/7/2023
18:30
1.50 INTRM1, EVALFM DLOG P Disconnect PWCH from DWCH applying
3,000 lbs pull above line weight,
released after 9 minutes. POOH with
cable to surface. Remove CSES as per
SLB.
7,512.0 7,512.0
9/7/2023
18:30
9/7/2023
20:30
2.00 INTRM1, EVALFM TRIP X POOH f/7,512' t/5,535' with SLB MDT to
reposition CSES for additional logging in
Albain 95 sand.
148K P/U
7,512.0 5,535.0
9/7/2023
20:30
9/7/2023
21:00
0.50 INTRM1, EVALFM CIRC X Circulate drill string volume to clear
DWCH w/160 gpm at 210 psi.
5,535.0 5,535.0
9/7/2023
21:00
9/7/2023
22:30
1.50 INTRM1, EVALFM DLOG X Install CSES with PWCH on cable,
lowered CSES below rotary and RIH
with cable to 5,100'. Pump down PWCH
to latch depth at 160 gpm with 220 psi.
Confirmed tool checks - good latch. P/U
and tighten pack off on CSES, install
clamp and pull test 3,000 lbs pull - good.
Set depth and confirm with SLB unit.
5,535.0 5,535.0
9/7/2023
22:30
9/7/2023
23:30
1.00 INTRM1, EVALFM TRIP X RIH f/5,535' t/6,169' w/stands from
derrick for log correlation.
123k P/U
105K S/O
5,535.0 6,169.0
9/7/2023
23:30
9/8/2023
00:00
0.50 INTRM1, EVALFM DLOG X Taking pre-tests in Albain 95 formation
with SLB MDT tool as per SLB/COPA.
First pre-test in progress at 6,169' DPM.
6,169.0 6,169.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 18/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/8/2023
00:00
9/8/2023
02:45
2.75 INTRM1, EVALFM DLOG X Performed 9 pre-tests in Albain 95
formation with SLB MDT tool as per
SLB/COPA f/6,169' t/6,206' DPM.
6,169.0 6,206.0
9/8/2023
02:45
9/8/2023
10:00
7.25 INTRM1, EVALFM DLOG X Set MDT Dual Packer at 6,206' DPM
and obtain formation sample. 7 hrs
packers inflated on wall.
6,206.0 6,206.0
9/8/2023
10:00
9/8/2023
10:30
0.50 INTRM1, EVALFM DLOG X Deflate MDT Dual Packers. P/U 260K to
break over (120K over pull), RIH to
6,467'.
P/U 140K
S/O 115K.
6,206.0 6,467.0
9/8/2023
10:30
9/8/2023
13:00
2.50 INTRM1, EVALFM CIRC X Circulate bottoms up and reciprocate
string. 85 units max gas.
300 GPM
549 PSI
137K P/U
113K S/O
6,467.0 6,467.0
9/8/2023
13:00
9/8/2023
14:30
1.50 INTRM1, EVALFM TRIP X POOH f/6,467' t/5,532' with SLB MDT to
CSES.
127K P/U
6,467.0 5,532.0
9/8/2023
14:30
9/8/2023
16:00
1.50 INTRM1, EVALFM DLOG X Disconnect PWCH from DWCH applying
3,000 lbs pull above line weight,
released after 10 minutes. POOH with
cable to surface. Remove CSES as per
SLB. Pump string volume at 470 gpm
w/480 psi to flush DWCH.
5,532.0 5,532.0
9/8/2023
16:00
9/8/2023
20:00
4.00 INTRM1, EVALFM TRIP P POOH f/5,532' t/160' with SLB MDT
tools.
127K P/U
5,532.0 160.0
9/8/2023
20:00
9/8/2023
20:30
0.50 INTRM1, EVALFM OWFF P OWFF f/15 min - well static.
SIMOPS: PJSM and prepare to L/D SLB
MDT tools.
160.0 160.0
9/8/2023
20:30
9/8/2023
22:30
2.00 INTRM1, EVALFM BHAH P L/D SLB MDT & Dual Packer tools with
sample bottles (5 x 420 cc + 3 x 250 cc
sample bottles) as per SLB rep's.
Note:Tools were packed with formation
clay. MDT packer element in good
condition with no signs of wear. Dual
packers show signs of wear, small piece
of rubber missing off top packer element
and bottom packer element has signs of
mushrooming.
160.0 0.0
9/8/2023
22:30
9/8/2023
23:30
1.00 INTRM1, EVALFM ELNE P Remove wireline sheave from derrick
and install in elevators. Send out MDT
tools off floor and clean rig floor.
0.0 0.0
9/8/2023
23:30
9/9/2023
00:00
0.50 INTRM1, EVALFM ELNE P M/U SLB MSCT tool string on wireline. 0.0 0.0
9/9/2023
00:00
9/9/2023
00:30
0.50 INTRM1, EVALFM ELOG P Continue M/U SLB MSCT tool string on
wireline. Functioned tools.
0.0 0.0
9/9/2023
00:30
9/9/2023
03:00
2.50 INTRM1, EVALFM ELOG P RIH with SLB MSCT tools on wireline.
Tagged up at 4,210'. Attempted to work
past obstruction without any progress.
0.0 4,210.0
9/9/2023
03:00
9/9/2023
04:00
1.00 INTRM1, EVALFM ELOG T POOH with SLB MSCT tools to surface.
Observed large pieces of clay on tool
standoffs.
Discussed with town on plan forward
while POOH and decision made to run
MSCT tools on TLC.
4,210.0 0.0
9/9/2023
04:00
9/9/2023
06:00
2.00 INTRM1, EVALFM DLOG P Reposition wireline sheave from
elevators to derrick finger for TLC
logging. R/U DWCH sub to tool string.
Connect wireline cable head to DWCH
and confirm communication with tools.
0.0 60.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 19/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/9/2023
06:00
9/9/2023
09:00
3.00 INTRM1, EVALFM TRIP P RIH at 55 fpm with SLB MSCT tool
string on 5" DP stands to 4,050'. Fill
pipe every 25 stands.
SIMOPS: Re-headed wireline cable to
PWCH.
P/O 103K
S/O 97K
60.0 4,050.0
9/9/2023
09:00
9/9/2023
11:00
2.00 INTRM1, EVALFM TRIP P RIH at 20 fpm with SLB MSCT tool
string on 5" DP stands to 5,791'. Fill
pipe every 25 stands.
Note: No obstruction observed at 4,210'.
S/O 94K
4,050.0 5,791.0
9/9/2023
11:00
9/9/2023
11:15
0.25 INTRM1, EVALFM CIRC P Fill pipe and circulate to flush DWCH.
590 GPM
600 PSI
P/U 122K
S/O 108K
5,791.0 5,791.0
9/9/2023
11:15
9/9/2023
12:30
1.25 INTRM1, EVALFM DLOG P Install CSES with PWCH on cable,
lowered CSES below rotary and RIH
with cable to 5,200'. Pump down PWCH
to latch depth at 208 gpm with 233 psi.
Confirmed tool checks - good latch. P/U
and tighten pack off on CSES, install
clamp and pull test 3,000 lbs pull - good.
Set depth and confirm with SLB unit.
5,791.0 5,791.0
9/9/2023
12:30
9/9/2023
18:00
5.50 INTRM1, EVALFM TRIP P RIH f/5,791' t/9,112' w/stands 5" DP
from derrick. Observed string taking
weight at 7,172' & 7,359', no change in
MSCT tool string head tension. P/U and
went back past each with no resistance.
153K P/U
118K S/O
5,791.0 9,112.0
9/9/2023
18:00
9/10/2023
00:00
6.00 INTRM1, EVALFM DLOG P Correlate with log for core depths. Cut
17 of 50 cores w/MSCT tool on TLC
f/9,055' t/8,964'.
Note; Average time to cut core 3
minutes each.
9,112.0 8,964.0
9/10/2023
00:00
9/10/2023
04:00
4.00 INTRM1, EVALFM DLOG P Cut 27 of 50 cores w/MSCT tool on TLC
f/8,964' t/8,912' WLM. Tool jammed on
core # 27,
Note: Average time to cut core 3
minutes each.
P/U 154K
8,964.0 8,912.0
9/10/2023
04:00
9/10/2023
08:00
4.00 INTRM1, EVALFM DLOG P POOH at 30 fpm f/8,912' t/5,820' at
CSES with SLB MSCT tools.
134K P/U
8,912.0 5,820.0
9/10/2023
08:00
9/10/2023
10:00
2.00 INTRM1, EVALFM DLOG P Disconnect PWCH from DWCH applying
3,000 lbs pull above line weight,
released from DWCH. POOH with cable
to surface. Remove CSES as per SLB.
Note: Found SLB wireline cable was
kinked in 2 places ~5' & ~10' above the
CSES.
5,820.0 5,820.0
9/10/2023
10:00
9/10/2023
10:30
0.50 INTRM1, EVALFM CIRC P Circulate w/600 gpm at 680 psi. Slug
pipe.
5,820.0 5,820.0
9/10/2023
10:30
9/10/2023
15:30
5.00 INTRM1, EVALFM TRIP P POOH at 30 fpm F/5,820' t/100' with
SLB MSCT tools.
5,820.0 100.0
9/10/2023
15:30
9/10/2023
16:00
0.50 INTRM1, EVALFM OWFF P OWFF f/15 min - well static. SIMOPS:
Prepare to L/D MSCT tools.
100.0 100.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 20/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/10/2023
16:00
9/10/2023
18:00
2.00 INTRM1, EVALFM RURD P L/D SLB MSCT tools and cores. Clean
and clear rig floor.
Note:23 of 27 cores recovered = 85%.
Observed a core separation marker
jammed in the top of core storage
sleeve. This prevents the separation
markers and cores from entering the
storage sleeve.
100.0 0.0
9/10/2023
18:00
9/10/2023
21:30
3.50 INTRM1, DRILL OTHR P Change out upper and lower IBOP's and
saver sub. Test to 3,500 psi. BHI upload
MWD tools. Performed weekly BOP
function test.
0.0 0.0
9/10/2023
21:30
9/10/2023
22:00
0.50 INTRM1, DRILL BHAH P RIH with BHI BHA from derrick. 0.0 186.0
9/10/2023
22:00
9/11/2023
00:00
2.00 INTRM1, DRILL TRIP P RIH f/186' t/2,900'. Filled pipe and
shallow tested MWD at 25 stands.
186.0 2,900.0
9/11/2023
00:00
9/11/2023
00:45
0.75 INTRM1, DRILL TRIP P RIH f/2,900' t/4,032'. Filled pipe every
25 stands.
2,900.0 4,032.0
9/11/2023
00:45
9/11/2023
01:45
1.00 INTRM1, DRILL SLPC P Slip & cut 110' drlg line. Calibrate block
height. Check COM while circulating at
200 gpm, 229 psi.
4,032.0 4,032.0
9/11/2023
01:45
9/11/2023
02:00
0.25 INTRM1, DRILL TRIP P RIH f/4,032' t/4,292'. Observed 25K
weight loss.
4,032.0 4,292.0
9/11/2023
02:00
9/11/2023
02:30
0.50 INTRM1, DRILL REAM P Ream f/4,292' t/4,415' with minimal
resistance.
800 GPM
1560 PSI
80-100 RPM
8K TQ
115K ROT
4,292.0 4,415.0
9/11/2023
02:30
9/11/2023
05:00
2.50 INTRM1, DRILL TRIP P RIH f/4,292' t/8,964'. Observed 25K
weight loss.
4,415.0 8,964.0
9/11/2023
05:00
9/11/2023
05:30
0.50 INTRM1, DRILL REAM P P/U and Ream f/8,928' t/9,033' with
minimal resistance.
800 GPM
2249 PSI
80 RPM
14K TQ
151K ROT
8,928.0 9,033.0
9/11/2023
05:30
9/11/2023
06:30
1.00 INTRM1, DRILL TRIP P RIH f/9,033' t/10,730'.
123K S/O
9,033.0 10,730.0
9/11/2023
06:30
9/11/2023
08:00
1.50 INTRM1, DRILL REAM P Precautionary Wash & Ream f/10,730'
t/10,930' staging gpm up to 1000 gpm.
Observed ~30' fill on bottom.
1000 GPM
3360 PSI
80 RPM
17-22K TQ
163K ROT
10,730.0 10,930.0
9/11/2023
08:00
9/11/2023
10:00
2.00 INTRM1, DRILL CIRC P Circulate and condition mud blending in
BFWP w/rotating and reciprocating
f/10,930' t/10,830'.
Note: Change out VFD drive on #2 MP.
520 GPM
1260 PSI
50 RPM
17-20K TQ
11.8 ECD
171K ROT
402 units Max Gas
10,930.0 10,830.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 21/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/11/2023
10:00
9/11/2023
12:00
2.00 INTRM1, DRILL DDRL P Drill 12-1/4" INT 1 f/10,930' t/11,016'.
24K WOB
1025 GPM
3710 PSI
135 RPM
23K TQ ON
21K TQ OFF
11.8 ECD
171K ROT
10,930.0 11,016.0
9/11/2023
12:00
9/11/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" INT 1 f/11,016' t/11,675'.
25K WOB
1020 GPM
3810 PSI
150 RPM
26K TQ ON
21K TQ OFF
11.8 ECD
270K P/U
130K S/O
175K ROT
ADT = 4.4
Bit Hrs = 77.8
Jar Hrs = 160
11,016.0 11,675.0
9/11/2023
18:00
9/12/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" INT 1 f/11,675' t/12,343'.
20K WOB
1010 GPM
3830 PSI
180RPM
27K TQ ON
22K TQ OFF
11.9 ECD
250K P/U
128K S/O
180K ROT
ADT = 4.1
Bit Hrs = 81.9
Jars Hrs = 164.1
11,675.0 12,343.0
9/12/2023
00:00
9/12/2023
06:00
6.00 INTRM1, DRILL DRLG P Drill 12-1/4" INT 1 f/12,343' t/12,943'.
31K WOB
980 GPM
4020 PSI
180 RPM
29K TQ ON
22K TQ OFF
12.1 ECD
293K P/U
128K S/O
187K ROT
ADT = 4.4
Bit Hrs = 86.3
Jars Hrs = 168.5
12,343.0 12,943.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 22/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/12/2023
06:00
9/12/2023
12:00
6.00 INTRM1, DRILL DRLG P Drill 12-1/4" INT 1 f/12,943' t/13,314'.
Note: At 12,974' while drilling observed
ECD spike to 13.1 ppg and lost 90 bbl's
to formation, P/U and reamed stand and
no additional losses.
17K WOB
950 GPM
3846 PSI
180 RPM
28K TQ ON
31K TQ OFF
11.9 ECD
312K P/U
128K S/O
186K ROT
ADT = 4.0
Bit Hrs = 90.3
Jars Hrs = 172.5
12,943.0 13,314.0
9/12/2023
12:00
9/12/2023
15:00
3.00 INTRM1, DRILL DDRL P Drill 12-1/4" INT 1 f/13,314' t/13,561' at
section TD.
20K WOB
950 GPM
3750 PSI
180 RPM
29K TQ ON
25K TQ OFF
11.8 ECD
340K P/U
125K S/O
186K ROT
ADT = 2.40
Bit Hrs = 92.7
Jars Hrs = 174.9
13,314.0 13,561.0
9/12/2023
15:00
9/12/2023
18:00
3.00 INTRM1, TRIPCAS CIRC P Circulate and condition mud on bottom
for 5 minutes (no rotation), P/U and rack
back 1 stand. Pump 40 bbl's low vis and
40 bbl's high vis sweeps, circulate s/s
while rotating and working string (25%
increase fines at shakers when at
surface).
950 GPM
3810 PSI
120 RPM
27K TQ OFF
11.8 ECD
340K P/U
128K S/O
186K ROT
13,561.0 13,375.0
9/12/2023
18:00
9/12/2023
18:30
0.50 INTRM1, TRIPCAS OWFF P OWFF f/ 30 min - well static.
20 RPM
26K TQ
13,375.0 13,375.0
9/12/2023
18:30
9/12/2023
21:00
2.50 INTRM1, TRIPCAS BKRM P BROOH f/13,375' t/12,810' when shaker
screens blinded off (primiraly black
products).
950 GPM
3750 PSI
120 RPM
26K TQ
92 Units Max Gas ( From Flow Check)
13,375.0 12,810.0
9/12/2023
21:00
9/12/2023
22:30
1.50 INTRM1, TRIPCAS CIRC P Circulate and changing screens f/200's
to 170's to 140's while stagings flow
rates up.
500-970 GPM
1100-3800 PSI
80-120 RPM
26-28K TQ
12,810.0 12,810.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 23/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/12/2023
22:30
9/12/2023
23:30
1.00 INTRM1, TRIPCAS BKRM P BROOH f/12,810' t/12,586', shaker
screens blinded off.
970 GPM
3850 PSI
120 RPM
28.5K TQ
12,810.0 12,586.0
9/12/2023
23:30
9/13/2023
00:00
0.50 INTRM1, TRIPCAS CIRC T Circulate while changing out shakers
screens.
500 GPM
1200 PSI
80 RPM
27K TQ
185K ROT
12,586.0 12,586.0
9/13/2023
00:00
9/13/2023
08:00
8.00 INTRM1, TRIPCAS BKRM P BROOH f/12,586 t/10,925'.
W/ 970 GPM, 3850 PSI, 120 RPM,
28.5K TQ
Notes: Observed pressure event(s) at
11,072', 10,899' with ~125psi to 200psi.
Able to work though without any further
issues
12,586.0 10,925.0
9/13/2023
08:00
9/13/2023
12:30
4.50 INTRM1, TRIPCAS CIRC P Circulate and condition mud from
10,925' to 11,015'.
W/ 1,000 GPM, 3750 PSI, 120 RPM,
26K TQ OFF, 11.5 ECD
Notes: Circulated 2 x 45 bbls sweeps
and dump and dilute w/290 bbls
10,925.0 11,015.0
9/13/2023
12:30
9/13/2023
13:00
0.50 INTRM1, TRIPCAS TRIP P POOH on elevators f/11,015' t/10,705'
Notess: Observed over pull @ 10,705'
of 30 klbs
11,015.0 10,705.0
9/13/2023
13:00
9/14/2023
00:00
11.00 INTRM1, TRIPCAS BKRM P BROOH f/10,705' t/7,637' at ~700 - 800
fph
W/ 970 GPM, 3850 PSI, 120 RPM,
28.5K TQ
Notes:Slow pulling speed at 8,027' to
450 fph, observed fluctuating torque
values
10,705.0 7,637.0
9/14/2023
00:00
9/14/2023
12:00
12.00 INTRM1, TRIPCAS BKRM P BROOH f/7,637' at ~4,030- 800 fph W/
988 GPM, 2350 PSI, 120 RPM, 14.5K
TQ, ECD 11.5 ppg.
Notes: At ~6,500' dump and dilute with
290 bbls. Slow pull BHA into the shoe,
no issues.
7,637.0 4,030.0
9/14/2023
12:00
9/14/2023
13:00
1.00 INTRM1, TRIPCAS CIRC P Circulate and condition mud at 4,030'
W/ 995 GPM, 1950 PSI, 120 RPM, 11K
TQ OFF, ECD 11.2 ppg.
4,030.0 4,030.0
9/14/2023
13:00
9/14/2023
15:30
2.50 INTRM1, TRIPCAS TRIP P TOOH to BHA.
Notes: OWFF at HWDP, well is static.
4,030.0 556.0
9/14/2023
15:30
9/14/2023
18:00
2.50 INTRM1, TRIPCAS BHAH P PJSM and LD 12/14" BHA, Clean and
clear floor.
556.0 0.0
9/14/2023
18:00
9/14/2023
19:00
1.00 INTRM1, CASING WWWH P RU and Flush the BOP stack to clear
any debris. RU and pull the waer
bushing.
0.0 0.0
9/14/2023
19:00
9/14/2023
20:30
1.50 INTRM1, CASING PUTB P PJSM & RU to Run 9 5/8" casing. 0.0 0.0
9/14/2023
20:30
9/15/2023
00:00
3.50 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 1,550'
Notes: Confirmed FS is pinned, MU
shoe track & pump to ensure functioning
properly.
0.0 1,550.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 24/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/15/2023
00:00
9/15/2023
05:00
5.00 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 4,050'
Notes: Displacement volumes tracking
per plan, top off every 10 jts
1,550.0 4,050.0
9/15/2023
05:00
9/15/2023
06:00
1.00 INTRM1, CASING CIRC P Circulate and condition mud at 4,050',
W/ 251 GPM, 161 PSI,
Notes: Circulate bottoms up. Obtain
TQD measures at 4,050': 165 PUW, 141
SOW, 151 RTW, 9.5k TQ w/20 RPM
4,050.0 4,050.0
9/15/2023
06:00
9/15/2023
11:00
5.00 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 7,300'
Notes: Displacement volumes tracking
closely per plan, top off every 10 jts
4,050.0 7,300.0
9/15/2023
11:00
9/15/2023
12:30
1.50 INTRM1, CASING CIRC P Circulate and condition mud at 7,300',
W/ 330 GPM, 240 PSI, 265 PUW, 155
SOW
Notes: Circulate casing volume
7,300.0 7,300.0
9/15/2023
12:30
9/15/2023
17:00
4.50 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 9,950'
Notes: Displacement volumes tracking
closely per plan, top off every 10 jts
7,300.0 9,950.0
9/15/2023
17:00
9/15/2023
18:30
1.50 INTRM1, CASING CIRC P Circulate and condition mud at 9,950',
W/ 330 GPM, 315 PSI, 350 PUW, 175
SOW
Notes: Circulate casing volume
9,950.0 9,950.0
9/15/2023
18:30
9/15/2023
20:00
1.50 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 10,900'
Notes: Displacement volumes tracking
closely per plan, top off every 10 jts
9,950.0 10,900.0
9/15/2023
20:00
9/15/2023
20:30
0.50 INTRM1, CASING CIRC P Circulate and condition mud at 10,900',
W/ 205 GPM, 250PSI, 370 PUW, 180
SOW
Notes:Pull spider slips and slack off to
adjust the drilling line on drawworks
spool
10,900.0 10,900.0
9/15/2023
20:30
9/16/2023
00:00
3.50 INTRM1, CASING PUTB P Run 9 5/8" casing per detail to 12,800'
Notes: Displacement volumes tracking
closely per plan, top off every 10 jts
10,900.0 12,800.0
9/16/2023
00:00
9/16/2023
04:00
4.00 INTRM1, CASING PUTB P Run 9 5/8" casing per detail from
12,800' to 13,549'
Notes: At ~12,500' began observing
additoinal drag wiith FF trend at ~.25
-.30. At 13,117' began working casing
string down with Volant, attempted to
circulate, not able to pump. Continue to
work casing string down to 13,549',
Landed successfully on hanger
12,800.0 13,549.0
9/16/2023
04:00
9/16/2023
08:45
4.75 INTRM1, CASING CIRC P Circulate and conditon mud at 13,549',
w/10 GPM 750 PSI
Notes: Initially unable to establish
circulation. After cycling pressure to 750
psi several times, began to get returns
13,549.0 13,549.0
9/16/2023
08:45
9/16/2023
09:15
0.50 INTRM1, CASING SVRG P Perform rig maintanence and inspect
Volant tool
13,549.0 13,549.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 25/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/16/2023
09:15
9/16/2023
14:45
5.50 INTRM1, CASING CIRC P Circulate and conditon mud at 13,549',
w/250 GPM 389 PSI
Notes:Slowly staged pump rate up over
several hours until pressures balance
and are able to pump at full cement rate.
13,549.0 13,549.0
9/16/2023
14:45
9/16/2023
16:15
1.50 INTRM1, CEMENT CMNT P PJSM, RU and test cement lines to
3500 PSI
Notes: Service cement line demco valve
and re-test
13,549.0 13,549.0
9/16/2023
16:15
9/16/2023
21:45
5.50 INTRM1, CEMENT CMNT P PJSM, Pump Int 1 cement job per detail.
- Mix and pump 63.9 bbls mud push
(extra 3.9 bbls mud push)
- Drop bottom plug
- Mix and pump 254.2 bbls of 13 ppg
Lead cement
- Mix and pump 152 bbls of 15.8 ppg
Tail cement (Tail wet at 1800 hrs)
- Drop top plug
- Pump 20 bbls clean up H20
- Displace with 989 bbls NAF mud
(bumped 8368 stks)
- Initial rate - 6 BPM, 380 PSI
- Final rate - 3 BPM, 585 PSI
- After bump: 1100 PSI for 5 min
(charted) Bumped at 2145 hrs
- Bleed off check floats - Floats held
13,549.0 13,549.0
9/16/2023
21:45
9/16/2023
22:45
1.00 INTRM1, CEMENT PRTS P PJSM. RU and Test 9 5/8" casing to
3500 psi for 30 min (Charted)
Notes: Pump 126 stks (14.8 bbls), After
test bleed back ~15 bbls
0.0 0.0
9/16/2023
22:45
9/17/2023
00:00
1.25 INTRM1, CEMENT CLEN P RD from Cement job, RD Volant CRT,
cement lines, Blow down all, Clean and
clear rig floor.
0.0 0.0
9/17/2023
00:00
9/17/2023
00:30
0.50 INTRM1, CEMENT CMNT P Lay down Landing joint, Casing
equipment, PU single of 5" DP for
setting pack-off
0.0 0.0
9/17/2023
00:30
9/17/2023
02:00
1.50 INTRM1, CEMENT WWSP P RU and set 9 5/8" pack-off per FMC
Rep. Test pack-off to 5000 psi for 10
min. Test was successful
Notes: Company Rep witness the test
0.0 0.0
9/17/2023
02:00
9/17/2023
03:00
1.00 INTRM1, CEMENT NUND P RU and change upper rams to 4 1/2" x
7"
Notes: SIMOPS - PU test Joint, MU floor
valves, etc.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 26/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/17/2023
03:00
9/17/2023
10:00
7.00 INTRM1, WHDBOP BOPE P RU and begin testing BOPE 250/3500
psi - Fill stack w/H2O, perform shell test
-Test annular & Ram #1,2 and 3 to
250/3500psi f/ 5/10min w/ 5" & 7" test
joint. -Test 2 ea 5" and 4" FOSV and 1
ea 5" and 4" dart.
-Function primary and remote BOPE
control stations.
-Test LEL and H2S gas alarms. Function
and grease choke valve 6, retest good. -
Service manual choke valve, retest
good.
- Perform koomy draw-down test
Complete derrick inspection per DDI
guidelines
- BLM Rep Mutasim Elganzoory Waived
witness.
- AOGCC Rep Brian Bixby waived
witness.
Note: SIMOPS - change swab and liner
to 5 1/2"
0.0 0.0
9/17/2023
10:00
9/17/2023
11:30
1.50 INTRM1, WHDBOP BOPE P Remove Test joint and trip nipple. Install
MPD test cap and flood MPD lines - Test
MPD to 250/1800 psi. Test good.
Remove test cap and Test line, Install
trip nipple
0.0 0.0
9/17/2023
11:30
9/17/2023
13:00
1.50 INTRM1, WHDBOP BOPE P Remove test plug and install wear
bushing. Blow down choke and kill lines
from BOP test. Clean and clear floor
0.0 0.0
9/17/2023
13:00
9/17/2023
14:30
1.50 INTRM1, DRILLOUT SLPC P PJSM. Cut and slip 94' fo drilling line,
Service rig
0.0 0.0
9/17/2023
14:30
9/17/2023
18:00
3.50 INTRM1, DRILLOUT BHAH P PJSM. PU BHA #7 per directional driller
- PU bit, auto-trak, MWD, non-mags,
exp reamer, stab, circ-sub, HWDP, and
jars
Notes: Found washout between first and
second joint of drill collars. Lay down
both joints, Pick up new to replace
0.0 542.0
9/17/2023
18:00
9/17/2023
19:30
1.50 INTRM1, DRILLOUT TRIP P TIH with BHA #5 f/542' t/2,890'
Note: Fill pipe every 25 stds
542.0 2,890.0
9/17/2023
19:30
9/17/2023
20:30
1.00 INTRM1, DRILLOUT DHEQ T Fill pipe and test Baker tools w/600
GPM, 2150 psi
Notes: Cycle pumps and downlink
several times to sync up tools and
adjust tool parameters between surface
and downhole tools. Trouble shooting
with remote MWD and night directional
driller
2,890.0 2,890.0
9/17/2023
20:30
9/18/2023
00:00
3.50 INTRM1, DRILLOUT TRIP P TIH with BHA #5 f/2,890' t/10,067'
Note: Fill pipe every 25 stds
2,890.0 10,067.0
9/18/2023
00:00
9/18/2023
02:30
2.50 INTRM1, DRILLOUT TRIP P TIH with BHA #5 f/10,067' t/13,194'
Note: Fill pipe every 25 stds,
10,067.0 13,194.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 27/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/18/2023
02:30
9/18/2023
03:30
1.00 INTRM1, DRILLOUT REAM P Wash down f/ 13,194' t/13,456'. W/250
GPM 975 PSI
Notes: No cement stringers or
excessive drag observed while washing
to plugs & FC
13,194.0 13,456.0
9/18/2023
03:30
9/18/2023
07:30
4.00 INTRM1, DRILLOUT DRLG P Begin drillling out shoe track and rat
hole f/13,456' t/13,561'
580 GPM 3650 PSI 60 RPM
14.5K TQ 3-12 WOB 12.8 ECD
F/O 35%
Notes: Tag plugs, FC, and FS on depth,
13,456.0 13,561.0
9/18/2023
07:30
9/18/2023
08:00
0.50 INTRM1, DRILLOUT DDRL P Drill 20' new hole f/13,561' t/13,581'
580 GPM 3650 PSI 80 RPM
14.5K TQ 3-12 WOB 12.8 ECD
F/O 35% Jar Hrs 175.2
Notes: Tag plugs, FC, and FS on depth
13,561.0 13,581.0
9/18/2023
08:00
9/18/2023
10:00
2.00 INTRM1, DRILLOUT CIRC P Circulate and condition mud for FIT.
Work string f/13,581' t/ 13,495'
580 GPM 3500 PSI 60 RPM 11K
TQ
12.7 ECD F/O 35%
Notes: Work string across the FS
multiple times, no issues
13,581.0 13,495.0
9/18/2023
10:00
9/18/2023
11:00
1.00 INTRM1, DRILLOUT FIT P RU and perfom FIT to 14.1 ppge mw at
13,495'
W/ 6 BPM for 43 STKS, 990 PSI
Notes: Bled back 3.6 BBLS
13,495.0 13,495.0
9/18/2023
11:00
9/18/2023
12:00
1.00 INTRM2, DRILL MPDA P Remove trip nipple and install MPD
bearing and break in MPD bearing per
the MPD
Notes: Obtain TQ&D parameters
PUW=226, SOW=162k, RTW=179k,
TQ=12k, Obtain SPR's
13,495.0 13,581.0
9/18/2023
12:00
9/18/2023
14:00
2.00 INTRM2, DRILL DDRL P Drill Int2 f/13,561' t/13,671'
590 GPM 3750 PSI 90 RPM
14K TQ 13 ECD F/O 35%
Notes: Begin trapping ~500psi with
MPD to maintain 13 ppge mw during
connections
13,581.0 13,671.0
9/18/2023
14:00
9/18/2023
16:00
2.00 INTRM2, DRILL UREM P Activate under-reamer at 13,645' per
detail
- BROOH f/13,671' t/13,645'
- Gather baseline parameters and drop
1.25" activation ball
- Pump ball drown W/250 GPM, 1265
PSI, BOS @ 2496 STKS
- PSI up to 1400 PSI, Observed PSI
drop
- Stage pump up to 590 GPM, 3460 PSI
- Confirm UR open, Cut 5' 9 7/8" ledge
- Set down 13k to confirm ledge cut -
Good test
13,671.0 13,671.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 28/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/18/2023
16:00
9/19/2023
00:00
8.00 INTRM2, DRILL DDRL P Drill Int2 f/13,671' to 14,300'
647 GPM 3850 PSI 161 RPM
17-19K TQ 11k WOB 13 ECD
169 RTW F/O 35%
4.2 ADT 7 TBH 181.9 TJH
Notes: Hold ~500psi W/MPD to maintain
13 ppge mw during connections. Drilling
with 9 7/8" UR open.
13,671.0 14,298.0
9/19/2023
00:00
9/19/2023
06:00
6.00 INTRM2, DRILL DDRL P Drill Int2 f/14,298' t/14,790'
640 GPM 3810 PSI 161 RPM
20K TQ 10k WOB 13 ECD
186 RTW F/O 30%
4.0 ADT 11 TBH 185.9 TJH
Notes: Hold ~500psi W/MPD to maintain
13 ppge mw during connections. Drilling
with 9 7/8" UR open.
14,298.0 14,790.0
9/19/2023
06:00
9/19/2023
16:30
10.50 INTRM2, DRILL DDRL P Drill Int2 f/14,790' t/15,527'
640 GPM 3810 PSI 161 RPM
20K TQ 10k WOB 12.9 ECD
186 RTW F/O 3%
8.6 ADT 19.6 TBH 1194.5 TJH
Notes: Hold ~500psi W/MPD to maintain
12.9 ppge mw during connections.
Drilling with 9 7/8" UR open. Slow ROP
last couple stands and pump
background LCM
14,790.0 15,527.0
9/19/2023
16:30
9/19/2023
17:30
1.00 INTRM2, TRIPCAS CIRC P Circulate and condition mud - Pump
hole volume before closing UR @
15,512'
660 GPM 3350PSI 140 RPM 20K
TQ
12.7 ECD F/O 35%
Notes: Obtain final survey at TD,
Downlink tools,
15,512.0 15,512.0
9/19/2023
17:30
9/19/2023
19:00
1.50 INTRM2, TRIPCAS UREM P Function UR closed per Directinal Driller
@ 15,512'
- Drop 1.75 torlon ball and pump down
W/250 GPM, 1600 PSI, for 1600 STKS
- Slow pump 100 GPM, 640 PSI last
~1000 STKS
- Ball on seat at 2738 STKS
- Pressure up to 1720 PSI
- Confirm UR closed - ~300 PSI and 600
TRPM increase - Confirmed
15,512.0 15,512.0
9/19/2023
19:00
9/19/2023
21:30
2.50 INTRM2, TRIPCAS CIRC P Circulate and condition mud for SOOH
@ 15512'
640 GPM 3900 PSI 120 RPM 17K
TQ
12.8 ECD F/O 30%
Notes: Circulate 2.5 BU, Hole appeares
to be clean. No pressure or tq spikes
observed. OWFF with ~490psi for a12.7
ppge for 10 minutes. No pressure build.
Well is static,
15,512.0 15,512.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 29/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/19/2023
21:30
9/20/2023
00:00
2.50 INTRM2, TRIPCAS SMPD P SOOH f/15,512' t/ 13,546'
Notes: No overpulls observed while
SOOH. Maintain 12.7 ppge per MPD
schedule
15,512.0 13,546.0
9/20/2023
00:00
9/20/2023
01:00
1.00 INTRM2, TRIPCAS CIRC P Circulate hole clean f/ shoe. Rotate and
reciprocate pipe.
650 GPM
3790 PSI
60 RPM
10-13k TQ
12.8ppg ECD
219k PU
167k SO
182k ROT
13,546.0 13,546.0
9/20/2023
01:00
9/20/2023
02:00
1.00 INTRM2, TRIPCAS OWFF P Flow check. Initial 1.27 BPH. After 15
minutes .5 BPH.
13,546.0 13,546.0
9/20/2023
02:00
9/20/2023
13:30
11.50 INTRM2, TRIPCAS SMPD P SOOH f/ 13546' to 660'. Holding
12.7ppg EMW w/ MPD.
Note: Dropped 2.40" hollow drift on std
#135.
13,546.0 660.0
9/20/2023
13:30
9/20/2023
14:00
0.50 INTRM2, TRIPCAS MPDA P Retrieve RCD bearing assembly and
install trip nipple.
660.0 660.0
9/20/2023
14:00
9/20/2023
14:30
0.50 INTRM2, TRIPCAS OWFF P Flow check. Static. 660.0 660.0
9/20/2023
14:30
9/20/2023
16:30
2.00 INTRM2, TRIPCAS BHAH P LD BHA. 660.0 0.0
9/20/2023
16:30
9/20/2023
17:30
1.00 INTRM2, CASING CLEN P Clean and clear rig floor 0.0 0.0
9/20/2023
17:30
9/20/2023
19:00
1.50 INTRM2, CASING RURD P RU to run liner. 0.0 0.0
9/20/2023
19:00
9/21/2023
00:00
5.00 INTRM2, CASING PUTB P MU shoetrack. Threadlock connections.
Pumped through shoetrack w/ 10 bbls
and check floats. Ok. RIH w/ 7" liner.
Note:
Joints 1-23 - 7" 29# TN110Cr13S Hyd
563
Joints 24-50 - 7" 29# L-80 Hyd 563
MU torque- 13.2k ft/lbs. Torque turn
connections.
0.0 1,659.0
9/21/2023
00:00
9/21/2023
00:45
0.75 INTRM2, CASING PUTB P RIH w/ 7" liner f/ 1659' to 2138'
Note:
Joints 1-23 - 7" 29# TN110Cr13S Hyd
563
Joints 24-50 - 7" 29# L-80 Hyd 563
MU torque- 13.2k ft/lbs. Torque turn
connections.
1,659.0 2,138.0
9/21/2023
00:45
9/21/2023
01:15
0.50 INTRM2, CASING PUTB P PU and MU liner hanger as per Baker.
Fill w/ ZanPlex
2,138.0 2,230.0
9/21/2023
01:15
9/21/2023
02:00
0.75 INTRM2, CASING CIRC P Break circulation and stage up rate to 6
BPM
6 BPM
290 PSI
2,230.0 2,230.0
9/21/2023
02:00
9/21/2023
02:30
0.50 INTRM2, CASING RGRP T Washpipe leaking SD and change
packing.
2,230.0 2,230.0
9/21/2023
02:30
9/21/2023
03:00
0.50 INTRM2, CASING CIRC P Finish circulating liner volume. 2,230.0 2,230.0
9/21/2023
03:00
9/21/2023
03:30
0.50 INTRM2, CASING MPDA P Retrieve trip nipple and install RCD
bearing assembly.
2,230.0 2,245.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 30/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/21/2023
03:30
9/21/2023
12:30
9.00 INTRM2, CASING RUNL P SIH w/ liner on DP. Holding 12.7ppg
EMW w/ MPD.
2,245.0 13,545.0
9/21/2023
12:30
9/21/2023
13:00
0.50 INTRM2, CASING CIRC P Circulate pipe volume at shoe. Take
parameters.
232k PU
137k SO
180k ROT
13,545.0 13,545.0
9/21/2023
13:00
9/21/2023
15:00
2.00 INTRM2, CASING RUNL P SIH w/ liner on DP f/ 13545 to 15500.
Holding 12.7ppg EMW.
13,545.0 15,500.0
9/21/2023
15:00
9/21/2023
15:30
0.50 INTRM2, CASING RURD P MU cement swivel and cement line. 15,500.0 15,500.0
9/21/2023
15:30
9/21/2023
16:30
1.00 INTRM2, CASING REAM P Ream to bottom.
84 GPM
930 PSI
20 RPM
18k TQ
195k ROT
15,500.0 15,527.0
9/21/2023
16:30
9/21/2023
19:00
2.50 INTRM2, CEMENT CIRC P Tag bottom. PU 1 ft. Stage rate to 6
BPM and circulate BU. Held PJSM f/
cement job while circulating.
252 GPM
885 PSI
Note: Shoe depth 15526'
15,527.0 15,526.0
9/21/2023
19:00
9/21/2023
21:30
2.50 INTRM2, CEMENT CMNT P Flood lines and test to 4700 PSI. Pump
70BBLS of 8.9ppg KCL Chem Wash.
126 GPM/715 PSI. Drop bottom dart.
Swap to cementers. Pump 77.2 BBLS of
15.8ppg cement @ 4-4.5 BPM. SD and
drop top dart. Pump 10 BBLS FW w/
cement unit. Swap to rig pumps and
displace at 6 BPM 600-850 PSI. Slow
rate to 3 BPM and bump plug. Pressure
up to 500 PSI over FCP to 1000 PSI.
Hold f/ 5 minutes and check floats.
Good. 1.3 BBLs bled back. Full returns
throughout job. No losses. Cement in
place @ 21:30hrs 9/21/23
15,526.0 15,526.0
9/21/2023
21:30
9/22/2023
00:00
2.50 INTRM2, CEMENT PACK P Set liner hanger and packer as per
Baker rep. RU and test liner top packer
to 1000 PSI f/ 10 minutes. Good test.
15,526.0 15,526.0
9/22/2023
00:00
9/22/2023
02:15
2.25 INTRM2, CEMENT CIRC P Circulate and clean up TOL. LD cement
swivel. Install wiper ball.Stage rates up
to 630 GPM. Circulate BU. (200bbls
interface)
15,526.0 13,328.0
9/22/2023
02:15
9/22/2023
03:15
1.00 INTRM2, CEMENT SLPC P Slip/Cut drilling line. 13,328.0 13,328.0
9/22/2023
03:15
9/22/2023
04:00
0.75 INTRM2, CEMENT MPDA P Retrieve RCD bearing asembly. Install
trip nipple.
13,328.0 13,290.0
9/22/2023
04:00
9/22/2023
12:00
8.00 INTRM2, CEMENT TRIP P Pump slug. POOH culling DP (worn
hardbanding) to 35'.
13,290.0 35.0
9/22/2023
12:00
9/22/2023
13:00
1.00 INTRM2, CEMENT PULD P LD running tool. 35.0 0.0
9/22/2023
13:00
9/22/2023
13:30
0.50 INTRM2, WHDBOP RURD P Retrieve wear bushing. 0.0 0.0
9/22/2023
13:30
9/22/2023
14:30
1.00 INTRM2, WHDBOP CIRC P MU jetting tool and jet stack. 0.0 0.0
9/22/2023
14:30
9/22/2023
15:30
1.00 INTRM2, WHDBOP RURD P Pull 5" RCD bearing assembly off of pup
joint. Swap out UPR to 2 7/8" x 5 1/2"
VBR.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 31/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/22/2023
15:30
9/22/2023
20:30
5.00 INTRM2, WHDBOP BOPE P RU test equipment. Test annular/UPR
and LPR w/ 4" test joint. Test UPR and
LPR w/ 5.5" test joint. All tests 250/3500
PSI. 5/10 min ea.RD test equipment.
0.0 0.0
9/22/2023
20:30
9/22/2023
21:00
0.50 INTRM2, WHDBOP RURD P Install 8.75" wear bushing. 0.0 0.0
9/22/2023
21:00
9/22/2023
22:30
1.50 INTRM2, WHDBOP PRTS P Test casing to 3500 PSI. for 30 minutes.
Good test.
0.0 0.0
9/22/2023
22:30
9/23/2023
00:00
1.50 INTRM2, DRILLOUT BHAH P MU and RIH w/ production BHA. 0.0 100.0
9/23/2023
00:00
9/23/2023
01:45
1.75 INTRM2, DRILLOUT BHAH P MU and RIH w/ 6 5/16" x 6 1/8"
production BHA to 239'
100.0 239.0
9/23/2023
01:45
9/23/2023
06:00
4.25 INTRM2, DRILLOUT PULD P RIH w/ BHA f/ 239' to 6000' on 4" DP
picking up doubles out of pipe shed.
239.0 6,000.0
9/23/2023
06:00
9/23/2023
10:15
4.25 INTRM2, DRILLOUT PULD P RIH logging at 1800 ft/hr w/ BHA f/6000'
to 8500' on 4" DP picking up doubles
out of pipe shed.
6,000.0 8,500.0
9/23/2023
10:15
9/23/2023
15:00
4.75 INTRM2, DRILLOUT PULD P RIH logging at 4600 ft/hr w/ BHA f/8500'
to 13300' on 4" DP picking up doubles
out of pipe shed.
8,500.0 13,300.0
9/23/2023
15:00
9/23/2023
17:00
2.00 INTRM2, DRILLOUT PULD P RIH logging at 1800 ft/hr w/ BHA
f/13300' to 15285' on 4" DP.
13,300.0 15,285.0
9/23/2023
17:00
9/23/2023
21:30
4.50 INTRM2, DRILLOUT DRLG P Wash/ream down f/ 15285' to 15324'.
Tag cement stringer. Drillout
plugs/landing collar @ 15435'.
200 GPM
1950 PSI
60 RPM
12k TQ
15,285.0 15,435.0
9/23/2023
21:30
9/23/2023
22:30
1.00 INTRM2, DRILLOUT CIRC T Tools turned off. Cycle pumps. Perform
hard reset. No success. Troubleshoot
15,435.0 15,435.0
9/23/2023
22:30
9/24/2023
00:00
1.50 INTRM2, DRILLOUT DRLG P Tools still not powering on. Drill
shoetrack and float collar to 15500'
15,435.0 15,500.0
9/24/2023
00:00
9/24/2023
00:30
0.50 INTRM2, DRILLOUT DRLG P Drill FC and shoetrack to 15520'. (5'
above FS).
15,500.0 15,520.0
9/24/2023
00:30
9/24/2023
05:30
5.00 INTRM2, DRILLOUT CIRC P Pump 40bbl LVT spacer + 100bbl
12.5ppg transition spacer + 100bbls
cleaning spacer + 50bbls 8.8 viscosified
tail spacer. Displace w/ 8.8ppg FloPro.
15,520.0 15,520.0
9/24/2023
05:30
9/24/2023
08:00
2.50 INTRM2, DRILLOUT CLEN P Clean shakers/Trough/flowline and flow
box.
15,520.0 15,520.0
9/24/2023
08:00
9/24/2023
09:00
1.00 INTRM2, DRILLOUT CIRC P Take SPRs. Troubleshoot bulk hopper. 15,520.0 15,520.0
9/24/2023
09:00
9/24/2023
20:30
11.50 INTRM2, DRILLOUT TRIP T POOH f/ 15520' to 540'. Several tight
connections.
15,520.0 540.0
9/24/2023
20:30
9/25/2023
00:00
3.50 INTRM2, DRILLOUT BHAH T PJSM. LD BHA. Plug in and diagnose
communication issue.
540.0 0.0
9/25/2023
00:00
9/25/2023
01:45
1.75 INTRM2, DRILLOUT BHAH T MU and RIH w/ 6 5/16" x 6 1/8" BHA. 0.0 237.0
9/25/2023
01:45
9/25/2023
12:00
10.25 INTRM2, DRILLOUT TRIP T RIH w/ 6 5/16" x 6 1/8" production BHA
f/ 237' to 14899'. PU dobles from pipe
shed and stds out of derrick. Shallow
est on first fill up. Good test.
237.0 14,899.0
9/25/2023
12:00
9/25/2023
13:45
1.75 INTRM2, DRILLOUT WASH T RIH f/ 14899'. Tag obstruction at 14940'.
Wash down f/ 14940' to 15187'.
RIH on elevators 15187' to 15465'.
14,899.0 15,465.0
9/25/2023
13:45
9/25/2023
15:00
1.25 INTRM2, DRILLOUT SLPC T Slip/Cut drill line. 15,465.0 15,465.0
9/25/2023
15:00
9/25/2023
16:00
1.00 INTRM2, DRILLOUT SFTY P Perform choke drill with rig crew. 15,465.0 15,465.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 32/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/25/2023
16:00
9/25/2023
16:30
0.50 INTRM2, DRILLOUT WASH P Wash down and tag cement at 15523'.
212 GPM
1020 PSI
50 RPM
18k TQ
15,465.0 15,523.0
9/25/2023
16:30
9/25/2023
18:00
1.50 INTRM2, DRILLOUT DRLG P Drill out cement and FS to 15527'.
212 GPM
1020 PSI
60 RPM
20k TQ
8k WOB
15,523.0 15,527.0
9/25/2023
18:00
9/25/2023
18:30
0.50 INTRM2, DRILLOUT DDRL P Drill 15527' to 15535'. Torque up and
stalling 24k TQ @ 15535'. 20-30k
Overpull
6k WOB
212 GPM
1020 PSI
60 RPM
21k TQ
15,527.0 15,535.0
9/25/2023
18:30
9/25/2023
20:00
1.50 INTRM2, DRILLOUT CIRC T Work pipe. 20-30k overpull and up to
24k torque. No pressure increases
observed. Mousehole stand and work
pipe to free obstruction. Ream back to
15535'.
15,535.0 15,535.0
9/25/2023
20:00
9/25/2023
20:30
0.50 INTRM2, DRILLOUT DDRL P Drill 15535' to 15547'.
6k WOB
212 GPM
1020 PSI
60 RPM
21k TQ
15,535.0 15,547.0
9/25/2023
20:30
9/25/2023
21:00
0.50 INTRM2, DRILLOUT CIRC P Circulate and backream up into casing
to 15472'.
15,547.0 15,472.0
9/25/2023
21:00
9/25/2023
22:30
1.50 INTRM2, DRILLOUT FIT P RU test equipment. Perform FIT to
12.0ppg EMW. RD test equipment.
15,472.0 15,472.0
9/25/2023
22:30
9/26/2023
00:00
1.50 PROD1, DRILL MPDA P Retrieve trip nipple and install 4" RCD
bearing assembly. Break in bearing.
Take SPRs.
15,472.0 15,472.0
9/26/2023
00:00
9/26/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 15547' MD to 16039' MD / 8201' TVD.
Closing chokes on connections. 0 PSI
build up.
14k WOB
240 GPM
1310 PSI
100 RPM
19k TQ on bttm
19k TQ off bttm
9.3ppg ECD
700 units Max gas @ 15972'
15,472.0 16,039.0
9/26/2023
06:00
9/26/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 16039' MD to 16566' MD / 8232' TVD.
Closing chokes on connections. 0 PSI
build up.
20k WOB
240 GPM
1350 PSI
120 RPM
12k TQ on bttm
9.4ppg ECD
600 units Max gas @ 16255'
16,039.0 16,566.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 33/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/26/2023
12:00
9/26/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 16566' MD to 17268' MD / 8232' TVD.
Closing chokes on connections. 0 PSI
build up.
12k WOB
240 GPM
1430 PSI
120 RPM
12k TQ on bttm
9.5ppg ECD
450 units Max gas @ 16620'
16,566.0 17,268.0
9/26/2023
18:00
9/27/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 17268' MD to 18000' MD / 8186' TVD.
Closing chokes on connections. 0 PSI
build up.
12k WOB
240 GPM
1550 PSI
120 RPM
12k TQ
9.5ppg ECD
192k PU
113k SO
149k ROT
1121 units Max gas @ 17950'
17,268.0 18,000.0
9/27/2023
00:00
9/27/2023
00:45
0.75 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 18000' MD to 18050' MD / 8188' TVD.
Closing chokes on connections. 0 PSI
build up.
12k WOB
240 GPM
1550 PSI
120 RPM
12k TQ
9.5ppg ECD
192k PU
113k SO
150k ROT
units Max gas @ 17950'
18,000.0 18,050.0
9/27/2023
00:45
9/27/2023
02:00
1.25 PROD1, DRILL MPDA P Swap RCD bearing f/ 4" to 5" 18,050.0 18,050.0
9/27/2023
02:00
9/27/2023
12:00
10.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 18050' MD to 19161' MD / 8199' TVD.
Closing chokes on connections. 0 PSI
build up.
11k WOB
240 GPM
1560 PSI
120 RPM
13k TQ
9.6ppg ECD
196k PU
122k SO
155k ROT
1728units Max gas @ 19106'
18,000.0 19,161.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 34/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/27/2023
12:00
9/27/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 19161' MD to 19822' MD / 8198' TVD.
Closing chokes on connections. 0 PSI
build up.
11k WOB
240 GPM
1580 PSI
120 RPM
11k TQ
9.6ppg ECD
203k PU
119k SO
169k ROT
units Max gas @ '
19,161.0 19,822.0
9/27/2023
18:00
9/28/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 19822' MD to 20575' MD / 8205' TVD.
Closing chokes on connections. 0 PSI
build up.
14k WOB
240 GPM
1580 PSI
120 RPM
16k TQ
9.7ppg ECD
209k PU
124k SO
168k ROT
240units Max gas @ 20457'
19,161.0 20,575.0
9/28/2023
00:00
9/28/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 20575' MD to 21234' MD / 8195' TVD.
Closing chokes on connections. 0 PSI
build up.
10k WOB
240 GPM
1640 PSI
120 RPM
19k TQ
9.7ppg ECD
212k PU
120k SO
158k ROT
904units Max gas @ 21250'
20,575.0 21,234.0
9/28/2023
06:00
9/28/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 21234' MD to 21895' MD / 8189' TVD.
Closing chokes on connections. 0 PSI
build up.
12k WOB
240 GPM
1580 PSI
120 RPM
19k TQ
9.7ppg ECD
215k PU
123k SO
165k ROT
904units Max gas @ 21250'
21,234.0 21,895.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 35/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/28/2023
12:00
9/28/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 21895' MD to 22595' MD / 8192' TVD.
Closing chokes on connections. 0 PSI
build up.
14k WOB
240 GPM
1580 PSI
120 RPM
16k TQ
9.7ppg ECD
206k PU
122k SO
164k ROT
1285units Max gas @ 22545'
21,234.0 21,895.0
9/28/2023
18:00
9/29/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 22595' MD to 23308' MD / 8186' TVD.
Closing chokes on connections. 0 PSI
build up.
12k WOB
240 GPM
1660 PSI
100 RPM
21k TQ
9.8ppg ECD
221k PU
120k SO
163k ROT
21,895.0 23,308.0
9/29/2023
00:00
9/29/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 23308' MD to 24061' MD / 8186' TVD.
Closing chokes on connections. 0 PSI
build up.
14k WOB
240 GPM
1700 PSI
120 RPM
24k TQ
9.8ppg ECD
233k PU
k SO
171k ROT
23,308.0 24,061.0
9/29/2023
06:00
9/29/2023
13:00
7.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 24061' MD to 24785' MD / 8167' TVD.
Closing chokes on connections. 0 PSI
build up.
14k WOB
240 GPM
1740 PSI
140 RPM
26k TQ
9.8ppg ECD
230k PU
k SO
171k ROT
24,061.0 24,785.0
9/29/2023
13:00
9/29/2023
17:00
4.00 PROD1, DRILL CIRC T Observed flow increase. SD and flow
check. Stsatic. Bring pumps back on
and observed 700PSI decrease in pump
pressure. Troubleshoot all surface
equipment. No issues. No
communication with DH tools.
24,785.0 24,785.0
9/29/2023
17:00
9/29/2023
17:30
0.50 PROD1, DRILL OWFF T Flow check. Static. Prep to SOOH. 24,785.0 24,785.0
9/29/2023
17:30
9/30/2023
00:00
6.50 PROD1, DRILL SMPD T SOOH f/ 24785' to 21331'. 24,785.0 21,331.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 36/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
9/30/2023
00:00
9/30/2023
04:30
4.50 PROD1, DRILL SMPD T SOOH f/ 21331' to 18047'. 21,331.0 18,047.0
9/30/2023
04:30
9/30/2023
05:15
0.75 PROD1, DRILL SMPD T Flow check. Slight loss. Swap RCD
bearing assembly 5" to 4".
18,047.0 18,047.0
9/30/2023
05:15
9/30/2023
09:15
4.00 PROD1, DRILL SMPD T SOOH f/ 18047' to 15469'. 18,047.0 15,469.0
9/30/2023
09:15
9/30/2023
09:30
0.25 PROD1, DRILL OWFF T Flow check. Static 15,469.0 15,469.0
9/30/2023
09:30
9/30/2023
12:30
3.00 PROD1, DRILL SMPD T SOOH f/ 15469' to 13303'. 15,469.0 13,303.0
9/30/2023
12:30
9/30/2023
13:30
1.00 PROD1, DRILL MPDA T Flow check. Static. Retrieve RCD
bearing assembly and install trip nipple.
13,303.0 13,303.0
9/30/2023
13:30
9/30/2023
19:00
5.50 PROD1, DRILL TRIP T SOOH f/ 13303' to 6483'. 13,303.0 6,483.0
9/30/2023
19:00
9/30/2023
23:30
4.50 PROD1, DRILL PULD T POOH f/ 6483' to 3645' LD doubles to
pipe shed.
6,483.0 3,645.0
9/30/2023
23:30
10/1/2023
00:00
0.50 PROD1, DRILL SVRG T Service rig. Inspect TD. 3,645.0 3,645.0
10/1/2023
00:00
10/1/2023
04:30
4.50 PROD1, DRILL TRIP T POOH f 3645' to 237'. LD doubles to
pipeshed. Found washout on Std #31
3,645.0 237.0
10/1/2023
04:30
10/1/2023
04:45
0.25 PROD1, DRILL OWFF T Flow check. Static/slight loss. 237.0 237.0
10/1/2023
04:45
10/1/2023
07:30
2.75 PROD1, DRILL BHAH T LD BHA. 237.0 0.0
10/1/2023
07:30
10/1/2023
08:00
0.50 PROD1, DRILL CLEN T Clean and clear rig floor. Retrieve wear
bushing.
237.0 0.0
10/1/2023
08:00
10/1/2023
15:00
7.00 PROD1, DRILL RGRP T Change out Annular element. Monitor
hole with injection line.
0.0 0.0
10/1/2023
15:00
10/1/2023
20:00
5.00 PROD1, DRILL MPDA T RU MPD and lines. Test to 250/1800
PSI f/ 5 min each. Good test.
0.0 0.0
10/1/2023
20:00
10/2/2023
00:00
4.00 PROD1, DRILL BOPE T Test BOPE to 250/3500 PSI for 5/10 min
ea. 4" Test joint- annular/UPR/C/M
valves 1,2 & 5-15. UPR/LWR IBOP/5"
Dart valve/#1 FOSV/Manual/HCR kill/ 4"
kill on floor. Test PVT gain/loss and flow
out alarms. Tets LEL and H2S alarms.
BLM waived witness 9/29/2023 @ 19:42
hrs. per email by Allie Schoessler
0.0 0.0
10/2/2023
00:00
10/2/2023
04:30
4.50 PROD1, DRILL BOPE T Test BOPE to 250/3500 PSI for 5/10 min
ea. 4" Test joint- LPR. 5.5" test joint -
Annular/UPR/LPR/Remaining choke
valves/Manual and super choke/Manual
kills and HCRs/4" FOSV #1 & #2/5"
FOSV #1 & #@/ 5" Dart valve/
Blind/Shear rams.
Perform KOOMEY drawdown, ACC =
3050 PSI. MANIF. = 1500 PSI. ACC =
1600 PSI After all functions on bottles,
14 sec for 200 psi. Build W/ 2 Elec.
pumps, 112 sec T/ Build full system.
Pressure W/ 2 Elec. & 2 Air pumps,
Closing times, Annular = 28 sec. UPR =
14 sec. Blind / Shears = 14 sec. LPR =
14 sec. Choke HCR = 2 sec. Kill HCR =
2 sec;
BLM waived witness 9/29/2023 @ 19:42
hrs. per email by Allie Schoessler
0.0 0.0
10/2/2023
04:30
10/2/2023
06:30
2.00 PROD1, DRILL RURD T RD test equipment. Drain stack and pull
test plug. Instal 8.75" wear bushing.
Stage BHA to rig floor.
0.0 0.0
10/2/2023
06:30
10/2/2023
12:00
5.50 PROD1, DRILL BHAH T MU and RIH w/ 6 5/16" x 6 1/8"
production BHA.
0.0 238.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 37/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/2/2023
12:00
10/2/2023
16:30
4.50 PROD1, DRILL TRIP T RIH w/ BHA f/ 238' to 2700' w/ doubles
from pipeshed. Culling bad joints as
needed.
238.0 2,700.0
10/2/2023
16:30
10/2/2023
17:00
0.50 PROD1, DRILL CIRC T Perform shallow test. Good. 2,700.0 2,700.0
10/2/2023
17:00
10/2/2023
23:30
6.50 PROD1, DRILL TRIP T RIH w/ BHA f/ 2700' to 6484' w/ doubles
from pipeshed. Culling bad joints as
needed.
2,700.0 6,484.0
10/2/2023
23:30
10/3/2023
00:00
0.50 PROD1, DRILL TRIP T RIH w/ BHA f/ 6484' to 6865'. 6,484.0 6,865.0
10/3/2023
00:00
10/3/2023
06:45
6.75 PROD1, DRILL TRIP T F/6,868' MD T/15,286'MD RIH W/4" DP
out of derrick, inspecting hard bands &
checking connection TQ. every 10
STDS, Fill pipe every 25 STDS, 173K
PUW 133K SOW,
6,865.0 15,286.0
10/3/2023
06:45
10/3/2023
07:45
1.00 PROD1, DRILL TRIP T Cut & Slip 95' Drill line 15,286.0 15,286.0
10/3/2023
07:45
10/3/2023
08:00
0.25 PROD1, DRILL TRIP T Calibrate Amphion Block Height, Hook
Load, Set COM
15,286.0 15,286.0
10/3/2023
08:00
10/3/2023
10:15
2.25 PROD1, DRILL TRIP T F/15,286'MD T/18,029'MD RIH W/4" DP
out of Derrick, Inspecting Hard Bands,
Fill Pipe Every 25 STDs, 173K PUW
133K SOW,
15,286.0 18,029.0
10/3/2023
10:15
10/3/2023
11:15
1.00 PROD1, DRILL TRIP T Retrieve trip nipple & Install 5" RCD
Element as Per Beyond Rep, Line up
pump across top of hole
18,029.0 18,029.0
10/3/2023
11:15
10/3/2023
18:30
7.25 PROD1, DRILL TRIP T RIH W/5" DP f/ 18029' to 24540' out of
derrick, inspectiong hard bands, fill pipe
every 25 Stds.
18,029.0 24,540.0
10/3/2023
18:30
10/3/2023
20:00
1.50 PROD1, DRILL WASH T Wash down f/ 24540' to 24785'.
240 GPM
1700PSI
24,540.0 24,785.0
10/3/2023
20:00
10/4/2023
00:00
4.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 24785' MD to 25197' MD / 8157' TVD.
Closing chokes on connections. 0 PSI
build up. (Observed losses @ 25048'.
Start adding background LCM).
8-17k WOB-240 GPM
1700 PSI
100 RPM
18k TQ
9.9ppg ECD
230k PU
k SO
170k ROT
24,785.0 25,197.0
10/4/2023
00:00
10/4/2023
01:00
1.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 25197' MD to 25295' MD / 8157' TVD.
(Pump 80 BBLS of 35ppb LCM pill while
drilling std down)
17k WOB
240 GPM
1468 PSI
100 RPM
18k TQ
9.8ppg ECD
230k PU
k SO
170k ROT
25,197.0 25,295.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 38/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/4/2023
01:00
10/4/2023
02:30
1.50 PROD1, DRILL CIRC T Slow pump rate to turn off smart tools
while LCM passes through BHA.
90 GPM
615 PSI
80 RPM
14k TQ
133 BPH loss rate.
25,295.0 25,295.0
10/4/2023
02:30
10/4/2023
04:30
2.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 25295' MD to 25478' MD / 8157' TVD.
(Pump 90 BBLS of 35ppb LCM pill while
drilling 2nd std down)
17k WOB
240 GPM
1468 PSI
100 RPM
18k TQ
9.8ppg ECD
230k PU
k SO
170k ROT
25,295.0 25,478.0
10/4/2023
04:30
10/4/2023
06:30
2.00 PROD1, DRILL CIRC T Slow pump rate to turn off smart tools
while LCM passes through BHA.
90 GPM
615 PSI
80 RPM
14k TQ
133 BPH loss rate.
25,478.0 25,478.0
10/4/2023
06:30
10/4/2023
08:00
1.50 PROD1, DRILL CIRC T Drop well commander opening ball and
pump down. Opened at 1866 PSI.
25,478.0 25,478.0
10/4/2023
08:00
10/4/2023
12:00
4.00 PROD1, DRILL CIRC T Drop well commander isolation ball and
pump down. At 2500 stks pumped 100
BBLs of 115 ppb LCM pill. chase with
15 BBLs FW.
205 GPM
900 PSI
10 RPM
12k TQ
112 BPH loss rate.
25,478.0 25,478.0
10/4/2023
12:00
10/4/2023
14:30
2.50 PROD1, DRILL SMPD T SOOH f/ 25478' to 24066'. Using MPD
to overcome swab (80PSI).
25,478.0 24,066.0
10/4/2023
14:30
10/4/2023
15:30
1.00 PROD1, DRILL CIRC T Drop 1.75" closing ball and close well
commander. Shifted at 1620 PSI. Stage
up to drilling rate. Losses 75-100 BPH.
24,066.0 24,066.0
10/4/2023
15:30
10/4/2023
20:00
4.50 PROD1, DRILL CIRC T Wash/ream back to bottom.
200 GPM
1380 PSI
80 RPM
14k TQ
24,066.0 25,478.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 39/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/4/2023
20:00
10/5/2023
00:00
4.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 25478' MD to 25856' MD / 8141' TVD.
Monitoring losses. Adding background
LCM. (Closing choke on connections 0-
40PSI buildup).
12k WOB
200 GPM
1500 PSI
100 RPM
19k TQ
9.9ppg ECD
250k PU
188k ROT
90-120 BPH losses
25,478.0 25,856.0
10/5/2023
00:00
10/5/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 25856' MD to 26464' MD / 8121' TVD.
Monitoring losses. Adding background
LCM. (Closing choke on connections 0-
30PSI buildup).
12k WOB
200 GPM
1546 PSI
120 RPM
21k TQ
10.1ppg ECD
238k PU
180k ROT
100 BPH losses
25,856.0 26,464.0
10/5/2023
06:00
10/5/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6 5 1/6" x 6 1/8" production section
f/ 26464' MD to 26989' MD / 8118' TVD.
TD section. Monitoring losses. (Closing
choke on connections 0-10PSI buildup).
12k WOB
200 GPM
1500 PSI
100 RPM
21k TQ
10.1ppg ECD
250k PU
188k ROT
100 BPH losses
26,464.0 26,989.0
10/5/2023
12:00
10/5/2023
20:00
8.00 PROD1, TRIPCAS CIRC P Circulate BU x 2 reciprocating DS.
Pumped 80 bbls of 35ppb LCM pill.
200 GPM
80 RPM
15k TQ
26,989.0 26,989.0
10/5/2023
20:00
10/5/2023
20:30
0.50 PROD1, TRIPCAS OWFF P Attempt to fingerprint well. No pressure
buildup. Flow check. 12 BPH loss rate.
26,989.0 26,989.0
10/5/2023
20:30
10/6/2023
00:00
3.50 PROD1, TRIPCAS CIRC P Circulate hole clean. Rack back std
every 2 BU.
190 GPM
1350 PSI
100 RPM
15k TQ
26,989.0 26,989.0
10/6/2023
00:00
10/6/2023
11:00
11.00 PROD1, TRIPCAS CIRC P Circulate hole clean. Rack back std
every 2 BU.
190 GPM
1350 PSI
100 RPM
15k TQ
26,989.0 26,989.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 40/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/6/2023
11:00
10/6/2023
19:00
8.00 PROD1, TRIPCAS DISP P Pump 80 bbls Hi Vis spacer. Displace to
8.8ppg Vis Brine.
180 GPM
1010 PSI
110 RPM
15k TQ
26,989.0 26,989.0
10/6/2023
19:00
10/6/2023
20:00
1.00 PROD1, TRIPCAS OWFF P Flow check. Slight losses. Static loss
rate 12 BPH.
26,989.0 26,989.0
10/6/2023
20:00
10/7/2023
00:00
4.00 PROD1, TRIPCAS SMPD P SOOH f/ 26989' to 24300'. Using MPD
to overcome swab.
26,989.0 24,300.0
10/7/2023
00:00
10/7/2023
07:30
7.50 PROD1, TRIPCAS SMPD P SOOH to 4" DP to 18020'. Using MPD
to overcome swab.
24,300.0 18,020.0
10/7/2023
07:30
10/7/2023
08:15
0.75 PROD1, TRIPCAS MPDA P Flow check. Retrieve 5" RCD bearing
assembly and Install 4" RCD bearing
assembly.
18,020.0 18,020.0
10/7/2023
08:15
10/7/2023
11:30
3.25 PROD1, TRIPCAS SMPD P SOOH to shoe @ 15526. Using MPD to
overcome swab.
18,020.0 15,526.0
10/7/2023
11:30
10/7/2023
13:30
2.00 PROD1, TRIPCAS CIRC P Flow check. Circulate liner volume. Drop
WC opening ball.
15,500.0 15,500.0
10/7/2023
13:30
10/7/2023
14:00
0.50 PROD1, TRIPCAS SVRG P Service rig. 15,500.0 15,500.0
10/7/2023
14:00
10/7/2023
19:00
5.00 PROD1, TRIPCAS SMPD P SOOH. LD 4" DP to 13533'. 15,500.0 13,533.0
10/7/2023
19:00
10/7/2023
20:00
1.00 PROD1, TRIPCAS MPDA P Flow check. Retrieve 5" RCD bearing
assembly and install trip nipple
13,533.0 13,533.0
10/7/2023
20:00
10/7/2023
22:30
2.50 PROD1, TRIPCAS CIRC P Open well commander. Circulate hole
clean. Drop WC closing ball.
13,533.0 13,533.0
10/7/2023
22:30
10/7/2023
23:30
1.00 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 13533' to 13022'. 13,533.0 13,022.0
10/7/2023
23:30
10/8/2023
00:00
0.50 PROD1, TRIPCAS CIRC P Close WC. Pump slug. 13,022.0 13,022.0
10/8/2023
00:00
10/8/2023
04:00
4.00 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 13022' to 10421'. 13,022.0 10,421.0
10/8/2023
04:00
10/8/2023
04:30
0.50 PROD1, TRIPCAS SVRG P Service rig. 10,421.0 10,421.0
10/8/2023
04:30
10/8/2023
05:00
0.50 PROD1, TRIPCAS RGRP T Repair hydraulic hose on pipe skate. 10,421.0 10,421.0
10/8/2023
05:00
10/8/2023
13:00
8.00 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 10421' to 4400'. 10,421.0 4,400.0
10/8/2023
13:00
10/8/2023
18:00
5.00 PROD1, TRIPCAS SLPC P Strip RCD bearings off of 5" and 4" DP.
MU side entry assembly. Slip/Cut drill
line.
SimOPs: Replace motor on pipe skate.
4,400.0 4,400.0
10/8/2023
18:00
10/9/2023
00:00
6.00 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 4400' to 1200'. 4,400.0 1,200.0
10/9/2023
00:00
10/9/2023
02:30
2.50 PROD1, TRIPCAS PULD P POOH LD 4" DP f/ 1200' to 238'. 1,200.0 238.0
10/9/2023
02:30
10/9/2023
04:30
2.00 PROD1, TRIPCAS BHAH P Flow check. LD BHA. 238.0 0.0
10/9/2023
04:30
10/9/2023
05:30
1.00 COMPZN, CASING CLEN P Clean and clear rig floor. 0.0 0.0
10/9/2023
05:30
10/9/2023
06:00
0.50 COMPZN, CASING RURD P RU to run lower completion. 0.0 0.0
10/9/2023
06:00
10/9/2023
17:30
11.50 COMPZN, CASING PUTB P PU shoe track. Visually inspect. RIH w/
4 1/2" L-80 12.6 # H563 liner to 11601'.
MU TQ - 5600 ft/lbs.
0.0 11,601.0
10/9/2023
17:30
10/9/2023
18:15
0.75 COMPZN, CASING PUTB P MU liner hanger/packer and RIH. 11,601.0 11,642.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 41/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/9/2023
18:15
10/10/2023
00:00
5.75 COMPZN, CASING RUNL P RIH w/ liner on DP f/ 11642' to 17400'.
Fill pipe w/ fill up hose every 25 stds.
Parameters @ 15517':
129k PU
111k SO
120k ROT
4k TQ @ 20 RPM
11,642.0 17,400.0
10/10/2023
00:00
10/10/2023
06:00
6.00 COMPZN, CASING RUNL P RIH w/ liner on DP f/ 17400' to 26989'.
Fill pipe w/ fill up hose every 25 stds.
Tag bottom with 5k.
17,400.0 26,989.0
10/10/2023
06:00
10/10/2023
06:45
0.75 COMPZN, CASING RURD P LD single. MU side entry sub assembly
and cement line. Shear Vertice sub @
1570 PSI. Fill liner w/ 176bbls of fluid
while venting air through top drive.
26,989.0 26,984.0
10/10/2023
06:45
10/10/2023
07:15
0.50 COMPZN, CASING CIRC P Line up and circulate through top drive.
4-6 BPM
1485 strokes.
26,984.0 26,984.0
10/10/2023
07:15
10/10/2023
09:30
2.25 COMPZN, CASING PACK P Drop 1.5" ball and set liner hanger and
packer as per Baker rep. Observed
shear at 4461 PSI.(used test pump).
26984' Shoe depth
15351.69' TOL
26,984.0 26,984.0
10/10/2023
09:30
10/10/2023
10:30
1.00 COMPZN, CASING PRTS P Line up and test packer to 3500 PSI.
Charted.
PU out of liner with running tool and LD
SES assembly and double.
26,984.0 26,984.0
10/10/2023
10:30
10/10/2023
13:30
3.00 COMPZN, CASING CIRC P Displace well to 8.8ppg CI brine. 26,984.0 26,984.0
10/10/2023
13:30
10/10/2023
14:00
0.50 COMPZN, CASING OWFF P Flow check.
Static loss rate- 21 BPH
26,984.0 26,984.0
10/10/2023
14:00
10/10/2023
21:45
7.75 COMPZN, WELLPR PULD P POOH LD DP f/ 15352' to 12174'. 15,352.0 12,174.0
10/10/2023
21:45
10/10/2023
22:15
0.50 COMPZN, WELLPR SVRG P Service rig.
SimOps: Replace hose on pipe skate.
12,174.0 12,174.0
10/10/2023
22:15
10/11/2023
00:00
1.75 COMPZN, WELLPR PULD P POOH LD DP f/ 12174' to 11379'. 12,174.0 11,379.0
10/11/2023
00:00
10/11/2023
06:00
6.00 COMPZN, WELLPR PULD P POOH L/D 5" Drill pipe from 11,379' MD
to 5,600' MD.
11,379.0 5,600.0
10/11/2023
06:00
10/11/2023
09:30
3.50 COMPZN, WELLPR PULD P POOH LD 5" drill pipe from 5,600' MD
to 2,505' MD.
57 joints 5" drill pipe bad.
Total bad 5" joints on location 127 joints.
5,600.0 2,505.0
10/11/2023
09:30
10/11/2023
10:15
0.75 COMPZN, WELLPR PULD P POOH LD 4" drill pipe from 2,505' MD
to 2,225' MD.
2,505.0 2,225.0
10/11/2023
10:15
10/11/2023
10:45
0.50 COMPZN, WELLPR SVRG P Service rig, 2,225.0 2,225.0
10/11/2023
10:45
10/11/2023
12:00
1.25 COMPZN, WELLPR PULD P POOH LD 4" drill pipe from 2,225' MD
to 1,570' MD.
2,225.0 1,570.0
10/11/2023
12:00
10/11/2023
16:00
4.00 COMPZN, WELLPR PULD P POOH LD 4" drill pipe from 1,570' MD
to Surface. L/D liner running tools.
Witnessed good shear on dog sub.
Total bad 4" joints on location 140 joints.
Total bad 4" joints HWT on location 11
joints.
1,570.0 0.0
10/11/2023
16:00
10/11/2023
16:30
0.50 COMPZN, WELLPR WWWH P R/U stack washer and wash stack with
600gpm 120psi 10rpms.
0.0 0.0
10/11/2023
16:30
10/11/2023
19:00
2.50 COMPZN, RPCOMP RURD P Clean and clear rig floor, Stage tree on
BOP deck, R/U to run upper completion.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 42/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/11/2023
19:00
10/11/2023
19:30
0.50 COMPZN, RPCOMP PUTB P P/U 4.5" 12.6ppf 563 upper completion
to 131' MD
0.0 131.0
10/11/2023
19:30
10/11/2023
20:00
0.50 COMPZN, RPCOMP PRTS P Make up gauge mandrel and install TEC
line and test to 9,500psi 10min.
131.0 131.0
10/11/2023
20:00
10/11/2023
23:00
3.00 COMPZN, RPCOMP PUTB P P/U 4.5" 12.6ppf 563 upper completion
from 131' MD to 2,105' MD.
131.0 2,105.0
10/11/2023
23:00
10/11/2023
23:30
0.50 COMPZN, RPCOMP PUTB P Make up 5.5" X/O and change out
handling equipment.
2,105.0 2,105.0
10/11/2023
23:30
10/12/2023
00:00
0.50 COMPZN, RPCOMP PUTB P P/U 5.5" 15.5ppf 563 upper completion
from 2,105' MD to 2,516' MD.
2,105.0 2,516.0
10/12/2023
00:00
10/12/2023
06:00
6.00 COMPZN, RPCOMP PUTB P P/U 5.5" 15.5ppf 563 upper completion
from 2,516' MD to 7,340' MD.
2,516.0 7,340.0
10/12/2023
06:00
10/12/2023
12:00
6.00 COMPZN, RPCOMP PUTB P P/U 5.5" 15.5ppf 563 upper completion
from 7,340' MD to 12,050' MD.
7,340.0 12,050.0
10/12/2023
12:00
10/12/2023
18:00
6.00 COMPZN, RPCOMP PUTB P P/U 5.5" 15.5ppf 563 upper completion
from 12,050' MD to 15,323' MD.
Running TEC line and installing Cannon
clamps every joint. Checking control line
every 1000' MD. Tag up, witness 20k
shear, SO 1' to NoGo with 10k @
15,354' MD. Calculate spaceout and
M/U pups (14.85', 9.67', 5.92')
PU: 184k
SO: 127k
12,050.0 15,351.0
10/12/2023
18:00
10/12/2023
20:30
2.50 COMPZN, RPCOMP THGR P MU hanger and landing joint. Terminate
line through hanger and test to 5000psi.
Good test. Land hanger at 15,351' MD
with 126k. RILD. Clean and clear rig
floor and R/U test equipment.
15,351.0 15,351.0
10/12/2023
20:30
10/12/2023
21:00
0.50 COMPZN, RPCOMP PRTS P Close annular and test hanger seals to
3000psi 10min (good test)
15,351.0 15,351.0
10/12/2023
21:00
10/12/2023
23:30
2.50 COMPZN, RPCOMP PRTS P RU test lines. Pressure up tubing to
3000psi (15min), set pkr and test tbg to
4,200 & hold for 30 minutes (witness
second shear at 2230psi). Bleed tubing
down to 3,000 psi & bring pressure on
IA to 3,500 psi & hold pressure for 30
minutes Bleed tubing to 0 psi, Shear
SOV at 2200psi diff. Tubing & IA
equalized & bled to 0 psi Observed IA
for flow for 30 minutes, No flow
15,351.0 15,351.0
10/12/2023
23:30
10/13/2023
00:00
0.50 COMPZN, RPCOMP RURD P R/D test equipment and L/D landing
joint. Drain BOP's.
15,351.0 15,351.0
10/13/2023
00:00
10/13/2023
01:00
1.00 COMPZN, WHDBOP PRTS P Set BPV and test to 3000psi (10 min) in
direction of flow.
15,351.0 0.0
10/13/2023
01:00
10/13/2023
02:00
1.00 COMPZN, WHDBOP RURD P Blow down service lines, Clean and
clear rig floor, De-energize Koomey, R/D
Orbit valve, clean flow box.
0.0 0.0
10/13/2023
02:00
10/13/2023
04:30
2.50 COMPZN, WHDBOP NUND P R/D choke and kill lines, Pull and L/D
mouse hole, Remove trip nipple, Break
bolts on stack, Skid flow box back and
remove MPD head.
0.0 0.0
10/13/2023
04:30
10/13/2023
06:00
1.50 COMPZN, WHDBOP NUND P Skid BOPs back and N/D risers. 0.0 0.0
10/13/2023
06:00
10/13/2023
10:30
4.50 COMPZN, WHDBOP NUND P Complete control line termination at WH.
NU adapter flange. Test to 5,000psi
10min. Witness by CPAI
BHP 4313.9 psi
Temp 177.9
0.0 0.0
10/13/2023
10:30
10/13/2023
12:00
1.50 COMPZN, WHDBOP RURD P Blow down service lines and R/D
equipment, Pull BPV, R/U for freeze
protect.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 43/43
MT7-94
Report Printed: 11/6/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/13/2023
12:00
10/13/2023
14:15
2.25 COMPZN, WHDBOP FRZP P Pressure test lines to 3500psi. Pump
85bbls diesel down IA taking returns up
TBG with LRS.
0.0 0.0
10/13/2023
14:15
10/13/2023
15:15
1.00 COMPZN, WHDBOP OTHR P Open well and let U-TUB 1 hr.
Final Pressures
OA 0psi
IA 0psi
TBG 150psi
0.0 0.0
10/13/2023
15:15
10/13/2023
16:30
1.25 COMPZN, WHDBOP PRTS P Bled tubing to 0psi, Install BPV and test
in direction of flow to 3500psi 10min
0.0 0.0
10/13/2023
16:30
10/13/2023
18:00
1.50 DEMOB, MOVE RURD P Blow down service lines, M/U gauge
flanges and secure well.
Rig release at 1800hrs 10-13-23
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/13/2023
Page 1/1
MT7-94
Report Printed: 11/6/2023
Cement Detail Report
Cement Details
Description
Surface String Cement
Cementing Start Date
8/27/2002 20:30
Cementing End Date
8/28/2023 01:30
Wellbore Name
MT7-94
Comment
Cement Stages
Stage # 1
Description
Surface String Cement
Objective
Returns to surface
Top Depth (ftKB)
39.2
Bottom Depth (ftKB)
4,096.0
Full Return?
Yes
Vol Cement …
198.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
776.0
P Plug Bump (psi)
411.0
Recip?
Yes
Stroke (ft)
10.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Bumped 4.6 bbl's over calculated pressured up to 500 psi over held for 5 minutes. Bled pressure off and checked floats held.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.2
Est Btm (ftKB)
3,586.0
Amount (sacks)
1,341
Class
Blend
Volume Pumped (bbl)
456.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sa…
6.68
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
223.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
3,586.0
Est Btm (ftKB)
4,096.0
Amount (sacks)
338
Class
G
Volume Pumped (bbl)
70.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
189.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Surface String Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 8/22/2…
Page 1/1
MT7-94
Report Printed: 11/6/2023
Cement Detail Report
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
9/17/2023 16:15
Cementing End Date
9/17/2023 21:45
Wellbore Name
MT7-94
Comment
Cement Stages
Stage # 1
Description
Primary – Full Bore
Objective
Mud Push
Top Depth (ftKB)
7,217.0
Bottom Depth (ftKB)
8,044.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
3
P Pump Final (psi)
279.0
P Plug Bump (psi) 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
Pump 63.9 bbls 12.5ppg mud push
Cement Fluids & Additives
Fluid
Fluid Type
MUD PUSH 12.5ppg
Fluid Description Estimated Top (ftKB)
7,217.0
Est Btm (ftKB)
8,044.0
Amount (sacks) Class
Blend
Volume Pumped (bbl)
63.9
Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal)
12.50
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 2
Description
Primary – Full Bore
Objective
Lead Cement 13.0ppg
Top Depth (ftKB)
8,044.0
Bottom Depth (ftKB)
11,549.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
5
P Pump Final (psi)
146.0
P Plug Bump (psi) 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
Pumped 254.2 bbls lead cement
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
8,044.0
Est Btm (ftKB)
11,549.0
Amount (sacks)
747
Class
G
Volume Pumped (bbl)
254.2
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sa…
10.27
Free Water (%) Density (lb/gal)
13.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 3
Description
Primary – Full Bore
Objective
Tail Cement 15.8ppg
Top Depth (ftKB)
11,549.0
Bottom Depth (ftKB)
13,561.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…
4
P Pump Final (psi)
540.0
P Plug Bump (psi) 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
Pumped 152 bbls tail cement
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
11,549.0
Est Btm (ftKB)
13,561.0
Amount (sacks)
734
Class
G
Volume Pumped (bbl)
152.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sa…
4.99
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 1 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 8/22/2…
Page 1/1
MT7-94
Report Printed: 11/6/2023
Cement Detail Report
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
9/21/2023 19:00
Cementing End Date
9/21/2023 21:30
Wellbore Name
MT7-94
Comment
Flood lines and test to 4700 PSI. Pump 70BBLS of 8.9ppg KCL Chem Wash. 126 GPM/715 PSI. Drop bottom dart. Swap to cementers. Pump 77.2 BBLS of
15.8ppg cement @ 4-4.5 BPM. SD and drop top dart. Pump 10 BBLS FW w/ cement unit. Swap to rig pumps and displace at 6 BPM 600-850 PSI. Slow rate to 3
BPM and bump plug. Pressure up to 500 PSI over FCP to 1000 PSI. Hold f/ 5 minutes and check floats. Good. 1.3 BBLs bled back. Full returns throughout job.
No losses. Cement in place @ 21:30hrs 9/21/23
Cement Stages
Stage # 1
Description
Liner Cement
Objective Top Depth (ftKB)
14,658.0
Bottom Depth (ftKB)
15,526.0
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
3
P Pump Final (psi)
453.0
P Plug Bump (psi)
1,000.0
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)
11,130.0
Est Btm (ftKB)
11,888.0
Amount (sacks)
606
Class
G
Volume Pumped (bbl)
128.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
4.75
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 2 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 8/22/2…
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WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED
COLOR
PRINTS
Electronic
delivery
GMTU MT7-94 50-103-20858-00-00 223-049 GMTU MEMORY geoVISION FINAL FIELD 5-Sep-23 1
Originated: Delivered to:6-Nov-23
Kayla Junke 06Nov23-VT01
Natural Resources Technician
Alaska Oil and Gas Conservation Commission
600 E 57th Place 333 W. 7th Ave, Anchorage, AK 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
TRANSMITTAL DATE
TRANSMITTAL #
Transmittal Receipt
________________________________ X____________________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
VTuong@slb.com SLB Auditor -
A Transmittal Receipt signature confirms that a package (box,
envelope, etc.) has been received and the contents of the package
have been verified to match the media noted above. The specific
content of the CDs and/or hardcopy prints may or may not have been
verified for correctness or quality level at this point.
# Schlumberger-Private
PTD: 223-049
T38123
Kayla Junke
11/8/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.11.08
10:02:03 -09'00'
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Oct 20, 2023
AOGCC
Attention: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
MT7-94
Greater Mooses Tooth
API #: 50-103-20858-00
Permit No: 223-049
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.
MT7-94 is located in a federal oil and gas unit. Only with respect to the MT7-94 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: 223-049
T38092
10/20/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.10.20
14:42:18 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________GMTU MT7-94
JBR 12/05/2023
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:0
Witnessed gas alarms and PVT's only
Test Results
TEST DATA
Rig Rep:R. Fritts/ C. BaliOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Benedict/ L. Shirley
Rig Owner/Rig No.:Doyon 25 PTD#:2230490 DATE:10/1/2023
Type Operation:DRILL Annular:
250/3500Type Test:OTH
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopAGE231018152339
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 3
MASP:
2836
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 NT
Lower Kelly 1 NT
Ball Type 4 NT
Inside BOP 2 NT
FSV Misc 0 NA
15 NTNo. Valves
1 NTManual Chokes
1 NTHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"NT
#1 Rams 1 2 7/8X5 1/2"NT
#2 Rams 1 Blind/Shear NT
#3 Rams 1 2 7/8X5 1/2"NT
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"NT
HCR Valves 2 3 1/8"NT
Kill Line Valves 2 3 1/8"NT
Check Valve 0 NA
BOP Misc 0 NA
System Pressure NT
Pressure After Closure NT
200 PSI Attained NT
Full Pressure Attained NT
Blind Switch Covers:NT
Bottle precharge NT
Nitgn Btls# &psi (avg)NT
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer NT
#1 Rams NT
#2 Rams NT
#3 Rams NT
#4 Rams NA
#5 Rams NA
#6 Rams NA
HCR Choke NT
HCR Kill NT
Operator performed full BOPE Test; Inspector unable to witness except
as noted. Charts from full BOPE test attached. -- J. Regg; 12/5/2023
BOPE Test - Doyon 25
GMTU MT7-94 (PTD 2230490)
10/1/2023
BOPE Test - Doyon 25
GMTU MT7-94 (PTD 2230490)
10/1/2023
MT7-94 10/1/2023 Tested to 250PSI/5MIN, 35OOPSI/10 MIN
4” Test Joint
1.Annular Preventer, UIBOP, Valves: 1, 13, 14, 15, Kill line
2.UPR (2 7/8” x 5 1/2”), LIBOP, Valves: 10, 12, 2, HCR KILL
3.Valves: 6, 9, 11, Manual Kill, 5” Dart valve.
4.Valves: 5, 7, 8; 5” FOSV #1
5.Valve: 3; 5” FOSV #2
6.LPR (2 7/8” x 5 ½”), 4” DART VALVE
7.BLIND RAMS, 4” FOSV #1, Valves:4
8.Hydraulic Choke A, Manual Choke B
5 1/2” Test Joint
9.Annular, 4” FOSV #2
10. UPR (2 7/8” x 5 ½”), Manual Choke
11.LPR (2 7/8 x 5 ½”)
PTD 2230490
ZZ3-049
SAMPLE TRANSMITTAL
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
MT7-94
4090 - 13561
6 Boxes
SENT BY: M. McCRACKEN
l 859
DATE: September 28, 2023
AIR BILL: N/A
CPAL CPA12023092801
CHARGE CODE: N/A
NAME: MT7-94
NUMBER OF BOXES: 6 Boxes
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
RECEIVED:
C �.` I V
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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, MT7-94
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-049
Surface Location: 1069 FSL, 2049 FWL, S32 T10N R2E, UM
Bottomhole Location: 174 FSL, 115 FEL, S10 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 July 2023. 05
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.07.05 15:18:28
-08'00'
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: 31,253 TVD: 8049
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): 139.5 15. Distance to Nearest Well Open
Surface: x- 290133 y- 5915890 Zone- 4 100.6 to Same Pool: 2028' to Rendezvouz A
16. Deviated wells: Kickoff depth: 500 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
42" 20" 94# H40 Welded 80 40 40 120 120
16" 13-3/8" 68# L80 H563 4040 40 40 4040 2998
12-1/4" 9-5/8" 47# T95 H563 13449 40 40 13449 7326
8-1/2" x 9-7/8" 7" 29#L80 H563 2140 13299 7258 15439 8099
6-1/8" 4-1/2" 12.6# L-80 H563 15989 15264 8060 31253 8049
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
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:
Chris Brillon Contact Email:Brad.Gorham@conocophillips.com
Wells Engineering Manager Contact Phone: 907-265-6487
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
Greater Mooses Tooth
Rendezvous
7/15/2023
5165' to AA081806
N/A
728 sx of 13.0 ppg Ext. Class G + 730 sx of
15.8 ppg Class G
Cement to surface with 10 yds slurry
1318 sx of 11.0 ppg DeepCRETE + 330 sx of
15.8 ppg Class G
366 sx of 15.8 ppg Class G
2836
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.
Authorized Name:
Authorized Title:
Authorized Signature:
Brad Gorham
Commission Use Only
See cover letter for other
requirements.
Perforation Depth MD (ft): Perforation Depth TVD (ft):
Liner
Production
Intermediate
Surface
Conductor/Structural
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
(including stage data)
3641
P.O. Box 100360 Anchorage, Alaska, 99510-0360
1069 FSL, 2049 FWL, S32 T10N R2E, UM AA081800, AA081803, AA081805
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 MT7-94
1952 FSL, 1810 FWL, S25 T10N R1E, UM 932535000, 932538000, 932540000
174 FSL, 115 FEL, S10 T10N R1E, UM 3776, 5756, 5756
GL / BF Elevation above MSL (ft):
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 9:45 am, May 24, 2023
VTL 7/04/2023
223-049
7/9/2023
X
Service - WAG
50-103-20858-00-00
MDG 7/3/2023
DSR-5/24/23
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
BOP test to 3000 psig approved while drilling the Int1 section
The alternate BOP configuration attached while drilling the Int 1 is approved
Diverter variance granted per 20 AAC 25.035(h)(2)
Waiver for CPAI Rotary BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate II cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
GCW 07/05/2021
07/05/23
07/05/23
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.07.05 15:18:48 -08'00'
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
March 2, 2023
Mr. Luke Lawrence
Wells Manager
ConocoPhillips Alaska
700 G Street
Anchorage, AK 99501
Re: Docket Number: OTH-21-018
CPAI Rotary Rig BOPE Test Frequency
Dear Mr. Lawrence:
By letter dated January 12, 2023, ConocoPhillips Alaska, Inc. (CPAI) requested a continuance of
the waiver granted under Docket OTH-21-018 allowing certain CPAI rotary drilling rigs to test
blowout prevention equipment (BOPE) on a 21-day test schedule. The Alaska Oil and Gas
Conservation Commission (AOGCC) grants CPAI’s request for a limited duration and scope.
OTH-21-018 approved the 21-day test interval for a 1-year period which expired on January 25,
2023. The AOGCC approved an extension to the pilot program by electronic mail on February 6,
2023, to accommodate review of the July-December 2022 BOPE Between Wells Maintenance
Report (received January 27, 2023, and revised February 3, 2023). AOGCC met with CPAI on
February 22, 2023 to discuss the Between Wells Maintenance Report and BOPE performance of
the CPAI-operated rigs during 2022 in considering the requested continuance.1
During the past year, CPAI-operated rigs Doyon 25 and Doyon 26 were authorized to participate
in the pilot – the other rigs working for CPAI failed to meet the conditions for testing BOPE at 21-
day intervals.2
CPAI’s request to continue the pilot project allowing BOPE testing on a 21-day interval is
approved for drilling rigs Doyon 25 and Doyon 26, with the following conditions:
- The pilot test duration is for ONE year from the approval date of this letter, subject to
potential extension and expansion to include other CPAI operated rigs with at least 3
months of continuous rig work and AOGCC review of a rig’s BOPE system reliability.
1 AOGCC approval of the Between Wells Maintenance program has enabled CPAI workover rigs to extend the
interval between BOPE tests from every 7 days to not exceeding 14 days and was also part of the justification for
allowing certain rigs to test BOPE on a 21-day interval. CPAI data shows the BWM has reduced the number of
component failures during BOPE testing by replacing components that indicate suspect integrity before those
components fail during testing.
2 Doyon 26 has additionally been approved (Permit-to-Drill) to test BOPE on an event-basis instead of at pre-
determined time intervals while drilling specific sections in an ultra-extended reach well.
Docket Number: OTH-21-018
March 2, 2023
Page 2 of 2
- CPAI must continue to implement the BWM program as approved by AOGCC.
- Development drilling wells only are included in this approval.
- The initial test after rigging up BOPE to drill a well must be to the rated working pressure
as provided in API Standard 53.
- CPAI is encouraged to take advantage of opportunities to test.
- CPAI must adhere to original equipment manufacturer recommendations and replacement
parts for BOPE.
- Requests for extensions beyond 21 days must include justification with supporting
information demonstrating the additional time is necessary for well control purposes or to
mitigate a stuck drill string.
- 48-hour advance notice for a BOPE test shall be provided to AOGCC for opportunity to
witness.
If you have questions regarding this, please contact Jim Regg at (907) 793-1236.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
cc: Greg Hobbs (CPAI)
Mike Kneale (CPAI)
Victoria Loepp (AOGCC)
AOGCC Inspectors (email)
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:09:23
-09'00'
'DdDdϳͲϵϰ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
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.
From:Gorham, Brad
To:Guhl, Meredith D (OGC); Hobbs, Greg S
Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Roby, David S (OGC)
Subject:RE: [EXTERNAL]GMTU MT7-94, PTD 223-049: Formation tops and pre-production?
Date:Friday, June 30, 2023 4:25:08 PM
Meredith,
Please see below for the formation tops:
Formation X Y TVDSS
TVD
(KB=139.5)MD
Perma_Frost 1430126.22 5915692.38 -840 979.5 984.87
C40 1430107.34 5915711.12 -943 1082.58 1091.34
C30 1430013.63 5915788.62 -1276 1415.86 1446.48
C20 1429918.91 5915857.19 -1501 1640.56 1699.92
C10 1429705.07 5915998.5 -1853 1992.87 2136.27
K3 1428358.69 5916780.51 -2835 2974.81 3989.9
SCP 1428320.11 5916802.47 -2858 2997.81 4039.9
Albian_97 1427363.87 5917346.85 -3428 3567.95 5279.22
Albian_96 1427044.19 5917528.84 -3619 3758.56 5693.55
Albian_95 1426714.28 5917716.66 -3816 3955.26 6121.12
Albian_94 1426070.9 5918082.92 -4199 4338.87 6954.97
Albian_93 1425225.95 5918563.94 -4703 4842.66 8050.05
Sub
Albian_93 1424804.84 5918803.68 -4954 5093.74 8595.84
Albian_92 1423151.81 5919744.73 -5940 6079.34 10738.22
Albian_91 1423055.61 5919799.5 -5997 6136.69 10862.9
FCS_HRZ 1422733.78 5919982.71 -6189 6328.58 11280
Susitna 1422641.43 5920035.29 -6244 6383.65 11399.7
HRZ 1421099.54 5920916.17 -7164 7303.11 13399.5
INT1 1421061.59 5920939.51 -7186 7325.81 13449.5
LCU 1420776.83 5921114.64 -7357 7496.15 13824.71
Alpine_D 1419710.3 5922052.34 -7948 8087.64 15386.53
INT2 1419685.31 5922094.34 -7959 8098.19 15436.53
Alpine_C 1419612.16 5922220.91 -7989 8128.2 15585.79
As far as pre-production is concerned, it is my understanding that the well will not be pre-produced,
just flowed back to clean the well up prior to injection.
Please let me know if you have any other questions or need any additional information.
Thanks,
Brad
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Friday, June 30, 2023 3:09 PM
To: Gorham, Brad <Brad.Gorham@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]GMTU MT7-94, PTD 223-049: Formation tops and pre-production?
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.
Hello Brad,
I’m reviewing the permit to drill package for GMTU MT7-94 and I cannot locate a list of formation
tops with MD/TVD measurements. On the previous GMTU permit (MT7-14) the formation tops were
provided on the Plan Summary in a box labeled Formation Top Details, but on MT7-94, that box is
blank. Could you please provide a list of formation tops with MD and/or TVD depths?
Also, will MT7-94 be pre-produced or will it just be flowed back for cleanup? If the well will be pre-
produced, how long does ConocoPhillips anticipate that lasting?
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, AK 99510-0360
Telephone 907-276-1215
May 23, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Permit to Drill MT7-94
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 July 15, 2023. It is intended that Doyon 25 be
used to drill the well.
MT7-94 will drill a 16” surface hole reaching total depth above the K3 sand. 13-3/8” casing will be run and
cemented to surface. The 12-1/4” intermediate 1 hole section will be drillied to the top of the HRZ formation. 9-
5/8” will be run and cemented in place with a 500’ or 250’ TVD column of cement above the highest hydrocarbon
bearing zone per AOGCC regulation. If an additional hydrocarbon zone is present, a 2 nd stage cement job will be
performed to cover 50’ TVD above and below the interval. The 8-1/2” x 9-7/8” intermediate 2 hole section will be
drilled to and landed in the Alpine D. A 7” liner will be set and cemented from total depth to secure the shoe and
cover 500’ or 250’ TVD above any hydrocarbon bearing zone.The 6-1/8” production interval will drilled horizontally
and geo-steered within the Alpine C sand. The well will be completed with a 4-1/2" cemented liner including frac
sleeves and swell packers. The upper completion run from surface will include a production packer and GLM’s.
It is requested that a variance from the diverter requirement under 20 AAC 25.035 (h) (2) is granted. At MT7 there
has been no significant indication of shallow gas or gas hydrates through the surface hole interval.
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 Brad Gorham at 907-265-6487
(Brad.Gorham@conocophillips.com) or Greg Hobbs at 907-263-4749 (greg.s.hobbs@conocophillips.com).
Regards,
Brad Gorham
Staff Drilling Engineer
cc:
MT7-94 Well File / Jenna Taylor ATO 1732
David Lee ATO 1552
Chris Brillon ATO 1548
Andy Mack Kuukpik Corp
*Recommend granting requested
variance: no shallow gas or gas
hydrates reported in nearby recently
drilled wells. This will be the 18th well
drilled from this pad. MDG 7/3/2023
variance from the diverter requirement under 20 AAC 25.035 (h)(2) *
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 1 | 20
MT7-94 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 ................................................................................................................ 7
5. MASP Calculations ................................................................................................................................. 7
6. Procedure for Conducting Formation Integrity Tests ............................................................................... 9
7. Casing and Cementing Program .............................................................................................................. 9
8. Drilling Fluid Program .......................................................................................................................... 11
9. Abnormally Pressured Formation Information ...................................................................................... 12
10. Seismic Analysis ................................................................................................................................... 12
11. Seabed Condition Analysis ................................................................................................................... 12
12. Evidence of Bonding ............................................................................................................................. 12
13. Discussion of Mud and Cuttings Disposal and Annular Disposal ............................................................ 13
14. Drilling Hazards Summary .................................................................................................................... 14
15. Proposed Completion Schematic .......................................................................................................... 16
16. MT7-14 Intermediate 1 MPSP Review & Ram Configuration ................................................................. 17
17. Area of Review..................................................................................................................................... 20
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 2 | 20
1. Well Name
Requirements of 20 AAC 25.005 (f)
The well for which this application is submitted will be designated as MT7-94
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
Location at Surface 887 FSL, 1714 FWL, S32 T10N R2E, UM
NAD27
Northing: 5915718.15
Easting: 289794.45
RKB Elevation 38.9’ AMSL
Pad Elevation 100.6’ AMSL
Top of Productive Horizon (Heel) 1010 FNL, 1689 FWL, S32 T10N R2E, UM
NAD27
Northing: 5919100.74
Easting: 289851.28
Measured Depth, RKB: 13449‘ MD
True Vertical Depth, RKB: 7326‘ TVD
True Vertical Depth, SS: 7187‘ TVDss
Total Depth (Toe) 391 FSL, 1083 FWL, S04 T9N R2E, UM
NAD27
Northing: 294295.47
Easting: 5909812.43
Measured Depth, RKB: 31253‘ MD
True Vertical Depth, RKB: 8049‘ TVD
True Vertical Depth, SS: 7909‘ TVDss
Please see attached well stick diagram for the current planned development of the pad.
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 3 | 20
Pad Layout
Well Stick Diagram
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 4 | 20
Well Plat
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 5 | 20
3. Proposed Drilling Program
1. MIRU Doyon 25 onto well over pre-installed 20” insulated conductor. Install diverter and function test.
2. Rig up and test riser, dewater cellar as needed.
3. Drill 16” hole to the surface casing point as per the directional plan, with KSI WBM. (LWD Program:
GR/RES).
4. Run and cement new 13-3/8” surface casing to surface. Results of the cement operation will be
submitted as soon as possible.
5. Install BOPE with the following equipment/configuration: 13-5/8” annular preventer, 9-5/8” FBR’s,
blind ram and 2-7/8” x 5-1/2” VBR’s.
x See section 16 for ram configuration justification.
6. Test BOPE to 250 psi low / 5,000 psi high (24-48 hr. regulatory notice).
7. Pick up and run in hole with 12-1/4” drilling BHA to drill intermediate #1. (LWD Program : GR/RES,
DEN/NEU/IMAGE)
8. Chart casing pressure test to 3,500 psi for 30 minutes.
9. Drill out shoe track and 20’ of new hole.
10. Perform LOT to maximum EMW of 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW.
11. Displace well to 11 ppg WBM.
12. Drill ahead to below Sub-Albian 93 formation. Circulate wellbore clean and POOH.
13. RU and obtain MDT samples and rotary side wall cores in the Sub-Ablian 93 formation.
14. Rig down logging equipment and tools.
15. PU and run in hole with 12-1/4” drilling BHA.
16. Drill ahead to 500’ before the FCS Fill. Weight up to 12.0 ppg.
17. Drill 12-1/4” hole to the casing point.
18. Circulate wellbore clean and POOH.
19. Run 9-5/8” intermediate 1 casing to TD.
20. Pump single stage cement job to isolate the casing shoe or 500’ MD above uppermost hydrocarbon
bearing zone. Note that a shallower hydrocarbon bearing sand may be encountered, and a 2nd stage
cement job will be completed if the one is detected while drilling. Results of the cement operation will
be submitted as soon as possible.
x There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and
require a second stage cement job to place cement 50’ TVD above and below the interval. The
required equipment and cement plans are prepared if this becomes necessary.
21. Change upper 9-5/8” solid body rams to 2-7/8” x 5-1/2” VBR’s. Test BOPE to 250/3,500 psi. (24-48 hr.
regulatory notice).
22. Pick up and run in hole with 8-1/2" x 9-7/8” drilling BHA to drill intermediate hole. SimOps, perform 9-
5/8” annulus LOT with Ball mill and freeze protect.
MDT samples and rotary side wall cores in the Sub-Ablian 93 formation.
There is potential for the presence of the Tusk sand, which may be hydrocarbon bearing and
require a second stage cement job to place cement 50’ TVD above and below the interval. T
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 6 | 20
23. Chart casing pressure test to 3,500 psi for 30 minutes.
24. Drill out shoe track and 20’ of new hole.
25. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 11 ppg EMW.
26. Drill 8-1/2" x 9-7/8” hole to section TD.
x As an identified contingency plan: If Casing Drilling is required due to Geologic Instability in the
intermediate 2 hole section, refer to below steps:
1. Pick up and run in hole with the 7” steerable drilling liner. Pick up and stab in 6” pilot
BHA assembly. (LWD Program: GR/RES).
2. RIH to bottom with 7” SDL on 5” drill pipe.
3. Drill 7” SDL hole to production casing point into the Alpine C sand using Managed
Pressure Drilling to maintain constant bottom hole pressure on connections. (LWD
Program: GR/RES).
4. Land 7” liner at TD. Disconnect SDL and POOH to surface with inner string and pilot.
5. Run in hole with inner string cementing BHA. Stab into liner. Circulate and condition
mud in preparations for cementing.
6. Cement 7” liner to top of liner. Set liner top packer. Circulate excess cement from top
of liner. POOH laying down 5” drill pipe.
7. Continue to Step 28 below.
27. Circulate wellbore clean and POOH.
28. Change out upper rams to 4” x 7” VBRs. Test same to 250 psi low / 3,500 psi high.
29. Pick up and run in hole with the 7” liner on 5” DP to section TD.
30. Circulate and condition mud in preparation for cementing.
31. Cement 7” liner to required TOC. Set liner top packer. POOH laying down 5” drill pipe. Results of the
cement operation will be submitted as soon as possible.
32. Change out upper rams to 2-7/8” x 5-1/2” VBRs. Test same to 250 psi low / 3,500 psi high.
33. Pick up 4” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice).
34. Pick up and RIH with 6-1/8” drilling assembly.
35. Displace well to FloPro WBM. Chart casing pressure test to 3,500 psi for 30 minutes and record results.
36. Drill out and perform FIT to 13.5 ppg EMW maximum. Minimum acceptable leak-off for drilling ahead
is 10.3 ppg EMW.
37. Drill 6-1/8" horizontal hole to section TD (LWD Program: GR/RES/DEN/NEU/IMAGE).
38. Circulate the hole clean and POOH.
39. Run 4-1/2” liner on 4” DP, set liner hanger and packer. Chart casing pressure test 3,500 psi. POOH LD
DP.
40.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.
41. Pressure test hanger seals to 2500 psi.
g Managed
Pressure Drilling t
MT7-94 AOGCC 10-401 APD
5/23/2023
MT7-94 AOGCC 10-401 APD 7 | 20
42. Drop ball & rod, pressure up and set production packer.
43. Pressure test tubing and IA and shear SOV.
44. Install BPV. ND BOPE and install tubing head adapter. Pressure test adapter to 5000 psi.
45. Install 10k frac tree and test.
46. Remove BPV and freeze protect well.
47. Secure well and RDMO.
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
SURF 16" 20" 120 120 10.9 8.7 54 4040 2998 8.7 1,356 56 56 1,056
INT1 12-1/4" 13-3/8" 4040 2998 14.5 8.7 1,356 13449 7326 9.4 3,581 1,961 1,961 2,848
INT2 8-1/2" x 9-7/8" 9-5/8" 13449 7326 16.5 9.4 3,581 15439 8099 8.7 3,664 2,854 5,553 2,854
PROD 6-1/8" 7" 15439 8099 12.5 8.7 3,664 31253 8049 8.7 3,641 2,836 4,455 2,836
*Maximum potential pore pressure in the Susitna Sand if present
(B) data on potential gas zones;
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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
The planned wellbore is expected to enter the gas cap and the area is expected to be normally pressured
(8.5-8.9 ppg).
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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 Cement to Surface
9-5/8" 12-1/4" 47# T95 H563 250’ TVD or 500’ MD, whichever is greater, above
highest significant hydrocarbon bearing zone
7" 8-1/2" x 9-7/8" 29# L80 H563 250’ TVD or 500’ MD, whichever is greater, above
highest significant hydrocarbon bearing zone
4-1/2" 6-1/8" 12.6# P110S H563 Uncemented open hole liner with frac ports and
swell packers
13-3/8" Surface Casing run to 4040' MD/ 2998' TVD Cement Plan:
Cement from 4040’ MD to 3540’ (500’ of tail) with DeepCRETE + Adds @ 15.8 ppg, and from 3540' to
surface with 11.0 ppg DeepCRETE. Assume 120% excess annular volume in permafrost and 50% excess
below the permafrost (985’ MD), zero excess in 20” conductor.
Lead 451 bbls => 1318 sx of 11.0 ppg DeepCRETE + Add's @ 1.92 ft³/sk
Tail 68 bbls => 330 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
9-5/8" Intermediate Casing run to 13449' MD/ 7326' TVD Cement Plan:
Primary cement job consists of 2000 ft 15.8 ppg tail slurry and top of 13.0 ppg lead slurry is designed to be
at 11449’ MD, which is 250' TVD above the prognosed shallowest hydrocarbon bearing zone Sub-Albian
93. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2nd stage
cement job will be performed to isolate this zone. Assume 30% excess annular volume.
Lead 246 bbls => 728 sx of 13.0 ppg Ext. Class G + Add's @ 1.9 ft³/sk
Tail 151 bbls => 730 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
7" Intermediate Liner run to 15439' MD/ 8099' TVD Cement Plan:
Top of slurry is designed to be at 14588’ MD, which is 250' TVD above the prognosed shallowest
hydrocarbon bearing zone Alpine D. Assume 40% + 20 Additional bbls excess annular volume.
Tail 76 bbls => 366 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
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8. Drilling Fluid Program
(Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate #1 Intermediate #2 Production
Hole Size in 16" 12-1/4" 8-1/2" x 9-7/8" 6-1/8"
Casing Size in 13-3/8" 9-5/8" 7" 4-1/2"
Density ppg 10.5 – 11.5 10.0 – 12.0 10.0 – 13.0 8.8 – 9.5
PV cP 13 10 40 15
YP lb./100 ft2 35-50 20 - 28 20 - 35 15 - 20
Funnel Viscosity s/qt 200 40 - 50 70 - 90 60 - 80
Initial Gels lb./100 ft2 50 10 14 10
10 Minute Gels lb./100 ft2 60 15 42 15
API Fluid Loss cc/30 min N.C. – 15.0 N/A N/A 4
HPHT Fluid Loss cc/30 min n/a 8.0 – 12.0 5.0 10.0
pH 11.0 9.5 – 10.0 9.5 – 10.0 9.0 – 9.5
Surface Hole:
A freshwater drilling fluid (KSI) will be used for the surface interval. Keep flow line viscosity at ± 200
sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight ч10.0
ppg by use of solids control system and dilutions where necessary.
Intermediate #1:
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing
fluid annular velocity. Maintain mud weight from 10-12.0 ppg and be prepared to add loss circulations
materials as needed. Good filter cake quality, hole cleaning and maintenance of low drill solids (by
diluting as needed) will all be important in maintaining wellbore stability.
Intermediate #2:
Versapro OBM will continue be used in this section for shale stability purpose. Ensure good hole cleaning
by maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the
reservoir is penetrated. Ensure adequate LCM material is available on location and in the field to address
any expected losses. Maintain mud weight from 10.0-12.0 ppg. Good filter cake quality, hole cleaning and
maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore
stability. The mud will be weighted up before pulling out of the hole.
Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability
and cycling.
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.
MPD will be used to hold back pressure, keeping the well dynamically balanced.
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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 MT7-94 will be disposed of into a permitted
annulus on the MT7 pad or hauled to the Class 1 disposal well on CD1.
The MT7-94 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to
freeze protecting with diesel to ~2000' TVD. Significant hydrocarbon zones include only the Alpine sand
based on pre-drill interpretations.
Once MT7-94 has been drilled and completed, consideration may be given to permit this well for annular
disposal.
An application for Sundry Operations form 10-403 will then be filed. Annular disposal of fluids occurring
due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As
stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular
disposal. There will be no USDW's open below the shoe or potable/industrial water wells within one mile
of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this
well.
Surface casing will be set near the base of the C10 formation, above the K3. These 450-500' thick shales
are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas.
The maximum volume of fluids to be disposed of down the annulus of this well will not exceed 35,000 bbl
without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12
ppg for drilling fluid wastes. Using 12 ppg fluid and the rig’s specified maximum pumping pressure of 1500
psi for annular disposal, the maximum pressure at the surface casing shoe is estimated by:
Max Shoe Pressure:
[ (12 ppg) * (0.052) * (Surf. Shoe TVD) ] + 1500 psi
[ (12 ppg) * (0.052) * (2998’) ] + 1500 psi
Max Shoe Pressure = 3371 psi
Pore Pressure: 1356 psi
Therefore
Differential Pressure: 3371 – 1356 = 2015 psi.
The internal casing pressure is conservative since frictional losses while pumping has not been taken into
consideration. The surface and intermediate casing strings exposed to annular disposal operations have
sufficient strength by using the 85% collapse and burst ratings listed in the following table:
OD Weight
(ppf) Grade Range Conn. Collapse
(psi)
85% of
Collapse
(psi)
Burst
(psi)
85% of
Burst
(psi)
13-3/8" 68# L80 3 H563 2260 1921 5020 4267
9-5/8" 47# T95 3 H563 5090 4327 8150 4573
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14. Drilling Hazards Summary
16" Hole | 13-3/8" Casing Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low First well on Pad, traveling cylinder diagrams
Gas Hydrates Low If observed – control drill, reduce pump rates and circulating time, reduce mud
temperatures
Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted
sweeps, reduce fluid viscosity, control ROP
Abnormal Pressure Low Diverter drills, increased mud weight. Shallow hazard study noted minimal risk
Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density
cement slurries, port collar, control pipe running speeds
12-1/4" Hole | 9-5/8" Casing Interval
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, MPD stripping practices
Abnormal Pressure in
Overburden Formations Low Well control drills, check for flow during connections, increase mud weight. Shallow
hazard study noted minimal risk
Hole Cleaning Low Monitor ECD and torque/drag trends, control drill and use best hole cleaning practices
8-1/2" x 9-7/8" Hole | 7" Liner - Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale, Tight hole High
MPD for shale stability, Steerable Drilling Liner, Increase mud weight, control ROP,
connection and trip speeds, sweeps, and real time equivalent circulating density (ECD)
monitoring, run casing as liner
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, Liner will be in place at TD
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increase mud weight
Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers
6-1/8" 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
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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.
x Lower Shale Stability:
HRZ/Kalubik/Miluveach in the pilot and intermediate 2 hole sections will require higher mud
weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be
used in conjunction with a 4-string casing design to mitigate shale instability in the
aforementioned formations. Standard LCM material and well bore strengthening pills are
expected to be effective in dealing with lost circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
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15. Proposed Completion Schematic
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16. MT7-94 Intermediate 1 MPSP Review & Ram Configuration
Proposal
Requesting approval to use a BOPE stack equipped with an annular preventer, fixed 9-5/8” solid body
rams, blind/shear rams and, variable rams (2-7/8” x 5-1/2”) while drilling and running casing in the
Intermediate 1 section of MT7-94.
The Maximum Potential Surface Pressure (MPSP) is expected to be 1961 psi while drilling the 12-1/4”
Intermediate 1 hole section with 5” drill pipe, satisfying 20 AAC 25.035.e.1.A. Please find the review
below for more detail.
20 AAC 25.035.e.1.A:
For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at least
three preventers, including:
i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except that pipe rams
need not be sixed to bottom-hole assemblies and drill collars.
ii. One with blind rams
iii. One annular type
Proposed Configuration:
x Annular Preventer (iii)
x 9-5/8” Solid Body Rams
x Blind/Shear Rams (ii)
x 2-7/8” x 5-1/2” VBR’s (i)
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Pore Pressure Assessment
A Normal Compaction Trend (NCT) is defined using the Bowers Method on a calibration well with little/no
erosion and global constants as a starting point. Both source rock and non-source rock NCTs are then
defined. For a given unit/zone, deviations slower than NCT indicate overpressure and allow calculation of
its magnitude. The NCT for individual wells is defined by modifying Bowers parameters to account for
specific erosion amounts.
The maximum estimated reservoir pressure in the Intermediate 1 section is 9.4 ppg.
Interval TVD
Top
TVD
Base
Max
PPG Note
Surface to Permafrost Base 0 977 8.3 Hydrostatic
Permafrost Base to C40 977 1079 9.1 Hydrostatic
C40 to C30 1079 1405 9.2 Rendezvous-2 DT Estimate
C30 to C20 1405 1642 8.45 Hydrostatic
C20 to C10 1642 1986 8.475 Hydrostatic
C10 to K3 1986 2999 9.3 Rendezvous-2 DT Estimate
K3 to Albian_97 2999 3607 8.55 Hydrostatic
Albian 97 to Albian 96 3607 3788 8.56 Hydrostatic
Albian 96 to Albian 95 3788 3972 8.56 Hydrostatic
Albian 95 to Albian 94 (Tusk Sand if present) 3972 4240 8.56 Hydrostatic
Albian 94 to Albian 93 4240 4895 8.57 Hydrostatic
Albian 93 to Albian 92 4895 6061 8.6 Hydrostatic
Albian 92 to Albian 91 6061 6121 8.6 Hydrostatic
Albian 91 to HRZ (Susitna Sand if present) 6121 7396 9.4 Offset Well DT/ Res Estimates
HRZ to LCU 7396 7591 11.6 Offset Well DT/ Res Estimates
LCU to Alpine D 7591 8237 11.75 Offset Well DT/ Res Estimates
Alpine D to Alpine C 8237 8263 11.4 MT7-04 Res Est.
Alpine C to UJU 8263 8359 8.8 Offset MDT’s
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Maximum Potential Surface Pressure
Surface Casing Point: 4040' MD/ 2998' TVD
Intermediate 1 Casing Point: 13449' MD/ 7326' TVD
Max Anticipated Pore Pressure: 9.4 ppg | Albian 91 > HRZ
Surface Casing Shoe FG: 14.5 ppg EMW | K3
Maximum Potential Surface Pressure (MPSP) is determined as the lesser of 1.) surface pressure at
breakdown of the formation casing seat with a gas gradient to the surface, or 2.) formation pore pressure
at the next casing point less a gas gradient to the surface as follows:
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
MPSP CALCULATIONS:
Method 1:
MPSP = [(FG x 0.052) – Gas Gradient] x TVD
MPSP = [(14.5 ppg EMW x 0.052) - 0.1 psi/ft] x 2998 TVD
MPSP = 1961 psi
Method 2:
MPSP = FPP – (Gas Gradient x TVD)
MPSP = (9.4 ppg x .052 x 7326‘ TVD) x (0.1 psi/ft x 7326’ TVD)
MPSP = 2848 psi
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17. Area of Review
There are currently no wells within a quarter mile radius of the MT7-94 wellbore.
39 500
500 1000
1000 1500
1500 2000
2000 2500
2500 3000
3000 3500
3500 8000
8000 15000
15000 31253
MT7-94_wp03 Plan Summary
MT7-94_wp03
MT7-92_wp04 70inc 3.2dls
MT7-14_wp07
MT7-GCEW1_wp01
MT7-08PB1
MT7-08
MT7-07
MT7-02
MT7-09
MT7-04
MT7-03
MT7-06MT7-06AMT7-06PB1
MT7-95_wp02
MT7-99
MT7-11
MT7-01
MT7-98
MT7-96
MT7-05
MT7-97
0
4
Dogleg Severity0 4500 9000 13500 18000 22500 27000 31500
Measured Depth
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Liner
50
50
100
100
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in]
MT7-92_wp04 70inc 3.2dls
MT7-14_wp07
MT7-GCEW1_wp01
MT7-95_wp02
MT7-99MT7-98MT7-96MT7-97
0
4500
True Vertical Depth-27000 -22500 -18000 -13500 -9000 -4500 0
Vertical Section at 153.00°
13-3/8" Surface Casing
9-5/8" Intermediate Casing7" Intermediate Liner
0
55
110
Centre to Centre Separation0 4500 9000 13500 18000 22500 27000 31500
Measured Depth
Equivalent Magnetic Distance
DDI
7.408
SURVEY PROGRAM
Date: 2023-03-27T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
38.90 1000.00 MT7-94_wp03 (MT7-94) SDI_Keeper_ADK
1000.00 4040.00 MT7-94_wp03 (MT7-94) MWD+IFR2+SAG+MS
4040.00 13449.00 MT7-94_wp03 (MT7-94) MWD+IFR2+SAG+MS
13449.00 15439.00 MT7-94_wp03 (MT7-94) MWD+IFR2+SAG+MS
15439.00 31253.26 MT7-94_wp03 (MT7-94) MWD+IFR2+SAG+MS
Surface Location
North / 5915634.39
East / 1430168.90Ground / 100.60
CASING DETAILS
TVD MD
Name
2997.90 4040.00 13-3/8" Surface Casing
7326.04 13449.00 9-5/8" Intermediate Casing
8099.18 15439.00 7" Intermediate Liner
8048.55 31253.26 4-1/2" Production Liner
Mag Model & Date: BGGM2023 01-Jul-23
Magnetic North is 13.99° East of True North (Magnetic Declination)
Mag Dip & Field Strength: 80.36° 57097.30nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation
1 38.90 0.00 0.00 38.90 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 500.00 3.00 325.00 499.91 4.29 -3.00 1.50 325.00 -5.18 Start Build 2.00
4 800.00 9.00 325.00 798.13 29.96 -20.98 2.00 0.00 -36.22 Start DLS 2.50 TFO -29.55
5 2986.92 62.61 298.06 2513.39 676.52 -1055.59 2.50 -29.55 -1082.01 Start 10234.27 hold at 2986.92 MD
6 13221.19 62.61 298.06 7222.07 4950.26 -9074.55 0.00 0.00 -8530.47 Start DLS 1.00 TFO 77.65
7 13398.54 63.00 300.00 7303.13 5026.80 -9212.47 1.00 77.65 -8661.29 Start 50.00 hold at 13398.54 MD
8 13448.54 63.00 300.00 7325.83 5049.08 -9251.05 0.00 0.00 -8698.65 Start 902.00 hold at 13448.54 MD
9 14350.54 63.00 300.00 7735.33 5450.92 -9947.07 0.00 0.00 -9372.68 Start DLS 2.88 TFO 65.68
10 15389.30 77.83 327.67 8088.70 6126.69 -10635.00 2.88 65.68 -10287.11 Start 50.00 hold at 15389.30 MD
11 15439.30 77.83 327.67 8099.24 6167.99 -10661.14 0.00 0.00 -10335.77 Start 50.00 hold at 15439.30 MD
12 15489.30 77.83 327.67 8109.79 6209.29 -10687.27 0.00 0.00 -10384.44 Start DLS 2.80 TFO 50.68
13 15701.75 81.63 332.32 8147.69 6390.26 -10791.72 2.80 50.68 -10593.10 Start 230.61 hold at 15701.75 MD
14 15932.37 81.63 332.32 8181.26 6592.31 -10897.71 0.00 0.00 -10821.24 Start DLS 2.80 TFO 4.36
15 16253.29 90.59 333.00 8203.01 6876.44 -11044.60 2.80 4.36 -11141.09 Start 14999.96 hold at 16253.29 MD
16 31253.26 90.59 333.00 8048.55 20240.79 -17854.08 0.00 0.00 -26140.26 TD at 31253.26
FORMATION TOP DETAILS
No formation data is available
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan KB (100.6 GL + 38.9 DF) @ 139.50usft
Plan View
Project: Western North Slope
Site:GMT2 Rendezvous Pad
Well: MT7-94
Wellbore: MT7-94
Design: MT7-94_wp03
-14000
0
14000
South(-)/North(+) (7000 usft/in)-28000 -14000 0 14000 28000
West(-)/East(+) (7000 usft/in)
MT7-94 Target 2 1320ft
MT7-94 Target 1 1320ft
M T 7 -9 2 _w p 04 7 0 in c 3 .2d ls
M T7 -14_w p 0 7MT7-GCEW1_wp01MT7 -0 8 P B1
M T 7-08
MT7-0 7
MT 7 -02
MT7 -09
MT7-0 4
M T 7-03
MT 7 -0 6
MT7-0
6 A
MT7-0
6
P B 1
MT7 -9 5_w p0 2
M T 7-99
MT7-1
1 MT7-01PB1MT7-0
1
M T7-98MT 7 -96MT7-0 5
M T7 -9 7
13-3/8" Surface Casing9-5/8" Intermediate Casing
7" Intermediate Liner
4-1/2" Production Liner
50010001500200025003000350040004500500055006000650070007500800080 49
M T7-9 4 _w p03
0
6000
12000True Vertical Depth (3000 usft/in)-24000 -18000 -12000 -6000 0
Vertical Section at 153.00° (3000 usft/in)
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7" Intermediate Liner
4-1/2" Production Liner
1000
20
0
0
3
0
0
0
4
0
0
05
0
0
0
6
0
0
0
7
0
0
08
0
0
0
9
0
0
0
1
0
0
0
0
1
10
0
0
1
2
0
0
0
1
3
0
0
0
1
40
0
015
00016000170001800019000200002100022000230002400025000260002700028000290003000031000MT7-94/MT7-94_wp03Start Build 1.50
Start Build 2.00
Start DLS 2.50 TFO -29.55
Start 10234.27 hold at 2986.92 MD
Start DLS 1.00 TFO 77.65
Start 50.00 hold at 13398.54 MD
Start 902.00 hold at 13448.54 MD
Start DLS 2.88 TFO 65.68
Start 50.00 hold at 15389.30 MD
Start 50.00 hold at 15439.30 MD
Start DLS 2.80 TFO 50.68
Start 230.61 hold at 15701.75 MD
Start DLS 2.80 TFO 4.36
Start 14999.96 hold at 16253.29 MD
TD at 31253.26
Section View
Project: Western North Slope
Site:GMT2 Rendezvous Pad
Well: MT7-94
Wellbore: MT7-94
Design: MT7-94_wp03
Standard Proposal Report
01 May, 2023
Plan: MT7-94_wp03
ConocoPhillips Alaska Inc_WNS
Western North Slope
GMT2 Rendezvous Pad
MT7-94
MT7-94
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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:
MT7-94
5,915,634.39 usft
1,430,168.90 usft
100.60 usftWellhead Elevation:0.00 usft
70° 10' 23.238 N
151° 41' 33.278 W
57.34 usft
105.35 usft
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
MT7-94
Model NameMagnetics
BGGM2023 7/1/2023 13.99 80.36 57,097.30
Phase:Version:
Audit Notes:
Design MT7-94_wp03
PLAN
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:38.90
153.000.000.0038.90
Depth From
(usft)
Plan Survey Tool Program
RemarksTool NameSurvey (Wellbore)
Depth To
(usft)
Date 5/1/2023
SDI_Keeper_ADK
SDI Keeper All-Attitude Drop
MT7-94_wp03 (MT7-94)38.90 1,000.001
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag
MT7-94_wp03 (MT7-94)1,000.00 4,040.002
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag
MT7-94_wp03 (MT7-94)4,040.00 13,449.003
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag
MT7-94_wp03 (MT7-94)13,449.00 15,439.004
MWD+IFR2+SAG+MS
OWSG MWD + IFR2 + Sag
MT7-94_wp03 (MT7-94)15,439.00 31,253.265
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 2
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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
0.000.000.000.000.000.0038.900.000.0038.90
0.000.000.000.000.000.00300.000.000.00300.00
325.000.001.501.50-3.004.29499.91325.003.00500.00
0.000.002.002.00-20.9829.96798.13325.009.00800.00
-29.55-1.232.452.50-1,055.59676.522,513.39298.0662.612,986.92
0.000.000.000.00-9,074.554,950.267,222.07298.0662.6113,221.19
77.651.100.221.00-9,212.475,026.807,303.13300.0063.0013,398.54
0.000.000.000.00-9,251.055,049.087,325.83300.0063.0013,448.54
0.000.000.000.00-9,947.075,450.927,735.33300.0063.0014,350.54
65.682.661.432.88-10,635.006,126.698,088.70327.6777.8315,389.30
0.000.000.000.00-10,661.146,167.998,099.24327.6777.8315,439.30
0.000.000.000.00-10,687.276,209.298,109.79327.6777.8315,489.30
50.682.191.792.80-10,791.726,390.268,147.69332.3281.6315,701.75
0.000.000.000.00-10,897.716,592.318,181.26332.3281.6315,932.37
4.360.212.792.80-11,044.606,876.448,203.01333.0090.5916,253.29 MT7-94 Target 1 13
0.000.000.000.00-17,854.0820,240.798,048.55333.0090.5931,253.26 MT7-94 Target 2 13
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 3
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
100.00 0.00 0.00 100.00 0.00 0.000.00 0.00 0.00 0.00
200.00 0.00 0.00 200.00 0.00 0.000.00 0.00 0.00 0.00
300.00 0.00 0.00 300.00 0.00 0.000.00 0.00 0.00 0.00
Start Build 1.50
400.00 1.50 325.00 399.99 -1.30 1.501.07 -0.75 1.50 0.00
500.00 3.00 325.00 499.91 -5.18 1.504.29 -3.00 1.50 0.00
Start Build 2.00
600.00 5.00 325.00 599.66 -12.09 2.0010.00 -7.00 2.00 0.00
700.00 7.00 325.00 699.11 -22.44 2.0018.56 -13.00 2.00 0.00
800.00 9.00 325.00 798.13 -36.22 2.0029.96 -20.98 2.00 0.00
Start DLS 2.50 TFO -29.55
900.00 11.24 318.67 896.57 -53.42 2.5043.69 -31.91 2.24 -6.33
1,000.00 13.57 314.45 994.23 -73.99 2.5059.23 -46.72 2.33 -4.22
1,100.00 15.96 311.46 1,090.92 -97.90 2.5076.55 -65.41 2.38 -2.99
1,200.00 18.37 309.23 1,186.46 -125.11 2.5095.62 -87.91 2.41 -2.23
1,300.00 20.80 307.51 1,280.67 -155.56 2.50116.40 -114.21 2.43 -1.72
1,400.00 23.25 306.13 1,373.37 -189.20 2.50138.85 -144.24 2.45 -1.38
1,500.00 25.70 305.01 1,464.38 -225.96 2.50162.93 -177.94 2.46 -1.13
1,600.00 28.17 304.07 1,553.52 -265.77 2.50188.60 -215.26 2.46 -0.94
1,700.00 30.64 303.26 1,640.63 -308.56 2.50215.80 -256.12 2.47 -0.80
1,800.00 33.11 302.57 1,725.55 -354.24 2.50244.48 -300.45 2.47 -0.69
1,900.00 35.59 301.97 1,808.11 -402.73 2.50274.59 -348.16 2.48 -0.61
2,000.00 38.06 301.43 1,888.15 -453.93 2.50306.08 -399.16 2.48 -0.54
2,100.00 40.55 300.95 1,965.52 -507.75 2.50338.87 -453.35 2.48 -0.48
2,200.00 43.03 300.51 2,040.08 -564.09 2.50372.91 -510.62 2.48 -0.43
2,300.00 45.51 300.12 2,111.68 -622.83 2.50408.14 -570.88 2.48 -0.40
2,400.00 48.00 299.75 2,180.18 -683.87 2.50444.48 -634.01 2.49 -0.36
2,500.00 50.49 299.42 2,245.46 -747.09 2.50481.87 -699.88 2.49 -0.34
2,600.00 52.97 299.10 2,307.39 -812.37 2.50520.24 -768.37 2.49 -0.31
2,700.00 55.46 298.81 2,365.86 -879.58 2.50559.51 -839.35 2.49 -0.29
2,800.00 57.95 298.53 2,420.74 -948.61 2.50599.61 -912.68 2.49 -0.28
2,900.00 60.44 298.27 2,471.95 -1,019.30 2.50640.46 -988.23 2.49 -0.26
2,986.92 62.61 298.06 2,513.39 -1,082.01 2.50676.52 -1,055.59 2.49 -0.25
Start 10234.27 hold at 2986.92 MD
3,000.00 62.61 298.06 2,519.41 -1,091.53 0.00681.99 -1,065.83 0.00 0.00
3,100.00 62.61 298.06 2,565.41 -1,164.31 0.00723.74 -1,144.19 0.00 0.00
3,200.00 62.61 298.06 2,611.42 -1,237.09 0.00765.50 -1,222.54 0.00 0.00
3,300.00 62.61 298.06 2,657.43 -1,309.87 0.00807.26 -1,300.90 0.00 0.00
3,400.00 62.61 298.06 2,703.44 -1,382.65 0.00849.02 -1,379.25 0.00 0.00
3,500.00 62.61 298.06 2,749.45 -1,455.43 0.00890.78 -1,457.60 0.00 0.00
3,600.00 62.61 298.06 2,795.46 -1,528.21 0.00932.54 -1,535.96 0.00 0.00
3,700.00 62.61 298.06 2,841.47 -1,600.99 0.00974.30 -1,614.31 0.00 0.00
3,800.00 62.61 298.06 2,887.48 -1,673.77 0.001,016.06 -1,692.67 0.00 0.00
3,900.00 62.61 298.06 2,933.49 -1,746.55 0.001,057.82 -1,771.02 0.00 0.00
4,000.00 62.61 298.06 2,979.49 -1,819.33 0.001,099.58 -1,849.38 0.00 0.00
4,040.00 62.61 298.06 2,997.90 -1,848.44 0.001,116.28 -1,880.72 0.00 0.00
13-3/8" Surface Casing
4,100.00 62.61 298.06 3,025.50 -1,892.11 0.001,141.33 -1,927.73 0.00 0.00
4,200.00 62.61 298.06 3,071.51 -1,964.89 0.001,183.09 -2,006.08 0.00 0.00
4,300.00 62.61 298.06 3,117.52 -2,037.67 0.001,224.85 -2,084.44 0.00 0.00
4,400.00 62.61 298.06 3,163.53 -2,110.45 0.001,266.61 -2,162.79 0.00 0.00
4,500.00 62.61 298.06 3,209.54 -2,183.23 0.001,308.37 -2,241.15 0.00 0.00
4,600.00 62.61 298.06 3,255.55 -2,256.01 0.001,350.13 -2,319.50 0.00 0.00
4,700.00 62.61 298.06 3,301.56 -2,328.79 0.001,391.89 -2,397.85 0.00 0.00
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 4
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
4,800.00 62.61 298.06 3,347.57 -2,401.56 0.001,433.65 -2,476.21 0.00 0.00
4,900.00 62.61 298.06 3,393.58 -2,474.34 0.001,475.41 -2,554.56 0.00 0.00
5,000.00 62.61 298.06 3,439.58 -2,547.12 0.001,517.17 -2,632.92 0.00 0.00
5,100.00 62.61 298.06 3,485.59 -2,619.90 0.001,558.93 -2,711.27 0.00 0.00
5,200.00 62.61 298.06 3,531.60 -2,692.68 0.001,600.68 -2,789.62 0.00 0.00
5,300.00 62.61 298.06 3,577.61 -2,765.46 0.001,642.44 -2,867.98 0.00 0.00
5,400.00 62.61 298.06 3,623.62 -2,838.24 0.001,684.20 -2,946.33 0.00 0.00
5,500.00 62.61 298.06 3,669.63 -2,911.02 0.001,725.96 -3,024.69 0.00 0.00
5,600.00 62.61 298.06 3,715.64 -2,983.80 0.001,767.72 -3,103.04 0.00 0.00
5,700.00 62.61 298.06 3,761.65 -3,056.58 0.001,809.48 -3,181.39 0.00 0.00
5,800.00 62.61 298.06 3,807.66 -3,129.36 0.001,851.24 -3,259.75 0.00 0.00
5,900.00 62.61 298.06 3,853.66 -3,202.14 0.001,893.00 -3,338.10 0.00 0.00
6,000.00 62.61 298.06 3,899.67 -3,274.92 0.001,934.76 -3,416.46 0.00 0.00
6,100.00 62.61 298.06 3,945.68 -3,347.70 0.001,976.52 -3,494.81 0.00 0.00
6,200.00 62.61 298.06 3,991.69 -3,420.48 0.002,018.28 -3,573.16 0.00 0.00
6,300.00 62.61 298.06 4,037.70 -3,493.26 0.002,060.03 -3,651.52 0.00 0.00
6,400.00 62.61 298.06 4,083.71 -3,566.04 0.002,101.79 -3,729.87 0.00 0.00
6,500.00 62.61 298.06 4,129.72 -3,638.82 0.002,143.55 -3,808.23 0.00 0.00
6,600.00 62.61 298.06 4,175.73 -3,711.60 0.002,185.31 -3,886.58 0.00 0.00
6,700.00 62.61 298.06 4,221.74 -3,784.38 0.002,227.07 -3,964.93 0.00 0.00
6,800.00 62.61 298.06 4,267.75 -3,857.16 0.002,268.83 -4,043.29 0.00 0.00
6,900.00 62.61 298.06 4,313.75 -3,929.94 0.002,310.59 -4,121.64 0.00 0.00
7,000.00 62.61 298.06 4,359.76 -4,002.72 0.002,352.35 -4,200.00 0.00 0.00
7,100.00 62.61 298.06 4,405.77 -4,075.50 0.002,394.11 -4,278.35 0.00 0.00
7,200.00 62.61 298.06 4,451.78 -4,148.28 0.002,435.87 -4,356.71 0.00 0.00
7,300.00 62.61 298.06 4,497.79 -4,221.05 0.002,477.62 -4,435.06 0.00 0.00
7,400.00 62.61 298.06 4,543.80 -4,293.83 0.002,519.38 -4,513.41 0.00 0.00
7,500.00 62.61 298.06 4,589.81 -4,366.61 0.002,561.14 -4,591.77 0.00 0.00
7,600.00 62.61 298.06 4,635.82 -4,439.39 0.002,602.90 -4,670.12 0.00 0.00
7,700.00 62.61 298.06 4,681.83 -4,512.17 0.002,644.66 -4,748.48 0.00 0.00
7,800.00 62.61 298.06 4,727.83 -4,584.95 0.002,686.42 -4,826.83 0.00 0.00
7,900.00 62.61 298.06 4,773.84 -4,657.73 0.002,728.18 -4,905.18 0.00 0.00
8,000.00 62.61 298.06 4,819.85 -4,730.51 0.002,769.94 -4,983.54 0.00 0.00
8,100.00 62.61 298.06 4,865.86 -4,803.29 0.002,811.70 -5,061.89 0.00 0.00
8,200.00 62.61 298.06 4,911.87 -4,876.07 0.002,853.46 -5,140.25 0.00 0.00
8,300.00 62.61 298.06 4,957.88 -4,948.85 0.002,895.22 -5,218.60 0.00 0.00
8,400.00 62.61 298.06 5,003.89 -5,021.63 0.002,936.97 -5,296.95 0.00 0.00
8,500.00 62.61 298.06 5,049.90 -5,094.41 0.002,978.73 -5,375.31 0.00 0.00
8,600.00 62.61 298.06 5,095.91 -5,167.19 0.003,020.49 -5,453.66 0.00 0.00
8,700.00 62.61 298.06 5,141.91 -5,239.97 0.003,062.25 -5,532.02 0.00 0.00
8,800.00 62.61 298.06 5,187.92 -5,312.75 0.003,104.01 -5,610.37 0.00 0.00
8,900.00 62.61 298.06 5,233.93 -5,385.53 0.003,145.77 -5,688.72 0.00 0.00
9,000.00 62.61 298.06 5,279.94 -5,458.31 0.003,187.53 -5,767.08 0.00 0.00
9,100.00 62.61 298.06 5,325.95 -5,531.09 0.003,229.29 -5,845.43 0.00 0.00
9,200.00 62.61 298.06 5,371.96 -5,603.87 0.003,271.05 -5,923.79 0.00 0.00
9,300.00 62.61 298.06 5,417.97 -5,676.65 0.003,312.81 -6,002.14 0.00 0.00
9,400.00 62.61 298.06 5,463.98 -5,749.43 0.003,354.57 -6,080.49 0.00 0.00
9,500.00 62.61 298.06 5,509.99 -5,822.21 0.003,396.32 -6,158.85 0.00 0.00
9,600.00 62.61 298.06 5,556.00 -5,894.99 0.003,438.08 -6,237.20 0.00 0.00
9,700.00 62.61 298.06 5,602.00 -5,967.76 0.003,479.84 -6,315.56 0.00 0.00
9,800.00 62.61 298.06 5,648.01 -6,040.54 0.003,521.60 -6,393.91 0.00 0.00
9,900.00 62.61 298.06 5,694.02 -6,113.32 0.003,563.36 -6,472.26 0.00 0.00
10,000.00 62.61 298.06 5,740.03 -6,186.10 0.003,605.12 -6,550.62 0.00 0.00
10,100.00 62.61 298.06 5,786.04 -6,258.88 0.003,646.88 -6,628.97 0.00 0.00
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 5
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
10,200.00 62.61 298.06 5,832.05 -6,331.66 0.003,688.64 -6,707.33 0.00 0.00
10,300.00 62.61 298.06 5,878.06 -6,404.44 0.003,730.40 -6,785.68 0.00 0.00
10,400.00 62.61 298.06 5,924.07 -6,477.22 0.003,772.16 -6,864.04 0.00 0.00
10,500.00 62.61 298.06 5,970.08 -6,550.00 0.003,813.91 -6,942.39 0.00 0.00
10,600.00 62.61 298.06 6,016.08 -6,622.78 0.003,855.67 -7,020.74 0.00 0.00
10,700.00 62.61 298.06 6,062.09 -6,695.56 0.003,897.43 -7,099.10 0.00 0.00
10,800.00 62.61 298.06 6,108.10 -6,768.34 0.003,939.19 -7,177.45 0.00 0.00
10,900.00 62.61 298.06 6,154.11 -6,841.12 0.003,980.95 -7,255.81 0.00 0.00
11,000.00 62.61 298.06 6,200.12 -6,913.90 0.004,022.71 -7,334.16 0.00 0.00
11,100.00 62.61 298.06 6,246.13 -6,986.68 0.004,064.47 -7,412.51 0.00 0.00
11,200.00 62.61 298.06 6,292.14 -7,059.46 0.004,106.23 -7,490.87 0.00 0.00
11,300.00 62.61 298.06 6,338.15 -7,132.24 0.004,147.99 -7,569.22 0.00 0.00
11,400.00 62.61 298.06 6,384.16 -7,205.02 0.004,189.75 -7,647.58 0.00 0.00
11,500.00 62.61 298.06 6,430.17 -7,277.80 0.004,231.51 -7,725.93 0.00 0.00
11,600.00 62.61 298.06 6,476.17 -7,350.58 0.004,273.26 -7,804.28 0.00 0.00
11,700.00 62.61 298.06 6,522.18 -7,423.36 0.004,315.02 -7,882.64 0.00 0.00
11,800.00 62.61 298.06 6,568.19 -7,496.14 0.004,356.78 -7,960.99 0.00 0.00
11,900.00 62.61 298.06 6,614.20 -7,568.92 0.004,398.54 -8,039.35 0.00 0.00
12,000.00 62.61 298.06 6,660.21 -7,641.70 0.004,440.30 -8,117.70 0.00 0.00
12,100.00 62.61 298.06 6,706.22 -7,714.48 0.004,482.06 -8,196.05 0.00 0.00
12,200.00 62.61 298.06 6,752.23 -7,787.25 0.004,523.82 -8,274.41 0.00 0.00
12,300.00 62.61 298.06 6,798.24 -7,860.03 0.004,565.58 -8,352.76 0.00 0.00
12,400.00 62.61 298.06 6,844.25 -7,932.81 0.004,607.34 -8,431.12 0.00 0.00
12,500.00 62.61 298.06 6,890.25 -8,005.59 0.004,649.10 -8,509.47 0.00 0.00
12,600.00 62.61 298.06 6,936.26 -8,078.37 0.004,690.85 -8,587.82 0.00 0.00
12,700.00 62.61 298.06 6,982.27 -8,151.15 0.004,732.61 -8,666.18 0.00 0.00
12,800.00 62.61 298.06 7,028.28 -8,223.93 0.004,774.37 -8,744.53 0.00 0.00
12,900.00 62.61 298.06 7,074.29 -8,296.71 0.004,816.13 -8,822.89 0.00 0.00
13,000.00 62.61 298.06 7,120.30 -8,369.49 0.004,857.89 -8,901.24 0.00 0.00
13,100.00 62.61 298.06 7,166.31 -8,442.27 0.004,899.65 -8,979.59 0.00 0.00
13,200.00 62.61 298.06 7,212.32 -8,515.05 0.004,941.41 -9,057.95 0.00 0.00
13,221.19 62.61 298.06 7,222.07 -8,530.47 0.004,950.26 -9,074.55 0.00 0.00
Start DLS 1.00 TFO 77.65
13,300.00 62.78 298.92 7,258.22 -8,588.18 1.004,983.66 -9,136.10 0.22 1.10
13,398.54 63.00 300.00 7,303.13 -8,661.29 1.005,026.80 -9,212.47 0.22 1.09
Start 50.00 hold at 13398.54 MD
13,400.00 63.00 300.00 7,303.79 -8,662.37 0.005,027.45 -9,213.59 0.00 0.00
13,448.54 63.00 300.00 7,325.83 -8,698.65 0.005,049.08 -9,251.05 0.00 0.00
Start 902.00 hold at 13448.54 MD
13,449.00 63.00 300.00 7,326.04 -8,698.99 0.005,049.28 -9,251.40 0.00 0.00
9-5/8" Intermediate Casing
13,500.00 63.00 300.00 7,349.19 -8,737.10 0.005,072.00 -9,290.76 0.00 0.00
13,600.00 63.00 300.00 7,394.59 -8,811.83 0.005,116.55 -9,367.92 0.00 0.00
13,700.00 63.00 300.00 7,439.99 -8,886.55 0.005,161.10 -9,445.09 0.00 0.00
13,800.00 63.00 300.00 7,485.39 -8,961.28 0.005,205.65 -9,522.25 0.00 0.00
13,900.00 63.00 300.00 7,530.79 -9,036.01 0.005,250.20 -9,599.41 0.00 0.00
14,000.00 63.00 300.00 7,576.19 -9,110.73 0.005,294.75 -9,676.58 0.00 0.00
14,100.00 63.00 300.00 7,621.59 -9,185.46 0.005,339.30 -9,753.74 0.00 0.00
14,200.00 63.00 300.00 7,666.98 -9,260.18 0.005,383.85 -9,830.90 0.00 0.00
14,300.00 63.00 300.00 7,712.38 -9,334.91 0.005,428.40 -9,908.07 0.00 0.00
14,350.54 63.00 300.00 7,735.33 -9,372.68 0.005,450.92 -9,947.07 0.00 0.00
Start DLS 2.88 TFO 65.68
14,400.00 63.59 301.45 7,757.55 -9,410.03 2.885,473.49 -9,985.04 1.20 2.93
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 6
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
14,500.00 64.84 304.33 7,801.06 -9,487.92 2.885,522.39 -10,060.64 1.24 2.88
14,600.00 66.13 307.15 7,842.56 -9,568.79 2.885,575.53 -10,134.47 1.30 2.82
14,700.00 67.48 309.91 7,881.95 -9,652.44 2.885,632.79 -10,206.36 1.35 2.76
14,800.00 68.87 312.62 7,919.13 -9,738.67 2.885,694.03 -10,276.12 1.39 2.71
14,900.00 70.31 315.28 7,954.00 -9,827.26 2.885,759.08 -10,343.57 1.44 2.66
15,000.00 71.79 317.89 7,986.48 -9,917.97 2.885,827.78 -10,408.55 1.47 2.61
15,100.00 73.30 320.46 8,016.49 -10,010.60 2.885,899.96 -10,470.90 1.51 2.57
15,200.00 74.84 322.99 8,043.95 -10,104.89 2.885,975.45 -10,530.45 1.54 2.53
15,300.00 76.40 325.48 8,068.78 -10,200.61 2.886,054.04 -10,587.05 1.57 2.49
15,389.30 77.83 327.67 8,088.70 -10,287.11 2.886,126.69 -10,635.00 1.59 2.46
Start 50.00 hold at 15389.30 MD
15,400.00 77.83 327.67 8,090.96 -10,297.52 0.006,135.53 -10,640.59 0.00 0.00
15,439.00 77.83 327.67 8,099.18 -10,335.48 0.006,167.74 -10,660.98 0.00 0.00
7" Intermediate Liner
15,439.30 77.83 327.67 8,099.24 -10,335.77 0.006,167.99 -10,661.14 0.00 0.00
Start 50.00 hold at 15439.30 MD
15,489.30 77.83 327.67 8,109.79 -10,384.44 0.006,209.29 -10,687.27 0.00 0.00
Start DLS 2.80 TFO 50.68
15,500.00 78.02 327.91 8,112.03 -10,394.86 2.806,218.14 -10,692.85 1.78 2.21
15,600.00 79.80 330.11 8,131.27 -10,492.74 2.806,302.26 -10,743.37 1.78 2.20
15,700.00 81.60 332.28 8,147.43 -10,591.37 2.806,388.72 -10,790.91 1.80 2.17
15,701.75 81.63 332.32 8,147.69 -10,593.10 2.806,390.26 -10,791.72 1.81 2.16
Start 230.61 hold at 15701.75 MD
15,800.00 81.63 332.32 8,161.99 -10,690.29 0.006,476.34 -10,836.87 0.00 0.00
15,900.00 81.63 332.32 8,176.55 -10,789.22 0.006,563.95 -10,882.83 0.00 0.00
15,932.37 81.63 332.32 8,181.26 -10,821.24 0.006,592.31 -10,897.71 0.00 0.00
Start DLS 2.80 TFO 4.36
16,000.00 83.52 332.46 8,190.00 -10,888.30 2.806,651.73 -10,928.78 2.79 0.21
16,100.00 86.31 332.68 8,198.86 -10,987.89 2.806,740.13 -10,974.66 2.79 0.21
16,200.00 89.10 332.89 8,202.87 -11,087.80 2.806,828.98 -11,020.36 2.79 0.21
16,253.29 90.59 333.00 8,203.01 -11,141.09 2.806,876.44 -11,044.60 2.79 0.21
Start 14999.96 hold at 16253.29 MD
16,300.00 90.59 333.00 8,202.53 -11,187.80 0.006,918.05 -11,065.80 0.00 0.00
16,400.00 90.59 333.00 8,201.50 -11,287.79 0.007,007.15 -11,111.20 0.00 0.00
16,500.00 90.59 333.00 8,200.47 -11,387.79 0.007,096.25 -11,156.59 0.00 0.00
16,600.00 90.59 333.00 8,199.44 -11,487.78 0.007,185.34 -11,201.99 0.00 0.00
16,700.00 90.59 333.00 8,198.41 -11,587.78 0.007,274.44 -11,247.39 0.00 0.00
16,800.00 90.59 333.00 8,197.38 -11,687.77 0.007,363.53 -11,292.78 0.00 0.00
16,900.00 90.59 333.00 8,196.35 -11,787.77 0.007,452.63 -11,338.18 0.00 0.00
17,000.00 90.59 333.00 8,195.32 -11,887.76 0.007,541.73 -11,383.58 0.00 0.00
17,100.00 90.59 333.00 8,194.29 -11,987.76 0.007,630.82 -11,428.97 0.00 0.00
17,200.00 90.59 333.00 8,193.26 -12,087.75 0.007,719.92 -11,474.37 0.00 0.00
17,300.00 90.59 333.00 8,192.23 -12,187.75 0.007,809.01 -11,519.77 0.00 0.00
17,400.00 90.59 333.00 8,191.20 -12,287.74 0.007,898.11 -11,565.16 0.00 0.00
17,500.00 90.59 333.00 8,190.17 -12,387.74 0.007,987.20 -11,610.56 0.00 0.00
17,600.00 90.59 333.00 8,189.14 -12,487.73 0.008,076.30 -11,655.96 0.00 0.00
17,700.00 90.59 333.00 8,188.11 -12,587.72 0.008,165.40 -11,701.35 0.00 0.00
17,800.00 90.59 333.00 8,187.08 -12,687.72 0.008,254.49 -11,746.75 0.00 0.00
17,900.00 90.59 333.00 8,186.05 -12,787.71 0.008,343.59 -11,792.15 0.00 0.00
18,000.00 90.59 333.00 8,185.02 -12,887.71 0.008,432.68 -11,837.54 0.00 0.00
18,100.00 90.59 333.00 8,183.99 -12,987.70 0.008,521.78 -11,882.94 0.00 0.00
18,200.00 90.59 333.00 8,182.96 -13,087.70 0.008,610.88 -11,928.34 0.00 0.00
18,300.00 90.59 333.00 8,181.93 -13,187.69 0.008,699.97 -11,973.73 0.00 0.00
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 7
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
18,400.00 90.59 333.00 8,180.90 -13,287.69 0.008,789.07 -12,019.13 0.00 0.00
18,500.00 90.59 333.00 8,179.88 -13,387.68 0.008,878.16 -12,064.53 0.00 0.00
18,600.00 90.59 333.00 8,178.85 -13,487.68 0.008,967.26 -12,109.92 0.00 0.00
18,700.00 90.59 333.00 8,177.82 -13,587.67 0.009,056.36 -12,155.32 0.00 0.00
18,800.00 90.59 333.00 8,176.79 -13,687.67 0.009,145.45 -12,200.72 0.00 0.00
18,900.00 90.59 333.00 8,175.76 -13,787.66 0.009,234.55 -12,246.11 0.00 0.00
19,000.00 90.59 333.00 8,174.73 -13,887.66 0.009,323.64 -12,291.51 0.00 0.00
19,100.00 90.59 333.00 8,173.70 -13,987.65 0.009,412.74 -12,336.91 0.00 0.00
19,200.00 90.59 333.00 8,172.67 -14,087.65 0.009,501.84 -12,382.30 0.00 0.00
19,300.00 90.59 333.00 8,171.64 -14,187.64 0.009,590.93 -12,427.70 0.00 0.00
19,400.00 90.59 333.00 8,170.61 -14,287.63 0.009,680.03 -12,473.10 0.00 0.00
19,500.00 90.59 333.00 8,169.58 -14,387.63 0.009,769.12 -12,518.49 0.00 0.00
19,600.00 90.59 333.00 8,168.55 -14,487.62 0.009,858.22 -12,563.89 0.00 0.00
19,700.00 90.59 333.00 8,167.52 -14,587.62 0.009,947.31 -12,609.29 0.00 0.00
19,800.00 90.59 333.00 8,166.49 -14,687.61 0.0010,036.41 -12,654.68 0.00 0.00
19,900.00 90.59 333.00 8,165.46 -14,787.61 0.0010,125.51 -12,700.08 0.00 0.00
20,000.00 90.59 333.00 8,164.43 -14,887.60 0.0010,214.60 -12,745.48 0.00 0.00
20,100.00 90.59 333.00 8,163.40 -14,987.60 0.0010,303.70 -12,790.87 0.00 0.00
20,200.00 90.59 333.00 8,162.37 -15,087.59 0.0010,392.79 -12,836.27 0.00 0.00
20,300.00 90.59 333.00 8,161.34 -15,187.59 0.0010,481.89 -12,881.67 0.00 0.00
20,400.00 90.59 333.00 8,160.31 -15,287.58 0.0010,570.99 -12,927.06 0.00 0.00
20,500.00 90.59 333.00 8,159.28 -15,387.58 0.0010,660.08 -12,972.46 0.00 0.00
20,600.00 90.59 333.00 8,158.25 -15,487.57 0.0010,749.18 -13,017.86 0.00 0.00
20,700.00 90.59 333.00 8,157.22 -15,587.57 0.0010,838.27 -13,063.25 0.00 0.00
20,800.00 90.59 333.00 8,156.19 -15,687.56 0.0010,927.37 -13,108.65 0.00 0.00
20,900.00 90.59 333.00 8,155.16 -15,787.56 0.0011,016.47 -13,154.05 0.00 0.00
21,000.00 90.59 333.00 8,154.13 -15,887.55 0.0011,105.56 -13,199.44 0.00 0.00
21,100.00 90.59 333.00 8,153.10 -15,987.54 0.0011,194.66 -13,244.84 0.00 0.00
21,200.00 90.59 333.00 8,152.07 -16,087.54 0.0011,283.75 -13,290.24 0.00 0.00
21,300.00 90.59 333.00 8,151.04 -16,187.53 0.0011,372.85 -13,335.63 0.00 0.00
21,400.00 90.59 333.00 8,150.01 -16,287.53 0.0011,461.95 -13,381.03 0.00 0.00
21,500.00 90.59 333.00 8,148.98 -16,387.52 0.0011,551.04 -13,426.43 0.00 0.00
21,600.00 90.59 333.00 8,147.95 -16,487.52 0.0011,640.14 -13,471.82 0.00 0.00
21,700.00 90.59 333.00 8,146.92 -16,587.51 0.0011,729.23 -13,517.22 0.00 0.00
21,800.00 90.59 333.00 8,145.89 -16,687.51 0.0011,818.33 -13,562.62 0.00 0.00
21,900.00 90.59 333.00 8,144.86 -16,787.50 0.0011,907.42 -13,608.01 0.00 0.00
22,000.00 90.59 333.00 8,143.83 -16,887.50 0.0011,996.52 -13,653.41 0.00 0.00
22,100.00 90.59 333.00 8,142.80 -16,987.49 0.0012,085.62 -13,698.81 0.00 0.00
22,200.00 90.59 333.00 8,141.77 -17,087.49 0.0012,174.71 -13,744.20 0.00 0.00
22,300.00 90.59 333.00 8,140.75 -17,187.48 0.0012,263.81 -13,789.60 0.00 0.00
22,400.00 90.59 333.00 8,139.72 -17,287.48 0.0012,352.90 -13,835.00 0.00 0.00
22,500.00 90.59 333.00 8,138.69 -17,387.47 0.0012,442.00 -13,880.39 0.00 0.00
22,600.00 90.59 333.00 8,137.66 -17,487.47 0.0012,531.10 -13,925.79 0.00 0.00
22,700.00 90.59 333.00 8,136.63 -17,587.46 0.0012,620.19 -13,971.19 0.00 0.00
22,800.00 90.59 333.00 8,135.60 -17,687.45 0.0012,709.29 -14,016.58 0.00 0.00
22,900.00 90.59 333.00 8,134.57 -17,787.45 0.0012,798.38 -14,061.98 0.00 0.00
23,000.00 90.59 333.00 8,133.54 -17,887.44 0.0012,887.48 -14,107.38 0.00 0.00
23,100.00 90.59 333.00 8,132.51 -17,987.44 0.0012,976.58 -14,152.77 0.00 0.00
23,200.00 90.59 333.00 8,131.48 -18,087.43 0.0013,065.67 -14,198.17 0.00 0.00
23,300.00 90.59 333.00 8,130.45 -18,187.43 0.0013,154.77 -14,243.57 0.00 0.00
23,400.00 90.59 333.00 8,129.42 -18,287.42 0.0013,243.86 -14,288.96 0.00 0.00
23,500.00 90.59 333.00 8,128.39 -18,387.42 0.0013,332.96 -14,334.36 0.00 0.00
23,600.00 90.59 333.00 8,127.36 -18,487.41 0.0013,422.06 -14,379.76 0.00 0.00
23,700.00 90.59 333.00 8,126.33 -18,587.41 0.0013,511.15 -14,425.15 0.00 0.00
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 8
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
23,800.00 90.59 333.00 8,125.30 -18,687.40 0.0013,600.25 -14,470.55 0.00 0.00
23,900.00 90.59 333.00 8,124.27 -18,787.40 0.0013,689.34 -14,515.95 0.00 0.00
24,000.00 90.59 333.00 8,123.24 -18,887.39 0.0013,778.44 -14,561.34 0.00 0.00
24,100.00 90.59 333.00 8,122.21 -18,987.39 0.0013,867.53 -14,606.74 0.00 0.00
24,200.00 90.59 333.00 8,121.18 -19,087.38 0.0013,956.63 -14,652.14 0.00 0.00
24,300.00 90.59 333.00 8,120.15 -19,187.38 0.0014,045.73 -14,697.53 0.00 0.00
24,400.00 90.59 333.00 8,119.12 -19,287.37 0.0014,134.82 -14,742.93 0.00 0.00
24,500.00 90.59 333.00 8,118.09 -19,387.36 0.0014,223.92 -14,788.33 0.00 0.00
24,600.00 90.59 333.00 8,117.06 -19,487.36 0.0014,313.01 -14,833.72 0.00 0.00
24,700.00 90.59 333.00 8,116.03 -19,587.35 0.0014,402.11 -14,879.12 0.00 0.00
24,800.00 90.59 333.00 8,115.00 -19,687.35 0.0014,491.21 -14,924.52 0.00 0.00
24,900.00 90.59 333.00 8,113.97 -19,787.34 0.0014,580.30 -14,969.91 0.00 0.00
25,000.00 90.59 333.00 8,112.94 -19,887.34 0.0014,669.40 -15,015.31 0.00 0.00
25,100.00 90.59 333.00 8,111.91 -19,987.33 0.0014,758.49 -15,060.71 0.00 0.00
25,200.00 90.59 333.00 8,110.88 -20,087.33 0.0014,847.59 -15,106.10 0.00 0.00
25,300.00 90.59 333.00 8,109.85 -20,187.32 0.0014,936.69 -15,151.50 0.00 0.00
25,400.00 90.59 333.00 8,108.82 -20,287.32 0.0015,025.78 -15,196.90 0.00 0.00
25,500.00 90.59 333.00 8,107.79 -20,387.31 0.0015,114.88 -15,242.29 0.00 0.00
25,600.00 90.59 333.00 8,106.76 -20,487.31 0.0015,203.97 -15,287.69 0.00 0.00
25,700.00 90.59 333.00 8,105.73 -20,587.30 0.0015,293.07 -15,333.09 0.00 0.00
25,800.00 90.59 333.00 8,104.70 -20,687.30 0.0015,382.17 -15,378.48 0.00 0.00
25,900.00 90.59 333.00 8,103.67 -20,787.29 0.0015,471.26 -15,423.88 0.00 0.00
26,000.00 90.59 333.00 8,102.64 -20,887.29 0.0015,560.36 -15,469.28 0.00 0.00
26,100.00 90.59 333.00 8,101.62 -20,987.28 0.0015,649.45 -15,514.67 0.00 0.00
26,200.00 90.59 333.00 8,100.59 -21,087.27 0.0015,738.55 -15,560.07 0.00 0.00
26,300.00 90.59 333.00 8,099.56 -21,187.27 0.0015,827.64 -15,605.47 0.00 0.00
26,400.00 90.59 333.00 8,098.53 -21,287.26 0.0015,916.74 -15,650.86 0.00 0.00
26,500.00 90.59 333.00 8,097.50 -21,387.26 0.0016,005.84 -15,696.26 0.00 0.00
26,600.00 90.59 333.00 8,096.47 -21,487.25 0.0016,094.93 -15,741.66 0.00 0.00
26,700.00 90.59 333.00 8,095.44 -21,587.25 0.0016,184.03 -15,787.05 0.00 0.00
26,800.00 90.59 333.00 8,094.41 -21,687.24 0.0016,273.12 -15,832.45 0.00 0.00
26,900.00 90.59 333.00 8,093.38 -21,787.24 0.0016,362.22 -15,877.85 0.00 0.00
27,000.00 90.59 333.00 8,092.35 -21,887.23 0.0016,451.32 -15,923.24 0.00 0.00
27,100.00 90.59 333.00 8,091.32 -21,987.23 0.0016,540.41 -15,968.64 0.00 0.00
27,200.00 90.59 333.00 8,090.29 -22,087.22 0.0016,629.51 -16,014.04 0.00 0.00
27,300.00 90.59 333.00 8,089.26 -22,187.22 0.0016,718.60 -16,059.43 0.00 0.00
27,400.00 90.59 333.00 8,088.23 -22,287.21 0.0016,807.70 -16,104.83 0.00 0.00
27,500.00 90.59 333.00 8,087.20 -22,387.21 0.0016,896.80 -16,150.23 0.00 0.00
27,600.00 90.59 333.00 8,086.17 -22,487.20 0.0016,985.89 -16,195.62 0.00 0.00
27,700.00 90.59 333.00 8,085.14 -22,587.19 0.0017,074.99 -16,241.02 0.00 0.00
27,800.00 90.59 333.00 8,084.11 -22,687.19 0.0017,164.08 -16,286.42 0.00 0.00
27,900.00 90.59 333.00 8,083.08 -22,787.18 0.0017,253.18 -16,331.81 0.00 0.00
28,000.00 90.59 333.00 8,082.05 -22,887.18 0.0017,342.28 -16,377.21 0.00 0.00
28,100.00 90.59 333.00 8,081.02 -22,987.17 0.0017,431.37 -16,422.61 0.00 0.00
28,200.00 90.59 333.00 8,079.99 -23,087.17 0.0017,520.47 -16,468.00 0.00 0.00
28,300.00 90.59 333.00 8,078.96 -23,187.16 0.0017,609.56 -16,513.40 0.00 0.00
28,400.00 90.59 333.00 8,077.93 -23,287.16 0.0017,698.66 -16,558.80 0.00 0.00
28,500.00 90.59 333.00 8,076.90 -23,387.15 0.0017,787.76 -16,604.19 0.00 0.00
28,600.00 90.59 333.00 8,075.87 -23,487.15 0.0017,876.85 -16,649.59 0.00 0.00
28,700.00 90.59 333.00 8,074.84 -23,587.14 0.0017,965.95 -16,694.99 0.00 0.00
28,800.00 90.59 333.00 8,073.81 -23,687.14 0.0018,055.04 -16,740.38 0.00 0.00
28,900.00 90.59 333.00 8,072.78 -23,787.13 0.0018,144.14 -16,785.78 0.00 0.00
29,000.00 90.59 333.00 8,071.75 -23,887.13 0.0018,233.23 -16,831.18 0.00 0.00
29,100.00 90.59 333.00 8,070.72 -23,987.12 0.0018,322.33 -16,876.57 0.00 0.00
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 9
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
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)
29,200.00 90.59 333.00 8,069.69 -24,087.12 0.0018,411.43 -16,921.97 0.00 0.00
29,300.00 90.59 333.00 8,068.66 -24,187.11 0.0018,500.52 -16,967.37 0.00 0.00
29,400.00 90.59 333.00 8,067.63 -24,287.10 0.0018,589.62 -17,012.77 0.00 0.00
29,500.00 90.59 333.00 8,066.60 -24,387.10 0.0018,678.71 -17,058.16 0.00 0.00
29,600.00 90.59 333.00 8,065.57 -24,487.09 0.0018,767.81 -17,103.56 0.00 0.00
29,700.00 90.59 333.00 8,064.54 -24,587.09 0.0018,856.91 -17,148.96 0.00 0.00
29,800.00 90.59 333.00 8,063.51 -24,687.08 0.0018,946.00 -17,194.35 0.00 0.00
29,900.00 90.59 333.00 8,062.49 -24,787.08 0.0019,035.10 -17,239.75 0.00 0.00
30,000.00 90.59 333.00 8,061.46 -24,887.07 0.0019,124.19 -17,285.15 0.00 0.00
30,100.00 90.59 333.00 8,060.43 -24,987.07 0.0019,213.29 -17,330.54 0.00 0.00
30,200.00 90.59 333.00 8,059.40 -25,087.06 0.0019,302.39 -17,375.94 0.00 0.00
30,300.00 90.59 333.00 8,058.37 -25,187.06 0.0019,391.48 -17,421.34 0.00 0.00
30,400.00 90.59 333.00 8,057.34 -25,287.05 0.0019,480.58 -17,466.73 0.00 0.00
30,500.00 90.59 333.00 8,056.31 -25,387.05 0.0019,569.67 -17,512.13 0.00 0.00
30,600.00 90.59 333.00 8,055.28 -25,487.04 0.0019,658.77 -17,557.53 0.00 0.00
30,700.00 90.59 333.00 8,054.25 -25,587.04 0.0019,747.87 -17,602.92 0.00 0.00
30,800.00 90.59 333.00 8,053.22 -25,687.03 0.0019,836.96 -17,648.32 0.00 0.00
30,900.00 90.59 333.00 8,052.19 -25,787.03 0.0019,926.06 -17,693.72 0.00 0.00
31,000.00 90.59 333.00 8,051.16 -25,887.02 0.0020,015.15 -17,739.11 0.00 0.00
31,100.00 90.59 333.00 8,050.13 -25,987.01 0.0020,104.25 -17,784.51 0.00 0.00
31,200.00 90.59 333.00 8,049.10 -26,087.01 0.0020,193.34 -17,829.91 0.00 0.00
31,253.26 90.59 333.00 8,048.55 -26,140.26 0.0020,240.79 -17,854.08 0.00 0.00
TD at 31253.26
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.
(°)
MT7-94 Target 2 1320 8,048.55 5,936,362.46 1,412,885.0220,240.79 -17,854.080.00 0.00 70° 13' 42.105 N 151° 50' 11.992 W
- plan hits target center
- Circle (radius 1,320.00)
MT7-94 Target 1 1320 8,203.01 5,922,814.72 1,419,320.196,876.44 -11,044.600.00 0.00 70° 11' 30.791 N 151° 46' 53.589 W
- plan hits target center
- Circle (radius 1,320.00)
Vertical
Depth
(usft)
Measured
Depth
(usft)
Casing
Diameter
(in)
Hole
Diameter
(in)Name
Casing Points
13-3/8" Surface Casing2,997.904,040.00 13.375 16.000
9-5/8" Intermediate Casing7,326.0413,449.00 9.625 12.250
7" Intermediate Liner8,099.1815,439.00 7.000 8.500
4-1/2" Production Liner8,048.5531,253.26 4.500 6.125
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 10
ConocoPhillips
Standard Proposal Report
Well MT7-94Local Co-ordinate Reference:Database:EDT 17 Alaska Prod
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:Western North SlopeProject:
TrueNorth Reference:GMT2 Rendezvous PadSite:
Minimum CurvatureSurvey Calculation Method:MT7-94Well:
MT7-94Wellbore:
MT7-94_wp03Design:
Measured
Depth
(usft)
Vertical
Depth
(usft)
+E/-W
(usft)
+N/-S
(usft)
Local Coordinates
Comment
Plan Annotations
300.00 300.00 0.00 0.00 Start Build 1.50
500.00 499.91 4.29 -3.00 Start Build 2.00
800.00 798.13 29.96 -20.98 Start DLS 2.50 TFO -29.55
2,986.92 2,513.39 676.52 -1,055.59 Start 10234.27 hold at 2986.92 MD
13,221.19 7,222.07 4,950.26 -9,074.55 Start DLS 1.00 TFO 77.65
13,398.54 7,303.13 5,026.80 -9,212.47 Start 50.00 hold at 13398.54 MD
13,448.54 7,325.83 5,049.08 -9,251.05 Start 902.00 hold at 13448.54 MD
14,350.54 7,735.33 5,450.92 -9,947.07 Start DLS 2.88 TFO 65.68
15,389.30 8,088.70 6,126.69 -10,635.00 Start 50.00 hold at 15389.30 MD
15,439.30 8,099.24 6,167.99 -10,661.14 Start 50.00 hold at 15439.30 MD
15,489.30 8,109.79 6,209.29 -10,687.27 Start DLS 2.80 TFO 50.68
15,701.75 8,147.69 6,390.26 -10,791.72 Start 230.61 hold at 15701.75 MD
15,932.37 8,181.26 6,592.31 -10,897.71 Start DLS 2.80 TFO 4.36
16,253.29 8,203.01 6,876.44 -11,044.60 Start 14999.96 hold at 16253.29 MD
31,253.26 8,048.55 20,240.79 -17,854.08 TD at 31253.26
5/1/2023 11:03:33AM COMPASS 5000.17 Build Page 11
01 May, 2023
Anticollision Summary Report
ConocoPhillips Alaska
Inc_WNS
Western North Slope
GMT2 Rendezvous Pad
MT7-94
MT7-94
MT7-94_wp03
ConocoPhillips
Anticollision Summary Report
Well MT7-94Local Co-ordinate Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:Western North SlopeProject:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:GMT2 Rendezvous PadReference Site:
TrueNorth Reference:0.00 usftSite Error:
Minimum CurvatureSurvey Calculation Method:MT7-94Reference Well:
Output errors are at 2.00 sigmaWell Error:0.00 usft
Reference Wellbore MT7-94 Database:EDT 17 Alaska Prod
Offset DatumReference Design:MT7-94_wp03 Offset TVD Reference:
Interpolation Method:
Depth Range:
Reference
Error Model:
Scan Method:
Error Surface:
Filter type:
ISCWSA
Trav. Cylinder North
Combined Pedal Curve
NO GLOBAL FILTER: Using user defined selection & filtering criteria
MD Interval 25.00usft
Unlimited
Maximum centre distance of 3,000.00usft
MT7-94_wp03
Results Limited by:
SigmaWarning Levels Evaluated at:2.79 Added to Error ValuesCasing Method:
From
(usft)
Survey Tool Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 5/1/2023
SDI_Keeper_ADK SDI Keeper All-Attitude Drop Keeper V 1.138.90 1,000.00 MT7-94_wp03 (MT7-94)
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Corre1,000.00 4,040.00 MT7-94_wp03 (MT7-94)
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Corre4,040.00 13,449.00 MT7-94_wp03 (MT7-94)
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Corre13,449.00 15,439.00 MT7-94_wp03 (MT7-94)
MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Corre15,439.00 31,253.26 MT7-94_wp03 (MT7-94)
Offset Well - Wellbore - Design
Reference
Measured
Depth
(usft)
Offset
Measured
Depth
(usft)
Between
Centres
(usft)
Between
Ellipses
(usft)
Separation
Factor
Warning
Summary
Site Name
Distance
GMT2 Rendezvous Pad
CCMT7-01 - MT7-01 - MT7-01 38.90 38.71 120.05 118.83 98.055
ESMT7-01 - MT7-01 - MT7-01 100.09 100.00 120.17 118.74 83.773
SFMT7-01 - MT7-01 - MT7-01 12,036.93 19,645.00 1,826.34 1,683.82 12.814
CCMT7-01 - MT7-01PB1 - MT7-01PB1 38.90 38.71 120.05 118.83 98.055
ESMT7-01 - MT7-01PB1 - MT7-01PB1 100.09 100.00 120.17 118.74 83.773
SFMT7-01 - MT7-01PB1 - MT7-01PB1 997.12 1,000.00 151.04 145.50 27.217
CCMT7-02 - MT7-02 - MT7-02 198.70 200.00 139.72 138.37 103.594
ESMT7-02 - MT7-02 - MT7-02 248.70 250.00 139.77 138.22 89.973
SFMT7-02 - MT7-02 - MT7-02 1,637.34 1,625.00 184.15 175.17 20.513
CCMT7-03 - MT7-03 - MT7-03 38.90 39.90 159.95 158.72 130.640
ESMT7-03 - MT7-03 - MT7-03 173.80 175.00 160.25 158.52 92.521
SFMT7-03 - MT7-03 - MT7-03 12,850.77 21,050.00 1,583.08 1,382.41 7.889
CCMT7-04 - GMT2-SW04 - MT7-04 1,107.83 1,100.00 164.87 158.55 26.057
ESMT7-04 - GMT2-SW04 - MT7-04 1,133.16 1,125.00 164.93 158.52 25.708
SFMT7-04 - GMT2-SW04 - MT7-04 1,549.23 1,550.00 212.48 203.23 22.970
CCMT7-05 - MT7-05 - MT7-05 38.90 39.40 199.99 198.77 163.345
ESMT7-05 - MT7-05 - MT7-05 349.55 350.00 200.82 198.20 76.708
SFMT7-05 - MT7-05 - MT7-05 13,551.37 21,916.00 2,089.06 1,783.14 6.829
CC, ESMT7-06 - MT7-06 - MT7-06 1,138.31 1,125.00 211.47 204.37 29.805
SFMT7-06 - MT7-06 - MT7-06 1,558.86 1,550.00 247.11 237.08 24.640
CC, ESMT7-06 - MT7-06A - MT7-06A 1,138.36 1,125.00 211.47 204.37 29.806
SFMT7-06 - MT7-06A - MT7-06A 1,558.91 1,550.00 247.12 237.09 24.643
CC, ESMT7-06 - MT7-06PB1 - MT7-06PB1 1,138.31 1,125.00 211.47 204.37 29.805
SFMT7-06 - MT7-06PB1 - MT7-06PB1 1,558.86 1,550.00 247.11 237.08 24.639
CCMT7-07 - MT7-07 - MT7-07 38.90 39.40 239.99 238.77 196.016
ESMT7-07 - MT7-07 - MT7-07 99.20 100.00 240.10 238.65 166.354
SFMT7-07 - MT7-07 - MT7-07 1,088.09 1,100.00 299.03 292.32 44.604
CCMT7-08 - MT7-08 - MT7-08 38.90 39.00 260.02 258.80 212.378
ESMT7-08 - MT7-08 - MT7-08 74.70 75.00 260.09 258.75 193.017
SFMT7-08 - MT7-08 - MT7-08 1,913.62 1,900.00 403.00 389.47 29.792
CCMT7-08 - MT7-08PB1 - MT7-08PB1 38.90 39.00 260.02 258.80 212.378
ESMT7-08 - MT7-08PB1 - MT7-08PB1 74.70 75.00 260.09 258.75 193.017
5/1/2023 11:05:52AM COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 2
ConocoPhillips
Anticollision Summary Report
Well MT7-94Local Co-ordinate Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:Western North SlopeProject:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:GMT2 Rendezvous PadReference Site:
TrueNorth Reference:0.00 usftSite Error:
Minimum CurvatureSurvey Calculation Method:MT7-94Reference Well:
Output errors are at 2.00 sigmaWell Error:0.00 usft
Reference Wellbore MT7-94 Database:EDT 17 Alaska Prod
Offset DatumReference Design:MT7-94_wp03 Offset TVD Reference:
Offset Well - Wellbore - Design
Reference
Measured
Depth
(usft)
Offset
Measured
Depth
(usft)
Between
Centres
(usft)
Between
Ellipses
(usft)
Separation
Factor
Warning
Summary
Site Name
Distance
GMT2 Rendezvous Pad
SFMT7-08 - MT7-08PB1 - MT7-08PB1 1,913.62 1,900.00 403.00 389.47 29.792
CCMT7-09 - MT7-09 - MT7-09 38.90 40.51 280.01 278.79 228.704
ESMT7-09 - MT7-09 - MT7-09 699.89 700.00 281.28 277.12 67.600
SFMT7-09 - MT7-09 - MT7-09 1,117.31 1,125.00 318.85 311.87 45.693
CCMT7-11 - MT7-11 - MT7-11 526.34 525.00 318.27 315.10 100.516
ESMT7-11 - MT7-11 - MT7-11 551.55 550.00 318.31 315.04 97.341
SFMT7-11 - MT7-11 - MT7-11 1,470.99 1,500.00 465.13 457.44 60.453
CCMT7-14 - MT7-14 - MT7-14_wp07 2,302.00 2,250.00 58.91 47.20 5.032
ESMT7-14 - MT7-14 - MT7-14_wp07 2,324.49 2,275.00 59.36 46.47 4.605
SFMT7-14 - MT7-14 - MT7-14_wp07 2,391.19 2,350.00 74.30 55.63 3.980
CCMT7-92 - MT7-92 - MT7-92_wp04 70inc 3.2dls 300.00 300.00 40.06 37.31 14.576
ESMT7-92 - MT7-92 - MT7-92_wp04 70inc 3.2dls 424.81 425.00 40.34 36.87 11.627
SFMT7-92 - MT7-92 - MT7-92_wp04 70inc 3.2dls 623.43 625.00 44.46 39.86 9.662
CCMT7-95 - MT7-95 - MT7-95_wp02 425.03 425.00 19.89 17.01 6.907
ESMT7-95 - MT7-95 - MT7-95_wp02 474.98 475.00 19.96 16.85 6.418
SFMT7-95 - MT7-95 - MT7-95_wp02 624.45 625.00 22.33 18.48 5.799
CCMT7-96 - MT7-96 - MT7-96 38.90 40.34 39.94 38.72 32.624
ESMT7-96 - MT7-96 - MT7-96 123.36 125.00 40.10 38.57 26.195
SFMT7-96 - MT7-96 - MT7-96 498.04 500.00 51.35 48.13 15.942
CCMT7-97 - MT7-97 - MT7-97 299.87 300.00 57.12 54.85 25.091
ESMT7-97 - MT7-97 - MT7-97 324.89 325.00 57.17 54.79 24.038
SFMT7-97 - MT7-97 - MT7-97 1,077.55 1,075.00 73.64 67.40 11.808
CCMT7-98 - MT7-98 - MT7-98 549.63 550.00 76.81 73.50 23.174
ESMT7-98 - MT7-98 - MT7-98 574.54 575.00 76.82 73.40 22.479
SFMT7-98 - MT7-98 - MT7-98 796.54 800.00 84.51 80.10 19.165
CCMT7-99 - MT7-99 - MT7-99 952.37 950.00 91.53 86.32 17.570
ESMT7-99 - MT7-99 - MT7-99 1,002.76 1,000.00 91.69 86.08 16.349
SFMT7-99 - MT7-99 - MT7-99 1,127.60 1,125.00 96.51 90.18 15.258
CC, ES, SFMT7-GCEW1 - MT7-GCEW1 - MT7-GCEW1_wp01 1,834.17 1,850.00 111.28 100.74 10.562
5/1/2023 11:05:52AM COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 3
ConocoPhillips
Anticollision Summary Report
Well MT7-94Local Co-ordinate Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:Western North SlopeProject:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:GMT2 Rendezvous PadReference Site:
TrueNorth Reference:0.00 usftSite Error:
Minimum CurvatureSurvey Calculation Method:MT7-94Reference Well:
Output errors are at 2.00 sigmaWell Error:0.00 usft
Reference Wellbore MT7-94 Database:EDT 17 Alaska Prod
Offset DatumReference Design:MT7-94_wp03 Offset TVD Reference:
0
750
1500
2250
3000
Centre to Centre Separation0 2500 5000 7500 10000 12500 15000
Measured Depth
Ladder Plot
MT7-92, MT7-92, MT7-92_wp04 70inc 3.2dls V0
MT7-14, MT7-14, MT7-14_wp07 V0
MT7-GCEW1, MT7-GCEW1, MT7-GCEW1_wp01 V0
MT7-08, MT7-08PB1, MT7-08PB1 V0
MT7-08, MT7-08, MT7-08 V0
MT7-07, MT7-07, MT7-07 V0
MT7-02, MT7-02, MT7-02 V0
MT7-09, MT7-09, MT7-09 V0
MT7-04, GMT2-SW04, MT7-04 V0
MT7-03, MT7-03, MT7-03 V 0
MT7-06, MT7-06, MT7-06 V 0
MT7-06, MT7-06A, MT7-06A V0
MT7-06, MT7-06PB1, MT7-06PB1 V0
MT7-95, MT7-95, MT7-95_wp02 V0
MT7-99, MT7-99, MT7-99 V 0
MT7-11, MT7-11, MT7-11 V 0
MT7-01, MT7-01PB1, MT7-01PB1 V0
MT7-01, MT7-01, MT7-01 V0
MT7-98, MT7-98, MT7-98 V0
MT7-96, MT7-96, MT7-96 V0
MT7-05, MT7-05, MT7-05 V0
MT7-97, MT7-97, MT7-97 V0
L E G E N D
Coordinates are relative to: MT7-94
Coordinate System is US State Plane 1983, Alaska Zone 4
Grid Convergence at Surface is: -1.59°Central Meridian is 150° 0' 0.000 W
Offset Depths are relative to Offset Datum
Reference Depths are relative to Plan KB (100.6 GL + 38.9 DF) @ 139
5/1/2023 11:05:52AM COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 4
ConocoPhillips
Anticollision Summary Report
Well MT7-94Local Co-ordinate Reference:ConocoPhillips Alaska Inc_WNSCompany:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftTVD Reference:Western North SlopeProject:
Plan KB (100.6 GL + 38.9 DF) @ 139.50usftMD Reference:GMT2 Rendezvous PadReference Site:
TrueNorth Reference:0.00 usftSite Error:
Minimum CurvatureSurvey Calculation Method:MT7-94Reference Well:
Output errors are at 2.00 sigmaWell Error:0.00 usft
Reference Wellbore MT7-94 Database:EDT 17 Alaska Prod
Offset DatumReference Design:MT7-94_wp03 Offset TVD Reference:
0.00
3.00
6.00
9.00
Separation Factor0 2500 5000 7500 10000 12500
Measured Depth
Normal Operations
Caution Monitor Closely
Take Immediate Action
STOP Drilling
Separation Factor Plot
MT7-92, MT7-92, MT7-92_wp04 70inc 3.2dls V0
MT7-14, MT7-14, MT7-14_wp07 V0
MT7-GCEW1, MT7-GCEW1, MT7-GCEW1_wp01 V0
MT7-08, MT7-08P B1, MT7-08PB1 V0
MT7-08, MT7-08, MT7-08 V0
MT7-07, MT7-07, MT7-07 V0
MT7-02, MT7-02, MT7-02 V0
MT7-09, MT7-09, MT7-09 V0
MT7-04, GMT2-SW04, MT7-04 V0
MT7-03, MT7-03, MT7-03 V0
MT7-06, MT7-06, MT7-06 V0
MT7-06, MT7-06A, MT7-06A V0
MT7-06, MT7-06PB1, MT7-06PB1 V0
MT7-95, MT7-95, MT7-95_wp02 V0
MT7-99, MT7-99, MT7-99 V0
MT7-11, MT7-11, MT7-11 V0
MT7-01, MT7-01PB1, MT7-01PB1 V0
MT7-01, MT7-01, MT7-01 V0
MT7-98, MT7-98, MT7-98 V0
MT7-96, MT7-96, MT7-96 V0
MT7-05, MT7-05, MT7-05 V0
MT7-97, MT7-97, MT7-97 V0
L E G E N D
Coordinates are relative to: MT7-94
Coordinate System is US State Plane 1983, Alaska Zone 4
Grid Convergence at Surface is: -1.59°Central Meridian is 150° 0' 0.000 W
Offset Depths are relative to Offset Datum
Reference Depths are relative to Plan KB (100.6 GL + 38.9 DF) @ 139
5/1/2023 11:05:52AM COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
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.
GMTU MT7-94
223-049
X
Rendezvous Oil
X
Greater Mooses Tooth
X
WELL PERMIT CHECKLIST
Company ConocoPhillips Alaska, Inc.
Well Name:GMTU MT7-94
Initial Class/Type SER / WAGIN GeoArea 890 Unit 10750 On/Off Shore On
Program SERField & Pool Well bore seg
Annular DisposalPTD#:2230490
GRTR MOOSES TOOTH, RENDEZV OIL - 2822
NA1 Permit fee attached
Yes Surface Location lies within AA0081800; Top Productive Interval lies in AA0081803; TD lies in AA0081805.2 Lease number appropriate
Yes3 Unique well name and number
Yes GRTR MOOSES TOOTH, RENDEZV OIL - 282200, governed by CO 7934 Well located in a defined pool
Yes5 Well located proper distance from drilling unit boundary
Yes6 Well located proper distance from other wells
Yes7 Sufficient acreage available in drilling unit
Yes8 If deviated, is wellbore plat included
Yes9 Operator only affected party
Yes10 Operator has appropriate bond in force
Yes11 Permit can be issued without conservation order
Yes12 Permit can be issued without administrative approval
Yes13 Can permit be approved before 15-day wait
Yes Area Injection Order No. 43, issued July 13, 2021, governs Rendezvous Oil Pool14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For s
Yes Currently there are no other wells within 1/4 mile of MT7-9415 All wells within 1/4 mile area of review identified (For service well only)
No Well will not be pre-produced other than flowback to clean up the well prior to injection. See email 6/3016 Pre-produced injector: duration of pre-production less than 3 months (For service well only)
NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
Yes 80'18 Conductor string provided
Yes 4040' MD19 Surface casing protects all known USDWs
Yes 72% Excess20 CMT vol adequate to circulate on conductor & surf csg
No21 CMT vol adequate to tie-in long string to surf csg
No22 CMT will cover all known productive horizons
Yes23 Casing designs adequate for C, T, B & permafrost
Yes24 Adequate tankage or reserve pit
NA25 If a re-drill, has a 10-403 for abandonment been approved
Yes anti-collision complete; no major risk failures26 Adequate wellbore separation proposed
Yes variance granted per 20 AAC 25.035(h)(2)27 If diverter required, does it meet regulations
Yes Max reservoir pressure 3641 psig(8.7 ppg EMW); will drill w/ 8.8-13.5 ppg EMW28 Drilling fluid program schematic & equip list adequate
Yes29 BOPEs, do they meet regulation
Yes MPSP is 2836 psig; will test BOPs to 5000 psig initial; 3500 psig subsequent30 BOPE press rating appropriate; test to (put psig in comments)
Yes31 Choke manifold complies w/API RP-53 (May 84)
Yes32 Work will occur without operation shutdown
No33 Is presence of H2S gas probable
Yes no wells in 1/4 mile radious34 Mechanical condition of wells within AOR verified (For service well only)
Yes None expected. Rig has sensors and alarms.35 Permit can be issued w/o hydrogen sulfide measures
Yes Expected Pressure Range is 8.3 to 11.8 EMW. Operator's planned mud program with MPD appears36 Data presented on potential overpressure zones
NA sufficient to control anticipated pressures and maintain wellbore stability.37 Seismic analysis of shallow gas zones
NA Tusk sand potential in Int1, will require a second stage cement job if encountered.38 Seabed condition survey (if off-shore)
NA High risk of hole instability in Int2 secion, see page 16. MPD will be utilized.39 Contact name/phone for weekly progress reports [exploratory only]
Appr
MDG
Date
7/3/2023
Appr
VTL
Date
7/4/2023
Appr
MDG
Date
7/3/2023
Administratio
Engineering
Geology
Geologic
Commissioner:Date:Engineering
Commissioner:Date Public
Commissioner Date
GCW 07/05/2023
