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Originated: Delivered to:2-Jan-25
Alaska Oil & Gas Conservation Commiss 02Jan25-NR
ATTN: Meredith Guhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
#FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24
1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24
1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24
1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24
1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24
1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24
1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24
2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24
2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24
1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24
MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24
MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39899
T39900
T39901
T39902
T39901
T39903
T39904
T39905
T39906
T39907T39908
T39909MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-24
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.01.03 08:13:20 -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: 1747' FSL, 3550' FEL 45 T9N R2E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 100.9 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 3048'
9-5/8" T-95 7472'
7-5/8" L-80 8355'
4 1/2" P110 8323'
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: 62.1ppg 15.8ppg Class G8.5"x9-7/8"
TUBING RECORD
21847'
Lead:79.5bbl 13.0ppg Class G
Tail: 118.1bbl 15.8ppg Class G
8317'
12-1/4"
6-1/2"
13859'4.5" 12207'MD/7326'TVD
13762'MD/8291'TVD
13851'MD/8317'TVD
BOTTOM
16" Lead: 459bbl 11.0ppg Blend
Tail: 70bbl 15.8 Class G
CASING
50-103-20872-00-00
GMT MT7-92
2/11/2024
21862'MD/8322'TVD
N/A
140.4
P.O.Box 100360, Anchorage, AK 99510-0360
290169
1093' FSL, 3191' FEL S32 T10N R2E
3416' FSL, 1783' FEL S32 T10N R2E
3/24/2024
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
4/1/2024 223-114
982'MD/979'TVD
SETTING DEPTH TVD
5918193
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER
PACKER SET (MD/TVD)
13851'
42"
12.6
5915909
Greater Mooses Tooth/Rendezvous
AA09885, AA081781, AA092341
369446000, 932516000, 340762000
40'
33.7
40'
12207'
4119'
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
294975
291634
CEMENTING RECORD
5911150
200010000
Gas Lift
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and
Number; Date perf'd or liner run):
Liner ( 3/7/2024): 12207'MD/7326'TVD - 14007'MD/8355'TVD
Liner (3/27/2024): 13851'MD/8317'TVD - 21847'MD/8323'TVD
2000
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
40'
40'
Per 20 AAC 25.283 (i)(2) attach electronic information
47
14007
38'
7326'
94
68
120'
38' 12383'
SIZE DEPTH SET (MD)
10 Yards
Sr Res EngSr Pet GeoSr Pet Eng
100
N/A
37
Oil-Bbl: Water-Bbl:
2000
Water-Bbl:
PRODUCTION TEST
4/22/2024
Date of Test: Oil-Bbl:
20010251300
4/22/2024 24
Flow Tubing
200
10000
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 12:11 pm, Apr 29, 2024
Completed
4/1/2024
JSB
RBDMS JSB 060424
4 JSB
GDSR-6/7/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
982 979
C-30 1426 1414
2087 2008
4089 3038
K-2 5045 3394
Albian 97 5776 3675
Albian 96 6278 3869
HRZ 12357 7451
Kalubik 12454 7529
Kuparuk C 12617 7654
12620 7656
14060 8365
21862 8322
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:
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
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
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.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
MT
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Page 1/51
MT7-92
Report Printed: 4/22/2024
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)
1/29/2024
12:00
1/29/2024
15:00
3.00 MIRU, MOVE RURD P Clean cellar. Prep pits and rig f/ move.
Remove torque tube and IBOPs.
0.0 0.0
1/29/2024
15:00
1/29/2024
18:30
3.50 MIRU, MOVE RURD P Scope down mast. Secure TD. Spool off
drill line.
0.0 0.0
1/29/2024
18:30
1/29/2024
22:30
4.00 MIRU, MOVE RURD P Blow down steam lines. Unplug
complexes. Prep to skid rig floor. Clean
snow from around stompers. Put casing
shed on suspension.
0.0 0.0
1/29/2024
22:30
1/30/2024
00:00
1.50 MIRU, MOVE RURD P Skid rig floor. 0.0 0.0
1/30/2024
00:00
1/30/2024
01:00
1.00 MIRU, MOVE MOB P PJSM. Prep derrick and lay over. 0.0 0.0
1/30/2024
01:00
1/30/2024
04:00
3.00 MIRU, MOVE MOB P Shovel snow from around and under
complexes. Unpin sub f/ pipeshed and
stomp pipeshed out. Stomp motor
complex out from under pump complex.
0.0 0.0
1/30/2024
04:00
1/30/2024
06:00
2.00 MIRU, MOVE MOB P Lay mats. Stomp and stage motor
complex.
0.0 0.0
1/30/2024
06:00
1/30/2024
08:30
2.50 MIRU, MOVE MOB P Stomp pits and pump complex and
stage with motor complex.
0.0 0.0
1/30/2024
08:30
1/30/2024
15:00
6.50 MIRU, MOVE MOB P Stomp sub away from well and west 20'.
Stomp pipeshed .
0.0 0.0
1/30/2024
15:00
1/30/2024
18:00
3.00 MIRU, MOVE MOB P Stomp pipeshed under sub. Shim and
pin pipeshed to sub. Spot pits
0.0 0.0
1/30/2024
18:00
1/30/2024
21:00
3.00 MIRU, MOVE MOB P Skid rig floor. Raise derrick. Raise upper
and lower cattle chutes. Retract C-
section.
0.0 0.0
1/30/2024
21:00
1/31/2024
00:00
3.00 MIRU, MOVE MOB P Spot casing shed. Spot pump and motor
complex. Shim complexes.
0.0 0.0
1/31/2024
00:00
1/31/2024
02:30
2.50 MIRU, MOVE MOB P Continue to plug in modules. Clean-up
well @ MT7-93. Hook-up and energize
rig floor steam and air.
0.0 0.0
1/31/2024
02:30
1/31/2024
03:30
1.00 MIRU, MOVE MOB P Spool line on drawworks. Remove top
drive pins. Hook-up scoping lines.
0.0 0.0
1/31/2024
03:30
1/31/2024
04:30
1.00 MIRU, MOVE MOB P Scope-up derrick. Remove scoping
lines. Lower derrick ladder.
0.0 0.0
1/31/2024
04:30
1/31/2024
06:00
1.50 MIRU, MOVE MOB P Clear rig floor and prep top drive for
maintenance.
0.0 0.0
1/31/2024
06:00
1/31/2024
08:00
2.00 MIRU, MOVE WAIT P Remove top drive wear bushing. Warm
and drain gearbox oil.
0.0 0.0
1/31/2024
08:00
1/31/2024
12:00
4.00 MIRU, MOVE WAIT P P/U tools and new top drive parts.
Remove wish bone, link tilt cylinders,
shot pin, hydraulic pump and rotating
link assembly. Install new suction screen
pod on pump #2. Inspect butterfly valve
in pits.
0.0 0.0
1/31/2024
12:00
1/31/2024
18:00
6.00 MIRU, MOVE WAIT P Mechanic disassemble RLA. Prep to
separate TD and blocks. Rebuild torque-
tube and back-up wrench. Rig crew
assist mechanic and NOV Reps. Clean
parts for mechanic. Clean rig, inspect
mud pumps. Electrician disconnect TD
motor leads. Disconnect energy track
and tie up.
0.0 0.0
1/31/2024
18:00
2/1/2024
00:00
6.00 MIRU, MOVE WAIT P Rig crew remove guide rail frame. Clean
-up TD. Remove pin for TD bail and
secure bail.
0.0 0.0
2/1/2024
00:00
2/1/2024
06:00
6.00 MIRU, MOVE WAIT P Remove wash pipe housing. Clean top
drive. Perform derrick inspection.
Complete work orders. Changeout snail
on mix pump #2.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 2/51
MT7-92
Report Printed: 4/22/2024
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)
2/1/2024
06:00
2/1/2024
12:00
6.00 MIRU, MOVE WAIT P Prep to remove bail and traction motors.
Remove hydraulic lines, electric wires
and cables. NOV work on easYgen
system.
0.0 0.0
2/1/2024
12:00
2/1/2024
18:00
6.00 MIRU, MOVE WAIT P Mechanic remove yoke on top drive.
Prep and remove traction motors.
Electrician assist with traction motor
removal. Rig crew assist Mechanic on
top drive. Work on mix pump #2. Work
on steam lines. Inspect mud pump
valves / seats and changeout liners to
6.5”.
0.0 0.0
2/1/2024
18:00
2/2/2024
00:00
6.00 MIRU, MOVE WAIT P Rig crew assist Mechanic on top drive.
Work on mix pump #2. Work on steam
lines. Inspect mud pump valves / seats
and changeout liners to 6.5". Clean and
prep for MPI.
0.0 0.0
2/2/2024
00:00
2/2/2024
06:00
6.00 MIRU, MOVE WAIT P Rig crew assist Mechanic on top drive.
Changeout liners to 6.5" on #2 pump.
Remove Katch can and clean for
modification. Mount skate control
bracket and change oil in Koomey.
0.0 0.0
2/2/2024
06:00
2/2/2024
12:00
6.00 MIRU, MOVE WAIT P Rig crew assist Mechanic on top drive.
(Replace encoder, remove gear cover
and prep to pull compound gears and
bull gear on top drive). Changeout liners
to 6.5" on #1 pump. Change out popoff
valves on mud pumps. Remove Orbit
valve and turn MPD head. Pick up
BOPs with block and modify BOP
carrier.
0.0 0.0
2/2/2024
12:00
2/2/2024
18:00
6.00 MIRU, MOVE WAIT P Rig crew assist Mechanic on top drive.
(Prep load bearing items for crack
check). Set BOP's in cradle, M/U MPD
head and orbit valve.
0.0 0.0
2/2/2024
18:00
2/3/2024
00:00
6.00 MIRU, MOVE WAIT P Prep load bearing items for crack check.
Change valves and seats on #2 mud
pump. Inspect suction valves on mud
pits.
0.0 0.0
2/3/2024
00:00
2/3/2024
06:00
6.00 MIRU, MOVE WAIT P Continue prepping load bearing items
for crack check and inspect butterfly
valves in pits. Conduct PM's on mud
pumps. Clear mud under rotary table
and retrieve Strip-O-Matic hoses.
0.0 0.0
2/3/2024
06:00
2/3/2024
12:00
6.00 MIRU, MOVE WAIT P Continue prepping load bearing items
for crack check. Hook-up Strip-O-Matic
lines and function. Organize on rig floor.
Fill accumulator with new hydraulic fluid.
Inspect mechaical seal on jet pump.
Weld new line and hanger brackets for
4" ball mill transfer line. Organize shaker
screens. Consolidate pallets of mud
products.
0.0 0.0
2/3/2024
12:00
2/3/2024
18:00
6.00 MIRU, MOVE WAIT P Continue prepping load bearing items
for crack check. Clear mud under rotary
table. C/O jet pump.
0.0 0.0
2/3/2024
18:00
2/4/2024
00:00
6.00 MIRU, MOVE WAIT P Continue prepping load bearing items
for crack check. Install new jet pump.
Reinstall hole fill pump.
0.0 0.0
2/4/2024
00:00
2/4/2024
06:00
6.00 MIRU, MOVE WAIT P Prep for crack check in derrick. Install
belt guards on jet pump. Inspect
impellars in max pumps. Change out
upper BOP rams to 9-5/8" SBR's.
Complete rig floor inventory.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 3/51
MT7-92
Report Printed: 4/22/2024
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)
2/4/2024
06:00
2/4/2024
12:00
6.00 MIRU, MOVE WAIT P Continue 5-year on top drive. BWM on
BOPs. Changeout impellar on hole fill
pump #2 and assemble hole fill pumps.
Modify hatches for 4" ball mill transfer
line. Install fluid maniflod on MPD. Prep
top drive for paint.
0.0 0.0
2/4/2024
12:00
2/4/2024
18:00
6.00 MIRU, MOVE WAIT P Prep top drive parts for paint. Prep
derrick pedestals for inspection. Prep
and inspect shackers for drilling.
0.0 0.0
2/4/2024
18:00
2/5/2024
00:00
6.00 MIRU, MOVE WAIT P Clean and prep top drive parts for
assembly. Clean and clear rig floor.
Paint BOP carrier. Paint inspected TD
parts.
0.0 0.0
2/5/2024
00:00
2/5/2024
06:00
6.00 MIRU, MOVE WAIT P Clean and paint top drive parts for assy,
bring in mud products for surface hole
section, clean and paint BOP carrier,
PM's on equipment
0.0 0.0
2/5/2024
06:00
2/5/2024
12:00
6.00 MIRU, MOVE WAIT P Continue with top drive 5 year service,
continue clean and paint BOP carrier,
modification on 4" ball mill transfer line,
install longer hyd hoses on cattle chute,
0.0 0.0
2/5/2024
12:00
2/5/2024
18:00
6.00 MIRU, MOVE WAIT P Continue top drive 5 year service,
continue clean and paint BOP carrier,
inspect butterfly vales in pits, modify
pits/pumps interconnect for ball mill
transfer line.
0.0 0.0
2/5/2024
18:00
2/6/2024
00:00
6.00 MIRU, MOVE WAIT P Continue top drive 5 year service,
continue clean and paint BOP carrier,
inspect butterfly valves in pits.
SIMOPS: Bulking 4" doubles and place
in tubs.
0.0 0.0
2/6/2024
00:00
2/6/2024
06:00
6.00 MIRU, MOVE WAIT P Continue paint BOP carrier, replace
gasket in jet pump and test, buck up 4"
drill pipe doubles, install compensator
top drive, clear snow on rig mats around
stompers for move
0.0 0.0
2/6/2024
06:00
2/6/2024
12:00
6.00 MIRU, MOVE WAIT P Continue top drive 5 year service, install
4" transfer line to ball mill, buck doubles,
shovel around stompers prep for move,
work on EZ generator
0.0 0.0
2/6/2024
12:00
2/6/2024
18:00
6.00 MIRU, MOVE WAIT P Continue top drive 5 year service, install
4" transfer line to ball mill, work on EZ
generator.
0.0 0.0
2/6/2024
18:00
2/7/2024
00:00
6.00 MIRU, MOVE WAIT P Continue top drive service, paint, buck
4" doubles and place in tubs, inspect
and chasnge out dump valves in pits
0.0 0.0
2/7/2024
00:00
2/7/2024
06:00
6.00 MIRU, MOVE WAIT P Change out rail guides on top drive,
buck doubles, paint, install conductor
valves on MT7-92
0.0 0.0
2/7/2024
06:00
2/7/2024
12:00
6.00 MIRU, MOVE WAIT P Continue buck doubles, paint, install 4"
transfer line to ball mill, top drive 5 year
service, change out lights in derrick
0.0 0.0
2/7/2024
12:00
2/7/2024
18:00
6.00 MIRU, MOVE WAIT P Continie 5 year top drive service, paint,
buck doubles, continue 4" ball mill
transfer line
0.0 0.0
2/7/2024
18:00
2/8/2024
00:00
6.00 MIRU, MOVE WAIT P Continue 5 year top drive service, paint,
buck doubles, nipple up 10' surface riser
on MT7-92, MP2's, make up riser on
MT7-92.
Rig Move Est 1800hrs 2-9-24.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 4/51
MT7-92
Report Printed: 4/22/2024
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)
2/8/2024
00:00
2/8/2024
06:00
6.00 MIRU, MOVE WAIT P Continue 5 year service on top drive,
nipple up 10' riser on MT7-92 and buck
doubles, clean tank room and BOP
deck, change out guides on blocks
0.0 0.0
2/8/2024
06:00
2/8/2024
12:00
6.00 MIRU, MOVE WAIT P Continue 5 year service on top drive,
buck doubles, clean tank room
0.0 0.0
2/8/2024
12:00
2/8/2024
18:00
6.00 MIRU, MOVE WAIT P Continue 5 year service on top drive,
buck doubles, clean tank room
0.0 0.0
2/8/2024
18:00
2/9/2024
00:00
6.00 MIRU, MOVE WAIT P Continue 5 year service on top drive,
clean tank room
0.0 0.0
2/9/2024
00:00
2/9/2024
06:00
6.00 MIRU, MOVE WAIT P Continue 5 year service, change out
guides, change out discharge flange
pump #2, MP2's, paint, buck doubles,
clean tank room
0.0 0.0
2/9/2024
06:00
2/9/2024
12:00
6.00 MIRU, MOVE WAIT P Continue 5 year service, buck doubles,
clean tank room, function test rotation,
brake & compensators on to drive
(good)
0.0 0.0
2/9/2024
12:00
2/9/2024
18:00
6.00 MIRU, MOVE WAIT P Continue 5 year top drive service,
Process 7 joints 13-3/8" casing, function
test top drive and check main bearing
inplay (all good)
0.0 0.0
2/9/2024
18:00
2/9/2024
22:30
4.50 MIRU, MOVE WAIT P Continue 5 year top drive service,
Installing guards and wire up bolts
restraints, Install swivel packing and
install clamps onto saver sub. Raise
derrick ladder, Blow down water system,
Complete final visual inspection on Top
Drive. Send out tools and equipment
from rig floor.
0.0 0.0
2/9/2024
22:30
2/10/2024
00:00
1.50 MIRU, MOVE RURD P Dolly pad not aligned correct with track.
Inspect and change out dolly pad. Bridle
up to scope derrick down.
0.0 0.0
2/10/2024
00:00
2/10/2024
01:00
1.00 MIRU, MOVE RURD P Continue hook up bridal lines, scope
down derrick
0.0 0.0
2/10/2024
01:00
2/10/2024
02:00
1.00 MIRU, MOVE RURD P Rig down bridal lines, pin top drive to
derrick, pull 10 wraps drill line off drum,
secure top drive energy track
0.0 0.0
2/10/2024
02:00
2/10/2024
03:30
1.50 MIRU, MOVE RURD P Swap to rig move generators, raise C
section, start unplugging interconnects
0.0 0.0
2/10/2024
03:30
2/10/2024
05:00
1.50 MIRU, MOVE RURD P Unplug interconnects, lower cattle
chute, skid floor
0.0 0.0
2/10/2024
05:00
2/10/2024
06:00
1.00 MIRU, MOVE RURD P Lower derrick, stomp casing shed away
from pipe shed
0.0 0.0
2/10/2024
06:00
2/10/2024
09:00
3.00 MIRU, MOVE RURD P Unpin sub, stomp pits, pump complexes
back from sub, stomp pipe shed away
from sub and stomp sub out of the way
from production to set well house
0.0 0.0
2/10/2024
09:00
2/10/2024
12:00
3.00 MIRU, MOVE RURD P Continue stomping sub and pipe shed
down well row followed by pits complex
to MT7-92 well.
0.0 0.0
2/10/2024
12:00
2/10/2024
16:30
4.50 MIRU, MOVE RURD P Continue stomp sub shim and set over
MT7-92, Stump pipe shed, pump, pits
and motor complex. Shim and pin sub.
0.0 0.0
2/10/2024
16:30
2/10/2024
18:00
1.50 MIRU, MOVE RURD P Raise derrick, retract raising cylinders in
stow position. Skid rig floor into drilling
postion. Stomp pits into position.
0.0 0.0
2/10/2024
18:00
2/10/2024
19:30
1.50 MIRU, MOVE RURD P Stomp pump complex, Stomp and shim
casing shed. Lower C section.
0.0 0.0
2/10/2024
19:30
2/10/2024
21:30
2.00 MIRU, MOVE RURD P Stomp motor complex and raise cattle
shute. Lower cellar.
SIMOPS: Hook up inter connections,
Steam, Water, vac and air.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 5/51
MT7-92
Report Printed: 4/22/2024
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)
2/10/2024
21:30
2/11/2024
00:00
2.50 MIRU, MOVE RURD P Hook up interconnections, Steam,
Water, vac and air.
0.0 0.0
2/11/2024
00:00
2/11/2024
01:00
1.00 MIRU, MOVE RURD P Hook up interconnections, Steam,
Water, vac and air.
0.0 0.0
2/11/2024
01:00
2/11/2024
01:30
0.50 MIRU, MOVE RURD P Trouble shoot A & B motor fault.
(Crossed wires)
0.0 0.0
2/11/2024
01:30
2/11/2024
04:30
3.00 MIRU, MOVE RURD P Scope up Derrick and secure. Remove
bridle lines and install service lines.
SIMOPS: Continue with
Interconnections, Load BHA in casing
shed. Working on rig acceptance
checklist.
Rig acceptance at 04:30hrs 2-11-24
0.0 0.0
2/11/2024
04:30
2/11/2024
06:00
1.50 MIRU, MOVE SLPC P Cut and slip 103' drill line. Recalibrate
block and C-O-M.
0.0 0.0
2/11/2024
06:00
2/11/2024
11:00
5.00 MIRU, MOVE NUND P Obtain RKB measurements, Install flow
box and seal up Joes box, Install flow
line and hook up drain lines hole fill and
jet lines. Install 90' mouse hole.
0.0 0.0
2/11/2024
11:00
2/11/2024
12:00
1.00 MIRU, MOVE BHAH P P/U BHA tools at beaver slide to floor. 0.0 0.0
2/11/2024
12:00
2/11/2024
13:30
1.50 MIRU, MOVE RURD P Pre derrick inspection, Adjust kelly hose,
Install 2" on conductor, Set up Totco.
0.0 0.0
2/11/2024
13:30
2/11/2024
15:15
1.75 MIRU, MOVE BHAH P P/U and rack back 5" HWT drill pipe. 0.0 0.0
2/11/2024
15:15
2/11/2024
16:30
1.25 SURFAC, DRILL BHAH P M/U 16" surface BHA #1. to 63' MD. 0.0 63.0
2/11/2024
16:30
2/11/2024
17:00
0.50 SURFAC, DRILL PRTS P Pump at 200gpm and fill pipe/hole, Tag
at 108' MD. Pressure test surface
equipment to 3,500psi (good test), Wash
to 120' MD.
63.0 120.0
2/11/2024
17:00
2/11/2024
18:15
1.25 SURFAC, DRILL DDRL P Drill 16" hole section from 120' MD to
244' MD 244' TVD
Spud at 17:00hrs 2-11-24.
WOB: 9k
GPM: 450
PSI: 640
RPM: 40
4.0 k TQ on bttm
4.0 k TQ off bttm
FO: 52%
ADT: 1.0 hrs
ART: 1.0 hrs
TBH: 32.6 hrs
120.0 244.0
2/11/2024
18:15
2/11/2024
18:45
0.50 SURFAC, DRILL SVRG P Service rig/Top drive. 244.0 244.0
2/11/2024
18:45
2/11/2024
19:45
1.00 SURFAC, DRILL RGRP T Trouble shoot top drive (loose encoder
belt)
244.0 244.0
2/11/2024
19:45
2/11/2024
20:15
0.50 SURFAC, DRILL DDRL P Drill 16" hole section from 244' MD to
275' MD 275' TVD
WOB: 9k
GPM: 450
PSI: 630
RPM: 60
4.0 k TQ on bttm
4.0 k TQ off bttm
FO: 54%
244.0 275.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 6/51
MT7-92
Report Printed: 4/22/2024
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)
2/11/2024
20:15
2/11/2024
21:15
1.00 SURFAC, DRILL BKRM P BROOH from 275' MD to 94' MD.
GPM: 450
PSI: 430
RPM: 40
275.0 94.0
2/11/2024
21:15
2/12/2024
00:00
2.75 SURFAC, DRILL BHAH P M/U final 16" surface BHA #1 94.0 241.0
2/12/2024
00:00
2/12/2024
01:00
1.00 SURFAC, DRILL BHAH P Continue make up surface BHA, shoot
survey @ 120' MD 0.26° base
conductor, continue TIH to 275' MD.
241.0 275.0
2/12/2024
01:00
2/12/2024
06:00
5.00 SURFAC, DRILL DDRL P Drill 16" surface from 275' MD to 636'
MD 636' TVD,
WOB: 5k
GPM: 700
PSI: 1450
ECD: 11.3ppg
RPM: 60
4.0 k TQ on bttm
4.0 k TQ off bttm
FO: 64%
PU: 87k
SO: 87k
ROT: 87k
ADT: 2.6 hrs
ART: 2.2 hrs
AST: 0.4 hrs
TBH: 35.5 hrs
TJH: 0.1 hrs
275.0 636.0
2/12/2024
06:00
2/12/2024
12:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface from 636' MD to 1110'
MD 1,107' TVD,
WOB: 5k
GPM: 800
PSI: 2000
ECD: 11.2ppg
RPM: 60
6.0 k TQ on bttm
6.0 k TQ off bttm
FO: 67%
PU: 108k
SO: 108k
ROT: 108k
ADT: 3.9 hrs
ART: 3.2 hrs
AST: 0.7 hrs
TBH: 39.4 hrs
TJH: 4.0 hrs
636.0 1,110.0
2/12/2024
12:00
2/12/2024
18:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface from 1,110' MD to
1,676' MD 1,649' TVD.
WOB: 10k
GPM: 900
PSI: 2530
ECD: 11.3ppg
RPM: 60
6.0 k TQ on bttm
6.0 k TQ off bttm
FO: 78%
PU: 115k
SO: 115k
ROT: 115k
ADT: 3.6 hrs
ART: 2.2 hrs
AST: 1.4 hrs
TBH: 43.0 hrs
TJH: 7.6 hrs
1,110.0 1,676.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 7/51
MT7-92
Report Printed: 4/22/2024
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)
2/12/2024
18:00
2/13/2024
00:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface from 1,676' MD to
2,341' MD 2,210' TVD,
WOB: 22k
GPM: 900
PSI: 2660
ECD: 11.3ppg
RPM: 60
7.0 k TQ on bttm
7.0 k TQ off bttm
FO: 77%
PU: 125k
SO: 125k
ROT: 125k
ADT: 4.0 hrs
ART: 2.6 hrs
AST: 1.4 hrs
TBH: 47.0 hrs
TJH: 11.6 hrs
1,676.0 2,341.0
2/13/2024
00:00
2/13/2024
06:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface from 2,341' MD to
2,966' MD 2,612' TVD,
WOB: 22k
GPM: 900
PSI: 2910
ECD: 11.4ppg
RPM: 60
9.0 k TQ on bttm
9.0 k TQ off bttm
FO: 66%
PU: 128k
SO: 128k
ROT: 125k
ADT: 4.1 hrs
ART: 2.1 hrs
AST: 2.0 hrs
TBH: 51.0 hrs
TJH: 15.7 hrs
2,341.0 2,966.0
2/13/2024
06:00
2/13/2024
11:30
5.50 SURFAC, DRILL DDRL P Drill 16" surface from 2,966' MD to
3,471' MD 2,829' TVD,
WOB: 25k
GPM: 900
PSI: 2980
ECD: 11.5ppg
RPM: 60
10.0 k TQ on bttm
10.0 k TQ off bttm
FO: 67%
PU: 128k
SO: 128k
ROT: 125k
ADT: 4.4 hrs
ART: 2.6 hrs
AST: 1.8 hrs
TBH: 55.5 hrs
TJH: 20.1 hrs
2,966.0 3,471.0
2/13/2024
11:30
2/13/2024
14:45
3.25 SURFAC, DRILL CIRC T Observe downhole packoff. ECD
increase from 11.5ppge to 14.2ppge.
Reduce flowrate and work pipe. At 3800
stks hole unload at surface and packoff
flowline.Stage up rate to 900 gpm as
hole allows clear ROT table/flowline,
total strokes pumped (18,500stks)
3,471.0 3,471.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 8/51
MT7-92
Report Printed: 4/22/2024
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)
2/13/2024
14:45
2/13/2024
16:00
1.25 SURFAC, DRILL DDRL P Drill 16" surface from 3,471' MD to
3,626' MD 2,884' TVD,
WOB: 27k
GPM: 900
PSI: 3090
ECD: 11.5ppg
RPM: 60
11.0 k TQ on bttm
11.0 k TQ off bttm
FO: 77%
PU: 125k
SO: 125k
ROT: 125k
ADT: 1.1 hrs
ART: 1.1 hrs
AST: 0.0 hrs
TBH: 56.6 hrs
TJH: 21.2 hrs
3,471.0 3,626.0
2/13/2024
16:00
2/13/2024
16:30
0.50 SURFAC, DRILL SVRG P Service top drive shot pin. 3,626.0 3,626.0
2/13/2024
16:30
2/13/2024
18:00
1.50 SURFAC, DRILL DDRL P Drill 16" surface from 3,626' MD to
3,745' MD 2,928' TVD,
WOB: 19k
GPM: 900
PSI: 3050
ECD: 11.6ppg
RPM: 60
10.0 k TQ on bttm
10.0 k TQ off bttm
FO: 77%
PU: 125k
SO: 125k
ROT: 125k
ADT: 1.0 hrs
ART: 1.0 hrs
AST: 0.0 hrs
TBH: 57.5 hrs
TJH: 22.2 hrs
3,626.0 3,745.0
2/13/2024
18:00
2/13/2024
22:15
4.25 SURFAC, DRILL DDRL P Drill 16" surface from 3,745' MD to
4,129' MD 3,051' TVD,
WOB: 30k
GPM: 900
PSI: 3450
ECD: 11.8ppg
RPM: 60
11.0 k TQ on bttm
11.0 k TQ off bttm
FO: 77%
PU: 126k
SO: 126k
ROT: 126k
ADT: 3.1 hrs
ART: 3.1 hrs
AST: 0.0 hrs
TBH: 60.7 hrs
TJH: 25.3 hrs
3,745.0 4,129.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 9/51
MT7-92
Report Printed: 4/22/2024
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)
2/13/2024
22:15
2/14/2024
00:00
1.75 SURFAC, TRIPCAS CIRC P Take final survey, Pump 2-40bbl LoVis
sweeps and back ream from 4,129' MD
to 4,096' MD. (sweeps came back
2000stks early)
4,129' MD 3,051.38' TVD
71.15°
145.99° Azm
GPM: 900
PSI: 2,950
ECD: 11.2ppg
RPM: 60
4,129.0 4,096.0
2/14/2024
00:00
2/14/2024
01:00
1.00 SURFAC, TRIPCAS CIRC P Pump 2-40bbl LoVis sweeps and back
ream from 4,096' MD to 4,006' MD.
(sweeps came back 1600stks early)
GPM: 900
PSI: 2,950
ECD: 11.2ppg
RPM: 60
4,096.0 4,006.0
2/14/2024
01:00
2/14/2024
01:30
0.50 SURFAC, TRIPCAS OWFF P OWFF (Static) 4,006.0 4,006.0
2/14/2024
01:30
2/14/2024
06:00
4.50 SURFAC, TRIPCAS BKRM P BROOH from 4,006' MD to 2,622' MD.
GPM: 900
PSI: 2,950
ECD: 11.7ppg
RPM: 60
4,006.0 2,622.0
2/14/2024
06:00
2/14/2024
12:00
6.00 SURFAC, TRIPCAS BKRM P BROOH from 2,622' MD to 706' MD. At
985' MD reduce flow rate to 750 GPM
and 40RPM.
GPM: 900
PSI: 2,452
ECD: 11.3ppg
RPM: 60
2,622.0 706.0
2/14/2024
12:00
2/14/2024
12:30
0.50 SURFAC, TRIPCAS CIRC P Pump 2-40bbl LoVis sweeps and back
ream from 706' MD to 600' MD.
GPM: 400-750
PSI: 500-1700
RPM: 40
706.0 600.0
2/14/2024
12:30
2/14/2024
13:45
1.25 SURFAC, TRIPCAS TRIP P POOH on elevators from 600' MD to
145' MD.
600.0 145.0
2/14/2024
13:45
2/14/2024
16:00
2.25 SURFAC, TRIPCAS BHAH P POOH and L/D 16" surface BHA #1. 145.0 0.0
2/14/2024
16:00
2/14/2024
17:00
1.00 SURFAC, CASING CLEN P Clean and clear rig floor of tools and
equipment.
0.0 0.0
2/14/2024
17:00
2/14/2024
18:30
1.50 SURFAC, CASING RURD P R/U 13-3/8" casing running equipment. 0.0 0.0
2/14/2024
18:30
2/14/2024
21:00
2.50 SURFAC, CASING PUTB P M/U 13-3/8" 68# L-80 H563 shoe track
(Baker lock first 4 connections) Circulate
shoe track at 178' MD. (All Good) Run
13-3/8" 68# L-80 H563 to 500' MD. fill
on fly and M/U with Volant.
Baker-Loc shoe track to joint #4.
Floats checked good
FC 3.34'
2- joints 86.54'
Shoe 2.25'
0.0 500.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 10/51
MT7-92
Report Printed: 4/22/2024
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)
2/14/2024
21:00
2/15/2024
00:00
3.00 SURFAC, CASING PUTB P Continue run 13-3/8" 68# L-80 H563
from 500' MD to 2,022' MD. Running on
elevators and topfill on the run. Break
circulation every 10 joints.
MU: 25k
SO: 148k
500.0 2,022.0
2/15/2024
00:00
2/15/2024
04:00
4.00 SURFAC, CASING PUTB P Continue run 13-3/8" 68# L-80 H563
from 2,022' MD to 4,119' MD. Running
on elevators and topfill on the run. Break
circulation every 10 joints.
2,022.0 4,078.0
2/15/2024
04:00
2/15/2024
04:30
0.50 SURFAC, CASING HOSO P M/U FMC hanger, RIH and land hanger
with 195K. (No Fill)
FC 3.34' @ 4,027' MD
2- joints 86.54'
Shoe 2.25' @ 4,119' MD
4,078.0 4,119.0
2/15/2024
04:30
2/15/2024
06:00
1.50 SURFAC, CEMENT CIRC P Circulating and Condition mud at 4,119'
MD. Stage pumps up from 1bpm to
8bpm. Reciprocate casing (~15' strokes)
GPM: 338
PSI: 205
ME: 11.0
RPM: 60
4,119.0 4,119.0
2/15/2024
06:00
2/15/2024
07:00
1.00 SURFAC, CEMENT CIRC P Blow down top drive, R/U cement line to
Volant, Continue Circulating at 8bpm.
4,119.0 4,119.0
2/15/2024
07:00
2/15/2024
11:30
4.50 SURFAC, CEMENT CMNT P Mix and pump 100 bbls of 11.0 ppg Mud
Push II @ 4 bbls/min, 400 psi, Dropped
bottom plug, Add two gallons dye. Start
batching lead (Cement wet @07:51hrs).
Pump 464 bbls of 11.0 ppg DeepCRETE
cement at 4.8 bbls/min, 680 psi ICP.
Batch tail cement (Cement wet @
09:43hrs) and pump 70 bbls of G Blend
Tail 15.8 ppg cement @ 4.3 bbls/min,
572 psi. Drop top plug & kick out with 20
bbls of fresh H2O. Swap to rig &
displace @ 8 bbls/min, 620 psi ICP, 800
psi FCP. Slow pumps 13 bbls prior to
calculated bump to 3 bbls/min, 409 psi
ICP, Bump plug with 930 psi (583.2 bbls
+ 20 bbls). 4930 strokes, final circ. PSI
409 Pressure up to 930 psi & hold for 5
minutes. Bleed off pressure, Check
floats good. 170 bbls cement to surface.
(Full returns) Cement in place @
11:34hrs 2/15/24
Lead: 11ppg
D047: 0.5 gal/sk Antifoam
D185: 0.09 gal/sk Dispersant
D167: 0.450% BWOB Fluid Loss
D177: 0.02 gal/sk Retarder
Tail: 15.8ppg
D047: 0.2 gal/sk Antifoam
D065: 0.65 % BWOC Dispersant
D225: 0.3% BWOB Fluid Loss
D186: 0.5 gal/sk Accelerator
4,119.0 4,119.0
2/15/2024
11:30
2/15/2024
12:00
0.50 SURFAC, CEMENT CLEN P Flush surface equipment. R/U to test
casing.
4,119.0 4,119.0
2/15/2024
12:00
2/15/2024
13:00
1.00 SURFAC, CEMENT PRTS P Pressure test 13-3/8" 68# L80 H563
casing to 3500psi 30min. Charted (good
test) pumped 9.7bbls and returned
8.0bbls.
4,119.0 4,119.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 11/51
MT7-92
Report Printed: 4/22/2024
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)
2/15/2024
13:00
2/15/2024
16:15
3.25 SURFAC, CEMENT RURD P R/D cement running equipment. L/D
landing joint. Cleaned and cleared rig
floor. Flushed all cement contaminated
lines thoroughly w/ black water. Flushed
surface riser w/ black water. Cleaned
cement valves. Cleaned out Joe's box.
SIMOPS: Finished testing choke
manifold offline 250/5000psi
5min/10min.
4,119.0 4,119.0
2/15/2024
16:15
2/15/2024
18:15
2.00 SURFAC, WHDBOP NUND P N/D surface risers.
SIMOPS: Remove jet lines, remove flow
line, and slide joe box. Clean up celler
with super sucker
4,119.0 0.0
2/15/2024
18:15
2/15/2024
20:30
2.25 SURFAC, WHDBOP NUND P Install casing & tubing spool as per
FMC, Orient same, Nipple up drilling
riser & BOPE, N/U MPD equipment Test
FMC wellhead seal t/ 1,000 psi f/ 10
minutes test witnessed by CPAI
0.0 0.0
2/15/2024
20:30
2/16/2024
00:00
3.50 SURFAC, WHDBOP NUND P Install choke/Kill lines, Torque riser and
BOP flanges, Seal Joes box and install
mouse hole. Install MPD clamp.
0.0 0.0
2/16/2024
00:00
2/16/2024
01:30
1.50 SURFAC, WHDBOP RURD P Set test plug, R/U and purge air from
system.
0.0 0.0
2/16/2024
01:30
2/16/2024
03:30
2.00 SURFAC, WHDBOP PRTS P Pressure test with 9-5/8" test joint, Test
Annular, Dart valve and CM valves
#13,14,15,1 and 4" kill line. Observed
slow leak, Trouble shoot system and
found 4" Demco valve leak. Rebuild
valve and re-test.
0.0 0.0
2/16/2024
03:30
2/16/2024
09:30
6.00 SURFAC, WHDBOP PRTS 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 = 3000 PSI. MANIF. =
1450 PSI. ACC = 1850 PSI After all
functions on bottles, 16 sec for 200 psi.
Build W/ 2 Elec. pumps, 82 sec T/ Build
full system. Pressure W/ 2 Elec. & 2 Air
pumps, Closing times, Annular = 22 sec.
UPR = 14 sec. Blind / Shears = 15 sec.
LPR = 6 sec. Choke HCR = 2 sec. Kill
HCR = 2 sec; Test PVT G/L and flow out
alarms, Test LEL and H2S alarms.
Witnessed by AOGCC Guy Cook
Waived Witness by BLM Quinn Sawyer
2/15/24 08:21hrs
0.0 0.0
2/16/2024
09:30
2/16/2024
11:00
1.50 SURFAC, WHDBOP PRTS P Install MPD test cap, Pressure test to
250/1750psi 5/10min.
0.0 0.0
2/16/2024
11:00
2/16/2024
11:30
0.50 SURFAC, WHDBOP OTHR P Pull test plug and install 12-7/8" wear
ring.
0.0 0.0
2/16/2024
11:30
2/16/2024
12:00
0.50 SURFAC, WHDBOP OTHR P Blow down top drive and all surface
equipment.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 12/51
MT7-92
Report Printed: 4/22/2024
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)
2/16/2024
12:00
2/16/2024
15:30
3.50 SURFAC, DRILLOUT BHAH P P/U 12-1/4" intermediate #1 BHA to 567'
MD.
Sensor offset:
Near bit Inc.: 5.61'
Near bit Gamma: 11.86'
Gamma: 30.83'
Pressure: 31.60'
Resistivity: 36.22
Directional/ VSS: 43.00'
0.0 567.0
2/16/2024
15:30
2/16/2024
17:30
2.00 SURFAC, DRILLOUT TRIP P TIH from 567' MD to 3,868' MD 567.0 3,868.0
2/16/2024
17:30
2/16/2024
18:30
1.00 SURFAC, DRILLOUT OTHR P Perform choke drill with crews. 3,868.0 3,868.0
2/16/2024
18:30
2/16/2024
20:00
1.50 SURFAC, DRILLOUT SLPC P Cut and slip 55' drill line. Calibrate
block.
3,868.0 3,868.0
2/16/2024
20:00
2/16/2024
20:30
0.50 SURFAC, DRILLOUT SVRG P Service rig and inspect top drive. 3,868.0 3,868.0
2/16/2024
20:30
2/16/2024
21:30
1.00 SURFAC, DRILLOUT WASH P Wash in hole tag stringers at 3,960' MD.
Ream in hole and tag cement at 4,011'
MD.
3,868.0 4,011.0
2/16/2024
21:30
2/17/2024
00:00
2.50 SURFAC, DRILLOUT DRLG P Drill cement and float collar from 4,011'
MD to 4,117' MD.
Float collar and shoe on depth/tally.
4,011.0 4,117.0
2/17/2024
00:00
2/17/2024
01:00
1.00 SURFAC, DRILLOUT DRLG P Continue drill out shoe track from 4,117'
MD to 4,119' MD. Clean out rat hole
from 4,119' MD to 4,129' MD.
WOB: 8/10k
GPM: 650
PSI: 1320
RPM: 80
14.0 k TQ on bttm
10.0 k TQ off bttm
ROT: 131k
4,117.0 4,129.0
2/17/2024
01:00
2/17/2024
01:30
0.50 SURFAC, DRILLOUT DDRL P Drill new formation from 4,129' MD to
4,148' MD.
WOB: 20k
GPM: 650
PSI: 1330
ECD: 11.3ppg
RPM: 80
14.0 k TQ on bttm
10.0 k TQ off bttm
FO: 63%
ROT: 132k
4,129.0 4,148.0
2/17/2024
01:30
2/17/2024
02:00
0.50 SURFAC, DRILLOUT CIRC P Circulate hole clean 11ppg in/out.
GPM: 650
PSI: 1330
ECD: 11.3ppg
RPM: 80
14.0 k TQ on bttm
10.0 k TQ off bttm
ROT: 132k
4,148.0 4,056.0
2/17/2024
02:00
2/17/2024
03:00
1.00 SURFAC, DRILLOUT FIT P Blow down top drive and R/U test
equipment. FIT with 11.0ppg mud to
1242psi EMW 18.8ppg @ 3,048' TVD
4,056.0 4,056.0
2/17/2024
03:00
2/17/2024
03:30
0.50 SURFAC, DRILLOUT REAM P Wash and ream from 4,056' MD to
4,148' MD. Down link tools.
4,056.0 4,148.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 13/51
MT7-92
Report Printed: 4/22/2024
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)
2/17/2024
03:30
2/17/2024
06:00
2.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermedate 1 hole section
from 4,148' MD to 4,336' MD 3,123'
TVD,
WOB: 7k
GPM: 850
PSI: 1670
ECD: 11.3ppg
RPM: 130
8.0 k TQ on bttm
8.0 k TQ off bttm
FO: 61%
ROT: 132k
ADT: 1.5 hrs
TBH: 1.5 hrs
TJH: 27.2 hrs
4,148.0 4,336.0
2/17/2024
06:00
2/17/2024
09:30
3.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermedate 1 hole section
from 4,336' MD to 4,713' MD 3,266'
TVD,
WOB: 7k
GPM: 850
PSI: 1670
ECD: 11.3ppg
RPM: 130
8.0 k TQ on bttm
8.0 k TQ off bttm
FO: 61%
ROT: 132k
ADT: 1.5 hrs
TBH: 1.5 hrs
TJH: 27.2 hrs
SIMOPS: Pump spacers and displace to
11.0ppg FWP mud.
4,336.0 4,713.0
2/17/2024
09:30
2/17/2024
10:00
0.50 INTRM1, DRILL SVRG P Service top drive. 4,713.0 4,713.0
2/17/2024
10:00
2/17/2024
12:00
2.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermedate 1 hole section
from 4,713' MD to 4,902' MD 3,339'
TVD,
WOB: 11k
GPM: 1000
PSI: 2304
ECD: 11.7ppg
RPM: 130
9.0 k TQ on bttm
9.0 k TQ off bttm
FO: 67%
PU: 138k
SO: 128k
ROT: 140k
ADT: 4.1 hrs
TBH: 6.0 hrs
TJH: 31.3 hrs
4,713.0 4,902.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 14/51
MT7-92
Report Printed: 4/22/2024
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)
2/17/2024
12:00
2/17/2024
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermedate 1 hole section
from 4,902' MD to 5620' MD 3,616' TVD,
WOB: 20k
GPM: 1000
PSI: 2304
ECD: 11.7ppg
RPM: 130
11.0 k TQ on bttm
9.0 k TQ off bttm
FO: 67%
PU: 138k
SO: 128k
ROT: 140k
ADT: 4.5 hrs
TBH: 10.5 hrs
TJH: 35.8 hrs
4,902.0 5,620.0
2/17/2024
18:00
2/18/2024
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermedate 1 hole section
from 5,620' MD to 6,353' MD 3,898'
TVD,
WOB: 11k
GPM: 1000
PSI: 2640
ECD: 12.3ppg
RPM: 130
13.0 k TQ on bttm
9.0 k TQ off bttm
FO: 67%
PU: 157k
SO: 136k
ROT: 144k
ADT: 4.6 hrs
TBH: 15.1 hrs
TJH: 40.4 hrs
5,620.0 6,353.0
2/18/2024
00:00
2/18/2024
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 6,353' MD to 7,160' MD 4,208'
TVD,
WOB: 30k
GPM: 1000
PSI: 2985
ECD: 11.8ppg
RPM: 150
13.0 k TQ on bttm
9.0 k TQ off bttm
FO: 66%
PU: 171k
SO: 142k
ROT: 163k
ADT: 4.6 hrs
TBH: 19.7 hrs
TJH: 60.1 hrs
6,353.0 7,160.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 15/51
MT7-92
Report Printed: 4/22/2024
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)
2/18/2024
06:00
2/18/2024
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 7,160' MD to 7,817' MD 4,460'
TVD,
WOB: 30k
GPM: 1000
PSI: 3020
ECD: 11.7ppg
RPM: 150
15.0 k TQ on bttm
12.0 k TQ off bttm
FO: 66%
PU: 174k
SO: 150k
ROT: 163k
ADT: 4.1 hrs
TBH: 23.8 hrs
TJH: 64.2 hrs
7,160.0 7,817.0
2/18/2024
12:00
2/18/2024
14:00
2.00 INTRM1, DRILL BKRM T Circulate at 7,817' MD, Hole unloading
and packing off. Well packed off and lost
returns. Drop pump rate to 100gpm
540psi with 20rpm 7-9k torque. Back
ream from 7,817' MD to 7,360' MD. At
7,360' MD, packed off around bit.
(Unable to pump)
ROT: 147k.
7,817.0 7,360.0
2/18/2024
14:00
2/18/2024
18:00
4.00 INTRM1, DRILL BKRM T Continue BROOH from 7,360' MD to
7,206' MD. Attempt to clear packoff.
Rotating free with 12-17k with no
returns. String stalled at 7,195' MD,
work string to 210k over pull, Work
string down with 35k (Free rotation with
20rpm with 13k torque) Attempt to
circulate, string pressured to 1000psi.
With pumps off pressure did not drop
(1000psi) P/U to 280k at 7,206' MD.
Jars fired. S/O to 50k, didn't see any jar
movement. P/U to 290k and jars fired.
S/O pipe torqued up to 25k. Continue
work string up/down with 35k. String
started rotating.
7,360.0 7,206.0
2/18/2024
18:00
2/18/2024
19:45
1.75 INTRM1, DRILL REAM T Work and ream down from 7,206' MD to
7,249' MD. Attempt to establish
circulation several times unsuccessfully
while reaming down. Free rotating 10-30
RPM, 13-14K torque. Observed tight
spot at 7,235' MD, able to work through
without difficulty. Stopped at tool joint
and backed out top drive to blow down
due to inability to circulate. Rotate with
rotary at 5rpm with 6k torque while BD
top drive.
7,206.0 7,249.0
2/18/2024
19:45
2/18/2024
21:30
1.75 INTRM1, DRILL JAR T Continue rotating at 5rpm with no pump
(letting well relax between pack off and
floats in string) Work pipe down to
7,249' MD and up to 7,252' MD (no
pump) Pulled up to 200k. Weight
dropped to 140k, Work string up to
7,240' MD with 200k (no pump and
string stalled with 30k torque) Jar down
by setting all string down. Jars fired after
10min, string increased from 50-60k.
Continue work string 180/250k up and
40-50k (all the string weight) Jars
starting hitting down (starting 9min to
3min cycles for jars to fire) Still unable to
rotate.
7,249.0 7,249.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 16/51
MT7-92
Report Printed: 4/22/2024
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)
2/18/2024
21:30
2/19/2024
00:00
2.50 INTRM1, DRILL JAR T Continue work string with 35k torque
and jarring down at 7,212' MD, Pipe
starting rotating free at 21:30hrs.10rpm
12.5k torque. Still no circulation.
Stage pipe pressure up from 350-
1000psi with 10rpm 12.5k torque ROT
wt. 145-142k (Hardly no lift pressure
and no circulation) Possible packed off
close to the bit. Continue work string
7,222' MD to 7,248' MD, rotary from 10-
150 rpm with 15k torque. Work pump
pressure from 0 to 1000psi, still unable
to establish returns.
7,249.0 7,212.0
2/19/2024
00:00
2/19/2024
02:00
2.00 INTRM1, DRILL JAR T Continue to work string and increase
pump pressure up from 1000psi to
2000psi, at 7,256' MD. (Pumped
1.5bbls). Noticed slight lift pressure
starting at 1800psi. Continue to work
string in hole to 7,256' MD. Established
injection pump rate at 1bpm / 820psi
and 2bpm / 900psi (still no returns). Pipe
moving free up and down 80-150 rpm,
10k torque.
7,212.0 7,344.0
2/19/2024
02:00
2/19/2024
03:00
1.00 INTRM1, DRILL CIRC T Continue to work string from 7,266' MD
to 7,344' MD with 1bpm, 730psi, 80
rpm, 10k torque. Working full stand.
Noticed slight returns. Rotate string
while returns start increasing.
7,344.0 7,344.0
2/19/2024
03:00
2/19/2024
06:00
3.00 INTRM1, DRILL CIRC T Continue to stage up pumps slow while
working pipe and rotating 80 rpm. At
06:00 hrs, pump rate = 990gpm
3000psi, rotating at 150rpm 8k torque,
ECD = 12.5ppg. Continue circulating
and clean up well.
7,344.0 7,344.0
2/19/2024
06:00
2/19/2024
07:30
1.50 INTRM1, DRILL CIRC T Continue cleanning up well. Pump 92bbl
bit balling sweep and circulate 2X BU at
990gpm, 3000psi, 11.8ppg ECD,
150rpm, 8k torque.
ROT: 158k
7,344.0 7,344.0
2/19/2024
07:30
2/19/2024
09:30
2.00 INTRM1, DRILL REAM T Wash and ream in hole from 7,344' MD
to 7,816' MD. Pumped 247bbl dilution at
7,630' MD.
GPM: 1000
PSI: 3000
ECD: 11.8ppg
RPM: 140
8.0 k TQ on bttm
8.0 k TQ off bttm
FO: 76%
ROT: 158k
7,344.0 7,816.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 17/51
MT7-92
Report Printed: 4/22/2024
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)
2/19/2024
09:30
2/19/2024
12:00
2.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 7,816' MD to 8,070' MD / 4,515'
TVD.
WOB:30k
GPM: 1000
PSI: 2854
ECD: 11.9ppg
RPM: 150
13.0 k TQ on bttm
9.0 k TQ off bttm
FO: 76%
PU: 178k
SO: 159k
ROT: 116k
ADT: 2.0 hrs
TBH: 25.8 hrs
TJH: 51.1 hrs
7,816.0 8,070.0
2/19/2024
12:00
2/19/2024
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 8,070' MD to 8,605' MD / 4,762'
TVD. Pumped bit balling sweep at
8,585' MD.
WOB:30k
GPM: 1000
PSI: 2854
ECD: 12.0ppg
RPM: 150
15.0 k TQ on bttm
8.0 k TQ off bttm
FO: 67%
PU: 187k
SO: 160k
ROT: 1174k
ADT: 4.1 hrs
TBH: 29.9 hrs
TJH: 55.2 hrs
8,070.0 8,605.0
2/19/2024
18:00
2/20/2024
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 8,605 MD to 9,231' MD / 5,001'
TVD.
WOB:30k
GPM: 1000
PSI: 3157
ECD: 12.2ppg
RPM: 150
18.0 k TQ on bttm
9.0 k TQ off bttm
FO: 66%
PU: 212k
SO: 1161k
ROT: 179k
ADT: 4.4 hrs
TBH: 34.3 hrs
TJH: 59.6 hrs
8,605.0 9,231.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 18/51
MT7-92
Report Printed: 4/22/2024
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)
2/20/2024
00:00
2/20/2024
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 9,231 MD to 9,797' MD / 5,286'
TVD. 275bbls Dilution at 9,350' MD.
ECD dropped from 12.5ppg to 12.3ppg.
At 00:00hrs Rig bumping power limit
~2400KW. Slowed pump rate down from
1000-950gpm. Electrician continue to
troubleshoot issue. Haven’t had this
issue before upgrading Drives. Pumped
bit balling sweep at 04:00hrs, 9,610'
MD. ECD dropped from 12.4ppg to
12.2ppg.
Complete building 4" doubles.
Complete processing 9-5/8" casing.
WOB:33k
GPM: 950
PSI: 3000
ECD: 12.1ppg
RPM: 150
16.0 k TQ on bttm
9.0 k TQ off bttm
FO: 64%
PU: 209k
SO: 167k
ROT: 186k
ADT: 4.8hrs
TBH: 39.1 hrs
TJH: 64.4 hrs
9,231.0 9,797.0
2/20/2024
06:00
2/20/2024
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 9,797 MD to 10,362' MD / 5,686'
TVD. 275bbls Dilution at 10,175' MD.
ECD dropped from 12.4ppg to 12.3ppg.
Alpine Phase 1 conditions at 09:19hrs.
WOB:33k
GPM: 950
PSI: 3050
ECD: 12.3ppg
RPM: 150
16.0 k TQ on bttm
9.0 k TQ off bttm
FO: 64%
PU: 239k
SO: 174k
ROT: 199k
ADT: 4.7hrs
TBH: 43.8 hrs
TJH: 69.1 hrs
9,797.0 10,362.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 19/51
MT7-92
Report Printed: 4/22/2024
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)
2/20/2024
12:00
2/20/2024
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 10,362 MD to 10,952' MD / 6,187'
TVD. At 17:30hrs increased pump rate
from 950-1000gpm. Power limit
increased to 3500KW at 17:30hrs .
Pumped bit balling sweep at 15:00hrs,
10,467' MD. ECD dropped from 12.4ppg
to 12.3ppg. 540 bbls dilution adding
black product at 18:00hrs, 10,936' MD.
Alpine Phase 2 conditions at 15:54hrs.
WOB:33k
GPM: 950
PSI: 3200
ECD: 12.4ppg
RPM: 150
16.0 k TQ on bttm
9.0 k TQ off bttm
FO: 64%
PU: 239k
SO: 174k
ROT: 199k
ADT: 4.7hrs
TBH: 43.8 hrs
TJH: 69.1 hrs
10,362.0 10,952.0
2/20/2024
18:00
2/20/2024
18:30
0.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 10,952 MD to 11,013' MD / 6,231'
TVD.
Alpine Phase 2 conditions
WOB:33k
GPM: 950
PSI: 3200
ECD: 12.5ppg
RPM: 150
10,952.0 11,013.0
2/20/2024
18:30
2/20/2024
19:30
1.00 INTRM1, DRILL CIRC P Circulate at 11,013' MD. Notice packoff.
Pump pressure 3700-4000psi, ECD
12.5-12.8ppg. Circulate and work string
to clean-up packoff.
11,013.0 11,013.0
2/20/2024
19:30
2/21/2024
00:00
4.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 11,013' MD to 11,362' MD / 6,563'
TVD.
Alpine Phase 2 conditions.
WOB:33k
GPM: 1000
PSI: 3820
ECD: 12.6ppg
RPM: 150
18.0 k TQ on bttm
12.0 k TQ off bttm
FO: 64%
PU: 280k
SO: 186k
ROT: 230k
ADT: 4.1hrs
TBH: 51.5 hrs
TJH: 77.6 hrs
11,013.0 11,362.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 20/51
MT7-92
Report Printed: 4/22/2024
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)
2/21/2024
00:00
2/21/2024
00:30
0.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 11,362' MD to 11,404' MD / 6,597'
TVD.
Alpine Phase 2 conditions.
WOB:33k
GPM: 1000
PSI: 3820
ECD: 12.6ppg
RPM: 150
18.0 k TQ on bttm
12.0 k TQ off bttm
FO: 64%
PU: 302k
SO: 196k
ROT: 230k
ADT: 0.5hrs
TBH: 52.0 hrs
TJH: 78.1 hrs
11,362.0 11,404.0
2/21/2024
00:30
2/21/2024
01:30
1.00 INTRM1, DRILL RGRP T Discharge module on #2 mud pump
washed out. Circulate at 11,404' MD,
500gpm 1340psi 120rpm 14.8trq.
Unable to clean hole with one pump.
No spare mud pump discharge module
on rig/Alpine.
Note: Phase 3 weather conditions at
01:30hrs.
11,404.0 11,404.0
2/21/2024
01:30
2/21/2024
17:00
15.50 INTRM1, DRILL WAIT T Circulate at 11,404' MD, 460gpm
1160psi 20rpm 14.8trq. Working string
slow to 11,302' MD.
Note: Phase 2 weather conditions at
17:00hrs.
Transport spare pump modules to
location. Arrived at 21:45hrs
11,404.0 11,302.0
2/21/2024
17:00
2/21/2024
17:30
0.50 INTRM1, DRILL SVRG P Service rig 11,302.0 11,302.0
2/21/2024
17:30
2/22/2024
00:00
6.50 INTRM1, DRILL RGRP T Circulate at 11,302' MD, 460gpm
1160psi 20rpm 14.8trq. Working string
slow to 11,214' MD.
11,302.0 11,214.0
2/22/2024
00:00
2/22/2024
01:00
1.00 INTRM1, DRILL RGRP T Circulate at 11,214' MD, 450gpm
1160psi 120rpm 14.8trq. Work string
slow to 11,214' MD while working on #2
mud pump.
11,214.0 11,214.0
2/22/2024
01:00
2/22/2024
01:45
0.75 INTRM1, DRILL RGRP T Circulate and wash/ream to bottom
11,404' MD. CBU.
GPM: 950
PSI: 3645
ECD: 11.9ppg
RPM: 120
21.0 k TQ off bttm
11,214.0 11,404.0
2/22/2024
01:45
2/22/2024
02:15
0.50 INTRM1, DRILL SVRG P Change out popoff on #1 mud pump.
Set at 4300psi, tripped at 3900 and
3700psi.
11,404.0 11,404.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 21/51
MT7-92
Report Printed: 4/22/2024
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)
2/22/2024
02:15
2/22/2024
03:30
1.25 INTRM1, DRILL RGRP T CBU at 11,404' MD.
GPM: 950
PSI: 3645
ECD: 11.9ppg
RPM: 120
21.0 k TQ off bttm
11,404.0 11,404.0
2/22/2024
03:30
2/22/2024
06:00
2.50 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 11,404' MD to 11,588' MD / 6,772
TVD.
WOB:32k
GPM: 965
PSI: 3836
ECD: 12.0ppg
RPM: 150
27.0 k TQ on bttm
23.0 k TQ off bttm
FO: 67%
PU: 324k
SO: 196k
ROT: 237k
ADT: 2.0hrs
TBH: 54.7 hrs
TJH: 80.0 hrs
11,404.0 11,588.0
2/22/2024
06:00
2/22/2024
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 11,588' MD to 12,024' MD / 7,168'
TVD.
WOB:32k
GPM: 965
PSI: 3836
ECD: 12.0ppg
RPM: 150
27.0 k TQ on bttm
23.0 k TQ off bttm
FO: 67%
PU: 324k
SO: 196k
ROT: 237k
ADT: 5.1hrs
TBH: 59.8 hrs
TJH: 85.1 hrs
11,588.0 12,024.0
2/22/2024
12:00
2/22/2024
14:00
2.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 12,024' MD to 12,156' MD / 7,477'
TVD
WOB:22k
GPM: 950
PSI: 3760
ECD: 12.0ppg
RPM: 150
28.0 k TQ on bttm
23.0 k TQ off bttm
FO: 66%
PU: 380k
SO: 195k
ROT: 242k
ADT: 2.0hrs
TBH: 61.8 hrs
TJH: 87.1 hrs
12,024.0 12,156.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 22/51
MT7-92
Report Printed: 4/22/2024
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)
2/22/2024
14:00
2/22/2024
15:00
1.00 INTRM1, DRILL CIRC P Circulate at 12,156' MD. Increase in
drag from 324k to 380k.
GPM: 950
PSI: 3838
ECD: 12.2ppg
RPM: 130
21.0 k TQ off bttm
12,156.0 12,156.0
2/22/2024
15:00
2/22/2024
18:00
3.00 INTRM1, DRILL DDRL P Drill 12-1/4" Intermediate 1 hole section
from 12,156' MD to 12,389' MD / 7,477'
TVD
WOB:22k
GPM: 950
PSI: 3760
ECD: 12.0ppg
RPM: 150
28.0 k TQ on bttm
23.0 k TQ off bttm
FO: 66%
PU: 380k
SO: 195k
ROT: 242k
ADT: 2.0hrs
TBH: 61.8 hrs
TJH: 87.1 hrs
12,156.0 12,389.0
2/22/2024
18:00
2/22/2024
22:15
4.25 INTRM1, TRIPCAS CIRC P Circulate and backream from 12,389'
MD to 12,253' MD, racking back stand /
BU.
Pumped 100bbl bit balling sweep. No
increase in cuttings.
GPM: 965
PSI: 3750
ECD: 11.9ppg
RPM: 130
32.0 k TQ off bttm
ROT: 230k
12,389.0 12,253.0
2/22/2024
22:15
2/22/2024
22:30
0.25 INTRM1, TRIPCAS OWFF P OWFF (Static)
SIMOPS: Change out flow line boot.
12,253.0 12,253.0
2/22/2024
22:30
2/22/2024
23:00
0.50 INTRM1, TRIPCAS CIRC P Circulate and backream from 12,253'
MD to 12,158' MD.
GPM: 965
PSI: 3750
ECD: 11.9ppg
RPM: 130
32.0 k TQ off bttm
ROT: 230k
12,253.0 12,158.0
2/22/2024
23:00
2/23/2024
00:00
1.00 INTRM1, TRIPCAS BKRM P Backream out hole from 12,158' MD to
11,890' MD.
GPM: 965
PSI: 3750
ECD: 11.9ppg
RPM: 130
32.0 k TQ off bttm
ROT: 230k
12,158.0 11,890.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 23/51
MT7-92
Report Printed: 4/22/2024
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)
2/23/2024
00:00
2/23/2024
12:00
12.00 INTRM1, TRIPCAS BKRM P Backream out hole from 11,890' MD to
9,329' MD.
Pumped 100bbl sweeps at 10,200' MD
and 9,950' MD.
Pumped 270bbls Dilution at 9,745' MD.
GPM: 1000
PSI: 3460
ECD: 11.8ppg
RPM: 130-150
12.0-20.0 k TQ off bttm
ROT: 157k
11,890.0 9,329.0
2/23/2024
12:00
2/23/2024
18:00
6.00 INTRM1, TRIPCAS BKRM P Backream out hole from 9,329' MD to
8.650' MD.
Pumped 250bbls Dilution at 8,750' MD.
GPM: 1000
PSI: 3460
ECD: 11.8ppg
RPM: 130-150
12.0-20.0 k TQ off bttm
ROT: 157k
9,329.0 8,650.0
2/23/2024
18:00
2/24/2024
00:00
6.00 INTRM1, TRIPCAS BKRM P Backream out hole from 8,650' MD to
7,819' MD.
Packing off
At 8,595' MD to 8,593' MD.
At 8,450' MD ECD increase from
11.7ppg to 12.0ppg. Pump 100bbls
sweep.
At 8,414' MD packing off, continue
working through area.
At 8,315' MD, high torque, slowed TD to
60-100rpm and increased pump to
1040gpm to manage torque spikes.
At 8,273' and 8,170' MD slight pack off.
At 8,170' MD, after packoff cleared ECD
drop from 12.0ppg to 11.6ppg.
At 8,024' MD, ECD's increase from
11.6ppg to 12.1ppg, Pump 48bbls
sweep. (Sweep came back 1300stks
early).
At 7,997' MD to 7,865' MD - packoff
(high torque).
GPM: 1000-1040
PSI: 3460
ECD: 11.8-12.2ppg
RPM: 80-150
10.0-27.0 k TQ off bttm
8,650.0 7,819.0
2/24/2024
00:00
2/24/2024
06:00
6.00 INTRM1, TRIPCAS BKRM P Continue BROOH from 7,819' MD to
6,150' MD. Pumped 50bbls sweep at
7,160' MD (came back 900stks early).
Pump 270bbls dilution at 6,400' MD.
ECD up from 11.6 to 11.9ppg.
GPM: 1020
PSI: 3100
ECD: 11.7ppg
RPM: 80-120
13.0-18.0 k TQ off btm
7,819.0 6,150.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 24/51
MT7-92
Report Printed: 4/22/2024
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)
2/24/2024
06:00
2/24/2024
12:00
6.00 INTRM1, TRIPCAS BKRM P Continue BROOH from 6,150' MD to
4,750' MD. Pumped 50bbls sweep and
pump 270bbls dilution at 5,950' MD.
GPM: 1020
PSI: 2620
ECD: 11.6ppg
RPM: 80-120
9.0-19.0 k TQ off btm
6,150.0 4,750.0
2/24/2024
12:00
2/24/2024
15:00
3.00 INTRM1, TRIPCAS BKRM P Continue BROOH from 4,750' MD to
4,119' MD.
GPM: 1030
PSI: 2425
ECD: 11.3ppg
RPM: 80-120
9.0-19.0 k TQ off btm
4,750.0 4,119.0
2/24/2024
15:00
2/24/2024
15:30
0.50 INTRM1, TRIPCAS CIRC P Circulate 2-BTM's up at 4,119' MD.
Pump 50bbls bit balling sweep.
GPM: 1030
PSI: 2420
ECD: 11.3ppg
RPM: 80
10.0 k TQ off btm
4,119.0 4,119.0
2/24/2024
15:30
2/24/2024
15:45
0.25 INTRM1, TRIPCAS OWFF P OWFF (Static). 4,119.0 4,119.0
2/24/2024
15:45
2/24/2024
22:15
6.50 INTRM1, TRIPCAS BKRM P Attempt to pull on elevators ~ 20k over
pull in casing. Continue BROOH from
4,119' MD to 1,794 ' MD.
Pumped 50bbl sweep at 2,350' MD ~
43° angle. (Sweep came back on time
with heavy load of cuttings).
Pumped 50bbl sweep at 1,840' MD ~
26° angle. (Sweep came back on time
with minimum cuttings).
GPM: 1030
PSI: 2420
ECD: 11.3ppg
RPM: 80
10.0 k TQ off btm
4,119.0 1,794.0
2/24/2024
22:15
2/24/2024
22:30
0.25 INTRM1, TRIPCAS OTHR P Blow down surface equipment at 1,794'
MD.
1,794.0 1,794.0
2/24/2024
22:30
2/24/2024
23:15
0.75 INTRM1, TRIPCAS TRIP P Pull out hole on elevators from 1,794'
MD to 567' MD.
1,794.0 567.0
2/24/2024
23:15
2/24/2024
23:30
0.25 INTRM1, TRIPCAS OWFF P OWFF (Static). Function test BOP's. 567.0 567.0
2/24/2024
23:30
2/25/2024
00:00
0.50 INTRM1, TRIPCAS BHAH P POOH and L/D 12-1/4" BHA #2 from
567' MD to 198' MD.
567.0 198.0
2/25/2024
00:00
2/25/2024
01:30
1.50 INTRM1, TRIPCAS BHAH P Continue L/D BHA from 198' MD. 198.0 0.0
2/25/2024
01:30
2/25/2024
01:45
0.25 INTRM1, CASING WWWH P Make up retrieval tool and pull wear
ring.
0.0 0.0
2/25/2024
01:45
2/25/2024
02:30
0.75 INTRM1, CASING WWWH P R/U and jet BOP stack. 0.0 0.0
2/25/2024
02:30
2/25/2024
03:30
1.00 INTRM1, CASING RURD P R/U 9-5/8" casing equipment. 0.0 0.0
2/25/2024
03:30
2/25/2024
04:30
1.00 INTRM1, CASING PUTB P M/U 9-5/8" shoe track and check floats
(all good). First 4 joints are thread
locked. Torqued to 15.8k.
0.0 130.0
2/25/2024
04:30
2/25/2024
06:00
1.50 INTRM1, CASING PUTB P Continue running 9-5/8", 47#, T-95,
H563 casing to 1,040' MD.
130.0 1,040.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 25/51
MT7-92
Report Printed: 4/22/2024
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)
2/25/2024
06:00
2/25/2024
07:30
1.50 INTRM1, CASING PUTB P Continue running 9-5/8", 47#, T-95,
H563 casing from 1,040' MD to 1,733'
MD. Filling pipe on the run, topping off
every 10 joints and using tongs to
torque to 15.8k.
1,040.0 1,733.0
2/25/2024
07:30
2/25/2024
08:00
0.50 INTRM1, CASING SVRG P Service rig and troubleshoot top drive. 1,733.0 1,733.0
2/25/2024
08:00
2/25/2024
12:00
4.00 INTRM1, CASING RGRP T Continue troubleshooting top drive issue
while circulating at 145gpm, 60psi at
1,733' MD.
1,733.0 1,733.0
2/25/2024
12:00
2/25/2024
18:00
6.00 INTRM1, CASING PUTB P Continue running 9-5/8", 47#, T-95,
H563 casing from 1,733' MD to 5,340'
MD. Filling pipe on the run, topping off
every 10 joints and using tongs to
torque to 15.8k.
At 4100' MD:
PU: 196
SO: 178k
ROT: 181k
RPM: 20
TRQ: 10k
1,733.0 5,430.0
2/25/2024
18:00
2/25/2024
23:30
5.50 INTRM1, CASING PUTB P Continue running 9-5/8", 47#, T-95,
H563 casing from 5,340' MD to 9,000'
MD. Filling pipe on the run, topping off
every 10 joints and using tongs to
torque to 15.8k.
5,430.0 9,000.0
2/25/2024
23:30
2/26/2024
00:00
0.50 INTRM1, CASING CIRC P Break circulation at 9,000' MD, stage
pumps up while wash in hole from
9,000' MD to 9,100' MD at 3bpm 290psi.
(at base of tangent section)
9,000.0 9,100.0
2/26/2024
00:00
2/26/2024
01:00
1.00 INTRM1, CASING CIRC P Break circulation at 9,100' MD. Stage
pumps up while washing in hole from
9,100' MD to 9,154' MD (base of tangent
section) at 8bpm 370psi. Circulate open
hole volume ~ 2400stks. In/Out mud
weight 11+ppg.
9,100.0 9,154.0
2/26/2024
01:00
2/26/2024
06:00
5.00 INTRM1, CASING PUTB P Continue running 9-5/8", 47#, T-95,
H563 casing from 9,154' MD to 12,338'
MD. Filling pipe on the run, topping off
every 10 joints and using tongs to
torque to 15.8k.
9,154.0 12,338.0
2/26/2024
06:00
2/26/2024
06:30
0.50 INTRM1, CASING WASH P Wash in hole from 12,338' MD at 2bpm.
Make up hanger. Continue washing in
hole and land at 12,379' MD. Washed fill
from 12,370' MD to 12,383' MD. Land
with 220k.
GPM: 84
PSI: 400-780
12,338.0 12,383.0
2/26/2024
06:30
2/26/2024
09:00
2.50 INTRM1, CEMENT CIRC P Circulate and condition mud at 12,378'
MD. Stage pumps up from 2bpm to
8bpm 390/440psi. Pumped 8700stks.
Mud weight 11.0# in/out, No increase of
cuttings at shakers.
12,383.0 12,383.0
2/26/2024
09:00
2/26/2024
10:00
1.00 INTRM1, CEMENT CMNT P R/U cement service line. Circulate
6bpm, 460psi while having PJSM.
Pressure test surface equipment to
250/3000psi (all good). Blow down and
prime mud pumps with OBM.
12,383.0 12,383.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 26/51
MT7-92
Report Printed: 4/22/2024
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)
2/26/2024
10:00
2/26/2024
14:30
4.50 INTRM1, CEMENT CMNT P Mix and pump 65bbls 12.5ppg mud
push II at 4 bpm. SD and drop bottom
plug. Mix and pump 79.5bbls 13 ppg G
lead cement at 4.5 bpm. Mix and pump
118.1bbls 15.8 ppg G Tail cement at 4.7
bpm. SD and drop top plug. Pump 20
bbls FW w/ cement unit and swap over
to rig pumps. Displace w/ rig pumps and
displace cement at 6bpm, 952psi. At
870bbls, slow rate to 3bpm, 628psi.
Plug bumped at 880.5bbls pumped.
FCP 640psi. Pressure up to 1154psi. SD
and monitor f/ 5 minutes. Bleed off and
check floats. Floats holding. Cement in
place @ 14:02hrs 2/26/24. Full returns
throughout cement job.
12,383.0 12,383.0
2/26/2024
14:30
2/26/2024
15:30
1.00 INTRM1, CEMENT PRTS P Test casing to 3,500psi for 30min.
Pumped/bled back 12.5bbls. (Good
test).
12,383.0 12,383.0
2/26/2024
15:30
2/26/2024
17:00
1.50 INTRM1, CEMENT OTHR P Flush casing equipment and blow down.
Drain BOP stack.
SIMOPS: Clean pits and update Totco
equipment.
12,383.0 12,383.0
2/26/2024
17:00
2/26/2024
18:30
1.50 INTRM1, WHDBOP WWSP P Lay down landing joint. Install FMC 9-
5/8" packoff and test to 5000psi for
10min. (Good Test - witness by CPAI).
12,383.0 12,383.0
2/26/2024
18:30
2/26/2024
20:00
1.50 INTRM1, WHDBOP RURD P R/D test equipment and clear floor.
Flush mud line.
0.0 0.0
2/26/2024
20:00
2/26/2024
20:30
0.50 INTRM1, WHDBOP SVRG P Service Koomey. 0.0 0.0
2/26/2024
20:30
2/26/2024
23:00
2.50 INTRM1, WHDBOP RGRP T Troubleshoot internal leak on
Blind/Shear rams.
0.0 0.0
2/26/2024
23:00
2/27/2024
00:00
1.00 INTRM1, WHDBOP BOPE P Change UPR from 9-5/8" FBR to 2-7/8"
x 5" VBR. R/U and purge air from
system.
0.0 0.0
2/27/2024
00:00
2/27/2024
01:15
1.25 INTRM1, WHDBOP PRTS P Pressure test 2-7/8" x 5" VBR with 5"
drill pipe to 250/3500psi for 5/10min.
R/D test equipment.
AOGCC: Adam Earl waived witness at
20:38hrs 2-24-24
BLM: Quinn Sawyer waived witness at
07:45hrs 2-26-24.
0.0 0.0
2/27/2024
01:15
2/27/2024
01:30
0.25 INTRM1, WHDBOP SVRG P Inspect drill line. 0.0 0.0
2/27/2024
01:30
2/27/2024
03:00
1.50 INTRM1, WHDBOP SLPC P Cut and slip 110' drill line., Calobrate
blocks and C-O-M.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 27/51
MT7-92
Report Printed: 4/22/2024
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)
2/27/2024
03:00
2/27/2024
12:00
9.00 INTRM1, WHDBOP RGRP T Troubleshoot Blind/Shear ram internal
leak. Open Blind/Shear rams. Remove
ram blocks and dissasemble operators
for inspection. Observed internal coating
particles in hydraulic fluid and
deteriorated coating surface on operator
cylinder internal.
SIMOPS: Change out #2 mud pump
suction modules. Change liners and
swabs to 5.5".
Conference call with Houston to discuss
path forward for troubleshooting BOP.
1) P/U contigency stand of DP with
FOSV and M/U to TD. Make ready to
RIH and close LPR.
2) KWF in well
3) Casing pressure tested to 3500psi for
30min.
4) Tail cement surface sample is firm.
5) Tail cement lab test 500psi 11:12 hrs,
1000psi 14:53hrs. Cement in place at
14:00hrs 2-26-24.
0.0 0.0
2/27/2024
12:00
2/28/2024
00:00
12.00 INTRM1, WHDBOP RGRP T Continue troubleshooting Blind/Shear
ram internal leak.
SIMOPS: Finish cleanning pits at
~1700hrs. General housekeeping. Filter
Koomey hydraulic oil. Work on MP2's
and Totco equipment.
0.0 0.0
2/28/2024
00:00
2/28/2024
08:00
8.00 INTRM1, WHDBOP RGRP T Continue troubleshooting Blind/Shear
ram internal leak.
SIMOPS: Filter Koomey hydraulic oil.
Use ball mill and freeze protect OA w/
72 bbls of diesel.
0.0 0.0
2/28/2024
08:00
2/28/2024
18:00
10.00 INTRM1, WHDBOP RGRP T ND MPD, Flow line, HCR's and
manuals. Remove top of annular and
pull element and piston. Set test plug.
Inspect annular piston and seals.
0.0 0.0
2/28/2024
18:00
2/29/2024
00:00
6.00 INTRM1, WHDBOP RGRP T Replace seals on blind ram operator.
Clean piston housing on annular.
Replace seals and install piston.
0.0 0.0
2/29/2024
00:00
2/29/2024
06:00
6.00 INTRM1, WHDBOP RGRP T Install annular piston in housing. Fill
annular w/ fresh hydraulic oil. Replace
retainer seals and install retainer ring.
Install annular cap.
0.0 0.0
2/29/2024
06:00
2/29/2024
18:00
12.00 INTRM1, WHDBOP RGRP T Replace seals in blind ram operator and
assemble. Install RCD head/orbit valve
and flowline. Remove left side UPR
operator.
Notes from WOM:
Left booster blind/shear (ram change
cylinder) damaged o-ring on ram
change piston.
Black sludge in bottom of koomey tank.
Scouring on most cylinders.
Right side blind operator - coating was
bubbled, wrinkled and flaking.
0.0 0.0
2/29/2024
18:00
3/1/2024
00:00
6.00 INTRM1, WHDBOP RGRP T Remove left side LPR operator. Right
side UPR operator. Inspect and rebuild
operators.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 28/51
MT7-92
Report Printed: 4/22/2024
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)
3/1/2024
00:00
3/1/2024
06:00
6.00 INTRM1, WHDBOP RGRP T Rebuild operators in shop. Remove right
side LPR operator and send to shop.
Clean accumulator hydraulic tank.
0.0 0.0
3/1/2024
06:00
3/1/2024
12:00
6.00 INTRM1, WHDBOP RGRP T Rebuild BOP operators in shop. Clean
tank room. Fill accumulator hydraulic
tank.
0.0 0.0
3/1/2024
12:00
3/1/2024
18:00
6.00 INTRM1, WHDBOP RGRP T Install right side lower pipe ram, mud
cross, blind/shear ram, upper pipe ram
and left side lower pipe ram.
0.0 0.0
3/1/2024
18:00
3/2/2024
00:00
6.00 INTRM1, WHDBOP RGRP T Continue rebuilding operators in shop.
Install left blind/shear ram and hang
upper pipe ram in place.
0.0 0.0
3/2/2024
00:00
3/2/2024
07:00
7.00 INTRM1, WHDBOP RGRP T Install left side Upper pipe ram
operators. Torque bolts on riser. MU
hydraulic lines. Install Upper pipe rams
on stack.
0.0 0.0
3/2/2024
07:00
3/2/2024
10:30
3.50 INTRM1, WHDBOP RGRP T Cycle operators. Purge air from system.
Function test all rams opem/close to
3000psi. Witnessed by COP.
0.0 0.0
3/2/2024
10:30
3/2/2024
12:00
1.50 INTRM1, WHDBOP RGRP T MU BOP operator bolts. Install MPD
manifold, flow box, flowline, purge air in
annular and HCRs.
0.0 0.0
3/2/2024
12:00
3/2/2024
14:30
2.50 INTRM1, WHDBOP RGRP T Clean and clear BOP deck. Seal Joe's
box. Connect MPD line to orbit valve.
Retrieve test plug and clean. Reset test
plug.
0.0 0.0
3/2/2024
14:30
3/2/2024
15:30
1.00 INTRM1, WHDBOP RGRP T RU to test BOPE. Fill stack and flood
lines.
0.0 0.0
3/2/2024
15:30
3/2/2024
16:00
0.50 INTRM1, WHDBOP RGRP T Observed leak on trip nipple. Pull trip
nipple and inspect seal. Install trip
nipple.
0.0 0.0
3/2/2024
16:00
3/2/2024
18:30
2.50 INTRM1, WHDBOP RGRP T Observed preeeure loss. Change out
seat on demco kill line valve.
0.0 0.0
3/2/2024
18:30
3/3/2024
00:00
5.50 INTRM1, WHDBOP RGRP T Test BOPE to 250psi low/5000psi high f/
5/10 min each, charted w/ annular
tested to 250psi low/3500psi high with
5" test joint. Tested annular, 2 7/8" x 5"
VBR UPR, 2 7/8" x 5" VBR LPR, choke
valves 1-3, 5-15, manual kill, HCR kill,
4" Demco on kill line, 5" FOSV #1 and
#2, dart valve, upper and lower IBOP.
Peform koomey unit drawdown: ACC =
2975 psi. Manifold = 1425 psi. Post
function=1900 psi, nitrogen 6 bottle
average.18 sec 200 psi increase with 2
electric pumps and 2 air pumps. Closing
times- Annular=26 sec, Upper pipe
rams=14 sec, Blind/Shear ram=15 sec.
Lower pipe ram=13 sec. Choke HCR=2
sec, Kill HCR=2 sec. Test
PVT/Gain/Loss and flow out alarms.
Test LEL and H2S alarms.
Witness waived by BLM - Quinn Sawyer
per email 2/28/24 12:41 hrs.
Witness waived by AOGCC -Kam
StJohn per email 3/2/24 06:24 hrs.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 29/51
MT7-92
Report Printed: 4/22/2024
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)
3/3/2024
00:00
3/3/2024
03:30
3.50 INTRM1, WHDBOP RGRP T Test BOPE to 250 psi low/5000 psi high
for 5/10 min each charted w/ Annular to
250 psi low/3500 psi high for 5/10 min
each with 4" tets joint. Test annular, 2-
7/8" x 5" VBR Upper pipe ram, 2-7/8" x
5" VBR Lower pipe ram, Blind/Shear
ram, Choke valve 4, Manual choke,
HCR choke, 4" FOSV #1 and #2 and
dart valve.
Witness waived by BLM - Quinn Sawyer
per email 2/28/24 12:41 hrs.
Witness waived by AOGCC - per email
Kam StJohn 3/2/24 06:24 hrs.
0.0 0.0
3/3/2024
03:30
3/3/2024
05:00
1.50 INTRM1, WHDBOP RGRP T Pull test joint. Retrieve trip nipple. Install
MPD test cap. Test MPD equipment.
0.0 0.0
3/3/2024
05:00
3/3/2024
06:30
1.50 INTRM1, WHDBOP RGRP T Remove MPD test cap. Install 8.6875"
wear bushing.
0.0 0.0
3/3/2024
06:30
3/3/2024
09:00
2.50 INTRM1, DRILLOUT BHAH P PJSM. MU and RIH w/ BHA #3. Interm 2
to 547'.
0.0 547.0
3/3/2024
09:00
3/3/2024
10:45
1.75 INTRM1, DRILLOUT TRIP P RIH w/ BHA #3 to 2897'. 547.0 2,897.0
3/3/2024
10:45
3/3/2024
11:15
0.50 INTRM1, DRILLOUT CIRC P Shallow test MWD. Good test. 2,897.0 2,897.0
3/3/2024
11:15
3/3/2024
16:30
5.25 INTRM1, DRILLOUT TRIP P RIH w/ BHA # 3 f/ 2897' to 12043'. 2,897.0 12,043.0
3/3/2024
16:30
3/3/2024
17:30
1.00 INTRM1, DRILLOUT WASH P Wash down f/ 12043' to 12288'
450 GPM
2550 PSI
12,043.0 12,288.0
3/3/2024
17:30
3/3/2024
18:00
0.50 INTRM1, DRILLOUT SVRG P Service TD and mud pumps. 12,288.0 12,288.0
3/3/2024
18:00
3/3/2024
20:30
2.50 INTRM1, DRILLOUT RGRP T Change out swab on MP #1. Inspect #1
& #3 liner seals.
12,288.0 12,288.0
3/3/2024
20:30
3/4/2024
00:00
3.50 INTRM1, DRILLOUT DRLG P Wash down and tag @ 12294'. Drill out
FC/shoetrack and FS.
450 GPM
1800-2000 PSI
80 RPM
10-12k TQ
12,288.0 12,384.0
3/4/2024
00:00
3/4/2024
02:00
2.00 INTRM1, DRILLOUT DRLG P Clean out rathole to 12389'. Pass
through FS w/ no issue. Drill new
formation to 12399'. Observed high
torque. Work up and observed high
torque at shoe. Work through shoe
multiple times until clear. Stage back to
12399'. Normal torque.
12,384.0 12,399.0
3/4/2024
02:00
3/4/2024
03:30
1.50 INTRM1, DRILLOUT DRLG P Drill 12399' MD to 12409' MD / 7493'
TVD. Slow drilling. PU and restart
several times. Vary rates/RPM and
WOB.
20-40k WOB
425-450 GPM
1760 PSI
60-80 RPM
12k TQ
12.4ppg ECD
12,399.0 12,409.0
3/4/2024
03:30
3/4/2024
05:00
1.50 INTRM1, DRILLOUT FIT P Backream into shoe. Mousehole stand.
RU and perform FIT to 14.0ppg EMW.
Good test. RD test equipment.
12,409.0 12,409.0
3/4/2024
05:00
3/4/2024
06:00
1.00 INTRM1, DRILLOUT MPDA P Retrieve trip nipple and install RCD
bearing assembly. Break in bearing.
12,409.0 12,409.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 30/51
MT7-92
Report Printed: 4/22/2024
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)
3/4/2024
06:00
3/4/2024
06:30
0.50 INTRM1, DRILLOUT WASH P Wash back to bottom at 12409'.
450 GPM
1760 PSI
12.4ppg ECD
12,409.0 12,409.0
3/4/2024
06:30
3/4/2024
12:00
5.50 INTRM2, DRILL DDRL P Drill 12409' MD to 12490' MD / 7558'
TVD. Holding 13.0ppg EMW w/ MPD on
connections
21k WOB
550 GPM
3380 PSI
80 RPM
14k TQ
12.9ppg ECD
4 Bit hrs
4 jar hrs
12,409.0 12,490.0
3/4/2024
12:00
3/4/2024
13:30
1.50 INTRM2, DRILL CIRC P PU to 12481'. Drop 1.625" Torlon ball
and pump down to open underreamer.
Observed shear and staged up rates
and obtain parameters. Perform ledge
test to confirm reamer open.
12,490.0 12,490.0
3/4/2024
13:30
3/5/2024
00:00
10.50 INTRM2, DRILL DDRL P Drill 12490' MD to 12985' MD / 7911'
TVD. Holding 13.0ppg EMW w/ MPD on
connections
24k WOB
600 GPM
3470 PSI
150 RPM
20k TQ
13.1ppg ECD
12.1 Bit hrs
12.1 jar hrs
12,490.0 12,985.0
3/5/2024
00:00
3/5/2024
04:30
4.50 INTRM2, DRILL DDRL P Drill 12985' MD to 13361' MD / 8132'
TVD. Holding 13.0ppg EMW w/ MPD on
connections
24k WOB
600 GPM
3420 PSI
150 RPM
22k TQ
13.1ppg ECD
15,6 Bit hrs
15.6 jar hrs
12,490.0 13,361.0
3/5/2024
04:30
3/5/2024
05:30
1.00 INTRM2, DRILL CIRC T Observed RCD bearing leaking.
Circulate while staging equipment to
change out bearing. PJSM.
600 GPM
3420 PSi
80 RPM
20k TQ
13,361.0 13,361.0
3/5/2024
05:30
3/5/2024
06:30
1.00 INTRM2, DRILL MPDA T Close annular and trap 550psi. Open
MPD chokes and bleed off pressure.
Swap RCD bearing assembly. Equalize
pressure. Open annular.
13,361.0 13,361.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 31/51
MT7-92
Report Printed: 4/22/2024
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)
3/5/2024
06:30
3/5/2024
12:00
5.50 INTRM2, DRILL DDRL P Drill 13361' MD to 13737' MD / 8125'
TVD. Holding 13.0ppg EMW w/ MPD on
connections
24k WOB
600 GPM
3440 PSI
150 RPM
22k TQ
12.9ppg ECD
19.5 Bit hrs
19.5 jar hrs
13,361.0 13,737.0
3/5/2024
12:00
3/5/2024
17:00
5.00 INTRM2, DRILL DDRL P Drill 13737' MD to 14012' MD / 8355'
TVD (Casing point). Holding 13.0ppg
EMW w/ MPD on connections
12k WOB
600 GPM
3410 PSI
160 RPM
19k TQ
12.9ppg ECD
24.1 Bit hrs
24.1 jar hrs
13,737.0 14,012.0
3/5/2024
17:00
3/5/2024
19:30
2.50 INTRM2, TRIPCAS CIRC P Observed losses at 300 BPH. Drop
1.625" Torlon closing ball. Pump halfway
down @ 250 GPM. Slow rate 100 GPM
and pump 111 BBLS of 35 PPB LCM
pill. Shear observed @ 1605 PSI. UR
closed. Continue spotting LCM pill on
bottom. Losses decreased.
14,012.0 14,012.0
3/5/2024
19:30
3/5/2024
23:00
3.50 INTRM2, TRIPCAS SMPD P Flow check. Static. SOOH f/ 14012' to
12326'. Observed overpull at 13455'.
Work down and back through tight spot.
No issue. Holding 100psi w/ MPD to
overcome swab. Pull into shoe with no
issues.
14,012.0 12,326.0
3/5/2024
23:00
3/6/2024
00:00
1.00 INTRM2, TRIPCAS CIRC P Circulate hole clean. Stage up rates
from 150 GPM to 525 GPM. No losses
observed.
150-525 GPM
60 RPM
13k TQ
12,326.0 12,326.0
3/6/2024
00:00
3/6/2024
01:00
1.00 INTRM2, TRIPCAS CIRC P Circulate hole clean. Stage up rates
from 150 GPM to 525 GPM. No losses
observed.
150-525 GPM
2800 PSI
60 RPM
13k TQ
12,326.0 12,326.0
3/6/2024
01:00
3/6/2024
13:30
12.50 INTRM2, TRIPCAS SMPD P Flow check. Blow down TD. Drop 2.81"
drift w/ tail down drill string. SOOH to
BHA. Holding 12.4 ppg EMW w/ MPD.
Retrieve drift.
12,326.0 547.0
3/6/2024
13:30
3/6/2024
14:00
0.50 INTRM2, TRIPCAS OWFF P Flow check. Static 547.0 547.0
3/6/2024
14:00
3/6/2024
15:00
1.00 INTRM2, TRIPCAS MPDA P Retrieve RCD bearing assembly. Install
trip nipple.
547.0 547.0
3/6/2024
15:00
3/6/2024
17:30
2.50 INTRM2, TRIPCAS BHAH P POOH LD BHA. Visually all ok. 547.0 0.0
3/6/2024
17:30
3/6/2024
18:00
0.50 INTRM2, CASING CLEN P Clean and clear rig floor. 0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 32/51
MT7-92
Report Printed: 4/22/2024
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)
3/6/2024
18:00
3/6/2024
22:30
4.50 INTRM2, CASING BOPE P Change out UPRs to 7 5/8" casing
rams. Pull wear bushing. Install test
plug. RU and test Annular and UPRs to
250psi low and 3500 psi high f/ 5 10 min
each. RD test equipment. Install wear
bushing.
0.0 0.0
3/6/2024
22:30
3/6/2024
23:00
0.50 INTRM2, CASING RURD P PU cement swivel. MU to 15' pup joint
and lay back down.
0.0 0.0
3/6/2024
23:00
3/7/2024
00:00
1.00 INTRM2, CASING RURD P RU liner running equipment . 0.0 0.0
3/7/2024
00:00
3/7/2024
00:30
0.50 INTRM2, CASING RURD P RU to run liner. PJSM 0.0 0.0
3/7/2024
00:30
3/7/2024
02:00
1.50 INTRM2, CASING PUTB P MU and RIH w/ 7 5/8" 29.7# L-80 HYD
523 shoetrack. Threadlock connections.
Check floats. Good.
0.0 166.0
3/7/2024
02:00
3/7/2024
04:30
2.50 INTRM2, CASING PUTB P RIH w/ 7 5/8" 33.7# L-80 HYD 523 liner
f/ 166' to 1775'. Top filling on the fly and
topping off every 10 joints.
166.0 1,775.0
3/7/2024
04:30
3/7/2024
06:00
1.50 INTRM2, CASING PUTB P MU Dril-Quip Liner hanger. Change over
to DP handling equipment. RIH 1 std
DP.
1,775.0 1,930.0
3/7/2024
06:00
3/7/2024
07:00
1.00 INTRM2, CASING CIRC P Stage up rates to 5 BPM 505 PSI and
circulate 1.25 liner volume.
1,930.0 1,930.0
3/7/2024
07:00
3/7/2024
07:30
0.50 INTRM2, CASING MPDA P Retrieve trip nipple and install RCD
bearing assembly. Take parameters
120k PU
82k SO
101k ROT
1,930.0 2,025.0
3/7/2024
07:30
3/7/2024
18:00
10.50 INTRM2, CASING RUNL P SIH w/ Interm 2 liner on DP from 2025'
to 12294'. Fill pipe on the fly and top off
every 25 stds.
Take parameters at shoe:
300k PU
168k SO
196k ROT
15k TQ @ 10 RPM
10k TQ @ 20 RPM
2,025.0 12,294.0
3/7/2024
18:00
3/7/2024
20:00
2.00 INTRM2, CASING RUNL P SIH w/ Interm 2 liner on DP from 12294'
to 13950'. Fill pipe on the fly and top off
every 25 stds. Observed taking weight
@ 13950' 20-30k.
12,294.0 13,950.0
3/7/2024
20:00
3/7/2024
21:30
1.50 INTRM2, CASING WASH P Wash down f/ 13950' to 13990'. MU
cement swivel and wash down to
14010'. PU and set on depth at 14007'.
13,950.0 14,007.0
3/7/2024
21:30
3/8/2024
00:00
2.50 INTRM2, CEMENT CIRC P Circulate and condition mud. Stage
pumps up to 5 BPM. PJSM w/
cementers.
206 GPM
780 PSI
14,007.0 14,007.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 33/51
MT7-92
Report Printed: 4/22/2024
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)
3/8/2024
00:00
3/8/2024
03:00
3.00 INTRM2, CEMENT CMNT P Rig pump 70bbls 8.9ppg KCL 5% deep
clean spacer at 4bpm 780psi. Flood
lines and test to 5000 PSI. Drop bottom
dart. Swap to cementers. Pump 62
BBLS of 15.8ppg cement @ 3 BPM. SD
and drop top dart. Pump 10 BBLS FW
w/ cement unit. Swap to rig pumps and
displace at 4 BPM 450-750psi. (Drop
BOZO plug 791 stks in displacement
BTM dart landed at 1571stks and
sheared at 920psi. Top dart landed at
2270stks and sheared at 1723psi. BTM
plug landed at 2436stks and sheared at
1730psi). Slow rate to 3 BPM and bump
plug 3187stks (5.75bbls early). FCP -
450psi. Pressure up to 1000psi. Hold
for 5 minutes and check floats. All Good.
Full returns throughout job. No losses.
Cement in place @ 02:40hrs, 1/8/24.
TOL: 12206' MD
Landing collar 13,880' MD
Float collar: 13,962' MD
Shoe: 14007' MD
14,007.0 14,007.0
3/8/2024
03:00
3/8/2024
04:30
1.50 INTRM2, CEMENT PACK P Line up mud pump. Pressure up to
3000psi. Swap over to test pump and
continue pressuring up. Observe shear
ring at 3790 psi. Continue pressuring up
to 5000psi. Hold 10 minutes. Bleed
pressure to 500 psi. PU string to 300 k.
Bleed off pressure. PU to 375k (75k
over). Confirm hanger set.
14,007.0 14,007.0
3/8/2024
04:30
3/8/2024
05:30
1.00 INTRM2, CEMENT PRTS P LD cement swivel. PU single of DP.
Slack off to 165k (30k down). Close
annular and test Liner top to 2000psi f/
10 minutes. Charted. Good test.
14,007.0 14,007.0
3/8/2024
05:30
3/8/2024
06:00
0.50 INTRM2, CEMENT PRTS P Pull running tool out of liner top (15-20k
OP). LD single and 15 ' pup joint. Rack
back 1 std of DP. Screw into TD and
pressure up to1000psi to Bleed off
pressure confirm BOZO plug seated.
14,007.0 14,007.0
3/8/2024
06:00
3/8/2024
08:00
2.00 INTRM2, CEMENT PRTS P RU 10k test pump and attempt to Shear
BOZO plug. Pressure up to 4000psi w/
mud pumps. Isolate mud pump and
swap over to 10k test pump. Unable to
build pressure with test pump. Discuss
with town and decision made to use
pump truck and hardline top shear
BOZO plug.
14,007.0 14,007.0
3/8/2024
08:00
3/8/2024
10:30
2.50 INTRM2, CEMENT RURD P Clean and clear rig floor. RU hard line to
cellar for cement unit to shear BOZO
plug.
11,968.0 11,968.0
3/8/2024
10:30
3/8/2024
13:00
2.50 INTRM2, CEMENT MPDA P Retrieve RCD bearing assembly and
install trip nipple. Perform PMs and
clean rig floor while waiting on cement
unit.
11,968.0 11,968.0
3/8/2024
13:00
3/8/2024
14:00
1.00 INTRM2, CEMENT CIRC P Spot cement truck. RU. Pressure test
lines to 7500 psi. Pressure up and
observe plug shear @ 6400 psi. Bleed
off pressure. Blow down lines and RD
equipment.
11,968.0 11,968.0
3/8/2024
14:00
3/8/2024
15:30
1.50 INTRM2, CEMENT CIRC P Circulate surface to surface. 113 bbls
interface dumped. Pump slug. Blow
down TD.
475 GPM
1750 PSI
11,968.0 11,968.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 34/51
MT7-92
Report Printed: 4/22/2024
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)
3/8/2024
15:30
3/9/2024
00:00
8.50 INTRM2, CEMENT TRIP P POOH f/ 11968' to running tool. Culling
and LD bad drill pipe.
11,968.0 523.0
3/9/2024
00:00
3/9/2024
00:30
0.50 INTRM2, CEMENT TRIP P POOH to running tool 523.0 40.0
3/9/2024
00:30
3/9/2024
02:00
1.50 INTRM2, CEMENT PULD P LD running tool. 40.0 0.0
3/9/2024
02:00
3/9/2024
02:45
0.75 INTRM2, CEMENT CIRC P Retrieve wear bushing. Jet BOPE and
wellhead.
0.0 0.0
3/9/2024
02:45
3/9/2024
04:00
1.25 INTRM2, WHDBOP BOPE P Close blind rams. Change out UPRs to
2 7/8" x 5" VBR. Set test plug.
0.0 0.0
3/9/2024
04:00
3/9/2024
05:30
1.50 INTRM2, WHDBOP BOPE P Test UPRs 250psi low/3500psi high f/ 5
10 min ea with 5" and 4" tets joints.
0.0 0.0
3/9/2024
05:30
3/9/2024
06:30
1.00 INTRM2, WHDBOP RURD P RD test equipment. Retrieve test plug.
Install 8.6875" wear bushing.
0.0 0.0
3/9/2024
06:30
3/9/2024
08:30
2.00 INTRM2, WHDBOP PRTS T Close blind rams and attempt to test
casing to 3500 psi. Observed pressure
leak off at 2612 psi. Monitor and
observe pressure bleed off to 1130 psi.
Bleed off 12 bbls pumped/3 bbls
returned.
2nd attempt: pressure up to 1234 psi
observed pressure bleeding off. Monitor
and pressure fell to 735 psi. 6 bbls
pumped/6 bbls returned.
0.0 0.0
3/9/2024
08:30
3/9/2024
11:00
2.50 INTRM2, WHDBOP WAIT T Discuss plan forward with office. 0.0 0.0
3/9/2024
11:00
3/9/2024
12:00
1.00 INTRM2, WHDBOP BHAH T Stage clean out BHA to floor. 0.0 0.0
3/9/2024
12:00
3/9/2024
23:30
11.50 INTRM2, DRILLOUT TRIP T RIH w/ 6 1/2" cleanout BHA to 4700'.
Log down f/ 4700' to 12206' Sonic tool
at 1800 FPH.
0.0 12,206.0
3/9/2024
23:30
3/10/2024
00:00
0.50 INTRM2, DRILLOUT WASH T Wash down through TOL.
160 GPM
550 PSI
0.0 12,206.0
3/10/2024
00:00
3/10/2024
02:00
2.00 INTRM2, DRILLOUT DRLG T Wash down and tag DPOB @ 12229'.
Drill out DPOB. Work through DPOB 3
times after drilling out.
160-300 GPM
500-1425 PSI
60 RPM
5-10k TQ
8-10k WOB
12,206.0 12,235.0
3/10/2024
02:00
3/10/2024
06:30
4.50 INTRM2, DRILLOUT WASH T Wash/Ream while logging 12235' to
13879' (Plugs/LC).
200 GPM
960 PSI
60 RPM
13k TQ
12,206.0 13,879.0
3/10/2024
06:30
3/10/2024
08:45
2.25 INTRM2, DRILLOUT PRTS T Rack back std. RU and attempt to test
casing. pressure up to 1789 PSI and
observed pressure leaking off. SD and
monitor. Pressure bled off to 958
PSI.Bled off pressure. 8bbls
pumped/3bbls returned.
13,879.0 13,879.0
3/10/2024
08:45
3/10/2024
10:15
1.50 INTRM2, DRILLOUT SLPC T Slip/Cut drill line. 13,879.0 13,879.0
3/10/2024
10:15
3/10/2024
20:00
9.75 INTRM2, DRILLOUT TRIP T POOH f/ 13879' to BHA. 13,879.0 132.0
3/10/2024
20:00
3/10/2024
20:45
0.75 INTRM2, DRILLOUT BHAH T Flow check. PJSM. LD BHA. 132.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 35/51
MT7-92
Report Printed: 4/22/2024
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)
3/10/2024
20:45
3/10/2024
21:15
0.50 INTRM2, DRILLOUT CLEN T Clean and clear rig floor. 0.0 0.0
3/10/2024
21:15
3/11/2024
00:00
2.75 INTRM2, DRILLOUT TRIP T MU 7 5/8" test packer and RIH f/ surface
to 3428'.
0.0 3,428.0
3/11/2024
00:00
3/11/2024
05:00
5.00 INTRM2, DRILLOUT TRIP T RIH f/ 3428' to 12244' w/ 7 5/8" test
packer.No issue going in to TOL.
0.0 12,244.0
3/11/2024
05:00
3/11/2024
06:00
1.00 INTRM2, DRILLOUT MPSP T MU cement swivel, Space out. Break
circulation. Set test packer as per Baker.
12,244.0 12,244.0
3/11/2024
06:00
3/11/2024
07:30
1.50 INTRM2, DRILLOUT PRTS T Close UPR. pressure up on IA to 3500
PSI. Held for 10 min. Good test. Bleed
off pressure.
Line up and pressure up down DS to
test 7 5/8" liner. Pressure up to 3500
PSI and hold f/ 20 min. Good test.
Repeat test and hold f/ 30 minutes.
Good test. Bleed off pressure .
12,244.0 12,244.0
3/11/2024
07:30
3/11/2024
08:00
0.50 INTRM2, DRILLOUT TRIP T Release packer and POOH to 12187'
Above TOL.
12,244.0 12,244.0
3/11/2024
08:00
3/11/2024
09:30
1.50 INTRM2, DRILLOUT PRTS T Line up to test 9 5/8"/7 5/8" casing
through kill line. Close UPR. Pressure
up to 3500 PSI. Hold for 30 minutes.
Charted. Good test. 14 bbls pumped
and 14 bbls returned. RD test
equipment.
12,244.0 12,244.0
3/11/2024
09:30
3/11/2024
18:00
8.50 INTRM2, DRILLOUT TRIP T POOH w/ test packer. LD test packer. 12,244.0 0.0
3/11/2024
18:00
3/11/2024
19:30
1.50 INTRM2, DRILLOUT CLEN P Clean and clear rig floor. 0.0 0.0
3/11/2024
19:30
3/11/2024
22:00
2.50 INTRM2, DRILLOUT BHAH P MU and rack back 4" DP in derrick. MU
BHA for polish run on DPOB. Complete
work orders. Wait on string mill.
0.0 0.0
3/11/2024
22:00
3/12/2024
00:00
2.00 INTRM2, DRILLOUT BHAH P MU 6 5/8" sting mill and RIH w/th
polishing BHA to 3354'.
0.0 3,354.0
3/12/2024
00:00
3/12/2024
04:00
4.00 INTRM2, DRILLOUT TRIP P Continue RIH w/ 6 5/8" string mill to
12210'
3,354.0 12,210.0
3/12/2024
04:00
3/12/2024
05:00
1.00 INTRM2, DRILLOUT REAM P Wash down to DPOB w/ string mill.
Engage rotary and wash/ream through
DPOB 4 times at 60 RPM 200 GPM.
Stop rotary and observed drag gong
through DPOB. Ream through 4 times
at 40 RPM/ 200 GPM. Drift through
DPOB w/ no rotary. No issues.
12,210.0 12,230.0
3/12/2024
05:00
3/12/2024
08:30
3.50 INTRM2, DRILLOUT CIRC P Pump slug. String still wet. Pumped 2nd
slug, Drillstring still full. Mix and pump
3rd slug. Pipe pulled dry.
12,230.0 12,230.0
3/12/2024
08:30
3/12/2024
13:30
5.00 INTRM2, DRILLOUT TRIP P POOH w/ string mill. 12,230.0 134.0
3/12/2024
13:30
3/12/2024
14:30
1.00 INTRM2, DRILLOUT BHAH P LD String mill and DC. 134.0 0.0
3/12/2024
14:30
3/12/2024
15:15
0.75 INTRM2, DRILLOUT CIRC P Jet BOPE and WH. 0.0 0.0
3/12/2024
15:15
3/12/2024
17:30
2.25 INTRM2, DRILLOUT RURD P Retrieve wear bushing. Install test plug.
RU to test BOPE.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 36/51
MT7-92
Report Printed: 4/22/2024
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)
3/12/2024
17:30
3/12/2024
23:30
6.00 INTRM2, DRILLOUT BOPE P BOPE Test All tests to 250psi/5min
3500psi/10min Annular 250psi/5min
3500psi/10min w/ exception of manual
and super choke t/ 2000 psi. 5” Test jt:
test 2 7/8" x 5" UPR/2 7/8" 5" LPR, W/
4" Test jt: test annular/2 7/8" x 5" UPR/2
7/8" 5" LPR,Test choke valves 1-15.
Manuals operated and super choke.
Choke manuals and HCR valves. 4" kill
line valve. Test 2x 4" FO safety valves.
4" dart valve. 2x 5" FO safety valves. 5"
dart valve. Test upper and lower IBOP.
Blind/Shear rams.
Performed Koomey draw down, ACC =
3000 psi, Manifold = 1400 psi, ACC =
1800 psi after all functions on bottles,14
sec for 200 psi. Build w/ 2 electric
pumps, 81 sec to build full system
pressure w/ 2 electrical and 2 air pumps,
closing times annular = 23 sec. UPR =
18 sec, Blind / Shears = 16 sec, LPR =
16 sec, choke HCR = 2 sec, Kill HCR =
2 sec. Test PVT gain/loss and flow out
alarms. Test LEL and H2S alarms.
AOGCC- Witnessed by Sean Sullivan
BLM Quinn M Sawyer waived witness
BOP test at 19:07hrs 3.12.24.
0.0 0.0
3/12/2024
23:30
3/13/2024
00:00
0.50 INTRM2, DRILLOUT RURD P RD test equipment. Retrieve test plug. 0.0 0.0
3/13/2024
00:00
3/13/2024
01:00
1.00 INTRM2, DRILLOUT RURD P Install 6.875" wear bushing. 0.0 0.0
3/13/2024
01:00
3/13/2024
04:30
3.50 INTRM2, DRILLOUT BHAH P PJSM. MU and RIH w/ 6 1/2" production
BHA. RIH to 523'.
0.0 523.0
3/13/2024
04:30
3/13/2024
05:00
0.50 INTRM2, DRILLOUT SVRG P Service PS-21s. 523.0 523.0
3/13/2024
05:00
3/13/2024
06:00
1.00 INTRM2, DRILLOUT TRIP P RIH f/ 523' to 2593' out of derrick. 523.0 2,593.0
3/13/2024
06:00
3/13/2024
07:30
1.50 INTRM2, DRILLOUT CIRC P Break circulation and perform shallow
test on MWD. Tools coming on @ 250
GPM.
2,593.0 2,593.0
3/13/2024
07:30
3/13/2024
08:00
0.50 INTRM2, DRILLOUT TRIP P RIH f/ 2593' to 3446' out of derrick. 2,593.0 3,446.0
3/13/2024
08:00
3/13/2024
17:00
9.00 INTRM2, DRILLOUT PULD P RIH f/ 3446' to 13479' w/ 4" doubles
from pipe shed.
3,446.0 13,479.0
3/13/2024
17:00
3/13/2024
19:00
2.00 INTRM2, DRILLOUT WASH P C/O handling equipment to 5" DP. RIH
to 13671'. Obtain parameters. PU single
of 5" DP and tag Landing collar @
13879'.
13,479.0 13,879.0
3/13/2024
19:00
3/14/2024
00:00
5.00 INTRM2, DRILLOUT DRLG P Drill out plugs/LC from 13879' to 13881'
Varying pump rates/WOB/RPM
140-190 GPM
697-1567 PSI
20-80 RPM
9-11k TQ
5-20k WOB
13,879.0 13,881.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 37/51
MT7-92
Report Printed: 4/22/2024
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)
3/14/2024
00:00
3/14/2024
05:00
5.00 INTRM2, DRILLOUT DRLG P Drill LC and shoetrack to FC at 13962'.
Several issues while drilling LC. Start w/
low WOB and 80 RPM. No progress
being made. Vary WOB/RPMs/flow
rates with no success. Work pipe and
restart several times. Pulled up above
LC and worked DS several times.
Wash/ream back down to LC and drilled
LC out with no issue. Washed down
through shoetrack to FC.
5-25k WOB
140-190 GPM
700-1100 PSI
60-100 RPM
9-10k TQ
13,881.0 13,962.0
3/14/2024
05:00
3/14/2024
06:00
1.00 INTRM2, DRILLOUT DRLG P PJSM on displacement. Drill out FC and
shoetrack to 13984' (5' above FS).
Pump 40bbl LVT + 100bbls 12.5ppg
transition spacer + 100bbls cleaning
spacer + 50bbls 8.8ppg viscosified tail
spacer + Chase w/ 8.5ppg FloPro.
13,962.0 13,984.0
3/14/2024
06:00
3/14/2024
09:30
3.50 INTRM2, DRILLOUT DISP P Circulate and reciprocate DS while
displace well to 8.5ppg FloPro.
250 GPM
1020 PSI
60 RPM
6k TQ
13,984.0 13,984.0
3/14/2024
09:30
3/14/2024
12:00
2.50 INTRM2, DRILLOUT CLEN P LD working single of 5" DP. Clean
surface equipment after displacement.
SimOps: Slip/Cut drill line.
13,984.0 13,984.0
3/14/2024
12:00
3/14/2024
19:00
7.00 INTRM2, DRILLOUT DRLG P Wash down and drill out cement to FS at
14007'. Vary WOB/RPMs/flow rates to
drill out FS. Set down on FS with no
rotary. Work std to clear debris.
5-30k WOB
160-220 GPM
700-980 PSI
60-100 RPM
2-6k TQ
13,984.0 14,008.0
3/14/2024
19:00
3/14/2024
21:30
2.50 INTRM2, DRILLOUT TRIP P Short trip 5 stds to 13576'. Work std
aggressively to clear any debris
wrapped around drill string.
160 GPM
510 PSI
80 RPM
2-8k TQ
14,008.0 13,576.0
3/14/2024
21:30
3/14/2024
22:00
0.50 INTRM2, DRILLOUT WASH P Wash/ream back to top of FS at 14007' 13,576.0 14,007.0
3/14/2024
22:00
3/14/2024
23:00
1.00 INTRM2, DRILLOUT DDRL P Drill out FS with 4-6k WOB. Clean out
RH. Drill 20' new formation to 14032'.
Work through float shoe with no issues.
BROOH into casing.
8-10k WOB
180 GPM
800 PSI
80 RPM
3-8k TQ
14,007.0 14,032.0
3/14/2024
23:00
3/15/2024
00:00
1.00 INTRM2, DRILLOUT FIT P RU and perform FIT to 12.0ppg EMW.
RD test equipment.
14,032.0 14,032.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 38/51
MT7-92
Report Printed: 4/22/2024
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)
3/15/2024
00:00
3/15/2024
00:30
0.50 PROD1, DRILL DDRL P Drill 14032' MD to 14048' MD/ 8355'
TVD
22k WOB
220 GPM
1005 PSI
80 RPM
8k TQ
8.8ppg ECD
14,032.0 14,048.0
3/15/2024
00:30
3/15/2024
01:30
1.00 PROD1, DRILL MPDA P Pull back into shoe. Retrieve trip nipple
and install RCD bearing assembly.
Ream back to bottom.
14,048.0 14,048.0
3/15/2024
01:30
3/15/2024
06:00
4.50 PROD1, DRILL DDRL P Drill 14048' MD to 14421' MD/ 8406'
TVD
22k WOB
220 GPM
1005 PSI
120 RPM
8k TQ
8.8ppg ECD
14,048.0 14,421.0
3/15/2024
06:00
3/15/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 14421' MD to 15045' MD/ 8434'
TVD. Close choke on connections 0 psi.
10k WOB
220 GPM
1120 PSI
145 RPM
8k TQ
9.1ppg ECD
225k PU
180k SO
204k ROT
8.6 Bit hrs
14,421.0 15,045.0
3/15/2024
12:00
3/15/2024
18:00
6.00 PROD1, DRILL DDRL P Drill 15045' MD to 15720' MD/ 8434'
TVD. Close choke on connections 0 psi.
10k WOB
190 GPM
1080 PSI
120 RPM
10k TQ
9.2ppg ECD
243 units max gas
235k PU
177k SO
195k ROT
12.6 Bit hrs
15,045.0 15,720.0
3/15/2024
18:00
3/16/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 15720' MD to 16400' MD/ 8429'
TVD. Close choke on connections 0 psi.
15k WOB
190 GPM
1094 PSI
120 RPM
10k TQ
9.2ppg ECD
1330 units max gas
240k PU
176k SO
197k ROT
17 Bit hrs
15,720.0 16,400.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 39/51
MT7-92
Report Printed: 4/22/2024
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)
3/16/2024
00:00
3/16/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 16400' MD to 17100' MD/ 8415'
TVD. Close choke on connections 0 psi.
15k WOB
190 GPM
1180 PSI
120 RPM
12k TQ
9.3ppg ECD
326 units max gas
240k PU
176k SO
197k ROT
21.4 Bit hrs
16,400.0 17,100.0
3/16/2024
06:00
3/16/2024
09:30
3.50 PROD1, DRILL DDRL P Drill 17100' MD to 17528' MD/ 8415'
TVD. Close choke on connections 0 psi.
18k WOB
180 GPM
1000 PSI
120 RPM
12k TQ
9.2ppg ECD
326 units max gas
240k PU
176k SO
197k ROT
21.4 Bit hrs
Observed 90/120 BPH loss rate at
17400'. Pumped 93 bbls of 35 ppb LCM
pill at 17436'.
17,100.0 17,528.0
3/16/2024
09:30
3/16/2024
10:30
1.00 PROD1, DRILL CIRC T Reciprocate drillstring whlie spotting
35ppb LCM pill @ 17528'.
17,528.0 17,528.0
3/16/2024
10:30
3/16/2024
11:30
1.00 PROD1, DRILL TRIP T POOH on elevators f/ 17528' to 16870'. 17,528.0 16,870.0
3/16/2024
11:30
3/16/2024
12:30
1.00 PROD1, DRILL OWFF T Establish static loss rate. 100 BPH 17,528.0 16,870.0
3/16/2024
12:30
3/16/2024
16:30
4.00 PROD1, DRILL WAIT T Circulate across top of hole and wait on
cementers.
17,528.0 16,870.0
3/16/2024
16:30
3/16/2024
17:30
1.00 PROD1, DRILL WAIT T Dowel trouble shoot iCem computer.
Unable to resolve. Decision made to
proceed and collect data manually.
16,870.0 16,870.0
3/16/2024
17:30
3/16/2024
18:00
0.50 PROD1, DRILL RURD T MU cement swivel and establish
injection rates.
Rate IA Press SPP
2 BPM 28 PSI 418 PSI
3 BPM 257 PSI712 PSI
4 BPM 315 PSI1010 PSI
17,528.0 16,870.0
3/16/2024
18:00
3/16/2024
20:30
2.50 PROD1, DRILL CMNT T PJSM. Test lines to 4500 PSI. Pump 30
BBLS of 12.0 ppg mudpush spacer +
156 BBLS of 14.0 ppg Thixotropic
cement (Shut in MPD chokes and begin
bullheading) + 20 BBLS 12.0 ppg
mudpush spacer + 20 BBLS FW w/
cement unit. Swap over to rig pumps.
Bullhead cement w/ 177 BBLS of 8.6
ppg FloPro mud at 3 BPM with injection
pressure building to 930 PSI. Observed
drillstring stall out at 20k TQ 80 BBLS
into bullheading. Worked pipe
unsuccessfully. Finished bullheading.
Slow rate to 2 BPM. w/ 10 BBLS left. SD
and monitor pressure. Bled off to 0 PSI.
Cement in place at 20:33 hrs 3/16/24
17,528.0 16,870.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 40/51
MT7-92
Report Printed: 4/22/2024
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)
3/16/2024
20:30
3/16/2024
21:30
1.00 PROD1, DRILL CIRC T LD cement swivel. Attempt to POOH.
Observed OP. Work pipe 90k over up
and 40k down. Stall out with rotary at
20k TQ. Pump at 2-3 BPM w/ minimal
returns. Attempt torque and slump with
no success. Stage up pumps to 200
GPM. Tools came on. Work pipe down
and torque broke over. Backream to top
of stand.
17,528.0 16,870.0
3/16/2024
21:30
3/17/2024
00:00
2.50 PROD1, DRILL BKRM T BROOH f/ 16870' to 16300'
200 GPM
1180 PSI
60 RPM
8k TQ.
Loss rate:
Static 35 BPH
Dynamic 100 BPH
17,528.0 16,870.0
3/17/2024
00:00
3/17/2024
06:00
6.00 PROD1, DRILL BKRM T BROOH f/ 16300' to 13981' into shoe.
200 GPM
1180 PSI
60 RPM
8k TQ.
Loss rate:
Static 35 BPH
Dynamic 100 BPH
16,870.0 13,981.0
3/17/2024
06:00
3/17/2024
07:30
1.50 PROD1, DRILL CIRC T Establish loss rates.
Static: 58 BPH
Dynamic: 84 BPH at 180 GPM
13,981.0 13,981.0
3/17/2024
07:30
3/17/2024
09:30
2.00 PROD1, DRILL CIRC T Circulate 47 BBL sugar water pill
surface to surface.
180 GPM
780 PSI
30 RPM
8k TQ
13,981.0 13,981.0
3/17/2024
09:30
3/17/2024
20:00
10.50 PROD1, DRILL REAM T Ream back in hole f/ 13981' to 17528'.
180 GPM
830 PSI
80 RPM
8k TQ
8.9 ppg ECD
Loss rate @ 200 GPM 25-30 BPH.
13,981.0 17,528.0
3/17/2024
20:00
3/17/2024
21:00
1.00 PROD1, DRILL DDRL P Drill 17528' MD to 17619' MD/ 8406'
TVD. Close choke on connections 0 psi.
Observed increase in cement
contamination on BU. Mud aired up.
18k WOB
180 GPM
1000 PSI
120 RPM
12k TQ
9.2ppg ECD
326 units max gas
240k PU
176k SO
197k ROT
21.4 Bit hrs
17,528.0 17,619.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 41/51
MT7-92
Report Printed: 4/22/2024
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)
3/17/2024
21:00
3/18/2024
00:00
3.00 PROD1, DRILL CIRC T Circulate and treat comtaminated/aired
up mud. Weak pulse from MWD tools.
Not receiving good data. Continue
circulating and troubleshooting tools. 30
bbls FW pill to clear tools.
17,619.0 17,619.0
3/18/2024
00:00
3/18/2024
03:00
3.00 PROD1, DRILL CIRC T Pump 2nd 30 BBLs FW pill to flush
pulser. Continue treating mud. PU single
and drill to 17646'. Troubleshooting
tools. No success.
200-250 GPM
900-1100 PSI
120 RPM
14k TQ
17,619.0 17,646.0
3/18/2024
03:00
3/18/2024
03:30
0.50 PROD1, DRILL OWFF T LD single. BD Top Drive. Flow check.
Static losses 18 BPH.
17,646.0 17,646.0
3/18/2024
03:30
3/18/2024
07:30
4.00 PROD1, DRILL SMPD T SOOH f/ 17646' to 13948'. 17,646.0 13,948.0
3/18/2024
07:30
3/18/2024
10:30
3.00 PROD1, DRILL CIRC T Pump 10 bbls hi vis spacer + 100 bbls
deep clean pill + 10 bbls hi vis spacer.
Circulate to surface. Troubleshoot tools
while circulating.
250-300 GPM
60 RPM
7k TQ
13,948.0 13,948.0
3/18/2024
10:30
3/18/2024
11:00
0.50 PROD1, DRILL SMPD T SOOH f/ 13948' to 13384'. 13,948.0 13,384.0
3/18/2024
11:00
3/18/2024
12:00
1.00 PROD1, DRILL MPDA T Flow check. Pump 30 bbls slug and
blow down top drive. Retrieve RCD
bearing assembly and install trip nipple.
13,384.0 13,384.0
3/18/2024
12:00
3/18/2024
20:30
8.50 PROD1, DRILL TRIP T POOH f/ 13384 to BHA @ 230'.
Note:
Observe greased out cement on tool
joints while TOOH. Clean powerslips
and rig floor as required.
13,384.0 230.0
3/18/2024
20:30
3/18/2024
21:00
0.50 PROD1, DRILL OWFF T Flow check. 18 BPH static loss. Perfrom
weekly BOP function test
17,646.0 17,646.0
3/18/2024
21:00
3/18/2024
23:00
2.00 PROD1, DRILL BHAH T PJSM. Inspect and LD BHA. 230.0 0.0
3/18/2024
23:00
3/19/2024
00:00
1.00 PROD1, DRILL CLEN T Clean and clear rig floor. Inspect BHA.
Note:
Observe greased out cement coating
entire BHA. Use surfactant and power
washer to clean off.
17,646.0 17,646.0
3/19/2024
00:00
3/19/2024
04:00
4.00 PROD1, DRILL BHAH T MU and RIH w/ 6 1/2" Production BHA
to 230'.
0.0 230.0
3/19/2024
04:00
3/19/2024
06:00
2.00 PROD1, DRILL TRIP T RIH f/ 230' to 2591' w/ 6 1/2" Production
BHA. Perform shallow test on first fillup.
Good test.
230.0 2,591.0
3/19/2024
06:00
3/19/2024
13:00
7.00 PROD1, DRILL TRIP T RIH f/ 2591' to 13479' w/ 6 1/2"
Production BHA.
2,591.0 13,479.0
3/19/2024
13:00
3/19/2024
14:00
1.00 PROD1, DRILL MPDA T Flow check. 18 BPH losses. PJSM.
Retrieve trip nipple and install RCD
bearing assembly.
13,479.0 13,479.0
3/19/2024
14:00
3/19/2024
14:30
0.50 PROD1, DRILL TRIP T RIH f/ 13479' to 13953' w/ 6 1/2"
Production BHA.
13,479.0 13,953.0
3/19/2024
14:30
3/19/2024
15:30
1.00 PROD1, DRILL T Slip/Cut drill line 13,953.0 13,953.0
3/19/2024
15:30
3/19/2024
16:00
0.50 PROD1, DRILL SVRG T Service Rig and Top Drive. 13,953.0 13,953.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 42/51
MT7-92
Report Printed: 4/22/2024
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)
3/19/2024
16:00
3/19/2024
19:00
3.00 PROD1, DRILL SMPD T SIH f/ 13953' to 17155' 13,953.0 17,155.0
3/19/2024
19:00
3/19/2024
20:45
1.75 PROD1, DRILL WASH T Wash/Ream down f/ 17155' to 17646'.
150-200 GPM
650-1060 PSI
60-80 RPM
10-13k TQ
17,155.0 17,646.0
3/19/2024
20:45
3/20/2024
00:00
3.25 PROD1, DRILL DDRL P Drill 17646' MD to 17905' MD / 8398'
TVD. Close choke on connections 0 psi.
10k WOB
200 GPM
1060 PSI
130 RPM
15k TQ
9.1ppg ECD
326 units max gas
240k PU
176k SO
197k ROT
2.3 Bit hrs
17,646.0 17,905.0
3/20/2024
00:00
3/20/2024
02:00
2.00 PROD1, DRILL DDRL T Drill 17,905' MD to 18,094' MD/ 8405'
TVD. Close choke on connections 0 psi.
@ 18,010'MD lost returns, pumped 98
bbls @ 7BPM on backside to fill the
hole, Continued drilling ahead, pumped
95BBLS of 35PPB LCM Pill.
15k WOB
200 GPM
1070/795 PSI
130 RPM
16k TQ
7.9-9.2ppg ECD
92 units max gas
272k PU
155k SO
219k ROT
2.3 Bit hrs
17,905.0 18,094.0
3/20/2024
02:00
3/20/2024
03:00
1.00 PROD1, DRILL CIRC T Circulate and reciprocate till LCM Pill
out of BHA. Slow pump rate to turn tools
off as pill passed through BHA., keep
pump on backside @ 42 GPM to keep
hole full, 192 BPH dynamic loss rate @
142 GPM
100 GPM
327 PSI
80 RPM
13K TQ
18,904.0 18,904.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 43/51
MT7-92
Report Printed: 4/22/2024
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)
3/20/2024
03:00
3/20/2024
05:30
2.50 PROD1, DRILL DDRL T Drill 18,094'MD to 18,283"MD, @
18,190'MD pump 90BBLS of 35PPB
LCM Pill. Loss rate @ 150-190 BPH.
Drilled through 5 features:
18010'/18080'/18088'/18105'/18130'.
8k WOB
180 GPM
913 PSI
130 RPM
13k TQ
9.1ppg ECD
52 units max gas
272k PU
222k SO
219k ROT
5.9 Bit hrs
18,094.0 18,283.0
3/20/2024
05:30
3/20/2024
06:00
0.50 PROD1, DRILL CIRC T Circulate and reciprocate till LCM Pill
out of BHA, Slow pump rate to turn tools
off as pill passed through BHA.
100 GPM
327 PSI
80 RPM
13K TQ
18,283.0 18,283.0
3/20/2024
06:00
3/20/2024
06:30
0.50 PROD1, DRILL CIRC T Down link tools off. Take SPR's. B/D top
drive
18,283.0 18,283.0
3/20/2024
06:30
3/20/2024
11:00
4.50 PROD1, DRILL SMPD T F/18,283'MD to 13,954'MD, SOOH on
elevators pumping across top of hole
3 BPM
231K PU
18,283.0 13,954.0
3/20/2024
11:00
3/20/2024
12:15
1.25 PROD1, DRILL RURD T Establish static loss rate of 80 BPH.
Make up cement swivel and cement
line, Establish circulation,
3 BPM-400 PSI SPP
4 BPM-675 PSI SPP
Close Chokes
3 BPM-210 PSI IA
4 BPM-225 PSI IA
13,954.0 13,954.0
3/20/2024
12:15
3/20/2024
15:30
3.25 PROD1, DRILL CMNT T PJSM. Swap over to cement unit. Flood
lines and test to 4500 PSI. Mix and
pump 31 bbls 13.0 ppg MudPush spacer
+ 159 bbls 14.0 ppg Thixotropic cement
+ 26 bbls 13.0 ppg MudPush spacer +
20 bbls FW (Closed MPD chokes after
pumping 100bbls of cement). Swap to
rig pumps and continue bullhead
cement to loss zones at 3 BPM. Max IA
pressure observed 604 PSI. SD and
monitor pressure. Bled to 0 PSI in 10
minutes. Cement in place at 15:08 hrs
3/20/24. Rotate at 5 RPM throughout
job.
13,954.0 13,954.0
3/20/2024
15:30
3/20/2024
16:00
0.50 PROD1, DRILL TRIP T LD cement swivel and POOH to 13575'. 13,954.0 13,575.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 44/51
MT7-92
Report Printed: 4/22/2024
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)
3/20/2024
16:00
3/20/2024
22:45
6.75 PROD1, DRILL WOC T Pump 35 bbls sugar water. Circulate
liner volume.
2-3 BPM
285-415 PSI
10 RPM
4k TQ
Circulate across top of hole while
waiting on cement.
Static loss rate 35-45 BPH
13,575.0 13,575.0
3/20/2024
22:45
3/21/2024
00:00
1.25 PROD1, DRILL WASH T Wash/Ream f/ 13575' to 13860'
200 GPM
810 PSI
60 RPM
4k TQ
Dynamic loss rate- 45-60 BPH
13,575.0 13,860.0
3/21/2024
00:00
3/21/2024
03:00
3.00 PROD1, DRILL WASH T Wash/Ream f/ 13860' to 15180', 200
GPM, 810 PSI, 60 RPM, 4k TQ.
Dynamic loss rate- 45-60 BPH.
13,860.0 15,180.0
3/21/2024
03:00
3/21/2024
03:30
0.50 PROD1, DRILL SVRG T Service PS-21s. 15,180.0 15,180.0
3/21/2024
03:30
3/21/2024
10:30
7.00 PROD1, DRILL WASH T Wash/Ream f/ 15180' to 18283', 200
GPM, 810 PSI, 60 RPM, 4k TQ.
Dynamic loss rate- 45-60 BPH.
15,180.0 18,283.0
3/21/2024
10:30
3/21/2024
15:30
5.00 PROD1, DRILL DDRL P Drill f/ 18283'MD to 18750'MD. Lost
returns at 18725'. Continue to drill std
down to 18750'. Loss rate 600-700
BPH.
15k WOB
180 GPM
1002 PSI
140 RPM
20k TQ
9.4ppg ECD
278k PU
212k ROT
7 Bit hrs
18,283.0 18,750.0
3/21/2024
15:30
3/21/2024
19:00
3.50 PROD1, DRILL DDRL T Drill f/ 18750'MD to 19032' MD. Pumped
100 BBLS of 35PPB LCM pill while
drilling std down. No improvement in
loss rate. Drill down 2 more stds. Loss
rate decreased to 400-450 BPH.
15k WOB
180 GPM
1002 PSI
140 RPM
20k TQ
9.4ppg ECD
278k PU
212k ROT
7 Bit hrs
18,750.0 19,032.0
3/21/2024
19:00
3/21/2024
20:00
1.00 PROD1, DRILL BKRM T BROOH to 18625' (above loss zone).
180 GPM
650 PSI
80 RPM
20k TQ
19,032.0 18,625.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 45/51
MT7-92
Report Printed: 4/22/2024
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)
3/21/2024
20:00
3/21/2024
23:00
3.00 PROD1, DRILL CIRC T Pump down WC opening ball. Shifted at
1420 PSI. Confirmed WC open. Drop
WC isolation ball down DP. Remove
screen f/ mud pump. Pump 30 BBLs
mud ahead and pump 100 BBLS of 130
PPB LCM pill. Slow rate when isolation
ball lands and stage up to 4 BPM.
Displace pill into annulus. Observed
losses decreasing as pill exited WC,
18,625.0 18,625.0
3/21/2024
23:00
3/22/2024
00:00
1.00 PROD1, DRILL SMPD T Drop WC closing ball and POOH f/
18625' to 17605'.
18,625.0 17,605.0
3/22/2024
00:00
3/22/2024
01:30
1.50 PROD1, DRILL SMPD T SOOH on elevators F/17,605' MD
T/16,117' MD.
258K PUW
17,605.0 16,117.0
3/22/2024
01:30
3/22/2024
02:30
1.00 PROD1, DRILL CIRC T Pressure up and shift Well Commander
closed. Shifted at 1780 PSI. Circulate at
3BPM to flush BHA. Stage up to 180
GPM and establish loss rates.
200 BPH dynamic
120 BPH static
16,117.0 16,117.0
3/22/2024
02:30
3/22/2024
05:00
2.50 PROD1, DRILL SMPD T SOOH on elevators F/16,117' MD
T/13,954' MD,
16,117.0 13,954.0
3/22/2024
05:00
3/22/2024
06:00
1.00 PROD1, DRILL OWFF T Establish static loss rate ~ 140 BPH.
M/U cement swivel.
13,954.0 13,954.0
3/22/2024
06:00
3/22/2024
07:30
1.50 PROD1, DRILL CIRC T Circulate at 1 BPM while waiting on
cementers.
13,954.0 13,954.0
3/22/2024
07:30
3/22/2024
08:30
1.00 PROD1, DRILL CIRC T Flush OH w/ 200 BBLs at 4-4.5 BPM/
740-100 PSI. Establish injection rate at
3 BPM/ SPP 502 PSI/IA 101 PSI.
13,954.0 13,954.0
3/22/2024
08:30
3/22/2024
11:45
3.25 PROD1, DRILL CMNT T Line up to cementers. Test lines to 3000
psi. Mix and pump 30 BBLs 13.0 ppg
MudPush + 151 BBLs 14.0 ppg
Thixotropic cement (closed MPD choke
at 100 BBLs pumped) + 20 BBLs 13.0
ppg MudPush spacer + 20 BBLs FW.
Swap over to rig pumps and bull head
tail end of cement to 16900' at 3 - 2
BPM/0-735 PSI IA pressure. Rotate at 5
rpm throughout job. SD and Monitor
pressure. Bled to 0 PSI in 10 minutes.
Cement in place at 11:48 hrs 3/22/24
13,954.0 13,954.0
3/22/2024
11:45
3/22/2024
12:00
0.25 PROD1, DRILL SMPD T SOOH F/13,954' MD T/13,575' MD. 13,954.0 13,575.0
3/22/2024
12:00
3/22/2024
12:30
0.50 PROD1, DRILL CIRC T Establish static loss rate = 24 BPH.
Flush downhole tools and stage rate up
to 180 GPM and confirm tools working.
13,575.0 13,575.0
3/22/2024
12:30
3/22/2024
19:15
6.75 PROD1, DRILL WOC T WOC. Monitor loses. Build mud
inventory. Flush cement swivel. Perform
housekeeping.
13,575.0 13,575.0
3/22/2024
19:15
3/23/2024
00:00
4.75 PROD1, DRILL WASH T Wash/Ream f/ 13575' to 15272'.
180 GPM
870 PSI
80 RPM
6k TQ
8.8-8.9ppg ECD
Dynamic loss rate 70-80 BPH.
13,575.0 13,575.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 46/51
MT7-92
Report Printed: 4/22/2024
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)
3/23/2024
00:00
3/23/2024
11:00
11.00 PROD1, DRILL WASH T Wash/Ream f/ 15272' to 19032'.
180 GPM
970 PSI
80 RPM
16k TQ
15,272.0 19,032.0
3/23/2024
11:00
3/23/2024
18:00
7.00 PROD1, DRILL DDRL P Drill 6-1/2" production F/19032' MD
to19700' MD 8347' TVD , closing choke
on connection 0 PSI build up.
Loss rate 70-120 BPH
18k WOB
180 GPM
1072 PSI
25% F/O
120 RPM
27k TQ
9.5ppg ECD
295k PU
205k ROT
12.1Bit hrs
19,032.0 19,700.0
3/23/2024
18:00
3/24/2024
00:00
6.00 PROD1, DRILL DDRL P Drill 6-1/2" production F/19700' MD to
20380' MD / 8347' TVD, closing choke
on connection - 0 PSI build up.
Loss rate 120 BPH.
14k WOB
210GPM
1345 PSI
21% F/O
150 RPM
26k TQ
9.5ppg ECD
318k PU
215k ROT
19.9Bit hrs
19,700.0 20,380.0
3/24/2024
00:00
3/24/2024
09:00
9.00 PROD1, DRILL DDRL P Drill 6-1/2" production F/ 20380' MD to
21388' MD / 8333' TVD, closing choke
on connection - 0 PSI build up.
Loss rate 130-150 BPH.
14k WOB
190 GPM
1254 PSI
19% F/O
150 RPM
27k TQ
9.6ppg ECD
319k PU
205k ROT
25.5Bit hrs
20,380.0 21,388.0
3/24/2024
09:00
3/24/2024
10:30
1.50 PROD1, DRILL CIRC T Troubleshoot DH tools. Cycle pumps
several times. Perform hard reset.
21,388.0 21,388.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 47/51
MT7-92
Report Printed: 4/22/2024
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)
3/24/2024
10:30
3/24/2024
17:30
7.00 PROD1, DRILL DDRL P Drill 6-1/2" production F/ 21388' MD to
21862' MD / 8322' TVD, closing choke
on connection - 0 PSI build up. Section
TD called by geologist.
Loss rate 130-150 BPH.
Note: Still having issues with RSS.
15k WOB
180 GPM
1230 PSI
21% F/O
160 RPM
26k TQ
9.4ppg ECD
340k PU
212k ROT
28.9Bit hrs
21,388.0 21,862.0
3/24/2024
17:30
3/25/2024
00:00
6.50 PROD1, TRIPCAS CIRC P Take final survey. Downlink tools off.
Circulate and condition mud. Performed
several PSTs. All passed.
180 GPM
1100 PSI
120 RPM
18k TQ
21,862.0 21,862.0
3/25/2024
00:00
3/25/2024
02:00
2.00 PROD1, TRIPCAS CIRC P Circulate and condition mud.
180 GPM
1100 PSI
120 RPM
18k TQ
21,862.0 21,862.0
3/25/2024
02:00
3/25/2024
02:30
0.50 PROD1, TRIPCAS OWFF P Flow check.
Static loss rate: 83 BPH
21,862.0 21,862.0
3/25/2024
02:30
3/25/2024
12:00
9.50 PROD1, TRIPCAS BKRM P BROOH f/ 21862' to 19010'. Dynamic
loss rate: 150 BPH
180 GPM
1020 PSI
80 RPM
12k TQ
21,862.0 19,010.0
3/25/2024
12:00
3/25/2024
23:30
11.50 PROD1, TRIPCAS BKRM P BROOH f/ 19010' to 13955'. Dynamic
loss rate: 150 BPH
180 GPM
1020 PSI
80 RPM
12k TQ
19,010.0 13,955.0
3/25/2024
23:30
3/26/2024
00:00
0.50 PROD1, TRIPCAS CIRC P Circulate 3 x liner volume.
180 GPM
800 PSI
60 RPM
6k TQ
13,955.0 13,955.0
3/26/2024
00:00
3/26/2024
00:30
0.50 PROD1, TRIPCAS CIRC P Finish circulating liner volumes. Hold
PJSM for RCD bearing. Drop 1.75" WC
opening ball down drillstring.
180 GPM
800 PSI
60 RPM
6k TQ
13,955.0 13,955.0
3/26/2024
00:30
3/26/2024
01:00
0.50 PROD1, TRIPCAS MPDA P Retrieve RCD bearing assembly and
install trip nipple.
13,955.0 13,955.0
3/26/2024
01:00
3/26/2024
02:30
1.50 PROD1, TRIPCAS TRIP P POOH f/ 13955' to 13854'. Install PS-21
slips. POOH to 12337'. WC at TOL.
13,955.0 12,337.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 48/51
MT7-92
Report Printed: 4/22/2024
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)
3/26/2024
02:30
3/26/2024
04:30
2.00 PROD1, TRIPCAS CIRC P Pressure up and open Well
Commander. Shifted open at 1389 PSI.
Circulate hole clean.
450 GPM
1160 PSI
80 RPM
5k TQ
12,337.0 12,337.0
3/26/2024
04:30
3/26/2024
06:00
1.50 PROD1, TRIPCAS TRIP P Drop 1.75" WC closing ball down
drillstring. POOH f/ 12337' to 11865'.
Pressure up and shift Well Commander
close. Shifted close at 1606 PSI. Pump
slug.
12,337.0 11,865.0
3/26/2024
06:00
3/26/2024
12:30
6.50 PROD1, TRIPCAS TRIP P Drop 2.14" hollow drift w/ tail down
drillstring. POOH to BHA at 230'.
11,865.0 230.0
3/26/2024
12:30
3/26/2024
14:00
1.50 PROD1, TRIPCAS BHAH P POOH and LD BHA. 230.0 0.0
3/26/2024
14:00
3/26/2024
16:00
2.00 COMPZN, CASING CLEN P Clean and clear rig floor. RU to run
lower completion. PJSM for Lower
completion run.
0.0 0.0
3/26/2024
16:00
3/26/2024
18:15
2.25 COMPZN, CASING PUTB P RIH w/ 4 1/2", 12.6 lb/ft, P110, Hyd 563
liner as per tally.
0.0 1,036.0
3/26/2024
18:15
3/26/2024
18:30
0.25 COMPZN, CASING WAIT P Stop RIH and change out tallies to
updated tally.
1,036.0 1,036.0
3/26/2024
18:30
3/27/2024
00:00
5.50 COMPZN, CASING PUTB P RIH w/ 4 1/2", 12.6 lb/ft, P110, Hyd 563
liner as per tally f/ 1036' to 4136'.
1,036.0 4,136.0
3/27/2024
00:00
3/27/2024
04:30
4.50 COMPZN, CASING PUTB P RIH with 4-1/2", 12.6 lb/ft, P110, Hyd
563 liner as per tally from 4,136' MD to
7,945' MD.
4,136.0 7,945.0
3/27/2024
04:30
3/27/2024
05:00
0.50 COMPZN, CASING THGR P P/U Baker HRDE ZXP liner hanger. Fill
tie back with Zanplex.
7,945.0 7,995.0
3/27/2024
05:00
3/27/2024
06:00
1.00 COMPZN, CASING CIRC P Make up stand of 4" drill pipe. Pump
through and confirm flow path.
PU: 119k
SO: 109k
ROT: 108k
RPM: 10-20
TRQ: 3.5-4.0k
7,995.0 8,099.0
3/27/2024
06:00
3/27/2024
07:00
1.00 COMPZN, CASING RUNL P RIH with 4-1/2", 12.6 lb/ft, P110, Hyd
563 liner on 4" drill pipe from 8,099' MD
to 9,709' MD.
8,099.0 9,709.0
3/27/2024
07:00
3/27/2024
08:30
1.50 COMPZN, CASING RUNL P RIH with 4-1/2", 12.6 lb/ft, P110, Hyd
563 liner on 5" drill pipe singles from
9,709' MD to 10,754' MD.
9,709.0 10,754.0
3/27/2024
08:30
3/27/2024
12:00
3.50 COMPZN, CASING RUNL P RIH with 4-1/2", 12.6 lb/ft, P110, Hyd
563 liner on 5" drill pipe stands from
10.754' MD to 15,118' MD.
10,754.0 15,118.0
3/27/2024
12:00
3/27/2024
19:00
7.00 COMPZN, CASING RUNL P Continue RIH with 4-1/2", 12.6 lb/ft,
P110, Hyd 563 liner on 5" drill pipe
stands from 15,118' MD to 21,847' MD.
PU: 512k
SO: 180k
15,118.0 21,847.0
3/27/2024
19:00
3/28/2024
00:00
5.00 COMPZN, CASING CIRC P Circulate BU. Dynamic loss rate -
77BPH.
71, 148, 160, 174, 200 GPM
291, 450, 520, 615, 675 PSI
SIMOPS: L/D 4" drill pipe. RU hardlines
and spot 1 acid truck for acid job.
Second acid truck arrived ay 00:00hrs.
21,847.0 21,847.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 49/51
MT7-92
Report Printed: 4/22/2024
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)
3/28/2024
00:00
3/28/2024
03:00
3.00 COMPZN, CASING WAIT T Schlumberger second acid truck arrived
at 00:00 hrs. Continue monitoring well
keeping backside full while staging and
R/U for acid job. 55bbls/hr static losses.
Wrong hose between acid trucks.
Discharge hose instead of suction hose,
(hose will collapse). Hands look for
connection to install proper hose.
21,847.0 21,847.0
3/28/2024
03:00
3/28/2024
03:30
0.50 COMPZN, CASING SFTY P PJSM for Acid job. 21,847.0 21,847.0
3/28/2024
03:30
3/28/2024
05:00
1.50 COMPZN, CASING WAIT T Attempt to test lines - Valve on transport
wouldn't open and Master discharge
valve on Pump unit wouldn't cycle.
Trouble shoot same.
21,847.0 21,847.0
3/28/2024
05:00
3/28/2024
10:00
5.00 COMPZN, CASING CIRC P Flood lines and test to 300/2500 PSI.
Good test. Pump 340bbls 9% formic
acid blend at 1.7bpm (problem with
pump, unable to increase rate). Chase
with 30bbls 8.6ppg clear brine. Swap to
rig pump and chase acid with 320bbls
8.6ppg clear brime at 8bpm 870psi.
21,847.0 21,847.0
3/28/2024
10:00
3/28/2024
16:00
6.00 COMPZN, CASING CIRC P Allow acid to soak while monitoring
static lost rate at 70-90bph.
SIMOPS: L/D 4" drill pipe (total 21
stands).
21,847.0 21,847.0
3/28/2024
16:00
3/28/2024
19:30
3.50 COMPZN, CASING CIRC P Circulate BTM's up at 200gpm, 250psi. 21,847.0 21,847.0
3/28/2024
19:30
3/28/2024
21:00
1.50 COMPZN, CASING PRTS P P/U to 310k. Drop 1.30" ball and rod.
Pump at 2bpm. Ball landed and
pressure up to 2500psi and hold 2min to
set hanger. Slack off to 165k to confirm
hanger set. Pressure up to 3800psi and
hold 2 min. P/U string to 200k and bled
pressure to 0psi. Slack off to 175k. P/U
and free weight at 273k. P/U and
expose dog sub. S/O to 175k (good set
indication). P/U to 258k and rotate at
20rpm 8k. S/O to 158k and torque
increased to 10k. P/U string with dog
sub 2' above liner top and pressure test
to 3500psi for 5min. (11bbls pumped
11bbls returned. Pressure up string to
500psi. P/U string to expose cup seals
above liner top.
21,847.0 21,847.0
3/28/2024
21:00
3/29/2024
00:00
3.00 COMPZN, WELLPR CIRC P Continue circulating at 13,848' MD at
130gpm, 82psi while conducting pit
management. Displace well with 8.6ppg
CI fluid at 336gpm, 530psi.
SIMOPS: L/D 4" drill pipe in derrick.
21,847.0 13,848.0
3/29/2024
00:00
3/29/2024
01:00
1.00 COMPZN, WELLPR CIRC P Continue circulate CI fluid at 336gpm
530psi. OWFF (Static). L/D double and
10' Pup joint.
13,848.0 13,765.0
3/29/2024
01:00
3/29/2024
02:00
1.00 COMPZN, WELLPR SLPC P Cut and slip 173' drill line. Calibrate
block hight and C-O-M.
13,765.0 13,765.0
3/29/2024
02:00
3/29/2024
12:00
10.00 COMPZN, WELLPR PULD P POOH L/D drill pipe from 13,765' MD to
3,000' MD.
13,765.0 3,000.0
3/29/2024
12:00
3/29/2024
16:30
4.50 COMPZN, WELLPR PULD P POOH L/D drill pipe from 3,000' MD to
38' MD.
3,000.0 38.0
3/29/2024
16:30
3/29/2024
17:00
0.50 COMPZN, WELLPR PULD P L/D Baker running tools. Good set
indication on dog sub.
38.0 0.0
3/29/2024
17:00
3/29/2024
20:30
3.50 COMPZN, WELLPR STRP P TIH with 4" drill pipe to 9,180' MD. 0.0 9,180.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 50/51
MT7-92
Report Printed: 4/22/2024
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)
3/29/2024
20:30
3/30/2024
00:00
3.50 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe from 9,180' MD
to 5,643' MD.
9,180.0 5,643.0
3/30/2024
00:00
3/30/2024
05:30
5.50 COMPZN, WELLPR PULD P POOH L/D 4" drill pipe from 5,643' MD
to surface.
5,643.0 0.0
3/30/2024
05:30
3/30/2024
07:00
1.50 COMPZN, WELLPR WWWH P Pump out stack and pull wear ring. R/U
and jet BOP stack. Install master
bushings. Blow down top drive.
SIMOPS: R/U upper completion
equipment.
0.0 0.0
3/30/2024
07:00
3/30/2024
07:45
0.75 COMPZN, RPCOMP RURD P Continue R/U upper completion
equipment.
0.0 0.0
3/30/2024
07:45
3/30/2024
08:45
1.00 COMPZN, RPCOMP PUTB P PJSM. Run upper completion to 161'
MD.
Self-Orienting locator sub
3.813" X nipple with RHC-M
Halliburton TNT Packer
Halliburton Opsis gauge mandrel
0.0 161.0
3/30/2024
08:45
3/30/2024
09:45
1.00 COMPZN, RPCOMP PRTS P MU control line and test to 9500psi 5min
(good test).
161.0 161.0
3/30/2024
09:45
3/30/2024
12:00
2.25 COMPZN, RPCOMP PUTB P Continue RIH with 4-1/2" 12.6ppf L-80
H563 upper completion from 161' MD to
2,176' MD, installing cameron clamps
every joint and testing TEC wire every
1000'.
161.0 2,176.0
3/30/2024
12:00
3/30/2024
18:00
6.00 COMPZN, RPCOMP PUTB P Continue RIH with 4-1/2" 12.6ppf L-80
H563 upper completion from 2,176' MD
to 7,900' MD, installing cameron clamps
every joint and testing TEC wire every
1000'.
2,176.0 7,900.0
3/30/2024
18:00
3/31/2024
00:00
6.00 COMPZN, RPCOMP PUTB P Continue RIH with 4-1/2" 12.6ppf L-80
H563 upper completion from 7,900' MD
to 13,558' MD, installing cameron
clamps every joint and testing TEC wire
every 1000'.
PU: 196k
SO: 132k
7,900.0 13,558.0
3/31/2024
00:00
3/31/2024
00:30
0.50 COMPZN, RPCOMP PUTB P Continue RIH with 4-1/2" 12.6ppf L-80
H563 upper completion from 13,558'
MD to 13,860'. PU: 196k, SO: 132k.
13,558.0 13,860.0
3/31/2024
00:30
3/31/2024
01:00
0.50 COMPZN, RPCOMP HOSO P Observe mule shoe enter liner top and
observe 11k shear at 13,859' MD. Slack
off to 118K - 14K down at 13,860' MD,
confirmed NO GO. Calculate space out
for 8.07' and 3.77' pup. L/D joint #333,
#332 and #331. Install 11.84' pups and
rerun joint #331. Make up FMC hanger
and landing joint.
13,860.0 13,825.0
3/31/2024
01:00
3/31/2024
02:00
1.00 COMPZN, RPCOMP OTHR P HES terminate TEC line in tubing
hanger and test (witnessed) to 5000 PSI
for 5 minutes. DHP - 3703psi, 169°F.
13,825.0 13,825.0
3/31/2024
02:00
3/31/2024
03:00
1.00 COMPZN, RPCOMP HOSO P Land hanger with 132k - 1.54' from
Locator. RILDS and Test FMC hanger
seals t/ 3500 psi f/ 5 minutes - Test
Good.
13,859.0 13,859.0
3/31/2024
03:00
3/31/2024
04:00
1.00 COMPZN, RPCOMP PRTS P Drop 1-7/8" ball & rod. R/U to pump on
tubing. Set HES TNT packer with 3000
PSI. Pressure up to 4200psi for 30
minutes charted.
13,859.0 13,859.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 51/51
MT7-92
Report Printed: 4/22/2024
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)
3/31/2024
04:00
3/31/2024
05:00
1.00 COMPZN, RPCOMP PRTS P Bleed tubing pressure down to 3000 PSI
and hold. Pressure test IA to 3000 PSI
for 30 minutes charted. Bleed tubing
and shear SOV. Slow bled off. Pump
down IA and take returns up tbg (good
flow path). OWFF (Static).
13,859.0 13,859.0
3/31/2024
05:00
3/31/2024
06:30
1.50 COMPZN, WHDBOP PRTS P Blow down surface lines and vac out
BOP stack. Install HP BPV and test to
3000 PSI for 10 minutes charted in
direction of flow. Blow down injection
line.
13,859.0 13,859.0
3/31/2024
06:30
3/31/2024
08:00
1.50 COMPZN, WHDBOP NUND P Clean flow box, blow down hole fill and
jet lines. Remove mouse hole, flow line
and skid back flow box. Break bolts on
BOP's.
0.0 0.0
3/31/2024
08:00
3/31/2024
10:00
2.00 COMPZN, WHDBOP MPDA P Remove RCD manifold, Head, orbit
valve and MPD equipment.
SIMOPS: Continue break bolts on
BOP's.
0.0 0.0
3/31/2024
10:00
3/31/2024
12:30
2.50 COMPZN, WHDBOP NUND P Skid BOP carrier in STOW position. R/U
50' slings and R/D high pressure risers.
0.0 0.0
3/31/2024
12:30
3/31/2024
13:30
1.00 COMPZN, WHDBOP THGR P HES terminate TEC line and test.
BHP: 3720psi
Temp: 173°F
0.0 0.0
3/31/2024
13:30
3/31/2024
17:45
4.25 COMPZN, WHDBOP NUND P N/U tbg head and production tree. Test
adapter flange to 5000psi for 10min
(good test). R/U and test tree
250/5000psi 5/10min (good test). R/D
test equipment.
0.0 0.0
3/31/2024
17:45
3/31/2024
18:00
0.25 COMPZN, WHDBOP OTHR P R/U and pull test plug, attempt to drift
tree to pull BPV. Unable to drift.
0.0 0.0
3/31/2024
18:00
3/31/2024
23:30
5.50 COMPZN, WHDBOP OTHR T Attempt to adjust trimming on actuator
valve. Unable to adjust enought to open
valve 100%. N/D tree above master and
change. Retest to 250/5000psi 5/10min.
0.0 0.0
3/31/2024
23:30
4/1/2024
00:00
0.50 COMPZN, WHDBOP OTHR P R/U and pull FMC BPV. 0.0 0.0
4/1/2024
00:00
4/1/2024
01:00
1.00 COMPZN, WHDBOP FRZP P R/U freeze protect lines and test to
250/3500psi.
0.0 0.0
4/1/2024
01:00
4/1/2024
01:30
0.50 COMPZN, WHDBOP FRZP P Pump 85bbls diesel down IA and take
returns up tubing at 2bpm 400psi, final
2.75bpm, 1900psi.
0.0 0.0
4/1/2024
01:30
4/1/2024
04:00
2.50 COMPZN, WHDBOP FRZP P Let well U-Tube 1 hr. R/D lines and
secure well.
0.0 0.0
4/1/2024
04:00
4/1/2024
06:00
2.00 DEMOB, MOVE RURD P Continue clearing equipment off rig.
Change BOP rams to 3-1/2" x 5-7/8".
Stomp out casing shed.
Rig released from MT7-92 well at
06:00hrs 4/1/24.
Final pressures
TBG: 175psi.
IA: 175psi
OA: 0psi
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 4/1/2024
Page 1/1
MT7-92
Report Printed: 4/22/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
2/15/2024 07:00
Cementing End Date
12/15/2023 11:30
Wellbore Name
MT7-92
Comment
Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4 bbls/min, 400 psi, Dropped bottom plug, Add two gallons dye. Start batching lead (Cement wet @07:51hrs).
Pump 464 bbls of 11.0 ppg DeepCRETE cement at 4.8 bbls/min, 680 psi ICP. Batch tail cement (Cement wet @ 09:43hrs) and pump 70 bbls of G Blend Tail 15.8
ppg cement @ 4.3 bbls/min, 572 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 620 psi ICP, 800 psi FCP. Slow
pumps 13 bbls prior to calculated bump to 3 bbls/min, 409 psi ICP, Bump plug with 930 psi (583.2 bbls + 20 bbls). 4930 strokes, final circ. PSI 409 Pressure up to
930 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 170 bbls cement to surface. (Full returns) Cement in place @ 11:34hrs 2/15/24
Lead: 11ppg
D047: 0.5 gal/sk Antifoam
D185: 0.09 gal/sk Dispersant
D167: 0.450% BWOB Fluid Loss
D177: 0.02 gal/sk Retarder
Tail: 15.8ppg
D047: 0.2 gal/sk Antifoam
D065: 0.65 % BWOC Dispersant
D225: 0.3% BWOB Fluid Loss
D186: 0.5 gal/sk Accelerator
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.8
Bottom Depth (ftKB)
4,129.0
Full Return?
Yes
Vol Cement …
170.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
4
P Pump Final (psi)
410.0
P Plug Bump (psi)
930.0
Recip?
Yes
Stroke (ft)
15.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Mix and pump 100 bbls of 11.0 ppg Mud Push II @ 4 bbls/min, 400 psi, Dropped bottom plug, Add two gallons dye. Start batching lead (Cement wet @07:51hrs).
Pump 464 bbls of 11.0 ppg DeepCRETE cement at 4.8 bbls/min, 680 psi ICP. Batch tail cement (Cement wet @ 09:43hrs) and pump 70 bbls of G Blend Tail 15.8
ppg cement @ 4.3 bbls/min, 572 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace @ 8 bbls/min, 620 psi ICP, 800 psi FCP. Slow
pumps 13 bbls prior to calculated bump to 3 bbls/min, 409 psi ICP, Bump plug with 930 psi (583.2 bbls + 20 bbls). 4930 strokes, final circ. PSI 409 Pressure up to
930 psi & hold for 5 minutes. Bleed off pressure, Check floats good. 170 bbls cement to surface. (Full returns) Cement in place @ 11:34hrs 2/15/24
Lead: 11ppg
D047: 0.5 gal/sk Antifoam
D185: 0.09 gal/sk Dispersant
D167: 0.450% BWOB Fluid Loss
D177: 0.02 gal/sk Retarder
Tail: 15.8ppg
D047: 0.2 gal/sk Antifoam
D065: 0.65 % BWOC Dispersant
D225: 0.3% BWOB Fluid Loss
D186: 0.5 gal/sk Accelerator
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.8
Est Btm (ftKB)
3,619.0
Amount (sacks)
1,350
Class
G
Volume Pumped (bbl)
459.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
6.70
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP) Thickening Time (hr)
6.42
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
3,619.0
Est Btm (ftKB)
4,129.0
Amount (sacks)
336
Class
G
Volume Pumped (bbl)
70.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
5.00
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr)
4.06
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
MT7-92
Report Printed: 4/22/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
2/26/2024 10:00
Cementing End Date
2/26/2024 14:02
Wellbore Name
MT7-92
Comment
Mix and pump 65bbls 12.5ppg mud push II at 4 bpm. SD and drop bottom plug. Mix and pump 79.5bbls 13 ppg G lead cement at 4.5 bpm, Mix and pump
118.1bbls 15.8 ppg G Tail cement at 4.7 bpm. SD and drop top plug. Pump 20 bbls FW w/ cement unit and swap over to rig pumps. Displace w/ rig pumps and
displace cement at 6bpm 952psi 870bbls slow rate to 3bpm 628psi. Plug bumped at 880.5bbls pumped. FCP 640psi pressure up to 1154psi SD and monitor f/ 5
minutes. Bleed off and check floats. Floats holding. Cement in place @ 14:02hrs 2/26/24 Full returns
Cement Stages
Stage # 2
Description
Primary – Full Bore
Objective
Lead Cement 13.0ppg
Top Depth (ftKB)
9,917.0
Bottom Depth (ftKB)
10,879.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
4
P Pump Final (psi)
453.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
11,467.0
Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
8 1/2
Comment
Pumped 65 bbls lead cement
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
9,917.0
Est Btm (ftKB)
10,879.0
Amount (sacks)
215
Class
G
Volume Pumped (bbl)
79.5
Yield (ft³/sack)
1.89
Mix H20 Ratio (gal/sack)
10.24
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)
10,879.0
Bottom Depth (ftKB)
12,389.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
5
P Pump Final (psi)
645.0
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 118 bbls tail cement
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
10,879.0
Est Btm (ftKB)
12,389.0
Amount (sacks)
579
Class
G
Volume Pumped (bbl)
118.1
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.05
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
MT7-92
Report Printed: 4/22/2024
Cement
Cement Details
Description
Intermediate String 2 Cement
Cementing Start Date
3/8/2024 00:00
Cementing End Date
3/8/2024 02:45
Wellbore Name
MT7-92
Comment
Rig pump 70bbls 8.9ppg KCL 5% deep clean spacer at 4bpm 780psi. Flood lines and test to 5000 PSI. Drop bottom dart. Swap to cementers. Pump 62 BBLS of
15.8ppg cement @ 3 BPM. SD and drop top dart. Pump 10 BBLS FW w/ cement unit. Swap to rig pumps and displace at 4 BPM 450-750psi. (Drop BOZO plug
791 stks ino displacement BTM dart landed at 1571stks and sheared at 920psi. Top dart landed at 2270stks and sheared at 1723psi. BTM plug landed at
2436stks and sheared at 1730psi). Slow rate to 3 BPM and bump plug 3187stks (5.75bbls early). FCP - 450psi. Pressure up to 1000psi. Hold for 5 minutes and
check floats. All Good. Full returns throughout job. No losses. Cement in place @ 02:40hrs, 1/8/24.
Cement Stages
Stage # 4
Description
Intermediate String 2
Cement
Objective Top Depth (ftKB)
13,318.0
Bottom Depth (ftKB)
14,012.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
3
P Pump Final (psi)
450.0
P Plug Bump (psi)
450.0
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
Pumped 62 bbls 15.8ppg cement
Cement Fluids & Additives
Fluid
Fluid Type
Primary Cement
Fluid Description Estimated Top (ftKB)
13,269.0
Est Btm (ftKB)
14,012.0
Amount (sacks) Class
G
Volume Pumped (bbl)
62.1
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 2 Cement
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From:Taylor, Jenna
To:Brooks, James S (OGC)
Subject:RE: [EXTERNAL]RE: Logged 10-407 CPAI GMT MT7-92 10-407
Date:Thursday, May 30, 2024 9:16:59 AM
Attachments:image001.png
James – It looks like it should read SEC 4
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Thursday, May 30, 2024 8:05 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]RE: Logged 10-407 CPAI GMT MT7-92 10-407
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Hi,
In box 4a:
The tpi coordinate is 1747 FSL, 3550 FEL, 45 T9N R2E
The value in red should be between 1-36.
Please fix.
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.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Monday, April 29, 2024 12:15 PM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: Logged 10-407 CPAI GMT MT7-92 10-407
Hi James,
Attached is stamped 10-407 for GMT MT7-92; it is logged in the 10-407 Excel spreadsheet.
Thank you,
Grace Christianson
Executive Assistant,
Alaska Oil & Gas Conservation Commission
(907) 793-1230
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Monday, April 29, 2024 11:54 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Gorham, Brad <Brad.Gorham@conocophillips.com>; Hobbs, Greg S
<Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>
Subject: GMT MT7-92 10-407
Hello – See attached 10-407 for GMT MT7-92. Please let me know if you need additional information.
Thank you,
Jenna
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
April 16, 2024
AOGCC
Attention: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
MT7-92
Greater Mooses Tooth
API #: 50-103-20872-00
Permit No: 223-114
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.
MT7-92 is located in a federal oil and gas unit. Only with respect to the MT7-92 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
223-114
T38704
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.04.16 11:29:40 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________GMTU MT7-92
JBR 05/17/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
Test was to reset the 21 day clock before drilling ahead. Tested with 4" and 5" TJ. Great test No issues. Crew stayed busy
cleaning during testing
Test Results
TEST DATA
Rig Rep:Jason FetterlyOperator:ConocoPhillips Alaska, Inc.Operator Rep:Jonathan Benadict
Rig Owner/Rig No.:Doyon 25 PTD#:2231140 DATE:3/12/2024
Type Operation:DRILL Annular:
250/3500Type Test:OTH
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopSTS240319081432
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
2899
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 4 P
Inside BOP 2 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 2 7/8 x 5 P
#2 Rams 1 blind/shear P
#3 Rams 1 2 7/8 x 5 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 2 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3025
Pressure After Closure P1950
200 PSI Attained P10
Full Pressure Attained P69
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1900
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P23
#1 Rams P6
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P2
Test charts attached
BOPE Test - 3/12/2024
Doyon 25 - GMTU MT7-92
AOGCC Inspect # bopSTS240319081432
BOPE Test - 3/12/2024
Doyon 25 - GMTU MT7-92
AOGCC Inspect # bopSTS240319081432
MT7-92 3/12/2024
Tested to 250PSI/5MIN, 3500PSI/10 MIN
4” Test Jt.
1.Annular Preventer, upper IBOP, Valves: 1, 13, 14, 15, Kill Line demco
2.Upper Pipe Rams (2.87” x 5”), Lower IBOP, HCR kill, Valves: 10,12,2
3.Valves: 6, 9 ,11, Manual Kill, 4” Dart
4.Valves: 5,7,8, 4” FOSV#1
5.Valve: 3, 4” FOSV#2
6.Lower (2.87”x5”)
7.Blind Rams, Valve: 4
8.Super Choke & Manually Operated (8A = MANUAL Choke – 8B = Hydraulic
Choke)
5” Test Jt
9.Upper Pipe Rams (2.87” x 5” VBR’S) &, HCR Choke, Valve: 2, 5” Dart
10.Lower pipe rams, 5” FOSV #1
11. Manual choke, 5” FOSV #2
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________GMTU MT7-92
JBR 04/05/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
5" and 9 5/8" test joints used. Demco kill valve failed in test #1. The valve was rebuilt and failed again. The valve was repaired
and passed.
Test Results
TEST DATA
Rig Rep:Victor TorresOperator:ConocoPhillips Alaska, Inc.Operator Rep:Percy Angelle/
Rig Owner/Rig No.:Doyon 25 PTD#:2231140 DATE:2/16/2024
Type Operation:DRILL Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopGDC240214182117
Inspector Guy Cook
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 9.5
MASP:
2899
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8" 5000 P
#1 Rams 1 9 5/8" Solids P
#2 Rams 1 Blind/Shear P
#3 Rams 1 2 7/8"x5"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8" 5000 P
HCR Valves 2 3 1/8" 5000 P
Kill Line Valves 1 3 1/8" 5000 P
Check Valve 0 NA
BOP Misc 1 demco valve FP
System Pressure P3000
Pressure After Closure P1900
200 PSI Attained P16
Full Pressure Attained P82
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1950
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P28
#1 Rams P6
#2 Rams P6
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P3
BOP - Doyon 25
GMTU MT7-92 (PTD 2231140)
AOGCC Insp #bopGDC240214182217
2/16/2024
BOP - Doyon 25
GMTU MT7-92 (PTD 2231140)
AOGCC Insp #bopGDC240214182217
2/16/2024
MT7-92 2/16/2024 250 Low for 5 min – 5000 High for 10 min
9 5/8 and 5” Test Jt
1.Annular Preventer ( 250 low / 3500 high)
2.Ram #1, valves: # 1, 13, 14, 15, 4” HCR Kill, 5” Dart.
3.Ram #1, valves: # 10, 12, 2, Kill line / 4” Demco, 5” FOSV # 1.
4.Valves: # 6, 9 ,11, 5” FOSV # 2.
5.Valves: # 5, 7, 8, Manual Kill
6.Valve: # 3 and Upper IBOP.
7.W/ 5’’ Test Jt. Ram #3, Manual choke, Manual IBOP.
8.W/5’’ Test Jt. Annular Preventer, Choke HCR (250 low /5000 high)
9.Ram #2 / Blinds, Valve: # 4
10.Manual & Super Choke
BOP - Doyon 25
GMTU MT7-92 (PTD 2231140)
AOGCC Insp #bopGDC240214182217
2/16/2024
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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:Rig 25
To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC);
BLM_AK_AKSO_EnergySection_Notifications@blm.gov; Drilling Supervisor, Doyon 25;
Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; Ben Wedin; Bill Walter; Samuel Dye
Subject:Doyon 25 03-09-24
Date:Saturday, March 9, 2024 12:14:16 PM
Attachments:Doyon 25 03-09-24.xlsx
Doyon Rig 25 UPR 2 7/8” x 5” test with 4” and 5” test joint.
Zak Coleman
Rig 25 Tourpusher
rig25@doyondrilling.com
907-670-4971
*07807
37'
9
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:25 DATE: 3/9/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231140 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/3500 Annular:250/3500 Valves:NT MASP:2899
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping NA Well Sign NA Upper Kelly 0NA
Permit On Location NA Hazard Sec.NA Lower Kelly 0NA
Standing Order Posted NA Misc.NA Ball Type 0NA
Test Fluid Water Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank NA NA
Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators NA NA
#1 Rams 1 2 7/8"x5"P Flow Indicator NA NA
#2 Rams 0 Blind / Shear NA Meth Gas Detector NA NA
#3 Rams 0 2 7/8"x5"NA H2S Gas Detector NA NA
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 0 3-1/8"x5000psi NA Time/Pressure Test Result
HCR Valves 0 3-1/8"x5000psi NA System Pressure (psi)NA
Kill Line Valves 0 3-1/8"x5000psi NA Pressure After Closure (psi)NA
Check Valve 0NA200 psi Attained (sec)NA
BOP Misc 0NAFull Pressure Attained (sec)NA
Blind Switch Covers: All stations NA
CHOKE MANIFOLD:Bottle Precharge:NA
Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA
No. Valves 0NA ACC Misc 0NA
Manual Chokes 0NA
Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer NA
#1 Rams NA
Coiled Tubing Only:#2 Rams NA
Inside Reel valves 0NA #3 Rams NA
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures: Test Time:1.0 HCR Choke NA
Repair or replacement of equipment will be made within days. HCR Kill NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3/6/24 8:02
Waived By
Test Start Date/Time:3/9/2024 4:30
(date) (time)Witness
Test Finish Date/Time:3/9/2024 5:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Changed Ram #1 to 2-7/8" x 5" VBR. With 4" x 5" test jts test #1 ram 250 low / 3500 high for 5 / 10 min ea. BLM rep Quinn
Sawyer waived witness of test.
Z. Coleman / J. Fetterly
CPAI
J. Benedict / L. Shirley
GMTU MT7-92
Test Pressure (psi):
rig25@doyondrilling.com
d25cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0309_BOP_Doyon25_VBR_GMTU_MT7-92
9
9
9
9
9 9 9
9
9
9
MEU
9
9
- 5HJJ
Changed Ram #1 to 2-7/8" x 5" VBR
%23(7HVW'R\RQ
9%5
*07807
37'
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:Rig 25
To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC);
BLM_AK_AKSO_EnergySection_Notifications@blm.gov; Drilling Supervisor, Doyon 25;
Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; Ben Wedin; Bill Walter; Samuel Dye
Subject:Doyon 25 03-06-24
Date:Thursday, March 7, 2024 8:49:23 AM
Attachments:Doyon 25 03-06-24.xlsx
Doyon 25 03-06-24 Test Chart.pdf
Doyon 25 Test Report UPR 7 5/8” 3/6/24
Zak Coleman
Rig 25 Tourpusher
rig25@doyondrilling.com
907-670-4971
*UHDWHU0RRVHV7RRWK8QLW07
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:25 DATE: 3/6/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231140 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/3500 Annular:250/3500 Valves:NT MASP:2899
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping NA Well Sign NA Upper Kelly 0NA
Permit On Location NA Hazard Sec.NA Lower Kelly 0NA
Standing Order Posted NA Misc.NA Ball Type 0NA
Test Fluid Water Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank NA NA
Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators NA NA
#1 Rams 1 7 5/8"P Flow Indicator NA NA
#2 Rams 0 Blind / Shear NA Meth Gas Detector NA NA
#3 Rams 0 2-7/8"x5"NA H2S Gas Detector NA NA
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 0 3-1/8"x5000psi NA Time/Pressure Test Result
HCR Valves 0 3-1/8"x5000psi NA System Pressure (psi)NA
Kill Line Valves 0 3-1/8"x5000psi NA Pressure After Closure (psi)NA
Check Valve 0NA200 psi Attained (sec)NA
BOP Misc 0NAFull Pressure Attained (sec)NA
Blind Switch Covers: All stations NA
CHOKE MANIFOLD:Bottle Precharge:NA
Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA
No. Valves 0NA ACC Misc 0NA
Manual Chokes 0NA
Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer NA
#1 Rams NA
Coiled Tubing Only:#2 Rams NA
Inside Reel valves 0NA #3 Rams NA
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures: Test Time:1.0 HCR Choke NA
Repair or replacement of equipment will be made within days. HCR Kill NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3/6/24 8:02
Waived By
Test Start Date/Time:3/6/2024 20:30
(date) (time)Witness
Test Finish Date/Time:3/6/2024 21:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Change Ram #1 to 7 5/8". With 7 5/8" test joint, test Annular and Ram #1 to 25/3500psi for 5/10min. BLM Rep. Quinn Sawyer
waived witness of test
R. Fritts / Z.Coleman
CPAI
R. Reinhardt / L.Shirley
GMTU MT7-92
Test Pressure (psi):
rig25@doyondrilling.com
d25cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0306_BOP_Doyon25_csg-ram_GMTU_MT7-92
9 9
9
9
9999
9
9
MEU 9
9
9
-5HJJ
7HVWFKDUWDWWDFKHG
%23(7HVW'R\RQ
&DVLQJ5DPVDQG$QQXODU
*07807
37'
-5HJJ
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:Rig 25
To:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Brooks, Phoebe L (OGC);
BLM_AK_AKSO_EnergySection_Notifications@blm.gov
Cc:Drilling Supervisor, Doyon 25; Greg.S.Hobbs@conocophillips.com; Operations Engineer, Doyon 25; Ben Wedin;
Bill Walter; Samuel Dye
Subject:Doyon 25 03-03-24
Date:Sunday, March 3, 2024 9:24:57 AM
Attachments:Doyon 25 03-03-24.xlsx
Doyon 03-03-24 Test charts.pdf
Doyon 25 03-03-24 Test Sequence.docx
3/3/24 BOPE test report
Roy Fritts
Rig 25 Toolpusher
rig25@doyondrilling.com
907-670-4971
*UHDWHU0RRVHV7RRWK8QLW07
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:25 DATE: 3/3/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231140 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:2899
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.P Ball Type 4P
Test Fluid Water Inside BOP 2P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8"x5000psi P Pit Level Indicators PP
#1 Rams 1 2-7/8"x5"P Flow Indicator PP
#2 Rams 1 Blind / Shear P Meth Gas Detector PP
#3 Rams 1 2-7/8"x5"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8"x5000psi P Time/Pressure Test Result
HCR Valves 2 3-1/8"x5000psi P System Pressure (psi)2975 P
Kill Line Valves 2 3-1/8"x5000psi P Pressure After Closure (psi)1900 P
Check Valve 0NA200 psi Attained (sec)18 P
BOP Misc 0NAFull Pressure Attained (sec)73 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6/1900 P
No. Valves 15 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 22 P
#1 Rams 5 P
Coiled Tubing Only:#2 Rams 7 P
Inside Reel valves 0NA #3 Rams 5 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:9.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 02/28/24 11:17
Waived By
Test Start Date/Time:3/2/2024 18:30
(date) (time)Witness
Test Finish Date/Time:3/3/2024 3:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Test Annular to 250/3500psi & Ram #1 & #3 to 250/5000psi w 4" & 5" test joint. Test ram #2 to 250/5000 psi. 2 ea 4" & 5" FOSV
and 1 ea 4" & 5" & Dart Valve tested to 250/ 5000 psi. All tests for 5/10 mins. Function primary & remote BOPE control stations.
Test LEL & H2S alarms. BLM Rep. Quinn Sawyer waived witness of test.
R. Fritts / Z.Coleman
CPAI
R. Reinhardt / L.Shirley
GMTU MT7-92
Test Pressure (psi):
rig25@doyondrilling.com
d25cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0303_BOP_Doyon25_GMTU_MT7-92
9 9
9
9 9 9 9
9
9
9
9
-5HJJ
%23(7HVW'R\RQ
*07807
37'
-5HJJ
%23(7HVW'R\RQ
*07807
37'
-5HJJ
MT7-92 3/3/2024
Tested to 250PSI/5MIN, 5000PSI/10 MIN
CHART #1
5” Test Jt.
1. Annular Preventer – 3500 PSI
2. Upper Pipe Rams (2.87” x 5”), Valves: 1, 13, 14, 15, Kill Line, 5” Dart
Valve
3. Valves: 2, 10, 12, HCR KILL & 5” FOSV #1
4. Valves: 6, 9 ,11, Manual Kill, 5” FOSV #2
5. Valves 5, 7, 8 & Auto IBOP
6. Valves 3 & MAN IBOP
%23(7HVW'R\RQ
*07807
37'
MT7-92 3/3/2024
Tested to 250PSI/5MIN, 5000PSI/10 MIN
CHART #2
7. Lower Pipe Rams (2.87” x 5” VBR’S)
8. Blind Shear Rams, Valve: 4
9. Super Choke & Manually Operated (9A = SUPER Choke – 9B = MANUAL Choke)
4” Test Jt
10. Annular Preventer (3,500 PSI)
11. Upper Pipe Rams (2.87” x 5” VBR’S) &, HCR Choke & 4” Dart
12. Manual Choke, 4” FOSV #1
13. Lower Pipe Rams (2.87” x 5” VBR’S), 4” FOSV #2
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, GMTU MT7-92
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-114
Surface Location: 1092 FSL, 2088 FWL, S32 T10N R2E, UM
Bottomhole Location: 1488 FSL, 1796 FWL, S29 T10N R2E, 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 _16_ day of January 2024.
.
Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.01.16 10:32:32 -09'00'
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: 25,599 TVD: 8227
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- 290169 y- 5915909 Zone- 4 100.5 to Same Pool: 1194' to MT7-14
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 4075 40 40 4075 3049
12-1/4" 9-5/8" 47# T95 H563 12398 40 40 12398 7510
8-1/2" x 9-7/8"7-5/8" 33.7#P-110 S H523 1767 12248 7258 14015 8369
6-1/2" 4-1/2" 12.6# P-110 S x L80 H563 11759 13840 8060 25599 8227
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
3722
P.O. Box 100360 Anchorage, Alaska, 99510-0360
1088 FSL, 2084 FWL, S32 T10N R2E, UM AA098885 AA081781 AA092341
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 MT7-92
1730 FSL, 1735 FWL, S04 T9N R2E, UM 369446000 932516000 340762000
1488 FSL, 1796 FWL, S29 T10N R2E, UM 1262 5720 1920
GL / BF Elevation above MSL (ft):
18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
(including stage data)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Casing Length Size Cement Volume MD
Intermediate
Surface
Conductor/Structural
Perforation Depth MD (ft): Perforation Depth TVD (ft):
Liner
Production
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.
Greater Mooses Tooth
Rendezvous
2/6/2024
1797.5' to AA081800
N/A
114 sx of 13.0 ppg Ext. Class G + 730 sx of
15.8 ppg Class G
Cement to surface with 10 yds slurry
1329 sx of 11.0 ppg DeepCRETE + 330 sx of
15.8 ppg Class G
286 sx of 15.8 ppg Class G
2899
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 2:19 pm, Dec 01, 2023
Initial BOP test to 5000 psig; subsequent BOP test to 3500 psig
Annular preventer test to 2500 psig
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.
VTL 01/16/2024 DSR-12/5/23
Diverter variance granted per 20 AAC 25.035(h)(2)
223-114
A.Dewhurst 09JAN24
GMTUAlaska, Inc.
1092
X
2088
50-103-20872-00-00
-A.Dewhurst 09JAN24
JLC 1/16/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.01.16 10:32:49 -09'00'
01/16/24
01/16/24
'DdDdϳͲϵϮ
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.
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'
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, AK 99510-0360
Telephone 907-276-1215
November 30, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Permit to Drill MT7-92
Dear Sir or Madam,
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C Sand - Single Lateral Producer
from the MT7 drilling pad. The intended spud date for this well is February 6, 2024. It is intended that Doyon 25
be used to drill the well.
MT7-92 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 7-5/8” 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 6-1/2” production interval will drilled
horizontally and geo-steered within the Alpine C sand. The well will be completed with a 4-1/2" production liner
with ICD's 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)
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
Drilling Engineer
cc:
MT7-92 Well File / Jenna Taylor ATO 1732
David Lee ATO 1552
Chris Brillon ATO 1548
Andy Mack Kuukpik Corp
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.
Recommend granting variance. -A.Dewhurst 04JAN24
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 1 | 19
MT7-92 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 ............................................................................... 8
7. Casing and Cementing Program .............................................................................................................. 8
8. Drilling Fluid Program .......................................................................................................................... 10
9. Abnormally Pressured Formation Information ...................................................................................... 11
10. Seismic Analysis ................................................................................................................................... 11
11. Seabed Condition Analysis ................................................................................................................... 11
12. Evidence of Bonding ............................................................................................................................. 11
13. Discussion of Mud and Cuttings Disposal and Annular Disposal ............................................................ 12
14. Drilling Hazards Summary .................................................................................................................... 13
15. Proposed Completion Schematic .......................................................................................................... 15
16. MT7-14 Intermediate 1 MPSP Review & Ram Configuration ................................................................. 16
17. Area of Review..................................................................................................................................... 19
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 2 | 19
1. Well Name
Requirements of 20 AAC 25.005 (f)
The well for which this application is submitted will be designated as MT7-92
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
Location at Surface 1088 FSL, 2084 FWL, S32 T10N R2E, UM
NAD27
Northing: 5915908.64
Easting: 290168.68
RKB Elevation 39’ AMSL
Pad Elevation 100.5’ AMSL
Top of Productive Horizon (Heel) 1730 FSL, 1735 FWL, S04 T9N R2E, UM
NAD27
Northing: 5911133.05
Easting: 294980.96
Measured Depth, RKB: 12398‘ MD
True Vertical Depth, RKB: 7510‘ TVD
True Vertical Depth, SS: 7371‘ TVDss
Total Depth (Toe) 1488 FSL, 1796 FWL, S29 T10N R2E, UM
NAD27
Northing: 290018.88
Easting: 5921595.12
Measured Depth, RKB: 25599‘ MD
True Vertical Depth, RKB: 8227‘ TVD
True Vertical Depth, SS: 8087‘ TVDss
Please see attached well stick diagram for the current planned development of the pad.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 3 | 19
Pad Layout
Well Stick Diagram
MT7
PHONE : 907-670-4739
PHONE : 907-670-4739
F
S TH49
T
OEAT
A
LAA
K
S
UMIAQ Design & Municipal
Services, LLC / AECL1316
PHONE : 907-670-4739
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 4 | 19
Well Plat
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 5 | 19
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” 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)
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 12-1/4” hole to the casing point.
13. Circulate wellbore clean and POOH.
14. Run 9-5/8” intermediate 1 casing to TD.
15. 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.
16. Change upper 9-5/8” solid body rams to 2-7/8” x 5” VBR’s. Test BOPE to 250/3,500 psi. (24-48 hr.
regulatory notice).
17. 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.
18. Chart casing pressure test to 3,500 psi for 30 minutes.
19. Drill out shoe track and 20’ of new hole.
20. Perform FIT to 14 ppg EMW. Minimum required to drill ahead is 11 ppg EMW.
21. 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:
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 6 | 19
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.
22. Circulate wellbore clean and POOH.
23. Change out upper rams to 7-5/8” FBRs. Test same to 250 psi low / 3,500 psi high.
24. Pick up and run in hole with the 7-5/8” liner on 5” DP to section TD.
25. Circulate and condition mud in preparation for cementing.
26. Cement 7-5/8” 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.
27. Change out upper rams to 2-7/8” x 5” VBRs. Test same to 250 psi low / 3,500 psi high.
28. Pick up 4” DP. Test BOPE to 250 psi low / 3,500 psi high. (24-48 hr. regulatory notice).
29. Pick up and RIH with 6-1/2” drilling assembly.
30. Displace well to FloPro WBM. Chart casing pressure test to 3,500 psi for 30 minutes and record results.
31. Drill out and perform FIT to 13.5 ppg EMW maximum. Minimum acceptable leak-off for drilling ahead
is 10.3 ppg EMW.
32. Drill 6-1/2" horizontal hole to section TD (LWD Program: GR/RES/DEN/NEU/IMAGE).
33. Circulate the hole clean and POOH.
34. Run 4-1/2” liner on 4” DP, set liner hanger and packer. Chart casing pressure test 3,500 psi. POOH LD
DP.
35. 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.
36. Pressure test hanger seals to 2500 psi.
37. Drop ball & rod, pressure up and set production packer.
38. Pressure test tubing and IA and shear SOV.
39. Install BPV. ND BOPE and install tubing head adapter. Pressure test adapter to 5000 psi.
40. Install 5k frac tree and test.
41. Remove BPV and freeze protect well.
42. Secure well and RDMO.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 7 | 19
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 4075 3049 8.7 1,379 56 56 1,074
INT1 12-1/4" 13-3/8" 4075 3049 14.5 8.7 1,379 12398 7510 9.4 3,671 1,994 1,994 2,920
INT2 8-1/2" x 9-7/8" 9-5/8" 12398 7510 16.5 9.4 3,671 14015 8369 8.7 3,786 2,949 5,692 2,949
PROD 6-1/2" 7-5/8" 14015 8369 12.5 8.7 3,786 25599 8227 8.7 3,722 2,899 4,603 2,899
*Maximum potential pore pressure in the Susitna Sand if present
(B) data on potential gas zones;
The planned wellbore is expected to enter the gas cap and the area is expected to be normally pressured
(8.5-8.9 ppg).
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost
circulation zones, and zones that have a propensity for differential sticking;
Please see Drilling Hazards Summary
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 8 | 19
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
7-5/8" 8-1/2" x 9-7/8" 33.7# P-110S H523
250’ TVD or 500’ MD, whichever is greater, above
highest significant hydrocarbon bearing zone
4-1/2" 6-1/2” 12.6# P-110S x L-
80 H563 Uncemented open hole liner with ICD’s and swell
packers
13-3/8" Surface Casing run to 4075' MD/ 3049' TVD Cement Plan:
Cement from 4075’ MD to 3575’ (500’ of tail) with DeepCRETE + Adds @ 15.8 ppg, and from 3575' to
surface with 11.0 ppg DeepCRETE. Assume 120% excess annular volume in permafrost and 50% excess
below the permafrost (981’ MD), zero excess in 20” conductor.
Lead 454 bbls => 1329 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 12398' MD/ 7510' 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 10398’ MD, which is 500' above the prognosed shallowest hydrocarbon bearing zone Sub-Albian 93. If a
shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2 nd stage cement job
will be performed to isolate this zone. Assume 30% excess annular volume.
Lead 39 bbls => 114 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
7-5/8" Intermediate Liner run to 14015' MD/ 8369' TVD Cement Plan:
Top of slurry is designed to be at 13287’ MD, which is 250' TVD above the prognosed shallowest
hydrocarbon bearing zone Alpine D. Assume 40% + 20 Additional bbls excess annular volume.
Tail 59 bbls => 286 sx of 15.8 ppg Class G + Add's @ 1.16 ft³/sk
prognosed shallowest hydrocarbon bearing zone Sub-Albian 93.
e prognosed shallowest
hydrocarbon bearing zone Alpine D. A
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MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 10 | 19
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" 6-1/2"
Casing Size in 13-3/8" 9-5/8" 7-5/8" 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.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 11 | 19
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.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 12 | 19
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 MT7-92 will be disposed of into a permitted
annulus on the MT7 pad or hauled to the Class 1 disposal well on CD1.
The MT7-92 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 MT7-92 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) * (3049’) ] + 1500 psi
Max Shoe Pressure = 3403 psi
Pore Pressure: 1379 psi
Therefore
Differential Pressure: 3403 – 1379 = 2024 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
Once MT7-92 has been drilled and completed, consideration may be given to permit this well for annular
disposal.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 13 | 19
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 | 7-5/8" 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
6-1/2" Hole | 4-1/2" Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add
lost circulation material
Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real
time ECD monitoring
Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight
Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight
Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers
To be posted in Rig Floor Doghouse Prior to Spud
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 14 | 19
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.
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 15 | 19
15. Proposed Completion Schematic
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 16 | 19
16. MT7-92 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”) while drilling and running casing in the
Intermediate 1 section of MT7-92.
The Maximum Potential Surface Pressure (MPSP) is expected to be 1994 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” VBR’s (i)
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 17 | 19
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
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 18 | 19
Maximum Potential Surface Pressure
Surface Casing Point: 4075' MD/ 3049' TVD
Intermediate 1 Casing Point: 12398' MD/ 7510' 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 3049 TVD
MPSP = 1994 psi
Method 2:
MPSP = FPP – (Gas Gradient x TVD)
MPSP = (9.4 ppg x .052 x 7510‘ TVD) x (0.1 psi/ft x 7510’ TVD)
MPSP = 2920 psi
MT7-92 AOGCC 10-401 APD
11/22/2023
MT7-92 AOGCC 10-401 APD 19 | 19
17. Area of Review
N/A
39 500
500 1000
1000 1500
1500 2000
2000 3000
3000 4000
4000 12000
12000 20000
20000 25600
MT7-92 wp07 (88+89 S2N)Plan Summary
MT7-92 wp07 (88+89 S2N)
MT7-14A
MT7-14
MT7-08PB1
MT7-08
MT7-07
MT7-01PB1
MT7-11
MT7-02
MT7-09
MT7-94
MT7-04
MT7-03
MT7-06A
MT7-06PB1
MT7-93_wp13
MT7-95
MT7-99
MT7-10_wp04
MT7-01
MT7-98
MT7-96MT7-05
MT7-97
MT7-06
0
4
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 4000 8000 12000 16000 20000 24000
Measured Depth
13-3/8" Surface Casing 9 5/8" INT1 Casing
7-5/8" INT2 Liner
4-1/2" Production 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]
MT7-94
MT7-93_wp13
MT7-95
MT7-98
MT7-96
MT7-97
0
5000
Tr
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-6000 -4000 -2000 0 2000 4000
Vertical Section at 356.89°
13-3/8" Surface Casing
9 5/8" INT1 Casing
7-5/8" INT2 Liner 4-1/2" Production Liner
0
450
900
Ce
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p
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0 1500 3000 4500 6000 7500
Measured Depth
Equivalent Magnetic Distance
DDI
7.313
SURVEY PROGRAM
Date: 2023-01-23T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1000.00 MT7-92 wp07 (88+89 S2N) (MT7-92)
SDI_Keeper_ADK
1000.00 4075.00 MT7-92 wp07 (88+89 S2N) (MT7-92)
MWD+IFR2+SAG+MS
4075.00 12398.00 MT7-92 wp07 (88+89 S2N) (MT7-92)
MWD+IFR2+SAG+MS
12398.00 14015.00 MT7-92 wp07 (88+89 S2N) (MT7-92)
MWD+IFR2+SAG+MS
14015.00 25600.00 MT7-92 wp07 (88+89 S2N) (MT7-92)
MWD+IFR2+SAG+MS
Surface Location
North / 5915652.61
East / 1430204.61Ground / 100.50
CASING DETAILS
TVD MD
Name
3048.90 4075.00 13-3/8" Surface Casing
7509.83 12398.00 9 5/8" INT1 Casing
8369.38 14015.00 7-5/8" INT2 Liner
8226.54 25599.00 4-1/2" Production Liner
Mag Model & Date: BGGM2023 10-Feb-24
Magnetic North is 13.71° East of True North (Magnetic Declination)
Mag Dip & Field Strength: 80.34° 57076.36nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 700.00 3.00 164.00 699.91 -5.03 1.44 1.50 164.00 -5.10 Start Build 2.00
4 1000.00 9.00 164.00 998.13 -35.16 10.08 2.00 0.00 -35.66 Start DLS 2.50 TFO -21.55
5 3368.19 67.62 144.05 2779.84 -1205.70 773.03 2.50 -21.55 -1245.83 Start 5843.16 hold at 3368.20 MD
6 9211.31 67.62 144.05 5004.19 -5579.92 3944.86 0.00 0.00 -5785.56 Start DLS 3.00 TFO -156.83
7 14440.30 90.92 332.95 8406.50 -4256.04 4766.71 3.00 -156.83 -4508.18 Start 11159.65 hold at 14440.35 MD
8 25600.00 90.92 332.95 8226.52 5681.25 -308.43 0.00 0.00 5689.61 TD at 25600.00
FORMATION TOP DETAILS
TVDPath Formation
979.50 Base Permafrost
1088.37 C40
1421.35 C30
1647.32 C20
2004.67 C10
3029.96 K2
3663.38 Albian_97
3881.17 Albian_96
4068.23 Albian_95
4966.87 Albian_94
5545.93 Albian_93
5705.17 Sub93
6292.63 Albian_92
6416.00 Albian_91
6588.41 Top FCS
6666.32 Susitna_Sand_Structure
7469.72 HRZ
7635.35 LCU
8359.74 Alpine_D
8399.62 Alpine_C
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 (100.5 GL + 39.0 DF) @ 139.50usft (Original Well Elev)
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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 no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
X
RENDEZVOUS OIL POOLGREATER MOOSES TOOTH
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s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
s
e
r
v
NA
15
Al
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
16
Pr
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
No
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
80
'
c
o
n
d
u
c
t
o
r
p
r
o
v
i
d
e
d
18
Co
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
SC
s
e
t
a
t
4
0
7
5
'
M
D
19
Su
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
68
%
e
x
c
e
s
s
20
CM
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
No
21
CM
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
No
un
c
e
m
e
n
t
e
d
I
C
D
s
a
n
d
s
w
e
l
l
p
a
c
k
e
r
s
22
CM
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
23
Ca
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
24
Ad
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
25
If
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
26
Ad
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
Di
v
e
r
t
e
r
v
a
r
i
a
n
c
e
g
r
a
n
t
e
d
p
e
r
2
0
A
A
C
2
5
.
0
3
5
(
h
)
(
2
)
27
If
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
Ma
x
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
i
s
3
7
2
2
p
s
i
g
(
8
.
7
p
p
g
E
M
W
)
;
w
i
l
l
d
r
i
l
l
w
/
8
.
8
-
9
.
5
p
p
g
E
M
W
28
Dr
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
29
BO
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
MP
S
P
i
s
2
8
9
9
p
s
i
g
;
w
i
l
l
t
e
s
t
B
O
P
s
t
o
5
0
0
0
p
s
i
g
i
n
i
t
i
a
l
l
y
a
n
d
3
5
0
0
p
s
i
g
s
u
b
s
e
q
u
e
n
t
l
y
30
BO
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
Ch
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
Wo
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
No
33
Is
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
34
Me
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
Ye
s
H2
S
n
o
t
e
x
p
e
c
t
e
d
;
r
i
g
h
a
s
s
e
n
s
o
r
s
a
n
d
a
l
a
r
m
s
.
35
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
Ma
x
p
o
r
e
p
r
e
s
s
u
r
e
a
n
t
i
c
i
p
a
t
e
d
t
o
b
e
1
1
.
4
p
p
g
E
M
W
i
n
s
h
a
l
e
s
o
f
A
l
p
i
n
e
D
.
E
x
p
e
c
t
i
n
g
8
.
7
p
p
g
i
n
r
e
s
e
r
v
o
i
r
.
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
1/
4
/
2
0
2
4
Ap
p
r
VT
L
Da
t
e
1/
1
6
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
1/
9
/
2
0
2
4
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
JL
C
1
/
1
6
/
2
0
2
4
