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223-128
T39170
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.11 09:07:36 -08'00'
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TITAN-1 50-103-20876-00-00 223-128 COLVILLE RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 3-Apr-24 1
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223-128
T38941
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.06.14 10:15:55 -08'00'
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:2105' FSL, 1079' FEL S13 T12N R3E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 2.2 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-40 135'
10-3/4"L-80 2358'
7-5/8"L-80 7260'
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
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl:Water-Bbl:
13051' Above Retainer 30 bbls 15.8ppg Class G
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test:Oil-Bbl:
Flow Tubing
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and
Number; Date perf'd or liner run):
Gas-Oil Ratio:Choke Size:
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
13051' Below Retainer 20 bbls 15.8ppg Class G
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7 52'
94
45.5
135'
52'13115'
SIZE DEPTH SET (MD)
10 Yards
PACKER SET (MD/TVD)
24"
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
346559
346905
CEMENTING RECORD
5994778
1309'MD/1297'TVD
SETTING DEPTH TVD
5992560
TOP HOLE SIZE AMOUNT
PULLED
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
50-103-20876-00-00
CRU Titan 1
3/8/2024
15520'MD/7276'TVD
Surface/Surface
58.74
P.O.Box 100360, Anchorage, AK 99510-0360
355268
490' FSL, 2430' FEL S17 T12N R4E
5175' FSL, 688' FEL S24 T12N R3E
4/1/2024
5992989
Colville River Unit/Alpine Oil Pool
ADL390345, ADL390348, ADL388466,
ADL388463, ASRC-NPR1, ASRC-NPR2
LONS 23-002
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
4/7/2024 223-128/324-181
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,
TUBING RECORD
Lead:397bbl 11.0ppg Class G
Tail: 48.1bbl 15.8ppg Blend
9.875x11"
TOP
SETTING DEPTH MD
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER, MUD
53'
55'
2671'
WT. PER
FT.
2788'3.5"None
BOTTOM
13.5"Lead: 367bbl 11.0ppg Blend
Tail: 100bbl 15.8 Class G
CASING GRADE
53'
55'
W
d 1b
0 D p
op and B om; Perf
L
s
((atta
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 2:58 pm, May 02, 2024
Abandoned
4/7/2024
JSB
RBDMS JSB 051724
DSR-11/22/24
G
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1309 1297
Schrader Bluff 1155 1149
2412 2196
3993 2982
Qannik 6268 4052
Albian 97 6942 4373
Kalubik 12729 7172
K1 12865 7208
13266 7283
15520 7275
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: Matt Nagel
Digital Signature with Date:
Contact Phone:907-263-4747
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
C-40
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:matt.b.nagel@conocophillips.com
Authorized Title: Drilling Engineer
C-10
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:
Kuparuk 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:
Kuparuk C
N
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
Conductor 20 19.12 54.5 135.0 135.0 94.00
Surface 10 3/4 9.95 53.3 2,671.1 2,358.3 45.50 L80 TXP
Intermediate 7 5/8 6.88 51.7 13,115.0 7,260.0 29.70 L80 H563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
51.1
Set Depth …
2,787.6
String Max No…
3 1/2
Set Depth …
2,422.2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE 8RD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
51.1 Landing Jt 4.500 3.958
51.1 Hanger 4.500 3.910
2,767.6 2,411.8 58.37 Shoe - Mule 3.500 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
2,800.0 2,428.6 59.18 RBP 4/5/2024
13,051.0 7,248.2 78.98 RBP 4/3/2024
HORIZONTAL, TITAN 1, 4/29/2024 1:34:50 PM
Vertical schematic (actual)
Squeeze – Formation Squeeze;
13,051.0 ftKB
Intermediate; 51.7-13,115.0
Plug – Plug Back /
Abandonment Plug; 12,619.0
ftKB
Plug – Plug Back /
Abandonment Plug (plug);
12,175.0 ftKB
Intermediate String 1 Cement;
11,115.0 ftKB
Stage Cementing; 54.5 ftKB
Surface; 53.3-2,671.1
Plug – Plug Back /
Abandonment Plug; 0.0 ftKB
Surface String Cement; 54.5
ftKB
Conductor; 54.5-135.0
Hanger; 51.1
Plug – Plug Back /
Abandonment Plug (plug); 0.0
ftKB
WNS
KB-Grd (ft)
54.54
RR Date
4/7/2024
Other Elev…
TITAN 1
...
TD
Act Btm (ftKB)
15,520.0
Well Attributes
Field Name
ALPINE
Wellbore API/UWI Wellbore Status
Max Angle & MD
Incl (°)
93.06
MD (ftKB)
14,794.65
WELLNAME WELLBORETITAN 1
Annotation End DateH2S (ppm) DateComment
Page 1/36
TITAN 1
Report Printed: 4/29/2024
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)
2/28/2024
02:00
2/28/2024
04:00
2.00 MIRU, MOVE MOB P Stomped pipe shed away from drill
module.
2/28/2024
04:00
2/28/2024
06:00
2.00 MIRU, MOVE MOB P Blew down water on sub base, BOP
module, & pipe shed. Prepped rig floor
interconnects to skid rig floor into
moving position.
2/28/2024
06:00
2/28/2024
07:00
1.00 MIRU, MOVE MOB P Stomped CPU away from pits & moved
to edge of pad.
2/28/2024
07:00
2/28/2024
09:00
2.00 MIRU, MOVE MOB P Skidded rig floor into move position and
secured same.
2/28/2024
09:00
2/28/2024
12:00
3.00 MIRU, MOVE MOB P Moved and staged motor, pump, pits
modules on CD5.
2/28/2024
12:00
2/28/2024
18:00
6.00 MIRU, MOVE MOB P Unpinned sub module from the BOP
module.Laid mat boards and turned drill
module toward pad entrance.
Note: 20" conductor cut to required
height above ice. StremFlo landing ring
installed on 20" conductor and 4"
nipples welded on conductor.
2/28/2024
18:00
2/29/2024
00:00
6.00 MIRU, MOVE MOB P Moved Drill, Motors and CPU modules
from CD5 well row down access road to
main road.
2/29/2024
00:00
2/29/2024
07:00
7.00 MIRU, MOVE MOB P Moved Sub, Motors and CPU modules
from main road at CD5, 1 mile to Titian
ice road. Continue down Titan ice road 6
miles to ~1 mile from Titan ice pad when
Sub module broke through the ice road.
2/29/2024
07:00
2/29/2024
12:00
5.00 MIRU, MOVE MOB T Broke through ice road with front tires of
moving system. Maneuvered sub
module out of damaged ice road using 2
D8 dozers and staged module back to
allow access to damaged area.
2/29/2024
12:00
2/29/2024
18:15
6.25 MIRU, MOVE MOB T Rolligon mobolized timbers to site. FIlled
damaged area with timbers and laid 2
layers mat boards over same. Water in
mat boards and allowed to freeze.
2/29/2024
18:15
2/29/2024
18:45
0.50 MIRU, MOVE MOB T Attempt to drive over this area and
broke through double layer mat boards
with front tires of moving system.
2/29/2024
18:45
2/29/2024
21:00
2.25 MIRU, MOVE MOB T Crib up under tires in the hole in the ice
road. Maneuvered sub module out of
damaged area using 2 D8 dozers and
staged module back on ice road to
allow access to damaged area.
2/29/2024
21:00
3/1/2024
00:00
3.00 MIRU, MOVE MOB T Move sub module away from ice road
damaged area. Pick up all plywood and
timbers used and mat boards.
SIMOPS: Staging Ice Road equipment
to the area.
3/1/2024
00:00
3/1/2024
18:00
18.00 MIRU, MOVE MOB T Wait on ice road to be rerouted before
resuming move. Preparations in
progress for ice road rerouting.
3/1/2024
18:00
3/2/2024
00:00
6.00 MIRU, MOVE MOB T Wait on ice road to be rerouted before
resuming move. Start building the ice
road reroute.
SIMOPS:Mobilize herculite to Titan pad.
Remove BOP pin kits for repair.
3/2/2024
00:00
3/2/2024
12:00
12.00 MIRU, MOVE MOB T Wait on ice road to be rerouted before
resuming move. Completed building the
ice road reroute and letting it cure.
SIMOPS: Laying herculite on Titan pad.
Removed remaining BOP pin kits for
repair. Jacked up BOP module and pin
tires for transport. Repair pin kit on front
DS wheel turning system.
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 2/36
TITAN 1
Report Printed: 4/29/2024
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)
3/2/2024
12:00
3/3/2024
00:00
12.00 MIRU, MOVE MOB T Ice road reroute completed and curing
prior to resuming rig move.
SIMOPS: Continue staging rig mats to
Titan ice pad. Installed BOP pin kits.
Jacked up Pit module and pin tires for
transport.
3/3/2024
00:00
3/3/2024
06:00
6.00 MIRU, MOVE MOB T Ice road reroute completed and curing
prior to resuming rig move. Positioning
Pit's, Pump's and BOP modules at CD5
and secure for travel to Titan.
SIMOPS: Continue staging rig mats and
misc equipment to Titan ice pad.
3/3/2024
06:00
3/3/2024
12:00
6.00 MIRU, MOVE MOB P Resume moving sub to Titan ice pad
using rerouted ice road (on pad at 09:30
hrs). Moving motor shed and CPU (were
staged behind sub) to Titan ice pad.
Continue with preparing ice pad with
herculite and rig mats.
3/3/2024
12:00
3/3/2024
13:15
1.25 MIRU, MOVE MOB P Continue moving motor shed and CPU
to Titan ice pad.
3/3/2024
13:15
3/3/2024
14:30
1.25 MIRU, MOVE MOB P Mobilize trucks and move pipe shed
from staging area to ice pad while
continuing to place rig mats and
herculite.
3/3/2024
14:30
3/3/2024
20:30
6.00 MIRU, MOVE MOB P Mobilize trucks to CD5 and move pump
room, BOP and pit modules (left this
module at ice road turn out) from CD5 to
Titan ice pad.
3/3/2024
20:30
3/4/2024
00:00
3.50 MIRU, MOVE MOB P Mobilize trucks and move pits from ice
road turn out to Titan ice pad while
continuing to set rig mats and herculite.
3/4/2024
00:00
3/4/2024
12:00
12.00 MIRU, MOVE MOB P Position pipe shed to edge mats, lay
herculite and back pipe shed into
position.
Reposition sub to east side of pad.
Spot BOP module in line with well
center and set down on stompers.
Lay herculite for sub and back sub into
spotting position.
Spot sub into position and pin to BOP
module.
Shim BOP module, set outriggers into
place and prepare to skid rig floor.
Skiding rig floor into drill position.
3/4/2024
12:00
3/5/2024
00:00
12.00 MIRU, MOVE MOB P Complete skidding rig floor to drill
position.
Lay herculite for pits and CPU.
Mobilize trucks and move pit module
and spot into position.
Mobilize trucks and move CPU module
and spot into position.
Lay herculite for pump room and motor
modules.
Mobilize trucks and move pump room
module and walk into position.
Move motor module, pipe shed and spot
into position.
Electrician started plugging in boards.
Begin with rig acceptance check list.
3/5/2024
00:00
3/5/2024
12:00
12.00 MIRU, MOVE MOB P Continue with rig acceptance check list.
Take on fuel and water.
Electrician finished with plug boards.
Swap to generator at 02:45 hrs.
Berm herculite around all modules.
Turn on steam and water.
Lay mats and herculite for MagTec.
Lay mats and herculite for camp move.
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 3/36
TITAN 1
Report Printed: 4/29/2024
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
12:00
3/5/2024
14:30
2.50 MIRU, MOVE MOB P Continue with rig acceptance check list.
Continue to berm herculite around all
modules.
Mobilize StreamFlo equipment to cellar.
Continue to prepare for camp move.
Start loading 5-7/8" drill pipe in pipe
shed.
3/5/2024
14:30
3/5/2024
17:00
2.50 MIRU, MOVE MOB P Install StreamFlo starting head on
conductor. Test to 250 psi for 10 minutes
- good test.
SIMOPS: FInish loading 81 joints 5-7/8"
drill pipe in shed.
3/5/2024
17:00
3/5/2024
19:30
2.50 MIRU, MOVE MOB P Lay herculite over mats for camp.
Continue berm herculite around all
modules. Continue with rig acceptance
checklist.
3/5/2024
19:30
3/6/2024
00:00
4.50 MIRU, MOVE MOB P Install diverter spool and 21-1/4" annular
on conductor. Start N/U 1st section of
riser on annular.
SIMOPS: Continue to berm herculite
around all modules. Spot and R/U DC1
camp on ice pad. Continue with rig
acceptance checklist.
3/6/2024
00:00
3/6/2024
12:00
12.00 MIRU, MOVE MOB P Cont. Install diverter spool and 21-1/4"
annular on conductor. Continue with Rig
acceptance check list. Thaw CPU and
turn on Rig water.
SIMOPS: Continue to berm herculite
around all modules. Adjust MagTec units
location, thaw and rig up MagTec lines,
containment berming etc., Continue with
rig acceptance checklist.
0.0 0.0
3/6/2024
12:00
3/7/2024
00:00
12.00 MIRU, MOVE MOB P Cont. install diverter lines and knife
valve. Cont. with rig acceptance check
list. Thaw CPU and turn on Rig water.
Move rig shop to Titan Pad. Begin
building stds.
Accept rig at 00:00hrs 3/7/24
SIMOPS: Cont. adjust MagTec unit
location, M/U & thaw lines, adjust
matting boards, containment berming
etc. Function test annular and diverter
system.
0.0 0.0
3/7/2024
00:00
3/7/2024
03:00
3.00 MIRU, MOVE MOB P Cont. with rig acceptance checklist.
Thaw CPU and turn on Rig water. Build
15 stds dp.
Accept rig at 00:00hrs 3/7/24
SIMOPS: Cont. rig up MagTec unit. and
electircal heating lines
0.0 0.0
3/7/2024
03:00
3/7/2024
04:30
1.50 MIRU, MOVE RURD P Conduct diverter fucntion/inspection test
with AOGCC Josh Hunt. Function 2 sec
close knife valve, 24 sec close annular
preventer, Tested hi/low alarms, gas
sensors. Passed all tests per AOGCC
inspector Josh Hunt. Perfrom Diverter
drill with Rig hands.
0.0 0.0
3/7/2024
04:30
3/7/2024
07:30
3.00 MIRU, MOVE RURD P Cont. with rig acceptance checklist.
Thaw CPU and turn on Rig water. Build
12 stds dp and 3 stds hwdp.
SIMOPS: Cont. rig up MagTec unit. and
electrical heating lines
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 4/36
TITAN 1
Report Printed: 4/29/2024
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)
3/7/2024
07:30
3/7/2024
10:00
2.50 MIRU, MOVE SVRG P Cut and slip 75' drilling line per Doyon.
Conduct full drawworks brake
inspection. Conduct Derrick inspection.
Mobilize clean out assembly to Rig floor
SIMOPS: Cont. rig up MagTec unit. and
electrical heating lines0
0.0 0.0
3/7/2024
10:00
3/7/2024
14:30
4.50 MIRU, MOVE BHAH P MU clean out assembly, Tri-cone, MM,
Stab per DD.
SIMOPS: Cont. rig up MagTec unit. and
electrical heating lines. Install 4" valves
on riser in cellar. Load shed with 10 3/4"
casing
0.0 0.0
3/7/2024
14:30
3/7/2024
21:30
7.00 MIRU, MOVE BHAH P MU stand of HWDP and load hole with
fluid, check for leaks
SIMOPS: Cont. to rig up MagTec unit
and electrical heating lines. Thawing
2nd tank. Working on air and glycol
circulation. Send first ACB to disposal, 1
haul truck down, Load shed and process
with 10 3/4" casing
0.0 0.0
3/7/2024
21:30
3/7/2024
22:30
1.00 MIRU, MOVE CIRC P MU DC to Clean out assm, Clean out
Conductor to 130'. GPM=450, psi-225,
rpm=35, Circulate conductor clean.
0.0 130.0
3/7/2024
22:30
3/7/2024
23:30
1.00 MIRU, MOVE BHAH P Rack back DC, Break bit. Clean and
clear floor.
130.0 0.0
3/7/2024
23:30
3/8/2024
00:00
0.50 SURFAC, DRILL BHAH P Pjsm and PU Surface BHA #1, MU
Kymera bit and orient
0.0 0.0
3/8/2024
00:00
3/8/2024
01:30
1.50 SURFAC, DRILL BHAH P PU Surface Bha #1 per DD, MU Kymera
bit to MM,
0.0 125.0
3/8/2024
01:30
3/8/2024
04:00
2.50 SURFAC, DRILL SFTY P Pre-Spud meeting with all hands -
Review Rig accept checklist
SIMOPS: Haul off first MagTec ACB,
w/3.5hrs round trip time, Had 1 haul
truck down. Hold off spud until MagTec
at full capacity
125.0 125.0
3/8/2024
04:00
3/8/2024
06:30
2.50 SURFAC, DRILL DDRL P Drill 13.5" surface section. f/133' Md
t/499' Md.
600gpm; 1400 psi
50 rpm; Tq on 8K, off 3K
WOB 25K
AST= .25hr, ART=1.13hr, ADT= 1.38hr,
Bit hrs= 1.38, Jar Hrs= 0.29
125.0 499.0
3/8/2024
06:30
3/8/2024
12:30
6.00 SURFAC, DRILL DDRL P Drill 13.5" surface section. f/499' Md
t/1331' Md.
600gpm; 1400 psi
50 rpm; Tq on 8K, off 3K
WOB 25K
AST= 2.08hr, ART=2.33hr, ADT= 4.41hr,
Bit hrs= 4.41, Jar Hrs= 3.32
499.0 1,331.0
3/8/2024
12:30
3/8/2024
18:30
6.00 SURFAC, DRILL DDRL P Drill 13.5" surface section. f/1331' Md
t/2,079' Md.
725gpm; 1700 psi
50 rpm; Tq on 10K, off 3K
WOB 22K
AST=3.44 hr,ART=3.45 hr,ADT= 6.89 hr,
Bit hrs= 6.89, Jar Hrs= 5.80
1,331.0 2,079.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 5/36
TITAN 1
Report Printed: 4/29/2024
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
18:30
3/8/2024
23:00
4.50 SURFAC, DRILL DDRL P Drill 13.5" surface section. f/2,079' Md
t/2,676' Md.
725gpm; 1700 psi
50 rpm; Tq on 10K, off 3K
WOB 22K
AST=5.23hr, ART=4.52hr, ADT= 9.75hr,
Bit hrs= 9.75, Jar Hrs= 8.66
2,079.0 2,676.0
3/8/2024
23:00
3/9/2024
00:00
1.00 SURFAC, TRIPCAS CIRC P Circulate hole clean 2 x BU at TD
GPM=800, Psi 1875, RPM=80, TQ=5k
Obtain final survey at TD
2,676.0 2,676.0
3/9/2024
00:00
3/9/2024
00:30
0.50 SURFAC, TRIPCAS OWFF P Blow Down Top drive - OWFF for 30
min. ** Static **
2,676.0 2,676.0
3/9/2024
00:30
3/9/2024
05:00
4.50 SURFAC, TRIPCAS BKRM P BROOH f/2,676' to 1,285'
Params: Gpm=800, Psi=1615, Rpm=50,
Tq=6k, Rtw=129k,
2,676.0 1,285.0
3/9/2024
05:00
3/9/2024
08:00
3.00 SURFAC, TRIPCAS PMPO P Pump OOH f/1,285' to 217'
Params: Gpm=250, Psi=187, Rpm=50,
Puw=95k
OWFF f/15 mins ** Static **
1,285.0 217.0
3/9/2024
08:00
3/9/2024
10:00
2.00 SURFAC, TRIPCAS BHAH P LD Bha per DD f/217' 217.0 0.0
3/9/2024
10:00
3/9/2024
14:00
4.00 SURFAC, CASING RURD P RU for Casing Equip. Mobilize 10 3/4" -
RU Volant, Spiders, Elevators and prep
for Dummy Run with StreamFlo. RU and
run Streamflo hanger landing joint per
Streamflo Rep. Landed on depth.
RD/LD landing joint and equip.
SIMOPS: Clean and clean floor, Prep
pits for Cement Job as secondary,
0.0 0.0
3/9/2024
14:00
3/9/2024
15:30
1.50 SURFAC, CASING PUTB P MU 10 3/4" Shoe track to 85'
PU shoe track, FS, 2 x joints, FC, Baker
-lock first 4 jts and Tq to 26k. Check
floats -> good,
0.0 85.0
3/9/2024
15:30
3/9/2024
18:00
2.50 SURFAC, CASING PUTB P Run 10 3/4" L-80 TXP surface casing
per detail f/85' to 593'
Notes: Tq casing to 22k. Fill casing on
fly and top off every 10 jts.
Observed weight stacking up at ~593'
85.0 593.0
3/9/2024
18:00
3/10/2024
00:00
6.00 SURFAC, CASING PUTB P Wash & ream 10 3/4" surface casing
f/593' to 711'
Params: Bpm=8, Psi=300, Rpm=15,
Tq=1.5k, w/Full returns.
Notes: Work casing with varying params
to work through the gravel and organics
zones.
593.0 711.0
3/10/2024
00:00
3/10/2024
06:00
6.00 SURFAC, CASING PUTB P Wash & ream 10 3/4" surface casing
f/711' to 750'
Params: Bpm=8, Psi=300, Rpm=15,
Tq=4.5k, w/Full returns.
Notes: Work casing with varying params
to work through the gravel and organics
zones.
711.0 750.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 6/36
TITAN 1
Report Printed: 4/29/2024
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
06:00
3/10/2024
10:00
4.00 SURFAC, CASING PUTB P Run 10 3/4" L-80 TXP surface casing
f/750' to 2,614'
Notes: Tq casing to 22k. Fill casing on
fly and top off every 10 jts.
750.0 2,614.0
3/10/2024
10:00
3/10/2024
11:00
1.00 SURFAC, CEMENT RURD P RD Csg equip. - Remove spiders, blow
down top drive, clean and clear floor
2,614.0 2,671.0
3/10/2024
11:00
3/10/2024
12:00
1.00 SURFAC, CEMENT PUTB P PU StreamlFlo hanger and landing joint
w17' pup
Run 10 3/4" StreamFlo hanger per
StreamFlo Rep. f/2,614' to 2,671',
SOW=145k
Notes: Tq all casing conn to 22k ft/lbs,
Land out on Hanger at 2,671'
2,671.0 2,671.0
3/10/2024
12:00
3/10/2024
18:00
6.00 SURFAC, CEMENT CIRC P Circulate and condition Mud for Cement
Job
Params: Bpm=8, Psi=365, Rpm=120,
Tq=4.5k, w/Full returns.
Note: Pre-Job for Cement with all hands
SIMOPS: Thawing rig and MagTec
transfer lines, Preparing truck and
Cementers for cement job
2,671.0 2,671.0
3/10/2024
18:00
3/10/2024
22:00
4.00 SURFAC, CEMENT CMNT P Fill lines and test to 3600psi,
Pump 100bbls 10.7ppg Mud Push,
Drop bottom plug,
Lead wet @ 1902 hrs, Pump 367 bbls
11.0 ppg lead cement at 6 bpm
w/530psi,
Tail wet @ 2010hrs, Pump 62.5 bbls
15.8 ppg tail cement at 5.5 bpm w/420
PSI,
Drop top plug.
Pump 20 Bbls H20 at 5 bpm 167 PSI.
Swap to rig pump and chase cement w/
10.5 ppg Drilplex mud at 7.5 BPM,
645PSI.
Slow rig pumps to 3 BPM for the last 10
Bbls,
Bumped plug on schedule with 1939
stks, 940 psi. Hold 5 min, bleed off
check floats, ok.
No losses throughout job,
272 Bbls cement to surface. CIP at
2121hrs.
OWFF - Static
2,671.0 2,671.0
3/10/2024
22:00
3/10/2024
22:30
0.50 SURFAC, CEMENT RURD P Shear StreamFlo hanger pins per
StreamFlo Rep. Back out and lay down
landing join and 17' pup.
0.0 0.0
3/10/2024
22:30
3/11/2024
00:00
1.50 SURFAC, CEMENT RURD P RD casing running tools and equipment,
Break connection on Vloant and lay
down same. Lay all equipment out and
clean and clear floor
0.0 0.0
3/11/2024
00:00
3/11/2024
03:00
3.00 SURFAC, CEMENT RURD P Cont clean up from Cement Job - MU
Stack washer and flush surface lines
with cement treatment water.
Flush annular, diverter & riser lines,
surface equipment, top drive, etc. Clean
and clear floor and blow down top drive.
SIMOPS: Thaw cellar drain valves,
Remove mouse-hole
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 7/36
TITAN 1
Report Printed: 4/29/2024
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)
3/11/2024
03:00
3/11/2024
05:00
2.00 SURFAC, CEMENT NUND P Begin ND surface diverter equipment
Power down koomy, Remove upper &
middle riser sections, break annular
bolts.
SIMOPS: Cont cement job haul off,
Begin Cleaning Pits, Clean and inspect
cement valves
0.0 0.0
3/11/2024
05:00
3/11/2024
09:00
4.00 SURFAC, CEMENT NUND P Cont. ND surface diverter equipment
Remove annular, knife valve, T-valve
from starting head. Mobilize StreamFlo
starting head and adapter to the cellar
SIMOPS: Install 5 1/2" x 7 5/8" VBR in
upper rams, Cont cleaning Pits,
Thawing frozen water intake line.
Remove DSA spool from bottom of HP
riser
0.0 0.0
3/11/2024
09:00
3/11/2024
10:00
1.00 SURFAC, CEMENT NUND P Prep StreamFlo wellhead equipment
Remove StreamFlo starting head form
conductor and prep for install of BOP
adapter spool. Cement observed about
30" below conductor,
SIMOPS: Cont. Cleaning Pits and
prepping to onboard new FWP mud
0.0 0.0
3/11/2024
10:00
3/11/2024
12:00
2.00 SURFAC, WHDBOP NUND P Install StreamFlo wellhead equipment
NU StreamFlo wellhead equipment per
StreamFlo Rep. Torque CRS bolts to 5k,
Conduct FS seal Test t/5000psi for 10
min, Witnessed by CPAI Rep.
SIMOPS: Cont. cleaning Pits and
prepping to onboard new FWP mud
0.0 0.0
3/11/2024
12:00
3/11/2024
18:00
6.00 SURFAC, WHDBOP NUND P NU BOP's - Install HP riser, BOP Stack,
choke line, kill line, riser to rig floor, RU
MPD lines to BOPS per MPD Advisor
SIMOPS: Cont. cleaning and prep mud
pits, grease choke manifold,
0.0 0.0
3/11/2024
18:00
3/11/2024
22:00
4.00 SURFAC, WHDBOP NUND P Break in Upper VBR's (5 1/2" x 7 5/8")
Cycle upper VBR's x 5 ea
- PU 5 7/8" test joint w/ pups
- PU 7 5/8" test joint w/ pups
LD the 7 5/8" and PU 5 7/8" test joint
0.0 0.0
3/11/2024
22:00
3/11/2024
23:00
1.00 SURFAC, WHDBOP NUND P Finish prep for BOP Test
Fill stack with H20 and purge all air,
Prep choke manifold to perform BOP
shell test
0.0 0.0
3/11/2024
23:00
3/12/2024
00:00
1.00 SURFAC, WHDBOP BOPE P Perform full BOP test with 5-7/8" & 7
5/8" test joints -Annular T/ 250/2500 psi
f/5 min. Remaining tests 250/5000 psi
f/5 min.
-#1 Annular 250 psi low, 2500 psi high.
-Test witnessed by AOGCC, Sean
Sullivan
0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 8/36
TITAN 1
Report Printed: 4/29/2024
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
00:00
3/12/2024
06:00
6.00 SURFAC, WHDBOP BOPE P Perform full BOP test with 5-7/8" & 7
5/8" test joints -Annular T/ 250/2500 psi
f/5 min. Remaining tests 250/5000 psi
f/5 min.
-#1 Annular 250 psi low, 2500 psi high.
-#2 Upper VBRs 3-1/2" x 6-5/8"; CMV
1,14, 15, 16; kill line #3.
-#3 Upper IBOP; HCR kill; CMV 10, 13,
needle valve above #1.
-#4 manual kill; Lower IBOP; CMV 4, 9,
12.
-#5 CMV 6, 8, 11.
-#6 CMV 5 & 7, 5-7/8" Dart valve.
-#7 CMV 2, 5-7/8" TIW valve
-#8 HCR choke valve.
-#9 Manual choke valve.
-#10 Lower VBRs 3-1/2" x 6-5/8".
-#11 Blind / shear rams; CMV 3,4,6.
-#12 Super choke to 1500 psi.
-#13 Super choke to 1500 psi.
-Conduct accumulator draw down.
System pressure 3050 psi; manifold
pressure 1550 psi; after all closures
1650 psi; 200 psi build with 2 electric
pumps in 12 seconds; full pressure
attained in 88 seconds. Closing times:
annular 18 seconds; UPR 16 seconds;
blind/shear 14 seconds; LPR 17
seconds; choke HCR 1 second; kill HCR
2 second. 10 bottles nitrogen backup
3850 psi avg. Gas detection system, pit
level indicators and flow alarms tested.
-Test witnessed by AOGCC, Sean
Sullivan
0.0 0.0
3/12/2024
06:00
3/12/2024
08:00
2.00 SURFAC, WHDBOP BOPE P Test MPD per MPD Advisor,
Pull 5 7/8" test joint, and Install RCD
test plug and orbit valve, Test to 250psi
low, 1200psi high
0.0 0.0
3/12/2024
08:00
3/12/2024
09:00
1.00 SURFAC, WHDBOP RURD P RD from BOPE Test, LD RCD test plug
and equip, Pull Test plug per Streamflo
Rep. Blow down surface lines & choke
manifold. RU and set wear ring per
Streamflo Rep.
0.0
3/12/2024
09:00
3/12/2024
10:00
1.00 SURFAC, WHDBOP PRTS T RU and test Casing to 4000psi
-Prep for Casing test - Flood lines
w/mud, Shut blind rams and pump
44stks at 4bpm.
- Notice psi bleed-off at ~3750psi, Shut
down to trouble-shoot. Shut HCR Kill
and monitor with all surface equip
isolated. Surface psi was constant with
Casing pressure still continuing to bleed
off.
- Test unsuccessful, Bleed off and
consult with town,
0.0 0.0
3/12/2024
10:00
3/12/2024
10:30
0.50 SURFAC, WHDBOP PRTS T Attempt to test Casing to 4000psi
- RU and pump and additional 15stks to
1250psi via HCR Kill. Monitor on IA
pressure. Pressure still bleeding off,
Bleed off pressure and blow down lines
- Test unsuccessful, Bleed off and
consult with town,
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 9/36
TITAN 1
Report Printed: 4/29/2024
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
10:30
3/12/2024
14:30
4.00 SURFAC, WHDBOP PULD T PU 16 std 5 7/8" drill pipe from shed and
stand back in derrick
SIMOPS: Consult with town, Mobilize
Baker equipment and necessary xo's to
perform casing test
0.0 0.0
3/12/2024
14:30
3/12/2024
15:30
1.00 SURFAC, WHDBOP BHAH T PU clean out assembly per Slb DD
- Mobilize Bha equipment per DD, MU 9
7/8" Bit, bit-sub, NMDC, HWDP, XO to
DP
0.0 256.0
3/12/2024
15:30
3/12/2024
19:00
3.50 SURFAC, WHDBOP PULD T PU 23 std 5 7/8" drill pipe from shed and
SIH to 2,361'
SIMOPS: Mobilizing Baker equipment
and necessary xo's to perform casing
test
256.0 2,361.0
3/12/2024
19:00
3/12/2024
20:00
1.00 SURFAC, WHDBOP REAM T W&R from 2,361' to 2,580'
-Params: Gpm=300, Psi=288, Rpm=30,
Tq=2k
-Tag top plug at 2,581.2' w/10klbs.
2,361.0 2,581.0
3/12/2024
20:00
3/12/2024
21:00
1.00 SURFAC, WHDBOP CIRC T Circulate and condition mud
-Params: Gpm=300, Psi=288, Rpm=30,
Tq=2k, Puw= 134, Sow=128, Rtw=130
- OWFF - Well static
2,581.0 2,581.0
3/12/2024
21:00
3/12/2024
23:00
2.00 SURFAC, WHDBOP TRIP T TOOH f/2,581' to Surface
- OWFF at BHA - Well static
2,581.0 226.0
3/12/2024
23:00
3/12/2024
23:30
0.50 SURFAC, WHDBOP BHAH T LD clean out assembly per Slb DD,
- Clean and clear floor
226.0 0.0
3/12/2024
23:30
3/13/2024
00:00
0.50 SURFAC, WHDBOP BHAH T PU Baker testing assembly with test
packer per Baker Rep.
- Mobilize Bha equip. PU bull-nose,
Baker test packer, pup jt, XO, 3 stds
hwdp
0.0 109.0
3/13/2024
00:00
3/13/2024
02:30
2.50 SURFAC, WHDBOP TRIP T Tripped in the hole with packer
assembly from 109'-2552' MD. PUW
132K; SOW 124K
109.0 2,552.0
3/13/2024
02:30
3/13/2024
03:00
0.50 SURFAC, WHDBOP CIRC T Circulated at 210 gpm, 201 psi, FO 7%. 2,552.0 2,552.0
3/13/2024
03:00
3/13/2024
03:30
0.50 SURFAC, WHDBOP RURD T Blew down top drive. Made up FOSV on
stand #27. Spaced out and set packer at
2552' MD per Baker Rep. Lined up &
flooded kill line to test casing above the
packer.
2,552.0 2,552.0
3/13/2024
03:30
3/13/2024
04:00
0.50 SURFAC, WHDBOP PRTS T Tested casing from 2552' MD to surface.
Pumped 3.4 bbls of 10.5 ppg mud to
4015 psi. Shut in and monitored
pressure for 30 minutes. Final pressure
recorded was 3994 psi. Bled back 3.4
bbls.
2,552.0 2,552.0
3/13/2024
04:00
3/13/2024
04:30
0.50 SURFAC, WHDBOP PRTS T Attempted to test casing below the
packer. Pumped 3.6 bbls to pressure up
to 630 psi. Observed a 200 psi pressure
loss in 5 minutes. Pumped up the
pressure to 1100 psi with another .24
bbl. Shut down and observed ~300 psi
loss in a couple of minutes. Bled off
pressure at surface after casing leak
determined below 2552' MD.
2,552.0 2,552.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 10/36
TITAN 1
Report Printed: 4/29/2024
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)
3/13/2024
04:30
3/13/2024
05:15
0.75 SURFAC, WHDBOP RURD T Released packer per Baker Rep. Blew
down top drive & prepped the rig floor
for trip out of the hole. Installed stripping
rubber.
2,552.0 2,552.0
3/13/2024
05:15
3/13/2024
05:30
0.25 SURFAC, WHDBOP OWFF T Monitored well, static. 2,552.0 2,552.0
3/13/2024
05:30
3/13/2024
07:00
1.50 SURFAC, WHDBOP TRIP T Tripped out of the hole from 2552'-109'
MD.
2,552.0 109.0
3/13/2024
07:00
3/13/2024
07:15
0.25 SURFAC, WHDBOP OWFF T Monitored well, static. 109.0 109.0
3/13/2024
07:15
3/13/2024
08:00
0.75 SURFAC, WHDBOP BHAH T Laid down Baker packer assembly as
per Rep. Cleared & cleaned rig floor.
109.0 0.0
3/13/2024
08:00
3/13/2024
16:15
8.25 SURFAC, DRILLOUT PULD P Picked up and racked back 53 stands of
5-7/8" drill pipe in the derrick.
0.0 0.0
3/13/2024
16:15
3/13/2024
17:45
1.50 SURFAC, DRILLOUT BHAH P Prepped rig floor to pickup BHA.
Mobilized BHA to the rig floor.
0.0 0.0
3/13/2024
17:45
3/13/2024
23:00
5.25 SURFAC, DRILLOUT BHAH P Picked up 9-7/8" X 11" Intermediate
BHA to 542' MD as per SLB DD. SOW
110K.
0.0 542.0
3/13/2024
23:00
3/14/2024
00:00
1.00 SURFAC, DRILLOUT PULD P Singled in the hole with 5-7/8" drill pipe
from 542'-1272' MD.
542.0 1,272.0
3/14/2024
00:00
3/14/2024
01:15
1.25 SURFAC, DRILLOUT PULD P Tripped in the hole from 1272'-2398' MD
with intermediate BHA. PUW 132K;
SOW 113K
1,272.0 2,398.0
3/14/2024
01:15
3/14/2024
02:15
1.00 SURFAC, DRILLOUT REAM P Washed & reamed from 2398'-2584'
MD, tagging the plugs with 10K.
500 gpm; 1420 psi; FO 23%
30 rpm; Tq 4K
2,398.0 2,584.0
3/14/2024
02:15
3/14/2024
04:30
2.25 SURFAC, DRILLOUT DRLG P Drilled out cement plugs & float collar
from 2584'-2586' MD.
500 gpm; 1456 psi; FO 26%
60 rpm; Tq 8K
WOB 12-18K
ECD 10.7
2,584.0 2,586.0
3/14/2024
04:30
3/14/2024
05:00
0.50 SURFAC, DRILLOUT DRLG P Drilled out cement from 2586'-2667' MD.
Did not notice any increase WOB
through shoe depth.
600 gpm; 2063 psi; FO 27%
60 rpm; Tq 8K
WOB 14K
ECD 11.61
2,586.0 2,667.0
3/14/2024
05:00
3/14/2024
05:30
0.50 SURFAC, DRILLOUT DRLG P Drilled out cement in rat hole from
2667'-2676' MD.
600 gpm; 1962 psi; FO 27%
60 rpm; Tq 8K
WOB 8K
2,667.0 2,676.0
3/14/2024
05:30
3/14/2024
05:45
0.25 SURFAC, DRILLOUT DDRL P Drilled intermediate section from 2676'-
2696' MD, 2375' TVD.
600 gpm; 1950 psi; FO 27%
60 rpm; Tq 7K
WOB 14K
ECD 11.09
ADT .16; BIT .16; JARS 8.82 hrs.
2,676.0 2,696.0
3/14/2024
05:45
3/14/2024
06:15
0.50 SURFAC, DRILLOUT CIRC P Circulated bottoms up from 2696'-2643'
MD.
600 gpm; 1943 psi; FO 26%
40 rpm; Tq 6K
ECD 11.15
2,696.0 2,643.0
3/14/2024
06:15
3/14/2024
07:00
0.75 SURFAC, DRILLOUT LOT P Blew down top drive. Rigged up to
perform FIT / LOT. SIMOPS prep for
displacement.
2,643.0 2,643.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 11/36
TITAN 1
Report Printed: 4/29/2024
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
07:00
3/14/2024
07:45
0.75 SURFAC, DRILLOUT LOT P Conducted LOT at shoe depth of 2671'
MD, 2358' TVD with 10.4 ppg mud to
16.5 ppg EMW. Pumped 1.3 bbls
pressuring up to 905 psi to observe
pressure break over. Shut in at 850 psi
and observed for 10 minutes. Final shut
in pressure was 480 psi. Bled back 1.0
bbl. Pressure deviated from the slope at
747 psi. Test was monitored on Totco IA
sensor.
2,643.0 2,643.0
3/14/2024
07:45
3/14/2024
08:00
0.25 INTRM1, DRILL LOT P Rigged down test equipment & blew
down lines. SIMOPS prep for
displacement.
2,643.0 2,643.0
3/14/2024
08:00
3/14/2024
09:00
1.00 INTRM1, DRILL CIRC P Circulated from 2643'-2696' to pump up
LOT data from SLB tools at 600 gpm,
1950 psi.
2,643.0 2,696.0
3/14/2024
09:00
3/14/2024
11:15
2.25 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 2696'-2885' MD, 2474' TVD.
SIMOPS displaced well to 11.0 ppg
FWP system.
750 gpm; 2650 psi; FO 32%
100 rpm; Tq on 7K; off 4K
WOB 5K
ECD 11.71
PUW 146K
SOW 143K
ROT 140K
ADT 1.67; BIT 1.83; JARS 10.49 hrs.
2,696.0 2,885.0
3/14/2024
11:15
3/14/2024
12:00
0.75 INTRM1, DRILL CIRC P Dropped 1.25" steel ball to activate
reamer open. Pumped down at 100
gpm, 105 psi, 30 rpm, Tq 2K. Pumped
16.6 bbls observe shear at 866 psi.
Back reamed to 2878' MD & pull tested
at shoe to 7K over. Went back down and
set 15K on shoulder. Reamer cutter
blocks 194' behind the bit. Reamer
verified open.
Benchmark parameters:
Closed 750 gpm; 2650 psi; 50 rpm; Tq
3K; RRS TRPM 4560; MWD TRPM
3985
Opened 750 gpm; 1860 psi; 50 rpm; Tq
5K; RRS TRPM 3900; MWD TRPM
3200
2,885.0 2,885.0
3/14/2024
12:00
3/14/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 2885'-3505' MD, 2758' TVD.
750 gpm; 2006 psi; FO 30%
150 rpm; Tq on 7K; off 2K
WOB 12K
ECD 12.0
PUW 148K
SOW 144K
ROT 143K
ADT 4.45; BIT 6.28; JARS 14.94 hrs.
2,885.0 3,505.0
3/14/2024
18:00
3/15/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 3505'-3879' MD, 2915' TVD.
Pumped bit balling sweeps every other
stand.
750 gpm; 2057 psi; FO 30%
150 rpm; Tq on 8K; off 2K
WOB 16K
ECD 12.17
PUW 156K
SOW 147K
ROT 146K
ADT 4.05; BIT 10.33; JARS 18.99 hrs.
3,505.0 3,879.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 12/36
TITAN 1
Report Printed: 4/29/2024
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
06:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 3879'-4503' MD, 3217' TVD.
Pumped bit balling sweeps every other
stand.
750 gpm; 2256 psi; FO 37%
150 rpm; Tq on 10K; off 7K
WOB 17K
ECD 12.58
PUW 159K
SOW 151K
ROT 149K
ADT 4.44; BIT 14.77; JARS 23.43 hrs.
3,879.0 4,503.0
3/15/2024
06:00
3/15/2024
12:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 4503'-5005 MD, 3451' TVD.
Pumped bit balling sweeps every other
stand.
750 gpm; 2267 psi; FO 31%
150 rpm; Tq on 10K; off 7K
WOB 14K
ECD 12.04
PUW 170K
SOW 154K
ROT 162K
ADT 4.49; BIT 19.26; JARS 27.92 hrs.
4,503.0 5,005.0
3/15/2024
12:00
3/15/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 5005'-5448 MD, 3660' TVD.
Pumped bit balling sweeps every 4th
stand.
750 gpm; 2357 psi; FO 32%
150 rpm; Tq on 9K; off 7K
WOB 14-22K
ECD 12.28
PUW 171K
SOW 165K
ROT 163K
ADT 4.95; BIT 24.21; JARS 32.87 hrs.
5,005.0 5,448.0
3/15/2024
18:00
3/16/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 5448'-5883 MD, 3865' TVD.
Pumped bit balling sweeps every 4th
stand.
750 gpm; 2492 psi; FO 35%
150 rpm; Tq on 9K; off 7K
WOB 16-22K
ECD 12.29
PUW 180K
SOW 160K
ROT 164K
ADT 4.69; BIT 28.90; JARS 37.56 hrs.
5,448.0 5,883.0
3/16/2024
00:00
3/16/2024
04:00
4.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 5883'-6198' MD, 4015' TVD.
Pumped bit balling sweeps every 4th
stand.
750 gpm; 2453 psi; FO 32%
150 rpm; Tq on 11K; off 7K
WOB 13K
ECD 12.16
PUW 186K
SOW 167K
ROT 174K
ADT 3.36; BIT 32.26; JARS 40.92 hrs.
5,883.0 6,198.0
3/16/2024
04:00
3/16/2024
04:30
0.50 INTRM1, DRILL CIRC P Circulated bottoms up at 750 gpm; 2480
psi; FO 30%; 90 rpm; Tq 6K; ECD
12.06.
6,198.0 6,198.0
3/16/2024
04:30
3/16/2024
04:45
0.25 INTRM1, DRILL OWFF P Monitored the well, static. 6,198.0 6,198.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 13/36
TITAN 1
Report Printed: 4/29/2024
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
04:45
3/16/2024
06:00
1.25 INTRM1, DRILL MPDA P Installed 5-7/8" MPD bearing per
Advisor. Flooded lines & tested to 500
psi. Function tested chokes & PRV as
per Advisor.
6,198.0 6,198.0
3/16/2024
06:00
3/16/2024
12:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 6198'-6614' MD, 4200' TVD.
Pumped bit balling sweeps every 4th
stand. Held 12.0 ppg EMW at the bit
with MPD.
800 gpm; 2726 psi; FO 40%
150 rpm; Tq on 11K; off 8K
WOB 12K
ECD 12.17
PUW 189K
SOW 168K
ROT 178K
ADT 4.45; BIT 36.71; JARS 45.37 hrs.
6,198.0 6,614.0
3/16/2024
12:00
3/16/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 6614'-7136' MD, 4464' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2767 psi; FO 37%
150 rpm; Tq on 13K; off 8K
WOB 17K
ECD 12.33
PUW 196K
SOW 165K
ROT 178K
ADT 4.34; BIT 41.05; JARS 49.71 hrs.
6,614.0 7,136.0
3/16/2024
18:00
3/17/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 7136'-7597' MD, 4682' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2738 psi; FO 35%
170 rpm; Tq on 15K; off 9K
WOB 25-30K
ECD 12.35
PUW 203K
SOW 163K
ROT 183K
ADT 4.53; BIT 45.58; JARS 54.24 hrs.
7,136.0 7,597.0
3/17/2024
00:00
3/17/2024
06:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 7597'-8104' MD, 4917' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2743 psi; FO 31%
150 rpm; Tq on 16K; off 11K
WOB 22-25K
ECD 12.21
PUW 210K
SOW 173K
ROT 190K
ADT 4.36; BIT 49.94; JARS 58.60 hrs.
7,597.0 8,104.0
3/17/2024
06:00
3/17/2024
12:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 8104'-8634' MD, 5162' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2843 psi; FO 34%
150 rpm; Tq on 17K; off 11K
WOB 22-27K
ECD 12.46
PUW 220K
SOW 172K
ROT 193K
ADT 4.??; BIT ??; JARS ? hrs.
8,104.0 8,634.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 14/36
TITAN 1
Report Printed: 4/29/2024
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
12:00
3/17/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 8634'-9103' MD, 5400' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2726 psi; FO 40%
150 rpm; Tq on 18K; off 11K
WOB 30K
ECD 12.4
PUW 230K
SOW 173K
ROT 196K
ADT 4.71; BIT 59.03; JARS 67.69 hrs.
8,634.0 9,103.0
3/17/2024
18:00
3/18/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 9103'-9540' MD, 5605' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2904 psi; FO 27%
150 rpm; Tq on 20K; off 13K
WOB 30K
ECD 12.41
PUW 235K
SOW 180K
ROT 201K
ADT 4.61; BIT 63.64; JARS 72.30 hrs.
9,103.0 9,540.0
3/18/2024
00:00
3/18/2024
06:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 9540'-10,003' MD, 5734' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3080 psi; FO 34%
175 rpm; Tq on 23K; off 18K
WOB 30-35K
ECD 12.47
PUW 245K
SOW 184K
ROT 205K
ADT 4.81; BIT 68.45; JARS 77.11 hrs.
9,540.0 10,003.0
3/18/2024
06:00
3/18/2024
12:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 10,003'-10,518' MD, 6079' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3034 psi; FO 37%
175 rpm; Tq on 25K; off 19K
WOB 35-40K
ECD 12.46
PUW 251K
SOW 190K
ROT 211K
ADT 4.49; BIT 72.94; JARS 81.60 hrs.
10,003.0 10,518.0
3/18/2024
12:00
3/18/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 10,518'-10,959' MD, 6309' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 2970 psi; FO 37%
175 rpm; Tq on 25K; off 20K
WOB 38K
ECD 12.33
PUW 260K
SOW 189K
ROT 213K
ADT 4.74; BIT 77.68; JARS 86.34 hrs.
10,518.0 10,959.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 15/36
TITAN 1
Report Printed: 4/29/2024
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)
3/18/2024
18:00
3/19/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 10,959'-11,399' MD, 6557' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3060 psi; FO 39%
175 rpm; Tq on 27K; off 22K
WOB 38K
ECD 12.46
PUW 280K
SOW 190K
ROT 218K
ADT 4.83; BIT 82.51; JARS 91.17 hrs.
10,959.0 11,399.0
3/19/2024
00:00
3/19/2024
06:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 11,399'-11,813' MD, 6780' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3030 psi; FO 34%
175 rpm; Tq on 31K; off 27K
WOB 28K
ECD 12.20
PUW 300K
SOW 198K
ROT 220K
ADT 4.59; BIT 87.10; JARS 95.76 hrs.
11,399.0 11,813.0
3/19/2024
06:00
3/19/2024
12:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 11,813'-12,209' MD, 6971' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3021 psi; FO 37%
175 rpm; Tq on 32K; off 27K
WOB 28K
ECD 12.23
PUW 321K
SOW 187K
ROT 230K
ADT 4.84; BIT 91.94; JARS 100.60 hrs.
11,813.0 12,209.0
3/19/2024
12:00
3/19/2024
18:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 12,209'-12,599' MD, 7128' TVD.
Pumped bit balling sweeps as needed.
Held 12.0 ppg EMW at the bit with MPD.
800 gpm; 3113 psi; FO 32%
175 rpm; Tq on 35K; off 32K
WOB 28K
ECD 12.34
PUW 325K
SOW 192K
ROT 228K
ADT 4.68; BIT 96.62; JARS 105.28 hrs.
12,209.0 12,599.0
3/19/2024
18:00
3/20/2024
00:00
6.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
from 12,599'-13,013 MD, 7236' TVD.
Pumped bit balling sweeps as needed.
Started holding 12.0 ppg EMW at the
top of the Kalubik with MPD at 12,732'
MD.
800 gpm; 3116 psi; FO 31%
175 rpm; Tq on 34K; off 32K
WOB 22K
ECD 12.32
PUW 327K
SOW 194K
ROT 228K
ADT 5.03; BIT 101.65; JARS 110.31 hrs.
12,599.0 13,013.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 16/36
TITAN 1
Report Printed: 4/29/2024
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
00:00
3/20/2024
02:00
2.00 INTRM1, DRILL DDRL P Drilled 9-7/8" x 11" intermediate section
to TD, from 13,013'-13,125' MD, 7260'
TVD. Pumped bit balling sweeps as
needed. Held 12.0 ppg EMW at the top
of the Kalubik with MPD.
800 gpm; 3075 psi; FO 39%
175 rpm; Tq on 33K; off 22K
WOB 21K
ECD 12.12
PUW 327K
SOW 194K
ROT 228K
ADT 1.66; BIT 103.31; JARS 111.97 hrs.
13,013.0 13,125.0
3/20/2024
02:00
3/20/2024
03:45
1.75 INTRM1, TRIPCAS CIRC P Obtained final survey & SCRs. Down
linked to MWD tools. Circulated bottoms
up reciprocating at 800 gpm; 3075 psi;
FO 30%; 120 rpm; Tq 30K; ECD 12.05.
13,125.0 13,125.0
3/20/2024
03:45
3/20/2024
04:30
0.75 INTRM1, TRIPCAS CIRC P Closed under reamer as per SLB DD.
Dropped 1.625" steel ball & pumped
down at 250-100 gpm; 750-540 psi; 40
rpm; Tq 27K. Observed pressure
increase to 1115 psi with 132 bbls
pumped. Reamer verified closed.
Benchmark parameters:
Opened 750 gpm; 2715 psi; 100 rpm;
Tq 36K; RRS TRPM 3860; MWD TRPM
3398
Closed 750 gpm; 3270 psi; 100 rpm; Tq
27K; RRS TRPM 4560; MWD TRPM
4101
13,125.0 13,125.0
3/20/2024
04:30
3/20/2024
06:15
1.75 INTRM1, TRIPCAS OWFF P Shut in 350 psi with MPD choke. Bled
off pressure with MPD to trip tank
gaining 4.1 bbls. Monitored slight
decreasing flow to trip tank. Lined up to
monitor well static for 30 minutes in the
BOP deck, good.
13,125.0 13,125.0
3/20/2024
06:15
3/20/2024
09:00
2.75 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 13,125'-
12,411' MD. Held an 12.0 EMW at the
top of the Kalubik with MPD.
125 gpm; 605 psi; FO 3%
25 rpm; Tq 19K
13,125.0 12,411.0
3/20/2024
09:00
3/20/2024
10:00
1.00 INTRM1, TRIPCAS CIRC P Circulated bottoms up racking back a
stand from 12,411-12,318' MD, 700
gpm; 2850 psi; FO 32%; 120 rpm; Tq
29K; ECD 12.02
12,411.0 12,318.0
3/20/2024
10:00
3/20/2024
12:00
2.00 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 12,318'-
11,850' MD. Held an 12.0 EMW at the
top of the Kalubik with MPD.
700 gpm; 2842 psi; FO 35%
120 rpm; Tq 28K
ECD 12.03
RTW 226K
12,318.0 11,850.0
3/20/2024
12:00
3/20/2024
18:00
6.00 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 11,850'-
9904' MD. Held an 12.0 EMW at the top
of the Kalubik with MPD.
700 gpm; 2800 psi; FO 34%
120 rpm; Tq 25K
ECD 12.32
RTW 209K
11,850.0 9,904.0
3/20/2024
18:00
3/21/2024
00:00
6.00 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 9904'-
8052' MD. Held an 12.0 EMW at the top
of the Kalubik with MPD.
700 gpm; 2750 psi; FO 35%
120 rpm; Tq 20K
ECD 12.49
RTW 185K
9,904.0 8,052.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 17/36
TITAN 1
Report Printed: 4/29/2024
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
00:00
3/21/2024
06:00
6.00 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 8052'-
5700' MD. Held an 12.0 EMW at the top
of the Kalubik with MPD.
700 gpm; 2570 psi; FO 30%
120 rpm; Tq 16K
ECD 12.8
RTW 163K
8,052.0 5,700.0
3/21/2024
06:00
3/21/2024
11:30
5.50 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 5700'-
3725' MD. Held an 12.0 EMW at the top
of the Kalubik with MPD. Had choke
plug off ~4880' MD. Flushed the choke
several times & worked through issues.
700 gpm; 2533 psi; FO 32%
120 rpm; Tq 17K
ECD 12.2
RTW 141K
5,700.0 3,725.0
3/21/2024
11:30
3/21/2024
13:45
2.25 INTRM1, TRIPCAS CIRC T Observed ~200 psi increase in pump
pressure. Reduced rates to 200 gpm;
476 psi; FO% 15; 25 rpm; Tq 3K.
Pumped 40 bbls of 35 ppb LCM pill.
Worked the string down to 3781' MD to
gain full returns. Staged up pump rate to
700 gpm; 2480 psi; 26%; 80 rpm; Tq 8-
9K; RTW 140K; ECD 12.25.
3,725.0 3,781.0
3/21/2024
13:45
3/21/2024
18:00
4.25 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 3781'-
3550' MD. Held an 12.0 EMW at the bit
with MPD. Adjusted rates as needed to
work through restrictions.
700 gpm; 2390 psi; FO 35%
100 rpm; Tq 8-9K
ECD 11.86
RTW 140K
3,781.0 3,550.0
3/21/2024
18:00
3/22/2024
00:00
6.00 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 3550'-
3187' MD. Held an 12.0 EMW at the bit
with MPD. Adjusted rates as needed to
work through restrictions.
700 gpm; 2360 psi; FO 36%
100 rpm; Tq 8K
ECD 11.95
RTW 137K
3,550.0 3,187.0
3/22/2024
00:00
3/22/2024
02:30
2.50 INTRM1, TRIPCAS BKRM P Back ream out of the hole from 3187-
2898' MD. Held an 12.0 EMW at the bit
with MPD. Adjusted rates as needed to
work through restrictions.
700 gpm; 2408 psi; FO 35%
100 rpm; Tq 7K
ECD 12.03
RTW 138K
3,187.0 2,898.0
3/22/2024
02:30
3/22/2024
04:00
1.50 INTRM1, TRIPCAS CIRC T Observed return flow decrease & losses
at 2898' MD. No pump pressure
increase noted. Did see 20K over pull at
same time with stabilizer coming into the
shoe. Tripped to 2940' MD with no
pumps & 10 rpm to get below a sand
stringer 2910'-2880' MD. Pumped 2; 40
bbls LCM pills, 35 ppb each at 200 gpm;
343 psi; 10 rpm; Tq 3K. Observed flow
out increase from 4% to 22% after
pumping 2nd pill. Staged pump rate up
to 400 gpm, 982 psi.
2,898.0 2,898.0
3/22/2024
04:00
3/22/2024
05:00
1.00 INTRM1, TRIPCAS BKRM P Back reamed out of the hole from 2898'-
2662' MD working through flow
restrictions.
400 gpm; 1021 psi
5 rpm; Tq 3K
PUW 143K
SOW 110K
2,898.0 2,662.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 18/36
TITAN 1
Report Printed: 4/29/2024
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)
3/22/2024
05:00
3/22/2024
06:00
1.00 INTRM1, TRIPCAS CIRC P Circulated bottoms up staging up pump
rate till shakers cleaned up.
700 gpm; 2530 psi; FO 35%
100 rpm; Tq 7K
ECD 11.79
2,662.0 2,662.0
3/22/2024
06:00
3/22/2024
08:00
2.00 INTRM1, TRIPCAS OWFF P Staged down pump rate to pumps off
monitoring returns. Lined up to trip tank
and monitored decreasing flow to
establish well bore breathing with 9 bbls
back. After flow stopped to trip tank,
monitored at BOP deck directly off of
RCD outlet 15 minutes static.
2,662.0 2,662.0
3/22/2024
08:00
3/22/2024
08:30
0.50 INTRM1, TRIPCAS MPDA P Removed MPD bearing as per SOP &
MPD Advisor.
2,662.0 2,662.0
3/22/2024
08:30
3/22/2024
11:15
2.75 INTRM1, TRIPCAS BKRM P Back reamed out of the hole from 2662'-
1560' MD
725 gpm; 2370 psi; 32%
100 rpm; Tq 3K
PUW 151K
SOW 136K
2,662.0 1,560.0
3/22/2024
11:15
3/22/2024
11:30
0.25 INTRM1, TRIPCAS CIRC P Circulated casing clean at 1560' MD.
725 gpm; 2365 psi; FO 32%
100 rpm; Tq 3K
ECD 11.55
1,560.0 1,560.0
3/22/2024
11:30
3/22/2024
12:15
0.75 INTRM1, TRIPCAS OWFF P Monitored well, static. SIMOPS blew
down top drive, cleared rig floor & lined
up on the trip tank.
1,560.0 1,560.0
3/22/2024
12:15
3/22/2024
13:30
1.25 INTRM1, TRIPCAS TRIP P Tripped out of the hole from 1560'-515'
MD. PUW 96K
1,560.0 515.0
3/22/2024
13:30
3/22/2024
13:45
0.25 INTRM1, TRIPCAS OWFF P Monitored the well, static. 515.0 515.0
3/22/2024
13:45
3/22/2024
19:30
5.75 INTRM1, TRIPCAS BHAH P Laid down BHA as per SLB DD to
surface. Cleared & cleaned rig floor.
515.0 0.0
3/22/2024
19:30
3/22/2024
22:15
2.75 INTRM1, CASING WWWH P Changed out elevators. Laid down a
single from a stand of 5-7/8" drill pipe.
Made up XO & StreamFlo wear ring
tool. Attempted to pull wear ring,
unsuccessful due to clay. Washed
wellhead two times. Removed wear ring
per StreamFlo Rep. Washed profile
again. Made up single of drill pipe and
rack back. SIMOPS mobilize casing
running equipment to the rig floor.
0.0 0.0
3/22/2024
22:15
3/22/2024
23:30
1.25 INTRM1, CASING RURD P Drained the stack, blew down the top
drive & changed out elevators. Picked
up landing joint with hanger & performed
dummy run with hanger. Laid down
hanger with landing joint & pup joint.
Hanger landed out 52.36' MD.
0.0 0.0
3/22/2024
23:30
3/23/2024
00:00
0.50 INTRM1, CASING RURD P Rigged up casing running equipment. 0.0 0.0
3/23/2024
00:00
3/23/2024
01:30
1.50 INTRM1, CASING RURD P Finished rigging up to run casing.
Conduct PJSM on running casing.
0.0 0.0
3/23/2024
01:30
3/23/2024
02:00
0.50 INTRM1, CASING PUTB P Picked up 7-5/8", 29.7#, L80, H523 &
TXP shoe track as per tally to 163' MD.
Checked floats, good. BakerLok
connections. Torque H523 to 17,300
ft/lbs & BTC to 8000 ft/lbs (made up to
triangles).
0.0 163.0
3/23/2024
02:00
3/23/2024
04:00
2.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, TXP casing as
per tally from 163'-804' MD. Centralized
with 9-3/8" Hyroforms each joint. Torque
TXP connections to 19.5K with BOL
2000 AG compound. PUW 86K, SOW
84K.
163.0 804.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 19/36
TITAN 1
Report Printed: 4/29/2024
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
04:00
3/23/2024
04:30
0.50 INTRM1, CASING PUTB T Laid down joints 21 & 20 due to
damaged threads at connection.
Replaced with spare joints 39.72' &
41.54'.
804.0 804.0
3/23/2024
04:30
3/23/2024
07:30
3.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, TXP casing as
per tally from 804'-2630' MD.
Centralized with 9-3/8" Hyroforms each
to 1491', total of 32. Torque TXP
connections to 19.5K with BOL 2000 AG
compound. PUW 105K, SOW 103K.
804.0 2,630.0
3/23/2024
07:30
3/23/2024
08:15
0.75 INTRM1, CASING CIRC P Circulated bottoms up at the shoe
staging up pump rate to 8 bpm, 240 psi,
FO 17%. Obtained parameters PUW
132K, SOW 132K, RW 130K, 30 rpm,
Tq 2K, 30 fpm.
2,630.0 2,630.0
3/23/2024
08:15
3/23/2024
12:00
3.75 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, TXP casing as
per tally from 2630'-4873' MD. Torque
TXP connections to 19.5K with BOL
2000 AG compound. PUW 146K, SOW
142K.
2,630.0 4,873.0
3/23/2024
12:00
3/23/2024
16:00
4.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, TXP casing as
per tally from 4873'-6449' MD. Torque
TXP connections to 19.5K with BOL
2000 AG compound. PUW 210K, SOW
160K.
4,873.0 6,449.0
3/23/2024
16:00
3/23/2024
16:15
0.25 INTRM1, CASING PUTB P Installed XO joint at 6449' MD. Made up
TXP box to BTC pin with BakerLok & 8K
Tq. Made up H653 connection to 15.1K
Tq.
6,449.0 6,449.0
3/23/2024
16:15
3/23/2024
18:00
1.75 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, H563 casing as
per tally from 6449'-6898' MD. Picked
up 9.85' pup & HES ES cementing
stage tool at 6687' MD. Stage tool
connections were BakerLoked. Installed
9-3/4" Hydroform centralizers on each
joint after stage tool. Torque H563
connections to 15.1K with BOL 2000 AG
compound. PUW 210K, SOW 163K.
6,449.0 6,898.0
3/23/2024
18:00
3/24/2024
00:00
6.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, H563 casing as
per tally from 6898'-10,170' MD.
Installed 9-3/4" Hydroform centralizers
on each joint to 7300' MD. Total of 15
centralizers installed. Torque H563
connections to 15.1K with BOL 2000 AG
compound. PUW 280K, SOW 180K.
6,898.0 10,170.0
3/24/2024
00:00
3/24/2024
02:45
2.75 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, H563 casing as
per tally from 10,170'-12,357' MD.
Installed 9-3/4" Hydroform centralizers
on each joint from 10,463'-12,357' MD.
Torque H563 connections to 15.1K with
BOL 2000 AG compound. PUW 308K,
SOW 193K.
10,170.0 12,357.0
3/24/2024
02:45
3/24/2024
05:45
3.00 INTRM1, CASING CIRC P Circulated bottoms up staging up pump
rate at 12,357' MD reciprocating 5 bpm;
480 psi. Highest return mud weight seen
11.3 ppg.
12,357.0 12,357.0
3/24/2024
05:45
3/24/2024
06:45
1.00 INTRM1, CASING PUTB P Run 7-5/8", 29.7#, L80, H563 casing as
per tally from 12,357'-13,062 MD.
Installed 9-3/4" Hydroform centralizers
on each joint from 12,357'-12,700 MD.
Installed 9-7/8" Centek centralizers to
13,022' MD. Torque H563 connections
to 15.1K with BOL 2000 AG compound.
PUW NA, SOW 145K. Total of 57 9-3/4"
Hydroforms & 8 Centek centralizers
installed.
12,357.0 13,062.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 20/36
TITAN 1
Report Printed: 4/29/2024
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
06:45
3/24/2024
07:15
0.50 INTRM1, CASING HOSO P Made up hanger & landing joint with pup
per StreamFlo Rep. Had to rotate down
with 10 rpm, Tq 12K to land on load
shoulder at 13,115' MD.
13,062.0 13,115.0
3/24/2024
07:15
3/24/2024
11:15
4.00 INTRM1, CEMENT CIRC P Circulated & conditioned mud for
cementing staging up the pump rate to 6
bpm, 583 psi, FO 12%.
13,115.0 13,115.0
3/24/2024
11:15
3/24/2024
12:00
0.75 INTRM1, CEMENT RURD P Blew down top drive. Rigged up cement
line to the cementing swivel.
13,115.0 13,115.0
3/24/2024
12:00
3/24/2024
15:15
3.25 INTRM1, CEMENT CIRC P Circulated & conditioned mud for
cementing at 6 bpm, 637 psi. SIMOPS
prep pits for cementing & rig up
cementers.
13,115.0 13,115.0
3/24/2024
15:15
3/24/2024
19:30
4.25 INTRM1, CEMENT CMNT P Lined up and cemented 1st stage per
SLB program. Pumped 5 bbls of H2O &
tested lines to 4300 psi. Pump 84 bbls
of 12.0 ppg mud push at 4.3 bpm, 400-
230 psi. Pumped 173 bbls of 15.8 ppg G
-Blend cement at 3.9-4.3 bpm, 280-57
psi. Dropped shut off dart. Pumped 20
bbls of H2O at 4.3 bpm, 64 psi.
Swapped over to rig pump and
displaced cement with 11.0 ppg FWP at
6 bpm, 277-1209 psi; 5 bpm, 1045 psi; 3
bpm, 999 psi. Dart landed on baffle
collar with 582.8 bbls pumped.
Pressured up to 1600 psi and held for 5
minutes. Bled back 3.6 bbls & floats
held. CIP 19:17 hrs.
13,115.0 13,115.0
3/24/2024
19:30
3/24/2024
20:15
0.75 INTRM1, CEMENT CIRC P Lined up and pressured up at 1 bpm to
3409 psi to open ES Cementer stage
tool. Staged up pump rate to 5 bpm, 320
psi. Circulated & conditioned mud while
prepping pits for 2nd stage cement job.
13,115.0 13,115.0
3/24/2024
20:15
3/25/2024
00:00
3.75 INTRM1, CEMENT CMNT P Lined up on cement unit & pumped 2
bbls of H2O to fluid pack line. Pumped
65 bbls of 11.0 ppg mud push at 4 bpm,
296-292 psi. Pumped 397 bbls of 11.0
ppg LiteCrete lead cement at 4 bpm,
350 psi. Pumped 48 bbls of 15.8 ppg G-
blend tail cement at 4 bpm, 340-242 psi.
Dropped ES cementer closing plug.
Pumped 20 bbls of H2O at 4 bpm, 111-
204 psi. Began displacing cement with
11.0 ppg FWP with rig pump at 6 bpm,
567 psi & 4 bpm, 573 psi. Pumped 175
bbls of displacement at 24:00 hrs.
13,115.0 13,115.0
3/25/2024
00:00
3/25/2024
00:45
0.75 INTRM1, CEMENT CMNT P Continued pumping 11.0 ppg FWP with
the rig pump with 175 bbls away.
Continued pumping at 4 bpm, 573-865
psi. Reduce pump rate with 226 bbls of
total mud pumped to 2 bpm, 755-680
psi. Noted pump pressure decreasing
with 240.9 bbls of mud pumped.
Bumped the closing plug with 277.1 bbls
of mud, pressuring up to 1895 psi.
Observed pressure bleed down to 1695
psi. Pressured up to 2034 psi & held for
5 minutes. Bled off pressure to observe
well.
13,115.0 0.0
3/25/2024
00:45
3/25/2024
01:00
0.25 INTRM1, CEMENT OWFF T Observed slight flow from the annulus
decreasing to indicate breathing.
Opened cementing equipment rigged
onto cement swivel, to observe steady
stream of mud indicating stage tool not
closed.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 21/36
TITAN 1
Report Printed: 4/29/2024
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)
3/25/2024
01:00
3/25/2024
02:45
1.75 INTRM1, CEMENT CIRC T Pressured up against the closing plug to
2175 psi, down to 2125 psi in 5 minutes.
Bled off pressure to check for flow.
Same steady stream from casing side.
Annulus was static. Consult with HES
Rep. in town. (SIMOP blow down
cement line & rig up hose from mud
manifold to cement swivel). Pressured
up to 2584 psi, down to 2531 psi in 5
minutes. Bled off and observed same
steady stream. Consult with town.
0.0 0.0
3/25/2024
02:45
3/25/2024
09:00
6.25 INTRM1, CEMENT WOC T Decision was made to pressure back up
to 800 psi & wait on cement tail to reach
50 psi compressive strength. SIMOPS
cleaned & inspected cementing valves;
flushed stack with black water from the
IA outlet; cleaned mud pits; worked on
MP2s & housekeeping.
0.0 0.0
3/25/2024
09:00
3/25/2024
09:15
0.25 INTRM1, CEMENT OWFF T Bled off pressure to trip tank, 4.6 bbls
back. Observed casing & annulus for
flow, static.
0.0 0.0
3/25/2024
09:15
3/25/2024
11:00
1.75 INTRM1, CEMENT RURD P Rigged down cementing equipment,
casing equipment & laid down landing
joint. Cleared & cleaned rig floor.
0.0 0.0
3/25/2024
11:00
3/25/2024
13:00
2.00 INTRM1, WHDBOP WWWH P Made up StreamFlo wash tool to a stand
of 5-7/8" drill pipe. Wash stack &
wellhead at max rate. Laid down wash
tool & XO. Blew down top drive. Drain
stack & top rinse.
0.0 0.0
3/25/2024
13:00
3/25/2024
13:30
0.50 INTRM1, WHDBOP WWSP P Set pack off per StreamFlo Rep. Rotate
to the right 10 times to lock pack off into
profile. Pulled 20K to verify pack off set.
Test pack off seals to 5000 psi for 10
minutes, witnessed by CPAI Rep.
0.0 0.0
3/25/2024
13:30
3/25/2024
14:30
1.00 INTRM1, WHDBOP RURD P Install wear bushing per StreamFlo Rep.
Laid down running tool & XOs.
OD 10.82"; ID 7.69"; L 16.75"
0.0 0.0
3/25/2024
14:30
3/25/2024
15:15
0.75 INTRM1, WHDBOP WWWH P Ran a stand of 5-7/8" drill pipe in the
stack. Functioned annular, upper rams,
& lower rams. Top rinsed while
functioned. Stood back stand.
Functioned & rinsed blind rams.
SIMOPS pulled mouse hole and
obtained RKB of BOP rams / annular.
0.0 0.0
3/25/2024
15:15
3/26/2024
00:00
8.75 INTRM1, WHDBOP PULD P Rigged up to lay down drill pipe. Laid
down 62 stands of 5-7/8" drill pipe.
SIMOPS changed out upper rams to 3-
1/2" X 6-5/8" VBRs; cleaned pits for
NAF.
0.0 0.0
3/26/2024
00:00
3/26/2024
08:30
8.50 INTRM1, WHDBOP PULD P Laid down 77 stands of 5-7/8" drill pipe
from the derrick. SIMOPS cleaned pits
for NAF.
0.0 0.0
3/26/2024
08:30
3/26/2024
12:00
3.50 INTRM1, WHDBOP RURD P Removed saver sub, upper & lower
IBOP from the top drive. Made up 4-1/2"
saver sub, new upper & lower IBOP.
SIMOPS cleaned pits for NAF; kicked
out all 5-7/8" drill pipe from the pipe
shed.
0.0 0.0
3/26/2024
12:00
3/26/2024
14:00
2.00 INTRM1, WHDBOP RURD P Continue removing saver sub, lower
IBOP & new upper IBOP from top drive.
New upper IBOP did not fit lock ring.
SIMOPS cleaned pits for NAF; kicked
out 5-7/8" drill pipe from the shed.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 22/36
TITAN 1
Report Printed: 4/29/2024
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
14:00
3/26/2024
17:00
3.00 INTRM1, WHDBOP SLPC P Hung the blocks & top drive. Removed
the guards from the drawworks. Slipped
& cut 66' of drill line. Inspected brakes,
greased the drawworks, serviced the top
drive & blocks. Calibrated the block
height on Amphion.
0.0 0.0
3/26/2024
17:00
3/26/2024
21:15
4.25 INTRM1, WHDBOP RURD T Installed saver sub, upper & lower
IBOPs. Installed torque rings. Changed
bell guide & grabber blocks to 4-1/2".
SIMOPS Cleaned pits for NAF; greased
choke manifold, manual & HCR valves.
0.0 0.0
3/26/2024
21:15
3/27/2024
00:00
2.75 INTRM1, WHDBOP PULD P Picked up and racked back 15 stands of
4-1/2" drill pipe from the pipe shed.
0.0 0.0
3/27/2024
00:00
3/27/2024
00:45
0.75 INTRM1, WHDBOP PULD P Picked up and racked back 4 stands of
4-1/2" drill pipe from the pipe shed.
SIMOPS cleaned pits for OBM.
0.0 0.0
3/27/2024
00:45
3/27/2024
01:45
1.00 INTRM1, WHDBOP SVRG P Serviced ST-120 & replaced a hydraulic
hose on it.
0.0 0.0
3/27/2024
01:45
3/27/2024
10:45
9.00 INTRM1, WHDBOP PULD P Picked up and racked back 76 stands of
4-1/2" drill pipe from the pipe shed.
SIMOPS finished cleaning pits; brought
on OBM to the pits.
0.0 0.0
3/27/2024
10:45
3/27/2024
11:15
0.50 INTRM1, WHDBOP RURD P Drained the stack. Made up 3-1/2" test
joint with pups to wear ring retrieval tool.
Pulled wear ring per StreamFlo Rep.
Blew down mud line.
0.0 0.0
3/27/2024
11:15
3/27/2024
13:00
1.75 INTRM1, WHDBOP RURD P Made up test plug to 3-1/2" test joint.
Set test plug per StreamFlo Rep.
Flooded the stack & all lines with H2O.
Rigged up testing equipment.
0.0 0.0
3/27/2024
13:00
3/27/2024
18:30
5.50 INTRM1, WHDBOP BOPE P Performed BOP test with 3-1/2" & 4-1/2"
test joint. Tested to 250 psi low & 4000
psi high on all components except
annular with 2500 psi high. Each test
was charted for 5 minutes. AOGCC Kam
StJohn waived witness of the test.
#1 Annular with 3-1/2" test joint 250 psi
low, 2500 psi high.
#2 Upper VBRs 3-1/2" test joint; CMV
1,14, 15, 16; upper IBOP; kill line valve
#3.
#3 Lower IBOP; HCR kill; CMV 10, 13,
needle valve above #1.
#4 Dart valve; manual kill; CMV 4, 9, 12.
#5 CMV 6, 8, 11 & 4-1/2" FOSV.
#6 CMV 5,7.
#7 CMV 2.
#8 HCR choke valve.
#9 Manual choke & kill valve.
#10 Lower VBRs 3-1/2" test joint.
#11 Blind / shear rams CMV 3, 4,6.
#12 Manual choke & super choke to
1500 psi.
#13 Upper VBRs 4-1/2" test joint.
#14 Lower VBRs 4-1/2" test joint.
Conduct accumulator draw down.
System pressure 3025 psi; manifold
pressure 1500 psi; after closure 1500
psi; 200 psi build with electric pumps in
9 seconds; full pressure attained in 86
seconds. Closing times: annular 15
seconds; UPR 14 seconds; blind/shear
14 seconds; LPR 13 seconds; choke
HCR 1 second; kill HCR 1 second. 10
bottles nitrogen averaged 3700 psi. Gas
detection system, flow out & pit level
indicators tested.
0.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 23/36
TITAN 1
Report Printed: 4/29/2024
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)
3/27/2024
18:30
3/27/2024
19:30
1.00 INTRM1, WHDBOP RURD P Rigged down testing equipment. Pulled
test plug. Installed wear ring per
StreamFlo Rep. Laid down test joint &
pups.
0.0 0.0
3/27/2024
19:30
3/27/2024
20:30
1.00 INTRM1, WHDBOP RURD P Blew down choke manifold, kill & choke
lines. Drained the stack of H20 & filled
with mud. SIMOPS installed bell guide.
0.0 0.0
3/27/2024
20:30
3/28/2024
00:00
3.50 INTRM1, DRILLOUT BHAH P Picked up 6-3/4" production section
BHA per SLB DD to 195' MD.
0.0 195.0
3/28/2024
00:00
3/28/2024
02:00
2.00 INTRM1, DRILLOUT BHAH P Picked up 6-3/4" production section
BHA per SLB DD to 236' MD.
195.0 236.0
3/28/2024
02:00
3/28/2024
04:00
2.00 INTRM1, DRILLOUT TRIP P RIH w/4.5" DP stands F/236' T/2,122'.
Monitor displacement on TT.
S/O = 96k
P/U = 100K
236.0 2,122.0
3/28/2024
04:00
3/28/2024
08:00
4.00 INTRM1, DRILLOUT DHEQ T Shallow hole test @ 2,118'. No signal
from DigiScope tool. Varied parameters
without any success. Blow down TDS,
flow check and prepare to trip out.
2,122.0 2,122.0
3/28/2024
08:00
3/28/2024
09:00
1.00 INTRM1, DRILLOUT TRIP T POOH F/ 2,118' T/236'. 2,122.0 236.0
3/28/2024
09:00
3/28/2024
09:15
0.25 INTRM1, DRILLOUT OWFF T Flow check at BHA, prepare to swap
tools.
236.0 236.0
3/28/2024
09:15
3/28/2024
12:00
2.75 INTRM1, DRILLOUT BHAH T POOH F/236' T/79' inspecting
mudguards and well commander - ok.
Plug in and dump StethoScope data -
good data. Function piston anchors on
StethoScope. Noticed top piston anchor
was damaged (appears to of backed out
a few threads). Replaced same and
verify both pistons working correctly.
236.0 79.0
3/28/2024
12:00
3/28/2024
13:45
1.75 INTRM1, DRILLOUT BHAH T L/D and C/O DigiScope tool with back
up. M/U BHA and RIH F/47' T/146'.
Note: Reprogram SonicScope to start
logging in memory mode.
79.0 146.0
3/28/2024
13:45
3/28/2024
14:15
0.50 INTRM1, DRILLOUT BHAH T PJSM. Load sources in ADN @ 146'. 146.0 146.0
3/28/2024
14:15
3/28/2024
15:15
1.00 INTRM1, DRILLOUT BHAH T Con't M/U BHA and RIH F/146' T/237'. 146.0 237.0
3/28/2024
15:15
3/28/2024
15:45
0.50 INTRM1, DRILLOUT TRIP T RIH w/15 stands 4.5" DP F/237'
T/1,557'.
237.0 1,557.0
3/28/2024
15:45
3/28/2024
16:45
1.00 INTRM1, DRILLOUT DHEQ T Shallow hole test MWD tools at 1,557' -
good test. Blow down TDS.
GPM = 230
PSI = 1378
1,557.0 1,557.0
3/28/2024
16:45
3/28/2024
17:00
0.25 INTRM1, DRILLOUT TRIP T RIH w/ 5 stands 4.5" DP F/1,557'
T/2,121'. Monitor displacement on TT.
S/O = 103K
1,557.0 2,121.0
3/28/2024
17:00
3/28/2024
17:45
0.75 INTRM1, DRILLOUT PULD P RIH w/ 4.5" DP singles from pipe shed
F/2,121' T/2,653'. Monitor displacement
on TT.
S/O = 104K
2,121.0 2,653.0
3/28/2024
17:45
3/28/2024
20:00
2.25 INTRM1, DRILLOUT DLOG P RIH w/ 4.5" DP singles from pipe shed
logging at 30ft/min with SonicScope
F/2,653' T/3,630'. Monitor displacement
on TT. Fill pipe every 20 stands.
S/O = 104K
2,653.0 3,630.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 24/36
TITAN 1
Report Printed: 4/29/2024
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
20:00
3/29/2024
00:00
4.00 INTRM1, DRILLOUT DLOG P RIH w/ 4.5" DP singles from pipe shed
logging at 30ft/min with SonicScope
F/3,630' T/6,363'. Monitor displacement
on TT. Fill pipe every 20 stands.
S/O = 102K
3,630.0 6,363.0
3/29/2024
00:00
3/29/2024
01:15
1.25 INTRM1, DRILLOUT DLOG P Wash & ream w/ 4.5" DP singles from
pipe shed logging at 30ft/min with
SonicScope F/6,363' T/6,415'. At 6,415'
able to slack off without rotation.
GPM = 230
PSI = 1725
RPM = 50
TQ = 8K
6,363.0 6,415.0
3/29/2024
01:15
3/29/2024
01:30
0.25 INTRM1, DRILLOUT DRLG P Tag ES collar @ 6,415' (on depth). Drill
out ES collar as per DD to 6,418'. Ream
through 3 times with no issues.
GPM = 230
PSI = 1786
RPM = 50
TQ = 8K
6,415.0 6,418.0
3/29/2024
01:30
3/29/2024
03:45
2.25 INTRM1, DRILLOUT DLOG P Wash and ream F/6,418' T/6,650' with
minimal resistance due to unable to
slack off without rotation. At 6,650' had
the ability to slack off without rotation.
GPM = 230
PSI = 1693
RPM = 50
TQ = 8K
6,418.0 6,650.0
3/29/2024
03:45
3/29/2024
04:15
0.50 INTRM1, DRILLOUT CIRC P Circulate bottoms up while preparing to
test casing.
GPM = 225
PSI = 1625
RPM = 50
TQ = 8
ECD = 11.57
6,650.0 6,650.0
3/29/2024
04:15
3/29/2024
05:00
0.75 INTRM1, DRILLOUT RURD P Blow down TDS and rig up to test
casing.
6,650.0 6,650.0
3/29/2024
05:00
3/29/2024
07:00
2.00 INTRM1, DRILLOUT PRTS P Pressure test casing to 4,000 psi w/10.6
ppg WBM for 30 minutes against upper
VBR rams.
Held for 30 minutes and charted with
Totco chart. Good test.
Bled off pressure, opened upper VBR
rams and rigged down test equipment.
Blew down choke and kill lines.
Pumped 8.2 bbls
Bled back 8.5 bbls.
6,650.0 6,650.0
3/29/2024
07:00
3/29/2024
11:00
4.00 INTRM1, DRILLOUT PULD P RIH w/ 4.5" DP singles from pipe shed
F/6,650' T/9,484'. Monitor displacement
on TT. Fill pipe every 20 stands. Ream
through cement stringer at 8,174' with
minimal resistance.
P/U = 196K
S/O = 116K
ROT = 141K
6,650.0 9,484.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 25/36
TITAN 1
Report Printed: 4/29/2024
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
11:00
3/29/2024
17:00
6.00 INTRM1, DRILLOUT DLOG P RIH w/ 4.5" DP singles from pipe shed
logging at 30ft/min with SonicScope
F/9,484, T/12,787'. Monitor
displacement on TT. Fill pipe every 20
stands.
P/U = 275K
S/O = 120K
ROT = 170K
9,484.0 12,787.0
3/29/2024
17:00
3/29/2024
17:15
0.25 INTRM1, DRILLOUT DLOG P RIH w/ 4.5" DP stands from derrick
logging at 30ft/min with SonicScope
F/12,787' T/12,877'.
P/U = 275K
S/O = 120K
ROT = 170K
12,787.0 12,877.0
3/29/2024
17:15
3/29/2024
17:45
0.50 INTRM1, DRILLOUT DLOG P Precautionary wash and ream F/12,877'
T/12,948' with minimal resistance.
ROT = 176K
GPM = 230
PSI = 2040
RPM = 50
TQ = 8K
12,877.0 12,948.0
3/29/2024
17:45
3/29/2024
18:15
0.50 INTRM1, DRILLOUT SVRG P Perform NOV torque unwind test at 20,
40, and 80 rpm.
12,948.0 12,948.0
3/29/2024
18:15
3/29/2024
19:00
0.75 INTRM1, DRILLOUT DLOG P Precautionary wash and ream F/12,948'
T/12,986' with minimal resistance. Tag
at 12,986' with 10K.
P/U = 285K
S/O = 129K
ROT = 176K
GPM = 230
PSI = 2045
RPM = 50
TQ = 8K
12,948.0 12,986.0
3/29/2024
19:00
3/29/2024
19:15
0.25 INTRM1, DRILLOUT PULD P L/D working single DP. Blew down TDS. 12,986.0 12,986.0
3/29/2024
19:15
3/29/2024
20:00
0.75 INTRM1, DRILLOUT MPDA P PJSM. Install 4.5" MPD bearing as per
MPD advisor.
12,986.0 12,986.0
3/29/2024
20:00
3/29/2024
22:30
2.50 INTRM1, DRILLOUT DISP P PJSM. Displace 10.6 ppg FWP mud to
11.3 ppg NAF mud as per Mud Engineer
plan. Pumped 100 bbls 5% Deep Clean
pill followed with 532 bbls 11.3 ppg NAF.
10 bbls of interface.
P/U = 285K
S/O = 129K
ROT = 176K
GPM = 230
PSI = 2045
RPM = 50
TQ = 8K
12,986.0 12,986.0
3/29/2024
22:30
3/29/2024
22:45
0.25 INTRM1, DRILLOUT MPDA P Obtain SPR's @ 12,967' w/ 11.3 ppg
NAF.
MP#1: 20 spm / 941 psi
30 spm / 1,445 psi
MP#2: 20 spm / 956 psi
30 spm / 1,460 psi
12,986.0 12,986.0
3/29/2024
22:45
3/30/2024
00:00
1.25 INTRM1, DRILLOUT SEQP P Well control choke drill with Driller, AD
and Motorman as per CPAI.
12,986.0 12,986.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 26/36
TITAN 1
Report Printed: 4/29/2024
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)
3/30/2024
00:00
3/30/2024
08:15
8.25 INTRM1, DRILLOUT DRLG P Drill out 7-5/8" shoe track F/12,986'
T/13,115' as per SLB DD. Ream through
3 times without any issues.
P/U = 288K
S/O= 129K
ROT = 163K
GPM = 230
PSI = 2864
RPm = 50-100
TQ = 10-11K
12,986.0 13,115.0
3/30/2024
08:15
3/30/2024
08:45
0.50 INTRM1, DRILLOUT REAM P Clean out rat hole F/13,115 T/13,125'.
P/U = 288K
S/O = 129K
ROT = 163K
GPM = 230
PSI = 2935
RPM = 50-100
TQ = 10-11K
WOB = 5K
13,115.0 13,125.0
3/30/2024
08:45
3/30/2024
09:00
0.25 INTRM1, DRILLOUT DDRL P Drill 6-3/4" production hole F/13,125'
T/13,145'.
P/U = 288K
S/O = 129K
ROT = 163K
GPM = 230
PSI = 2926
RPM = 100
TQ = 10K
WOB = 4K
ECD = 12.89
13,125.0 13,145.0
3/30/2024
09:00
3/30/2024
10:15
1.25 INTRM1, DRILLOUT CIRC P Circulate bottoms up while
reciprocating prior to FIT test F/13,145'
T/13,108'.
P/U = 288K
S/O = 129K
ROT = 163K
GPM = 230
PSI = 3038
RPM = 100
TQ = 10K
ECD = 13.2
13,145.0 13,145.0
3/30/2024
10:15
3/30/2024
10:30
0.25 INTRM1, DRILLOUT LOT P POOH F/13,145' T/13,066' racking back
1 stand.
13,145.0 13,066.0
3/30/2024
10:30
3/30/2024
11:00
0.50 INTRM1, DRILLOUT LOT P R/U and perform FIT pumping 11.3 ppg
OBM to 1,069 psi, observed break over
at 768 psi. FIT= 13.3 EMW.
Pumped 3.5 bbls, bled back 3.5 bbls.
13,066.0 13,066.0
3/30/2024
11:00
3/30/2024
11:15
0.25 INTRM1, DRILLOUT LOT P Precautionary wash and ream F/13,066'
T/13,145.
GPM = 250
PSI = 3045
RPM = 110
TQ = 11K
ECD = 13.2
13,066.0 13,145.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 27/36
TITAN 1
Report Printed: 4/29/2024
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)
3/30/2024
11:15
3/30/2024
17:45
6.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/13,145'
T/13,444'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 232K
S/O = 129K
ROT = 172K
GPM = 230
PSI = 2926
RPM = 100
TQ = 10K OFF / 14K ON
WOB = 9K
ECD = 13.00
ADT = 4.49
BIT HRS = 4.49
13,145.0 13,444.0
3/30/2024
17:45
3/30/2024
19:00
1.25 PROD1, DRILL DLOG P Downlink and perform correlation log for
StethoScope pretest station depth.
P/U = 232 K
S/O = 129K
13,444.0 13,444.0
3/30/2024
19:00
3/30/2024
19:30
0.50 PROD1, DRILL DLOG P Perform 20 min stick test. No issues
coming off the wall.
GPM = 260
PSI = 3071
13,444.0 13,444.0
3/30/2024
19:30
3/30/2024
20:30
1.00 PROD1, DRILL DLOG P Perform StethoScope formation
pressure test at 13,296' and 13,284'. On
station for 11 min and 14 min. No issues
coming off stations.
1st:: 10.21 EMW Pore Pressure
2nd: 10.2 EMW Pore Pressure
13,444.0 13,444.0
3/30/2024
20:30
3/31/2024
00:00
3.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/13,444'
T/13,634'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 232K
S/O = 124K
ROT = 172K
GPM = 280
PSI = 3651
RPM = 100
TQ = 10K OFF / 13K ON
WOB = 5-10K
ECD = 13.09
ADT = 2.63
BIT HRS = 7.12
13,444.0 13,634.0
3/31/2024
00:00
3/31/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/13,634'
T/13,916'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 223K
S/O = 133K
ROT = 172K
GPM = 270
PSI = 3374
RPM = 100
TQ = 10K OFF / 11K ON
WOB = 5-10K
ECD = 12.97
MAX GAS = 133
ADT = 4.56
BIT HRS = 11.68
13,634.0 13,916.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 28/36
TITAN 1
Report Printed: 4/29/2024
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
06:00
3/31/2024
12:00
6.00 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/13,916'
T/14,204'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 236K
S/O = 130K
ROT = 173K
GPM = 270
PSI = 3386
RPM = 120
TQ = 8K OFF / 15K ON
WOB = 5-10K
ECD = 12.94
MAX GAS = 173
ADT = 4.68
BIT HRS = 16.36
13,916.0 14,204.0
3/31/2024
12:00
3/31/2024
15:30
3.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/14,204'
T/14,387'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 220K
S/O = 136K
ROT = 179K
GPM = 270
PSI = 3345
RPM = 120
TQ = 8K OFF / 14K ON
WOB = 5-10K
ECD = 12.94
MAX GAS = 250
ADT = 2.29
BIT HRS = 18.65
14,204.0 14,387.0
3/31/2024
15:30
3/31/2024
16:00
0.50 PROD1, DRILL DLOG P Pull up T/14,333' and circulate prior to
performing stick test for StethoScope
pressure.
GPM = 260
PSI = 3372
14,387.0 14,333.0
3/31/2024
16:00
3/31/2024
16:30
0.50 PROD1, DRILL DLOG P Perform 15 min stick test. No issues
coming off the wall.
GPM = 260
PSI = 3272
14,333.0 14,333.0
3/31/2024
16:30
3/31/2024
17:30
1.00 PROD1, DRILL DLOG P Perform StethoScope formation
pressure test at 14,224' (probe depth).
On station for 12 min. No issues coming
off station.
10.44 ppg EMW Pore Pressure.
GPM = 260
PSI = 3272
14,333.0 14,387.0
3/31/2024
17:30
4/1/2024
00:00
6.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/14,387'
T/14,850'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 245K
S/O = 126K
ROT = 180K
GPM = 270
PSI = 3370
RPM = 120
TQ = 8K OFF / 14K ON
WOB = 5-10K
ECD = 12.87
MAX GAS = 529
ADT = 4.67
BIT HRS = 23.32
14,387.0 14,850.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 29/36
TITAN 1
Report Printed: 4/29/2024
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)
4/1/2024
00:00
4/1/2024
06:00
6.00 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/14,850'
T/15,240'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 247K
S/O = 120K
ROT = 180K
GPM = 270
PSI = 3325
RPM = 120
TQ = 8K OFF / 16K ON
WOB = 5-10K
ECD = 12.88
MAX GAS = 103
ADT = 4.59
BIT HRS = 29.74
14,850.0 15,240.0
4/1/2024
06:00
4/1/2024
07:15
1.25 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/15,240'
T/15,331'. Maintain 12.2 EMW at shoe
on connections with MPD.
P/U = 240K
S/O = 136K
ROT = 178K
GPM = 270
PSI = 3325
RPM = 120
TQ = 11K OFF / 14K ON
WOB = 8K
ECD = 12.88
MAX GAS = 91
ADT = 1.49
BIT HRS = 31.23
15,240.0 15,331.0
4/1/2024
07:15
4/1/2024
08:15
1.00 PROD1, DRILL DLOG P Pull up T/15,225' and circulate and rack
back 1 stand prior to performing stick
test for StethoScope pressure.
P/U = 225K
S/O = 134K
ROT = 180K
GPM = 270
PSI = 3372
15,331.0 15,225.0
4/1/2024
08:15
4/1/2024
08:45
0.50 PROD1, DRILL DLOG P P/U working single. Perform 15 min stick
test @ 15,227'. No issues coming off the
wall.
P/U = 225K
S/O = 134K
ROT = 180K
GPM = 270
PSI = 3372
15,225.0 15,227.0
4/1/2024
08:45
4/1/2024
10:00
1.25 PROD1, DRILL DLOG P Perform StethoScope formation
pressure tests at 15,149' &
15,154' (probe depth).
On station for 13 & 12 min. No issues
coming off station.
Test #4: 11.12 ppg EMW Pore Pressure
@ 15,149'.
Test #5: 11.11 ppg EMW Pore Pressure
@ 15,154'.
GPM = 270
PSI = 3372
15,227.0 15,149.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 30/36
TITAN 1
Report Printed: 4/29/2024
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)
4/1/2024
10:00
4/1/2024
10:30
0.50 PROD1, DRILL DLOG P L/D working single to pipe shed, RIH
and precautionary ream down F/15,235'
T/15,331'.
GPM = 270
PSI = 3548
RPM = 100
TQ = 11K
ECD = 12.77
15,149.0 15,331.0
4/1/2024
10:30
4/1/2024
13:00
2.50 PROD1, DRILL WAIT P Circulate with rotation and reciprocation
while waiting on decision from town on
plan forward.
GPM = 270
PSI = 3300
RPM = 100
TQ = 11K
ECD = 12.76
15,331.0 15,331.0
4/1/2024
13:00
4/1/2024
15:30
2.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole F/15,331'
T/15,520'. Maintain 12.2 EMW at shoe
on connections with MPD.
Note: TD called at 15,520'.
P/U = 240K
S/O = 136K
ROT = 178K
GPM = 270
PSI = 3402
RPM = 120
TQ = 8K OFF / 15K ON
WOB = 10K
ECD = 13.07
MAX GAS =256
ADT = 2.11
BIT HRS = 33.44
15,331.0 15,520.0
4/1/2024
15:30
4/1/2024
17:00
1.50 PROD1, TRIPCAS CIRC P Circulate with rotation and reciprocation
bottoms up weighiting up from 11.3 ppg
to 11.5 ppg..
GPM = 270
PSI = 3300
RPM = 100
TQ = 11K
ECD = 12.76
15,520.0 15,520.0
4/1/2024
17:00
4/1/2024
17:15
0.25 PROD1, TRIPCAS CIRC P Obtain SPR's with 11.5 ppg and obtain
final torque and drag readings.
#1 MP 20 spm = 868 psi
30 spm = 1264 psi
#2 MP 20 spm = 865 psi
30 spm = 1230 psi
15,520.0 15,520.0
4/1/2024
17:15
4/1/2024
17:45
0.50 PROD1, TRIPCAS OWFF P Flow check with MPD holding pressure
at 12.2 ppg EMW. Pressure stabilized at
11.8 ppg EMW (120 psi).
15,520.0 15,520.0
4/1/2024
17:45
4/1/2024
18:00
0.25 PROD1, TRIPCAS OWFF P Blow down TDS. 15,520.0 15,520.0
4/1/2024
18:00
4/1/2024
19:30
1.50 PROD1, TRIPCAS STRP P SOOH w/MPD holding 12.2 ppg @ shoe
F/15,488' T/14,852'.
P/U = 240K
15,520.0 14,852.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 31/36
TITAN 1
Report Printed: 4/29/2024
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)
4/1/2024
19:30
4/1/2024
20:00
0.50 PROD1, TRIPCAS DLOG P Perform StethoScope formation
pressure test at 14,775' (probe depth).
On station for 13 min. No issues coming
off station.
Test #6: 10.34 ppg EMW Pore Pressure
@ 14,775'.
P/U = 220K
S/O = 122K
GPM = 270
PSI = 3372
14,852.0 14,775.0
4/1/2024
20:00
4/1/2024
21:15
1.25 PROD1, TRIPCAS STRP P SOOH w/MPD holding 12.2 ppg @ shoe
F/14,852' T/14,402'.
P/U = 218K
14,775.0 14,402.0
4/1/2024
21:15
4/1/2024
21:45
0.50 PROD1, TRIPCAS DLOG P Perform StethoScope formation
pressure test at 14,325' (probe depth).
On station for 12 min. No issues coming
off station.
Test #7: 10.53 ppg EMW Pore Pressure
@ 14,325'.
P/U = 224K
S/O = 122K
GPM = 270
PSI = 3338
14,402.0 14,402.0
4/1/2024
21:45
4/1/2024
23:00
1.25 PROD1, TRIPCAS STRP P SOOH w/MPD holding 12.2 ppg @ shoe
F/14,402' T/13,777'.
P/U = 232K
14,402.0 13,777.0
4/1/2024
23:00
4/1/2024
23:30
0.50 PROD1, TRIPCAS DLOG P Perform StethoScope formation
pressure test at 13,700' (probe depth).
On station for 12 min. No issues coming
off station.
Test #8: 10.21 ppg EMW Pore Pressure
@ 13,700'.
P/U = 222K
S/O = 122K
GPM = 270
PSI = 3311
13,777.0 13,777.0
4/1/2024
23:30
4/2/2024
00:00
0.50 PROD1, TRIPCAS STRP P SOOH w/MPD holding 12.2 ppg @ shoe
F/13,777' T/13,637'.
P/U = 232K
13,777.0 13,637.0
4/2/2024
00:00
4/2/2024
00:30
0.50 PROD1, TRIPCAS DLOG P Perform StethoScope formation
pressure test at 13,700' &
13,560' (probe depth).
On station for 12 min each. No issues
coming off station.
Test #8: 10.21 ppg EMW Pore Pressure
@ 13,700'.
Test #9: 10.22 ppg EMW Pore Pressure
@ 13.560'.
P/U = 222K
S/O = 122K
GPM = 270
PSI = 3311
13,637.0 13,560.0
4/2/2024
00:30
4/2/2024
02:00
1.50 PROD1, TRIPCAS SMPD P SOOH w/MPD holding 12.2 ppg @ shoe
F/13,560' T/13,071'.
P/U = 225K
13,560.0 13,071.0
4/2/2024
02:00
4/2/2024
02:30
0.50 PROD1, TRIPCAS OWFF P Flow check with MPD holding pressure
at 11.8 ppg EMW - static f/15 min.
Decreased MPD pressure fully open at
11.5 ppg EMW - static f/15 min.
13,071.0 13,071.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 32/36
TITAN 1
Report Printed: 4/29/2024
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)
4/2/2024
02:30
4/2/2024
07:15
4.75 PROD1, TRIPCAS SMPD P SOOH racking 4.5" DP stands in derrick
w/MPD holding 12.2 ppg @ shoe
F/13,071' T/8,251'. Monitor hole fill on
pit #5.
P/U = 189K
13,071.0 8,251.0
4/2/2024
07:15
4/2/2024
12:00
4.75 PROD1, TRIPCAS SMPD P SOOH L/D 4.5" DP to pipe shed w/MPD
holding 12.2 ppg @ shoe F/8,251'
T/5,328'. Monitor hole fill on pit #5.
P/U = 139K
8,251.0 5,328.0
4/2/2024
12:00
4/2/2024
19:00
7.00 PROD1, TRIPCAS SMPD P SOOH L/D 4.5" DP to pipe shed w/MPD
holding 12.2 ppg @ shoe F/5,328'
T/325'. Monitor hole fill on pit #5.
P/U = 80K
5,328.0 325.0
4/2/2024
19:00
4/2/2024
19:15
0.25 PROD1, TRIPCAS OWFF P OWFF - well static. 325.0 325.0
4/2/2024
19:15
4/2/2024
20:00
0.75 PROD1, TRIPCAS MPDA P Drain riser. Pull RCD bearing on stand
DP as per MPD rep.
325.0 325.0
4/2/2024
20:00
4/3/2024
00:00
4.00 PROD1, TRIPCAS BHAH P PJSM. L/D 6-3/4" production BHA.
Remove sources as per SLB and
mobilize off floor.
325.0 0.0
4/3/2024
00:00
4/3/2024
01:30
1.50 PROD1, TRIPCAS CLEN P Clean and clear SLB tools from rig floor. 0.0 0.0
4/3/2024
01:30
4/3/2024
11:30
10.00 COMPZN, PLUG TRIP P M/U Baker Cement Retainer and
running tool. TIH on 4.5" DP T/ 13,030'.
Monitor displacement on TT.
0.0 13,030.0
4/3/2024
11:30
4/3/2024
12:45
1.25 COMPZN, PLUG MPDA P Rack back stand. P/U stand with 4.5"
MPD bearing and install as per MPD
rep.
13,030.0 13,030.0
4/3/2024
12:45
4/3/2024
13:00
0.25 COMPZN, PLUG CIRC P Obtain SPR's @ 13,024'.
MP#1: 20 spm = 509 psi
30 spm = 748 psi
MP#2: 20 spm = 510 psi
30 spm = 738 psi
13,030.0 13,030.0
4/3/2024
13:00
4/3/2024
15:00
2.00 COMPZN, PLUG WAIT P Circulating while waiting on orders from
town.
GPM = 126
PSI = 474
13,030.0 13,030.0
4/3/2024
15:00
4/3/2024
15:45
0.75 COMPZN, PLUG SQEZ P P/U joint of 4.5" DP for space out. Set
Baker Cement Retainer at 13,051' as
per Baker rep.
13,030.0 13,051.0
4/3/2024
15:45
4/3/2024
16:15
0.50 COMPZN, PLUG PRTS P Close upper pipe rams. Test cement
retainer pumping down annulus to 2,500
psi for 10 minutes - good test. Bled off
pressure and open upper pipe rams.
Charted test on Totco. Pumped 4.4 bbls
and returned 4.3 bbls.
13,051.0 13,051.0
4/3/2024
16:15
4/3/2024
16:45
0.50 COMPZN, PLUG PRTS P Blow down TDS. M/U pump in assembly
and head pin on string. S/O 20k down
on cement retainer.
13,051.0 13,051.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 33/36
TITAN 1
Report Printed: 4/29/2024
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)
4/3/2024
16:45
4/3/2024
18:30
1.75 COMPZN, PLUG SQEZ P R/U to perform injectivity test.
Established injection rate with 11.5 ppg
NAF at 0.5 bpm with 2.1 bbls pumped
when pressure broke over. 899 max
pressure.
Performed injectivity test staging up to 5
bpm. Pumped total 24 bbls.
1 bpm = 956 psi
2 bpm = 1074 psi
3 bpm = 1210 psi
4 bpm = 1376 psi
5 bpm = 1598 psi
Stop pumping and monitored pressure
for 10 minutes.
Initial = 1595 psi, Final = 809 psi.
Sting out of retainer.
13,051.0 13,051.0
4/3/2024
18:30
4/3/2024
19:00
0.50 COMPZN, PLUG SQEZ P PJSM for squeezing cement. Pressure
test SLB cement lines to 3,500 psi -
good test.
135,051.0 13,051.0
4/3/2024
19:00
4/3/2024
21:15
2.25 COMPZN, PLUG SQEZ P Perform squeeze cement job per SLB
and Baker holding 680 psi with MPD.
SLB:
Pumped 42 bbls 12.0 pps spacer @ 4
bpm
Pumped 52.7 bbls 15.8 ppg cement @ 4
bpm
Pumped 5 bbls 12.0 ppg spacer @ 4
bpm
Pumped 10 bbls fresh water @ 4 bpm
Rig:
Rig pumped 88.5 bbls (746 stks) 11.5
ppg NAF @ 4 bpm
Stung into cement retainer and S/O 30k.
Squeezed with rig pump 40 bbls (337
stks) 11.5 ppg NAF @ 4 bpm, 1044-
1223 psi
Stung out of cement retainer (384 psi
below cement retainer when stung into).
Rig pumped 15 bbls (127 stks) 11.5
NAF @ 2.8 bpm, 1300 psi.
Stopped pump and bled off pressure.
13,051.0 13,051.0
4/3/2024
21:15
4/3/2024
21:30
0.25 COMPZN, PLUG SQEZ P R/D cement lines and equipment. Put
working single in mouse hole.
13,051.0 13,051.0
4/3/2024
21:30
4/3/2024
23:30
2.00 COMPZN, PLUG TRIP P POOH 12 stands F/13,051' T/11,895 @
15 ft/min to above TOC.
Note: CIP @ 23:30 hrs. Est TOC @
12,619'.
P/U = 210K
13,051.0 11,895.0
4/3/2024
23:30
4/4/2024
00:00
0.50 COMPZN, PLUG CIRC P Pump wiper ball down and circulate
staging up rate.
11,895.0 11,895.0
4/4/2024
00:00
4/4/2024
02:45
2.75 COMPZN, PLUG CIRC P Circulate hole clean reciprocate
F/11,895' T/11,830'. Flush chokes, blow
down TDS.
P/U = 191K
S/O = 143K
GPM = 300
PSI = 1525
11,895.0 11,830.0
4/4/2024
02:45
4/4/2024
03:15
0.50 COMPZN, PLUG OWFF P OWFF - static. 11,830.0 11,830.0
4/4/2024
03:15
4/4/2024
04:00
0.75 COMPZN, PLUG MPDA P PJSM. Remove RCD bearing as per
MPD rep.
11,830.0 11,830.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 34/36
TITAN 1
Report Printed: 4/29/2024
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)
4/4/2024
04:00
4/4/2024
14:30
10.50 COMPZN, PLUG WOC P Wait on cement to achieve 1,500 psi
compressive strength while pumping 84
gpm at 350 psi and slowly reciprocating
string.
SIMOPS: R/D SLB MWD equipment as
per SLB rep. L/D 6 stands excess 4.5"
DP from derrick.
11,830.0 11,830.0
4/4/2024
14:30
4/4/2024
15:30
1.00 COMPZN, PLUG PRTS P Close upper pipe rams. Test casing and
cement plug to 2,500 psi for 30 minutes
with 11.5 ppg NAF. Pumped at 5 spm,
50 stks total. Bled of pressure and
opened rams.
Charted on Totco and witnessed by
AOGCC, Austin McLeod.
11,830.0 11,830.0
4/4/2024
15:30
4/4/2024
16:30
1.00 COMPZN, PLUG TRIP P RIH on elevators F/11,830' T/12,173'.
Tag cement at 12,173' w/5K.
P/U to 12,164'. Wash down at 50 gpm,
368 psi and tag at 12,175' w/ 10K.
Observed 100 psi increase.
Witnessed by AOGCC, Austin McLeod.
11,830.0 12,175.0
4/4/2024
16:30
4/4/2024
17:15
0.75 COMPZN, PLUG CIRC P Circulate bottoms up at 293 gpm, 1650
psi while reciprocating F/12,172'
T/12,113'.
12,175.0 12,175.0
4/4/2024
17:15
4/4/2024
17:45
0.50 COMPZN, PLUG OWFF P OWFF - static. 12,175.0 12,175.0
4/4/2024
17:45
4/4/2024
18:45
1.00 COMPZN, PLUG CIRC P Pump 25 bbls dry job. Blow down TDS
and choke and kill lines. Install stripping
rubber.
12,175.0 12,175.0
4/4/2024
18:45
4/5/2024
00:00
5.25 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/12,175' T/6,500".
Monitor displacement on TT.
12,175.0 6,500.0
4/5/2024
00:00
4/5/2024
04:30
4.50 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/6,500' T/2,281".
Monitor displacement on TT.
6,500.0 2,281.0
4/5/2024
04:30
4/5/2024
05:45
1.25 COMPZN, PLUG TRIP P POOH racking back 4.5" DP F2,281'
T/surface.Monitor displacement on TT.
2,281.0 0.0
4/5/2024
05:45
4/5/2024
06:15
0.50 COMPZN, PLUG BHAH P L/D Baker cement retainer running tool
(no visual issues). P/U Baker 7-5/8"
CIBP as per Baker rep.
0.0 0.0
4/5/2024
06:15
4/5/2024
08:45
2.50 COMPZN, PLUG TRIP P RIH w/4.5" DP stands T/2,815' at 60
fpm. L/D top joint for space out.
Monitor displacement on TT.
0.0 2,815.0
4/5/2024
08:45
4/5/2024
09:00
0.25 COMPZN, PLUG CIRC P Circulate capacity of string at 3 bpm,
175 psi. Pumped 39 bbls.
2,815.0 2,815.0
4/5/2024
09:00
4/5/2024
09:15
0.25 COMPZN, PLUG PACK P Set Baker 7-5/8" CIBP at 2,800' as per
Baker rep.
Drop 1.438" setting ball and pump at 3
bpm then slowed to 1 bpm. Pumped 100
stks and ball on seat.
Increased pressure to 2,300 psi and
held. P/U on string to 119K and
observed good indication CIBP set with
weight loss and pressure bled off.
P/U = 109K
2,815.0 2,800.0
4/5/2024
09:15
4/5/2024
09:45
0.50 COMPZN, PLUG PRTS P P/U full stand above CIBP.
Close annular and pump down string to
test CIBP to 1,500 psi for 10 minutes.
Charted test on Totco - good test.
Bled off pressure and open annular.
2,800.0 2,720.0
4/5/2024
09:45
4/5/2024
10:15
0.50 COMPZN, PLUG CIRC P Pump 15 bbls 13.2 ppg slug. L/D stand
#30 and blow down TDS.
2,720.0 2,720.0
4/5/2024
10:15
4/5/2024
15:00
4.75 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/2,720' T/surface.
L/D Baker running tool - no visual issues
observed.
Monitor displacement on TT.
2,720.0 0.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 35/36
TITAN 1
Report Printed: 4/29/2024
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)
4/5/2024
15:00
4/5/2024
16:45
1.75 COMPZN, PLUG WWWH P M/U StreamFlo wear ring running tool
on double 4.5" DP. Pull wear ring as per
StreamFlo rep. M/U to TDS and wash
wellhead profile pumping at 778 gpm.
POOH L/D StreamFLo wear ring ,
running tool and double DP.
0.0 0.0
4/5/2024
16:45
4/5/2024
18:00
1.25 COMPZN, PLUG RURD P Blow down TDS. Clean and clear rig
floor. R/U tubing running equipment.
0.0 0.0
4/5/2024
18:00
4/5/2024
23:00
5.00 COMPZN, PLUG PUTB P M/U 3.5" mule shoe joint and RIH on
3.5", 9.3#, L-80, EUE tubing as per tally.
Monitor displacement on TT.
Torque to 2,400 ft/lbs.
Tag CIBP at 2,800' w/10K. L/D 3 joints.
0.0 2,800.0
4/5/2024
23:00
4/5/2024
23:30
0.50 COMPZN, PLUG THGR P M/U StreamFLo tubing hanger on 4.5"
landing joint as per StreamFlo rep. S/O
and land out in wellhead. 22k landed on
tubing hanger. Mule shoe @ 2,787'.
2,800.0 2,787.0
4/5/2024
23:30
4/5/2024
23:45
0.25 COMPZN, PLUG PRTS P Test hanger seal to 5,000 psi for 10
minutes - good test.
Set hanger by turning landing joint 6
turns to the right.
2,787.0 2,787.0
4/5/2024
23:45
4/6/2024
00:00
0.25 COMPZN, PLUG RURD P R/U up to cement. 2,787.0 2,787.0
4/6/2024
00:00
4/6/2024
01:00
1.00 COMPZN, PLUG RURD P PJSM with rig crew on cement job line
up. Line up fluid paths from wellhead to
rig and cellar. Checked all hard lines.
Positioned 3 super suckers access to
cellar.
2,787.0 2,787.0
4/6/2024
01:00
4/6/2024
01:45
0.75 COMPZN, PLUG PRTS P PJSM with all personal for cement job.
SLB pump 5 bbls water and test lines to
2,700 psi for 5 min.
2,787.0 2,787.0
4/6/2024
01:45
4/6/2024
03:15
1.50 COMPZN, PLUG CMNT P Surface P&A Cement Job: SLB pumped
40 bbls 12.0 ppg mud push spacer @
3.9 bpm.
Mix and pumped 143 bbls 15.7 ppg
slurry @ 4-5 bpm, 335-621 psi. Took 85
bbls NAF returns to pits then diverted
returns to cellar box. Cement to surface
(15.1 ppg) after pumping 120 bbls
cement. CIP @ 03:07 hrs 4-6-2024.
2,787.0 2,787.0
4/6/2024
03:15
4/6/2024
05:00
1.75 COMPZN, WHDBOP CLEN P Back out and L/D 4.5" StreamFlo
landing joint (broke off pup jt). Flush with
black water/deep clean and blow down
all surface cement lines.
SIMOPS: Clean cellar box from cement
returns with super suckers. R/D high
pressure hoses and equipment in cellar.
R/D casing equipment from floor.
2,787.0 2,787.0
4/6/2024
05:00
4/6/2024
09:00
4.00 COMPZN, WHDBOP WWWH P M/U stacker wash tool on 4.5" DP. Flush
black water & deep clean pill through
BOP, HP lines, all 4 mud pumps, MPD
manifold and chokes, hole fill, and jet
lines. Function BOP components.
SIMOPS: Clean out cement valves on
rig floor.
2,787.0 2,787.0
4/6/2024
09:00
4/6/2024
12:00
3.00 COMPZN, WHDBOP NUND P PJSM. N/D BOP and transfer to stowed
position, R/D MPD lines, choke and kill
lines. L/D low pressure riser. Rack back
high pressure riser.
SIMOPS: Offloading mud, cleaning pits
and shakers.
2,787.0 2,787.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 36/36
TITAN 1
Report Printed: 4/29/2024
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)
4/6/2024
12:00
4/6/2024
18:00
6.00 COMPZN, WHDBOP CLEN P N/D StreamFlo adapter off well head.
Secure high and low pressure risers.
Install adapter flange on high pressure
riser and torque to spec. Clean all
surface equipment in pits, shakers, and
through's. Empty and clean all 4 mud
pumps, suction pots, surge tanks and
mud lines. Remove StreamFlo spool
and adapters from cellar. Clean and
clear rig floor.Pump 40 bbls hot water to
cellar to thaw ice.
2,787.0 2,787.0
4/6/2024
18:00
4/7/2024
00:00
6.00 DEMOB, MOVE CLEN P Continue cleaning surface equipment in
pits, shakers and troughs. Cleaning pits.
Continue empty and clean mud pumps,
suction pots, surge tanks and mud lines.
Continue to clean rig floor, pipe racks
and drip pan of OBM. Remove hanging
ice hazards around rig. Mobilize pup
joints off floor.
2,787.0 2,787.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 1/4
TITAN 1
Report Printed: 5/2/2024
Operations Summary (with Timelog Depths)
Job: ABANDONMENT P&A
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/3/2024
00:00
4/3/2024
01:30
1.50 CLEN P Clean and clear SLB tools from rig floor. 0.0 0.0
4/3/2024
01:30
4/3/2024
11:30
10.00 COMPZN, PLUG TRIP P M/U Baker Cement Retainer and
running tool. TIH on 4.5" DP T/ 13,030'.
Monitor displacement on TT.
0.0 13,030.0
4/3/2024
11:30
4/3/2024
12:45
1.25 COMPZN, PLUG MPDA P Rack back stand. P/U stand with 4.5"
MPD bearing and install as per MPD
rep.
13,030.0 13,030.0
4/3/2024
12:45
4/3/2024
13:00
0.25 COMPZN, PLUG CIRC P Obtain SPR's @ 13,024'.
MP#1: 20 spm = 509 psi
30 spm = 748 psi
MP#2: 20 spm = 510 psi
30 spm = 738 psi
13,030.0 13,030.0
4/3/2024
13:00
4/3/2024
15:00
2.00 COMPZN, PLUG WAIT P Circulating while waiting on orders from
town.
GPM = 126
PSI = 474
13,030.0 13,030.0
4/3/2024
15:00
4/3/2024
15:45
0.75 COMPZN, PLUG SQEZ P P/U joint of 4.5" DP for space out. Set
Baker Cement Retainer at 13,051' as
per Baker rep.
13,030.0 13,051.0
4/3/2024
15:45
4/3/2024
16:15
0.50 COMPZN, PLUG PRTS P Close upper pipe rams. Test cement
retainer pumping down annulus to 2,500
psi for 10 minutes - good test. Bled off
pressure and open upper pipe rams.
Charted test on Totco. Pumped 4.4 bbls
and returned 4.3 bbls.
13,051.0 13,051.0
4/3/2024
16:15
4/3/2024
16:45
0.50 COMPZN, PLUG PRTS P Blow down TDS. M/U pump in assembly
and head pin on string. S/O 20k down
on cement retainer.
13,051.0 13,051.0
4/3/2024
16:45
4/3/2024
18:30
1.75 COMPZN, PLUG SQEZ P R/U to perform injectivity test.
Established injection rate with 11.5 ppg
NAF at 0.5 bpm with 2.1 bbls pumped
when pressure broke over. 899 max
pressure.
Performed injectivity test staging up to 5
bpm. Pumped total 24 bbls.
1 bpm = 956 psi
2 bpm = 1074 psi
3 bpm = 1210 psi
4 bpm = 1376 psi
5 bpm = 1598 psi
Stop pumping and monitored pressure
for 10 minutes.
Initial = 1595 psi, Final = 809 psi.
Sting out of retainer.
13,051.0 13,051.0
4/3/2024
18:30
4/3/2024
19:00
0.50 COMPZN, PLUG SQEZ P PJSM for squeezing cement. Pressure
test SLB cement lines to 3,500 psi -
good test.
135,051.0 13,051.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 2/4
TITAN 1
Report Printed: 5/2/2024
Operations Summary (with Timelog Depths)
Job: ABANDONMENT P&A
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/3/2024
19:00
4/3/2024
21:15
2.25 COMPZN, PLUG SQEZ P Perform squeeze cement job per SLB
and Baker holding 680 psi with MPD.
SLB:
Pumped 42 bbls 12.0 pps spacer @ 4
bpm
Pumped 52.7 bbls 15.8 ppg cement @ 4
bpm
Pumped 5 bbls 12.0 ppg spacer @ 4
bpm
Pumped 10 bbls fresh water @ 4 bpm
Rig:
Rig pumped 88.5 bbls (746 stks) 11.5
ppg NAF @ 4 bpm
Stung into cement retainer and S/O 30k.
Squeezed with rig pump 40 bbls (337
stks) 11.5 ppg NAF @ 4 bpm, 1044-
1223 psi
Stung out of cement retainer (384 psi
below cement retainer when stung into).
Rig pumped 15 bbls (127 stks) 11.5
NAF @ 2.8 bpm, 1300 psi.
Stopped pump and bled off pressure.
13,051.0 13,051.0
4/3/2024
21:15
4/3/2024
21:30
0.25 COMPZN, PLUG SQEZ P R/D cement lines and equipment. Put
working single in mouse hole.
13,051.0 13,051.0
4/3/2024
21:30
4/3/2024
23:30
2.00 COMPZN, PLUG TRIP P POOH 12 stands F/13,051' T/11,895 @
15 ft/min to above TOC.
Note: CIP @ 23:30 hrs. Est TOC @
12,619'.
P/U = 210K
13,051.0 11,895.0
4/3/2024
23:30
4/4/2024
00:00
0.50 COMPZN, PLUG CIRC P Pump wiper ball down and circulate
staging up rate.
11,895.0 11,895.0
4/4/2024
00:00
4/4/2024
02:45
2.75 COMPZN, PLUG CIRC P Circulate hole clean reciprocate
F/11,895' T/11,830'. Flush chokes, blow
down TDS.
P/U = 191K
S/O = 143K
GPM = 300
PSI = 1525
11,895.0 11,830.0
4/4/2024
02:45
4/4/2024
03:15
0.50 COMPZN, PLUG OWFF P OWFF - static. 11,830.0 11,830.0
4/4/2024
03:15
4/4/2024
04:00
0.75 COMPZN, PLUG MPDA P PJSM. Remove RCD bearing as per
MPD rep.
11,830.0 11,830.0
4/4/2024
04:00
4/4/2024
14:30
10.50 COMPZN, PLUG WOC P Wait on cement to achieve 1,500 psi
compressive strength while pumping 84
gpm at 350 psi and slowly reciprocating
string.
SIMOPS: R/D SLB MWD equipment as
per SLB rep. L/D 6 stands excess 4.5"
DP from derrick.
11,830.0 11,830.0
4/4/2024
14:30
4/4/2024
15:30
1.00 COMPZN, PLUG PRTS P Close upper pipe rams. Test casing and
cement plug to 2,500 psi for 30 minutes
with 11.5 ppg NAF. Pumped at 5 spm,
50 stks total. Bled of pressure and
opened rams.
Charted on Totco and witnessed by
AOGCC, Austin McLeod.
11,830.0 11,830.0
4/4/2024
15:30
4/4/2024
16:30
1.00 COMPZN, PLUG TRIP P RIH on elevators F/11,830' T/12,173'.
Tag cement at 12,173' w/5K.
P/U to 12,164'. Wash down at 50 gpm,
368 psi and tag at 12,175' w/ 10K.
Observed 100 psi increase.
Witnessed by AOGCC, Austin McLeod.
11,830.0 12,175.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 3/4
TITAN 1
Report Printed: 5/2/2024
Operations Summary (with Timelog Depths)
Job: ABANDONMENT P&A
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/4/2024
16:30
4/4/2024
17:15
0.75 COMPZN, PLUG CIRC P Circulate bottoms up at 293 gpm, 1650
psi while reciprocating F/12,172'
T/12,113'.
12,175.0 12,175.0
4/4/2024
17:15
4/4/2024
17:45
0.50 COMPZN, PLUG OWFF P OWFF - static. 12,175.0 12,175.0
4/4/2024
17:45
4/4/2024
18:45
1.00 COMPZN, PLUG CIRC P Pump 25 bbls dry job. Blow down TDS
and choke and kill lines. Install stripping
rubber.
12,175.0 12,175.0
4/4/2024
18:45
4/5/2024
00:00
5.25 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/12,175' T/6,500".
Monitor displacement on TT.
12,175.0 6,500.0
4/5/2024
00:00
4/5/2024
04:30
4.50 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/6,500' T/2,281".
Monitor displacement on TT.
6,500.0 2,281.0
4/5/2024
04:30
4/5/2024
05:45
1.25 COMPZN, PLUG TRIP P POOH racking back 4.5" DP F2,281'
T/surface.Monitor displacement on TT.
2,281.0 0.0
4/5/2024
05:45
4/5/2024
06:15
0.50 COMPZN, PLUG BHAH P L/D Baker cement retainer running tool
(no visual issues). P/U Baker 7-5/8"
CIBP as per Baker rep.
0.0 0.0
4/5/2024
06:15
4/5/2024
08:45
2.50 COMPZN, PLUG TRIP P RIH w/4.5" DP stands T/2,815' at 60
fpm. L/D top joint for space out.
Monitor displacement on TT.
0.0 2,815.0
4/5/2024
08:45
4/5/2024
09:00
0.25 COMPZN, PLUG CIRC P Circulate capacity of string at 3 bpm,
175 psi. Pumped 39 bbls.
2,815.0 2,815.0
4/5/2024
09:00
4/5/2024
09:15
0.25 COMPZN, PLUG PACK P Set Baker 7-5/8" CIBP at 2,800' as per
Baker rep.
Drop 1.438" setting ball and pump at 3
bpm then slowed to 1 bpm. Pumped 100
stks and ball on seat.
Increased pressure to 2,300 psi and
held. P/U on string to 119K and
observed good indication CIBP set with
weight loss and pressure bled off.
P/U = 109K
2,815.0 2,800.0
4/5/2024
09:15
4/5/2024
09:45
0.50 COMPZN, PLUG PRTS P P/U full stand above CIBP.
Close annular and pump down string to
test CIBP to 1,500 psi for 10 minutes.
Charted test on Totco - good test.
Bled off pressure and open annular.
2,800.0 2,720.0
4/5/2024
09:45
4/5/2024
10:15
0.50 COMPZN, PLUG CIRC P Pump 15 bbls 13.2 ppg slug. L/D stand
#30 and blow down TDS.
2,720.0 2,720.0
4/5/2024
10:15
4/5/2024
15:00
4.75 COMPZN, PLUG PULD P POOH L/D 4.5" DP F/2,720' T/surface.
L/D Baker running tool - no visual issues
observed.
Monitor displacement on TT.
2,720.0 0.0
4/5/2024
15:00
4/5/2024
16:45
1.75 COMPZN, PLUG WWWH P M/U StreamFlo wear ring running tool
on double 4.5" DP. Pull wear ring as per
StreamFlo rep. M/U to TDS and wash
wellhead profile pumping at 778 gpm.
POOH L/D StreamFLo wear ring ,
running tool and double DP.
0.0 0.0
4/5/2024
16:45
4/5/2024
18:00
1.25 COMPZN, PLUG RURD P Blow down TDS. Clean and clear rig
floor. R/U tubing running equipment.
0.0 0.0
4/5/2024
18:00
4/5/2024
23:00
5.00 COMPZN, PLUG PUTB P M/U 3.5" mule shoe joint and RIH on
3.5", 9.3#, L-80, EUE tubing as per tally.
Monitor displacement on TT.
Torque to 2,400 ft/lbs.
Tag CIBP at 2,800' w/10K. L/D 3 joints.
0.0 2,800.0
4/5/2024
23:00
4/5/2024
23:30
0.50 COMPZN, PLUG THGR P M/U StreamFLo tubing hanger on 4.5"
landing joint as per StreamFlo rep. S/O
and land out in wellhead. 22k landed on
tubing hanger. Mule shoe @ 2,787'.
2,800.0 2,787.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
Page 4/4
TITAN 1
Report Printed: 5/2/2024
Operations Summary (with Timelog Depths)
Job: ABANDONMENT P&A
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
4/5/2024
23:30
4/5/2024
23:45
0.25 COMPZN, PLUG PRTS P Test hanger seal to 5,000 psi for 10
minutes - good test.
Set hanger by turning landing joint 6
turns to the right.
2,787.0 2,787.0
4/5/2024
23:45
4/6/2024
00:00
0.25 COMPZN, PLUG RURD P R/U up to cement. 2,787.0 2,787.0
4/6/2024
00:00
4/6/2024
01:00
1.00 COMPZN, PLUG RURD P PJSM with rig crew on cement job line
up. Line up fluid paths from wellhead to
rig and cellar. Checked all hard lines.
Positioned 3 super suckers access to
cellar.
2,787.0 2,787.0
4/6/2024
01:00
4/6/2024
01:45
0.75 COMPZN, PLUG PRTS P PJSM with all personal for cement job.
SLB pump 5 bbls water and test lines to
2,700 psi for 5 min.
2,787.0 2,787.0
4/6/2024
01:45
4/6/2024
03:15
1.50 COMPZN, PLUG CMNT P Surface P&A Cement Job: SLB pumped
40 bbls 12.0 ppg mud push spacer @
3.9 bpm.
Mix and pumped 143 bbls 15.7 ppg
slurry @ 4-5 bpm, 335-621 psi. Took 85
bbls NAF returns to pits then diverted
returns to cellar box. Cement to surface
(15.1 ppg) after pumping 120 bbls
cement. CIP @ 03:07 hrs 4-6-2024.
2,787.0 2,787.0
4/6/2024
03:15
4/6/2024
05:00
1.75 COMPZN, WHDBOP CLEN P Back out and L/D 4.5" StreamFlo
landing joint (broke off pup jt). Flush with
black water/deep clean and blow down
all surface cement lines.
SIMOPS: Clean cellar box from cement
returns with super suckers. R/D high
pressure hoses and equipment in cellar.
R/D casing equipment from floor.
2,787.0 2,787.0
4/6/2024
05:00
4/6/2024
09:00
4.00 COMPZN, WHDBOP WWWH P M/U stacker wash tool on 4.5" DP. Flush
black water & deep clean pill through
BOP, HP lines, all 4 mud pumps, MPD
manifold and chokes, hole fill, and jet
lines. Function BOP components.
SIMOPS: Clean out cement valves on
rig floor.
2,787.0 2,787.0
4/6/2024
09:00
4/6/2024
12:00
3.00 COMPZN, WHDBOP NUND P PJSM. N/D BOP and transfer to stowed
position, R/D MPD lines, choke and kill
lines. L/D low pressure riser. Rack back
high pressure riser.
SIMOPS: Offloading mud, cleaning pits
and shakers.
2,787.0 2,787.0
4/6/2024
12:00
4/6/2024
18:00
6.00 COMPZN, WHDBOP CLEN P N/D StreamFlo adapter off well head.
Secure high and low pressure risers.
Install adapter flange on high pressure
riser and torque to spec. Clean all
surface equipment in pits, shakers, and
through's. Empty and clean all 4 mud
pumps, suction pots, surge tanks and
mud lines. Remove StreamFlo spool
and adapters from cellar. Clean and
clear rig floor.Pump 40 bbls hot water to
cellar to thaw ice.
2,787.0 2,787.0
4/6/2024
18:00
4/7/2024
00:00
6.00 DEMOB, MOVE CLEN P Continue cleaning surface equipment in
pits, shakers and troughs. Cleaning pits.
Continue empty and clean mud pumps,
suction pots, surge tanks and mud lines.
Continue to clean rig floor, pipe racks
and drip pan of OBM. Remove hanging
ice hazards around rig. Mobilize pup
joints off floor.
2,787.0 2,787.0
Rig: DOYON 26
RIG RELEASE DATE 4/7/2024
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Page 1/1
TITAN 1
Report Printed: 4/29/2024
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
3/10/2024 18:00
Cementing End Date
3/10/2024 21:15
Wellbore Name
TITAN 1
Comment
Cement job went very well. Plugs bumped as per the plan, floats held, well static
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
54.5
Bottom Depth (ftKB)
2,671.1
Full Return?
Yes
Vol Cement …
272.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
7
P Pump Final (psi)
445.0
P Plug Bump (psi)
500.0
Recip?
Yes
Stroke (ft)
1.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Good returns during job. Bump plug on strokes. Floats held. Cement to surface.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
54.5
Est Btm (ftKB)
2,171.0
Amount (sacks)
1,912
Class
*NOT IN LIBRARY
Volume Pumped (bbl)
367.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
6.71
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
295.0
Thickening Time (hr)
4.83
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
2,171.0
Est Btm (ftKB)
2,671.0
Amount (sacks)
364
Class
G
Volume Pumped (bbl)
75.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.02
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
132.0
Thickening Time (hr)
3.97
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Spacer
Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class
*NOT IN LIBRARY
Volume Pumped (bbl)
100.0
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal)
10.50
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/2
TITAN 1
Report Printed: 4/29/2024
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
3/24/2024 15:15
Cementing End Date
3/25/2024 00:45
Wellbore Name
TITAN 1
Comment
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective
Cement from shoe to
11,115' MD.
Top Depth (ftKB)
11,115.0
Bottom Depth (ftKB)
13,125.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
4
P Pump Final (psi)
1,085.0
P Plug Bump (psi)
1,600.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type
Intermediate Cement
Fluid Description Estimated Top (ftKB)
11,115.0
Est Btm (ftKB)
13,125.0
Amount (sacks)
830
Class
Blend
Volume Pumped (bbl)
173.0
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
4.65
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
80.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 2
Description
Stage Cementing
Objective
Cement from 6415' to
surface.
Top Depth (ftKB)
54.5
Bottom Depth (ftKB)
6,415.0
Full Return?
No
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
5
P Pump Final (psi)
680.0
P Plug Bump (psi)
1,895.0
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
Noted pump pressure decreasing with 240.9 bbls of mud pumped. Pressure continued to decrease till bumping the closing plug. Did not get good cement to
surface. Did start to see cement interface right before bumping the plug. Stage tool did not close completely. Attempted 3 times to pressure up to close.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB) Est Btm (ftKB)
5,915.0
Amount (sacks)
1,142
Class
*NOT IN LIBRARY
Volume Pumped (bbl)
397.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
6.69
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
177.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
5,915.0
Est Btm (ftKB)
6,415.0
Amount (sacks)
231
Class
Blend
Volume Pumped (bbl)
48.1
Yield (ft³/sack)
1.17
Mix H20 Ratio (gal/sack)
4.67
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
269.0
Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 3
Description
Squeeze – Formation
Squeeze
Objective Top Depth (ftKB)
13,051.0
Bottom Depth (ftKB)
13,499.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m… Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…P Pump Final (psi)
1,335.0
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
Intermediate String 1 Cement
Page 2/2
TITAN 1
Report Printed: 4/29/2024
Cement
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 4
Description
Plug – Plug Back /
Abandonment Plug
Objective Top Depth (ftKB)
12,619.0
Bottom Depth (ftKB)
13,051.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m… Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…P Pump Final (psi)
1,335.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
12,175.0
Tag Method
Pipe/String
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Stage # 5
Description
Plug – Plug Back /
Abandonment Plug
Objective Top Depth (ftKB)
0.0
Bottom Depth (ftKB)
2,800.0
Full Return?
Yes
Vol Cement …Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
4
P Pump Final (psi)
621.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
0.0
Tag Method
Visual
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
Page 1/1
TITAN 1
Report Printed: 4/29/2024
Cement
Cement Details
Description
Cement Squeeze
Cementing Start Date
4/3/2024 19:30
Cementing End Date
4/3/2024 21:00
Wellbore Name
TITAN 1
Comment
Squeeze job went as per plan
Cement Stages
Stage # <Stage Number?>
Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return?Vol Cement …Top Plug? Btm Plug?
Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Cement Squeeze
Page 1/1
TITAN 1
Report Printed: 4/29/2024
Cement
Cement Details
Description
Cement Plug
Cementing Start Date
4/3/2024 21:00
Cementing End Date
4/3/2024 21:15
Wellbore Name
TITAN 1
Comment
Balanced plug job went as planned.
Cement Stages
Stage # <Stage Number?>
Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return?Vol Cement …Top Plug? Btm Plug?
Q Pump Init (bbl/m… Q Pump Final (bbl/… Q Pump Avg (bbl/…P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Cement Fluids & Additives
Fluid
Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack) Mix H20 Ratio (gal/sack) Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
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2024-0414_Surface_Abandon_CRU_Titan-1_bb
Page 1 of 3
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: April 15, 2024
P. I. Supervisor
FROM: Brian Bixby SUBJECT: Surface Abandonment
Petroleum Inspector Colville River Unit Titan 1
ConocoPhillips Alaska Inc.
PTD 2231280; Sundry 324-181
04/13/2024: I arrived at Titan #1 and met with Mike Winfree (CPAI Wells Infrastructure
Supv.) to witness the cutoff, top of cement, and marker plate for Titan 1 well. Upon
arrival they were still in the process of cutting the tree off. After the tree was cut off it
was noticed that there was good cement in all strings except for the annulus between
tubing 7-inch casing. Hard cement was tagged at 17 feet below the cutoff. I told Mike
they needed to get it topped off and I would return tomorrow.
04/14/24: I returned to Titan #1 and witnessed hard cement in all strings. I took a
piece of flat bar to test the cement and it was hard about 3-inches from the top. Verified
the cutoff is 3 feet below tundra level and all the correct information was on the marker
plate. Gave the ok to weld the marker plate to the conductor.
Attachments: 4 Pictures
2024-0414_Surface_Abandon_CRU_Titan-1_bb
Page 2 of 3
Surface Abandonment – CRU Titan-1 (PTD 2231280)
Photos by AOGCC Inspector B. Bixby
4/14/2024
2024-0414_Surface_Abandon_CRU_Titan-1_bb
Page 3 of 3
SAMPLE TRANSMITTAL
TO: AOGCC
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
TITAN 1
2796 - 15520 MD
7 Boxes
SENT BY: M. McCRACKEN
DATE: April 1, 2024
AIR BILL: N/A
CPAI: CPA12024041001
CHARGE CODE: N/A
NAME: Titan 1
NUMBER OF BOXES: 7 Boxes
UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY
OF THIS FORM TO:
RECEIVED: 6)
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
RECEIVE®
APR 10 2024
AOGCC
V�L�3(DNVS '4h0j'?,(4
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:17 Township:12N Range:4E Meridian:Umiat
Drilling Rig:Doyon 26 Rig Elevation:51.09 ft Total Depth:15,521 ft MD Lease No.:ADL 390345
Operator Rep:Suspend:P&A:X
Conductor:20"O.D. Shoe@ 135 Feet Csg Cut@ NA Feet
Surface:10-3/4"O.D. Shoe@ 2,668 Feet Csg Cut@ NA Feet
Intermediate:7-5/8"O.D. Shoe@ 13,113 Feet Csg Cut@ NA Feet
Production:O.D. Shoe@ Feet Csg Cut@ NA Feet
Liner:O.D. Shoe@ Feet Csg Cut@ NA Feet
Tubing:O.D. Tail@ Feet Tbg Cut@ NA Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Open Hole Retainer 13,051 ft MD 12,175 ft MD 11.5 ppg Drillpipe tag
Initial 15 min 30 min 45 min Result
Tubing
IA 2567 2524 2517
OA 0 0 0
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
I traveled to location to witness the pressure test and tag of the bottom zone isolating cement plug to abandon the well. Retainer
was set at 13,051 ft MD (62 feet above intermediate shoe). Cement was pumped below the retainer (20 barrels) into the 6-3/4"
open hole section and across casing shoe then once unstung 33 barrels was laid on top inside the 7-5/8". At 11,900 ft MD they
achieved a passing pressure test of the plug. With 4-1/2" drillpipe and the retainer running tool (6.3" OD) they tagged higher than
expected at 12,175 ft MD with 15k pounds set down twice. Pump pressure increased ~ 100 psi once tagged. I found no issues
with this inspection. Above rig elevation is to lock down pins. Ground level- 58.5 feet.
April 4, 2024
Austin McLeod
Well Bore Plug & Abandonment
Colville River Unit Titan 1
ConocoPhillips Alaska, Inc
PTD 2231280; Sundry 324-181
none
Test Data:
P
Casing Removal:
Tyler Hunt
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-0404_Plug_Verification_Titan-1_am
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 26
To:DOA AOGCC Prudhoe Bay; Doyon 26 Driling Supervisor; Hobbs, Greg S; Regg, James B (OGC); Brooks, Phoebe L
(OGC)
Cc:Bill Walter; Samuel Dye
Subject:Doyon 26 BOP Form
Date:Saturday, March 30, 2024 5:16:01 PM
Attachments:3-27-2024 BOP Doyon 26.xlsx
Some people who received this message don't often get email from rig26@doyondrilling.com. Learn why this is
important
All, attached is a BOP test form from Doyon 26, test date 3-27-24
Johnny Newman
Rig 26 Toolpusher
Rig26@doyondrilling.com
Rig Cell 907-301-1502
Office 907-670-4187
&ROYLOOH5LYHU8QLW7LWDQ
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.:26 DATE: 3/27/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2231280 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250/4000 Annular:250/2500 Valves:250/4000 MASP:3812
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.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 18-3/4"x5000psi P Pit Level Indicators PP
#1 Rams 1 3 1/2" x 6 5/8"P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 3-1/2"x6-5/8"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 3-1/16" & 3-1/8"P System Pressure (psi)3025 P
Kill Line Valves 2 3" & 3-1/16"P Pressure After Closure (psi)1500 P
Check Valve 0NA200 psi Attained (sec)9 P
BOP Misc 0NAFull Pressure Attained (sec)86 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 3700 P
No. Valves 16 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 15 P
#1 Rams 14 P
Coiled Tubing Only:#2 Rams 14 P
Inside Reel valves 0NA #3 Rams 13 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:5.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3/22/24 10:29
Waived By
Test Start Date/Time:3/27/2024 13:00
(date) (time)Witness
Test Finish Date/Time:3/27/2024 18:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Doyon
Test Annular W/ 3-1/2" Test Joint to 250/2500psi Low/High F/ 5min each. Test #1 & #3 Rams W/ 3-1/2" TJ & 4-1/2" TJ, Blind
Rams, Auto & Manual IBOP's, Choke Manifold Valves #1-16, Kill lines and Choke line HCR's & Manual Valves, 4-1/2" FOSV &
Dart valves all tested to 250/5000psi Low/High F/ 5min each. Tested Gas Alarms. Tested Manual & Remote Manifold Chokes to
1,800psi.
R. Pankratz / A. Agnes
ConocoPhillips
P. Stewart / A. Lundale
CRU Titan 1
Test Pressure (psi):
rig26@doyondrilling.com
d26cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0327_BOP_Doyon26_CRU_Titan-1
9 9
9
9 9 9 9
9
9
9
-5HJJ
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating: 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?NA CRU Titan 1
Yes No
9. Property Designation (Lease Number): 10. Field:
Colville River Unit Alpine Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Matt Nagel
Contact Email:matt.b.nagel@conocophillips.com
Contact Phone: 907-263-4747
Authorized Title: Drilling Engineer
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
4/4/2024
Perforation Depth MD (ft):
13113
20
10.75
135
7.62513113
2668
MD
6890
5210
135
2356
7260
135
2668
Length Size
Proposed Pools:
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL390345, ADL390348, ADL388466, ADL388463, ASRC-NPR1,
ASRC-NPR2
223-128
P.O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20876
ConocoPhillips Alaska, Inc
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Serv ice
BOP Test Mechanical Integrity Test
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 1:05 pm, Mar 26, 2024
10-407
A.Dewhurst 02APR24
VTL 4/2/2024
AOGCC inspection required after cutoff and before remedial cementing
Well abandonment marker to meet requirements of 20 AAC 25.120
X
-00-00
BOP test to 4000 psig
Annular preventer test to 2500 psig
Processed sonic logs and cement job reports required to be submitted to the AOGCC
on the intermediate 1st and 2nd stage cementing for approval prior to P&A operations.
X
X
DSR-4/2/24JLC 4/3/2024
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
March 26th, 2024
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Sundry for Titan 1 Plug and Abandon
Dear Sir or Madam:
ConocoPhillips Alaska, Inc hereby applies for Application for Sundry Approval to Plug and Abandon Titan 1 (PTD #: 223-128) an onshore
well.
Titan 1 is a Kuparuk C sand pilot well. The 13-1/2 surface hole was TDd above the C-30 sand and then 10-3/4 casing will be set and
cemented to surface.
The intermediate section was drilled with a 9-7/8 x 11 under-reamed steerable drilling assembly and TDd ~10 TVD above the Kuparuk C
sand. A 7-5/8 casing string was set and cemented from TD to secure the shoe and cover 250 TVD (which is greater than 500 MD) above
the shoe. A second stage cement job was performed to isolate a clean sand in Qannik formation and was pumped to surface isolating the 10-
3/4 x 7-5/8 annulus.
The production interval will be comprised of a 6-3/4 horizontal hole that will be geo-steered in the Kuparuk C sand. The production hole
will be left unlined and a cement plug will be pumped to isolate the reservoir section.
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 10-403
2. A proposed drilling program
3. As Built Conductor Location
4. Current Wellbore Schematic
5. Proposed Abandonment Wellbore Schematic
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:
Matt Nagel, (907) 263-4747 & Matt.B.Nagel@conocophillips.com,
Sincerely, cc:
Titan 1 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
Titan 1
AOGCC Application for Sundry
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ...................................................... 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) .................................... 2
Requirements of 20 AAC 25.050(b) ........................................................................................................ 2
3. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) ................. 3
4. Attachments ............................................................................................................. 3
Attachment 1 As Built Location ............................................................................................................... 3
Attachment 2 Curent Wellbore Schematic .............................................................................................. 3
Attachment 3 Proposed Abandonment Wellbore Schematic .................................................................. 3
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU Titan 1.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (Titan 1 Slot) 490 FSL, 2430 FEL, Sec 17, T12N, R4E
NAD 27
Northings: 5992989
Eastings: 355268
RKB Elevation 58.4 AMSL
Pad Elevation 4.2 AMSL
Location at Productive Horizon (Heel) 2385 FSL, 1063 FEL, Sec 13, T12N, R3E
NAD 27
Northings: 5995057
Eastings: 346580
Measured Depth, RKB: 13,233
Total Vertical Depth, RKB: 7,270
Total Vertical Depth, SS: 7,205
Location at Total Depth (Toe) 4878 FSL, 4776 FEL, Sec 30, T12N, R4E
NAD 27
Northings: 5986969
Eastings: 347544
Measured Depth, RKB: 21,114
Total Vertical Depth, RKB: 7,290
Total Vertical Depth, SS: 7,225
Requirements of 20 AAC 25.050(b)
The Applicant is the only affected owner.
3. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13))
The proposed drilling program is listed below. Please refer to Completion Schematic.
1. PU 7-5/8 CIBP and RIH on 4-1/2 DP to ~13,040 MD and set CIBP.
2. RU and test CIBP to 2,500 psi for mechanical integrity.
a. Minimum test pressure is 0.25 psi/ft * 7246 TVD = 1,812 psi
3. RU cementers and pump 20 bbls of 15.8 ppg cement below CIBP.
4. POOH and pump 20 bbls of 15.8 ppg cement on top of CIBP.
5. TOOH and lay down cementing string.
6. PU 7-5/8 CIBP and RIH with 4-1/2 DP to ~2,800 MD and set CIBP.
7. RU and test CIBP to 1,500 psi for mechanical integrity.
a. Minimum test pressure is 1,500 psi
8. TOOH
9. PU and run 3-1/2 tubing to CIBP. XO to 4-1/2 hanger and land in wellhead.
10. RU cementers and pump 15.8 ppg cement to surface taking returns through casing valve.
11. NDBOP
12. Rig down and release rig.
13. After the rig moves off location, the wellhead will be cut off 5 below ground level. A marker plate will be
welded on call casing strings with the following information:
ConocoPhillips
Titan 1
PTD: 223-128
API: 50-103-20876
4. Attachments
Attachment 1 As Built Location
Attachment 2 Curent Wellbore Schematic
Attachment 3 Proposed Abandonment Wellbore Schematic
cement retainer
VTL 3/27/2024
Weld 1/4" thick cover plate over all casing strings with the following information
bead welded into the top. Photo document. AOGCC witness required.
AOGCC inspection required after cutoff and before remedial cementing
Well abandonment marker to meet requirements of 20 AAC 25.120
cement retainer
Provide sonic logs to AOGCC.
VTL 3/27/2024
cement retainer
cement retainer
WOC. State witnessed PT and tag required.
-00-00
VTL 03/29/2024
cement retainer
N
I
G
L
I
Q
C
H
A
N
N
NOTES:
PROJECT
SITE
PHONE : 907-670-4739
6-3/4" Open Hole TD
15,520' MD / 7275' TVD
20" Conductor to 135'
Kuparuk C Sand Top
13265' MD / ~7284' TVD
Titan, FWK Pilot Horizontal
Current Schematic updated 3/26/24, D26, RKB 54.5 ft, wp10.0
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,668' MD / 2,356' TVD
Kalubik
12732' MD / 7172' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~6428' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
13,113' MD / 7260' TVD @ 79°
C30 Sand Top
2829' MD / 2445' TVD
HRZ Top
12510' MD / 7101' TVD
TOC @ 12,284' MD
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
Qannik Top
6268' MD / 4042' TVD
Cementing Tool @ 6,415/
4,122'
TOC @ Surface
6-3/4" Open Hole TD
15,520' MD / 7275' TVD
20" Conductor to 120'
Kuparuk C Sand Top
13265' MD / ~7284' TVD
Titan, FWK Pilot Horizontal
Proposed Schematic updated 4/1/24, D26, RKB 54.5 ft, As Drilled
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,668' MD / 2,356' TVD
Kalubik
12732' MD / 7172' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~6428' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
13,113' MD / 7260' TVD @ 79°
C30 Sand Top
2829' MD / 2445' TVD
HRZ Top
12510' MD / 7101' TVD
Cement Plug
200' above and
below CIBP
CIBP Baker CIBP
~2800' MD / ~2429' TVD
15.7ppg cement
To surface
TOC @ 12,284' MD
3.5" 9.3 ppf L-80 Cement String
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
CIBP
Baker CIBP
~13,040' MD / ~7246' TVD
Qannik Top
6268' MD / 4042' TVD
Cementing Tool @ 6,415/
4,122'
TOC @ Surface
6-3/4" Open Hole TD
21,124' MD / 7283' TVD
20" Conductor to 135'
Kuparuk C Sand Top
~13233' MD / ~7270' TVD
Titan, FWK Pilot Horizontal
Current Schematic updated 3/26/24, D26, RKB 54.5 ft, wp10.0
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,668' MD / 2,356' TVD
Kalubik
12570' MD / 7123' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~6428' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
13,113' MD / 7260' TVD @ 79°
C30 Sand Top
2894' MD / 2462' TVD
HRZ Top
12386' MD / 7053' TVD
TOC @ 12,284' MD
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
Qannik Top
6230' MD / 4034' TVD
Cementing Tool @ 6,415/
4,122'
TOC @ Surface
2829' MD / 2449' TVD SFD
12510' MD / 7101' TVD SFD
Superseded by updated schematic. -A.Dewhurst 02APR24
~12961' MD / ~7241' TVD SFD
6268' MD / 4042' TVD SFD
12732' MD / 7172' TVD SFD
6-3/4" Open Hole TD
21,124' MD / 7283' TVD
20" Conductor to 120'
Kuparuk C Sand Top
~13233' MD / ~7270' TVD
Titan, FWK Pilot Horizontal
Proposed Schematic updated 3/25/24, D26, RKB 54.5 ft, wp10.0
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,668' MD / 2,356' TVD
Kalubik
12570' MD / 7123' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~6428' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
13,113' MD / 7260' TVD @ 79°
C30 Sand Top
2894' MD / 2462' TVD
HRZ Top
12386' MD / 7053' TVD
Cement Plug
200' above and
below CIBP
CIBP Baker CIBP
~2800' MD / ~2429' TVD
15.7ppg cement
To surface
TOC @ 12,284' MD
3.5" 9.3 ppf L-80 Cement String
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
CIBP
Baker CIBP
~13,040' MD / ~7246' TVD
Qannik Top
6230' MD / 4034' TVD
Cementing Tool @ 6,415/
4,122'
TOC @ Surface
Superseded by updated proposal. -A.Dewhurst 02APR24
2829' MD / 2449' TVD SFD
12510' MD / 7101' TVD SFD
~12961' MD / ~7241' TVD SFD
6268' MD / 4042' TVD SFD
12732' MD / 7172' TVD SFD
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.
223-128
Alpine Oil
Titan 1
Colville River
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:Operations Engineer, Doyon 26
To:Loepp, Victoria T (OGC)
Cc:Nagel, Matt B
Subject:Titan 1 7 5/8" casing test and FIT
Date:Sunday, March 31, 2024 12:32:19 PM
Attachments:image001.png
Titan-1 Int1 FIT or LOT Pressure Integrity Test Form .xlsx
Titan 1 - INTRM1 DRILLOUT - Pressure Test 7.625i_WSC Surveillance Tec.png
Hi Victoria,
On the Titan 1 well the 7 5/8 casing was successfully pressure tested to 4,000 psi and
formation integrity test performed after drillout, see attached. The FIT had a very slight slope
change at 13.3 ppg, but as you can see the formation was pressured up to just over 14 ppg and
held with minimal leak off.
Regards,
Scott
WSC Operations Engineer Doyon 26
Scott Kolstad
26opseng@conocophillips.com
907.263.4552 (Office)
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:Loepp, Victoria T (OGC)
To:Operations Engineer, Doyon 26
Cc:Nagel, Matt B; Coates, David; Hobbs, Greg S; Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC)
Subject:RE: Titan 1 Intermediate casing cement report and sonic log discussion
Date:Friday, March 29, 2024 10:16:00 AM
Attachments:image002.png
image003.png
Scott,
Free ringing pipe may be obtained by logging below the ES-cementer. Please log for 100 below the
cementer to show free pipe.
Logs must show cementing of the Qannik prior to full P&A. The AOGCC must be provided the logs
for review before the zone is P&As.
From: Operations Engineer, Doyon 26 <Doyon26.OperationsEngineer@conocophillips.com>
Sent: Thursday, March 28, 2024 4:58 PM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>; Coates, David
<David.Coates2@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: Titan 1 Intermediate casing cement report and sonic log discussion
Victoria,
Attached is the SLB cement report for the 7 5/8 cement job.
The Intermediate hole was drilled to 13,125 and landed at approximately 81 deg. Inclination in
the base of the Kalubik shale approximately 10 20 TVD above the top of the Kuparuk
reservoir. This section did NOT drill into the Kuparuk reservoir.
The 7 5/8 casing was run to the planned depth of 13,116 and landed on the hanger.
First stage cement job:
Circulation was established and rate staged up with NO packing off.
The first stage cement job was pumped with 85 bbls of 12.0 ppg mud push spacer,
followed by 177 bbls of 15.8 ppg cement, and displaced with 11.0 ppg mud.
The plug was bumped on calculated strokes with no losses during the job.
The first stage job did NOT isolate any hydrocarbons.
Second stage cement job:
The casing was pressured up to open the ES Cementer (6,415)
circulation was established for the second stage job
The second stage job was pumped with 65 bbls of 11.0 ppg mud push spacer, 397 bbls
of DeepCrete lead with 325 lbs of cemnet added at 1 ppb, and 48 bbls of 15.8 ppg
cement.
Cement was displaced with 11.0 ppg mud
Plug bumped and pressure bleed off
Observed pipe jump when ES-cementer shifted closed
Observed small stream of fluid bleed back.
Most likely from thermal expansion of the mud in the casing as has been
observed on MT7.
Re-applied pressure 2 more times to ensure ES-cementer is closed.
Just in case the ES cementer was leaking, pressured up to 800 psi and held until
cement reached 50 psi compressive strength.
Returns sample was caught at surface with pH of 11.9 compared to the mud pH of
8.8
Pressure bleed off and observed static
LWD Sonic Log
We have an LWD sonic tool in the BHA in recorded mode. According to SLB, this tool cannot
be used to assess cement bond inside 2 strings of casing. We plan to log below the surface
casing shoe to the ES Cementer depth of 6,415.
The only option on this one is to obtain free ringing pipe below the stage tool. This differs from
the Conditions of Approval in the permit, #2 which is snipped below for your reference.
There is no free ringing pipe expected in this interval as the string was cemented from the stage
tool to surface. Please advise if Condition of Approval #2 can be changed and free ringing
pipe obtained below the stage tool?
For the first stage, as stated above the reservoir was not penetrated, no hydrocarbons are
isolated, no losses.
This well is not an injector (as per 20 AAC 25.030 (d)(7)) and 20 AAC 25.412 (d)) and will not be
stimulated. Can you please help me understand what part of the regulation is driving the
requirement for the cement log and approval prior to P&A?
Best Regards,
Scott
WSC Operations Engineer Doyon 26
Scott Kolstad
26opseng@conocophillips.com
907.263.4552 (Office)
1
Dewhurst, Andrew D (OGC)
From:Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent:Tuesday, April 2, 2024 09:04
To:Dewhurst, Andrew D (OGC)
Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC)
Subject:RE: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Attachments:Titan As Built 4-2-24.pdf; Titan Proposed P&A.pdf; Titan 1 Surveys.xlsx; Titan 1 Formation Tops.xlsx
Hi Andy,
For consistency Ive a ached updated schema cs with as-drilled forma on tops. Ive also sent updated surveys and nal
forma on tops.
I would also like to provide a quick opera onal update:
As of yesterday a ernoon, 4/1, we have reached our nal TD at 15,520 MD. Decision was made to call TD a er
decreasing reservoir quality was observed along our lateral. We are currently coming out of the hole to lay down BHA
and we an cipate being on surface around 9pm this evening. We will then lay down BHA and download the Sonic data
that was gathered and send over to yall as soon as available. We have asked for this informa on to be downloaded rst
from the BHA and should have this data tomorrow morning.
We an cipate being prepare to RIH with our rst plug around 5 AM tomorrow, 4/3, and are asking for permission to
proceed with the 1st cement retainer and pump the 1st plug to isolate the Kuparuk C while the Sonic data is being
processed.
Please feel free to give me a call with any addi onal ques ons.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, April 1, 2024 11:09 AM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Ma ,
Once you have the nal forma on tops, would you please send an updated schema c? All we need is the single page
PDF and I will update the exis ng sundry.
Thanks,
Andy
2
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 20:03
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Andy,
The 7-5/8 intermediate was set ~10 TVD above the an cipated Kuparuk C top. We have not entered the reservoir yet.
The 12,961 MD is the pre-drill es mate.
And I apologize. The schema c I sent had the tops with the pre-drill es mates and not the updated tops based on as
drilled.
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 4:44 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Ma ,
Thanks for the data.
I have two ques ons related to the forma on tops:
Would you con rm that the intermediate casing was set below the top of the Kuparuk C? The 9-7/8 shows a
depth of 13,113 MD and Kuparuk C actual shows 12,961 MD (from the Daily Geological Report sent earlier
today). This di ers from the pre- and post-drill wellbore schema cs provided to date.
Would you please con rm the geologic tops posted on the wellbore schema c? They do not agree with the
actual tops provided earlier today.
Thanks,
Andy
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 14:57
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Yessir. Here you go.
3
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 2:49 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Ma ,
Thanks. Could I please get the LWD logs in .las format also?
Andy
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 14:46
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Hi Andy,
Please see a ached.
Let me know if these work ok for you.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 1:07 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl,
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.
4
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
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.
Ma ,
To support our review of the Titan-1 P&A sundry, would you please provide eld copies of the direc onal survey, LWD
logs, and geological tops for the well?
Please note that this preliminary informa on does not meet the nal repor ng requirements of Regula on 20 AAC
25.071 for this well.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas Conserva on Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
From:Loepp, Victoria T (OGC)
To:Nagel, Matt B
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC)
Subject:Re: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Date:Tuesday, April 2, 2024 6:59:56 AM
Matt,
Thank you for the update. We will address your request by the EOB today.
Victoria
Sent from my iPhone
On Apr 2, 2024, at 6:05AM, Nagel, Matt B
<Matt.B.Nagel@conocophillips.com> wrote:
Hi Andy,
For consistency Ive attached updated schematics with as-drilled formation tops. Ive
also sent updated surveys and final formation tops.
I would also like to provide a quick operational update:
As of yesterday afternoon, 4/1, we have reached our final TD at 15,520 MD. Decision
was made to call TD after decreasing reservoir quality was observed along our lateral.
We are currently coming out of the hole to lay down BHA and we anticipate being on
surface around 9pm this evening. We will then lay down BHA and download the Sonic
data that was gathered and send over to yall as soon as available. We have asked for
this information to be downloaded first from the BHA and should have this data
tomorrow morning.
We anticipate being prepare to RIH with our first plug around 5 AM tomorrow, 4/3, and
are asking for permission to proceed with the 1st cement retainer and pump the 1st
plug to isolate the Kuparuk C while the Sonic data is being processed.
Please feel free to give me a call with any additional questions.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Monday, April 1, 2024 11:09 AM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Matt,
Once you have the final formation tops, would you please send an updated schematic?
All we need is the single page PDF and I will update the existing sundry.
Thanks,
Andy
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 20:03
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Andy,
The 7-5/8 intermediate was set ~10 TVD above the anticipated Kuparuk C top. We
have not entered the reservoir yet. The 12,961 MD is the pre-drill estimate.
And I apologize. The schematic I sent had the tops with the pre-drill estimates and not
the updated tops based on as drilled.
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 4:44 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL]RE: CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Matt,
Thanks for the data.
I have two questions related to the formation tops:
Would you confirm that the intermediate casing was set below the top of the
Kuparuk C? The 9-7/8 shows a depth of 13,113 MD and Kuparuk C actual
shows 12,961 MD (from the Daily Geological Report sent earlier today). This
differs from the pre- and post-drill wellbore schematics provided to date.
Would you please confirm the geologic tops posted on the wellbore schematic?
They do not agree with the actual tops provided earlier today.
Thanks,
Andy
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 14:57
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Yessir. Here you go.
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 2:49 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Matt,
Thanks. Could I please get the LWD logs in .las format also?
Andy
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: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, March 28, 2024 14:46
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
Hi Andy,
Please see attached.
Let me know if these work ok for you.
Thanks
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, March 28, 2024 1:07 PM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL]CRU Titan-1 Sundry 324-181 (PTD 223-128): Question
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.
Matt,
To support our review of the Titan-1 P&A sundry, would you please provide field copies
of the directional survey, LWD logs, and geological tops for the well?
Please note that this preliminary information does not meet the final reporting
requirements of Regulation 20 AAC 25.071 for this well.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
<Titan As Built 4-2-24.pdf>
<Titan Proposed P&A.pdf>
<Titan 1 Surveys.xlsx>
<Titan 1 Formation Tops.xlsx>
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIV UNIT TITAN 1
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
Tested with 5 7/8 and 7 5/8 TJ, Great test no issues
Test Results
TEST DATA
Rig Rep:Einer FleagleOperator:ConocoPhillips Alaska, Inc.Operator Rep:Tyler Hunt
Rig Owner/Rig No.:Doyon 26 PTD#:2231280 DATE:3/12/2024
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopSTS240313205443
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6.75
MASP:
3812
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 1 P
Inside BOP 1 P
FSV Misc 0 NA
16 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 18 3/4 P
#1 Rams 1 41/2x75/8 vari P
#2 Rams 1 Blind/Shear P
#3 Rams 1 3 1/2 x 6 5/8 P
#4 Rams 0 P
#5 Rams 0 P
#6 Rams 0 P
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/16 &3 1/8 P
Kill Line Valves 2 3&3 1/16 P
Check Valve 0 P
BOP Misc 0 P
System Pressure P3050
Pressure After Closure P1650
200 PSI Attained P12
Full Pressure Attained P88
Blind Switch Covers:Pal stations
Bottle precharge P
Nitgn Btls# &psi (avg)P10@3850
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 P16
#1 Rams P11
#2 Rams P17
#3 Rams P14
#4 Rams P0
#5 Rams P0
#6 Rams P0
HCR Choke P1
HCR Kill P1
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:COLVILLE RIV UNIT TITAN 1
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
Remarks:Tested with 5 7/8 and 7 5/8 TJ, Great test no issues
Test Results
TEST DATA
Rig Rep:Einer FleagleOperator:ConocoPhillips Alaska, Inc.Operator Rep:Tyler Hunt
Rig Owner/Rig No.:Doyon 26 PTD#:2231280 DATE:3/12/2024
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopSTS240313205443
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:BOPOP000011225
INSIDE REEL VALVES
Quantity P/F
(Valid for Coil Rigs Only)
Test Time:6.75
MASP:
3812
Sundry No:
Control System Response Time (sec):
P/FTime
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 1 P
Inside BOP 1 P
FSV Misc 0 NA
16 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 18 3/4 P
#1 Rams 1 41/2x75/8 v P
#2 Rams 1 Blind/Shea P
#3 Rams 1 3 1/2 x 6 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 1/16 &3 1 P
Kill Line Valves 2 3&3 1/16 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3050
Pressure After Closure P1650
200 PSI Attained P12
Full Pressure Attained P88
Blind Switch Covers:Pal stations
Bottle precharge P
Nitgn Btls# &psi (avg)P10@3850
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 P16
#1 Rams P11
#2 Rams P17
#3 Rams P14
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
REVISED
Revised Misc components P/F to NA - J. Regg, 6/7/2024
JBR; 6/7/2024
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________COLVILLE RIV UNIT TITAN 1
JBR 04/12/2024
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:0
Remarks:Test performed with 5 7/8" drill pipe.
5 Alarms stgations tested.
Nitrogen 36@1000. Very good test for something they don’t do on the regular on this rig.
TEST DATA
Rig Rep:Archie Agnes, Johnny Operator:ConocoPhillips Alaska, Inc.Operator Rep:K. Harding, T. Hunt
Contractor/Rig No.:Doyon 26 PTD#:2231280 DATE:3/7/2024
Well Class:DEV Inspection No:divJDH240306094534
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
Test Time:1
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign P
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:P P
Hydrogen Sulfide:P P
Gas Detectors Misc:0 NA
Designed to Avoid Freeze-up?0 P
Remote Operated Diverter?0 P
No Threaded Connections?0 P
Vent line Below Diverter?0 P
Diverter Size:21.25 P
Hole Size:13.5 P
Vent Line(s) Size:16 P
Vent Line(s) Length:101 P
Closest Ignition Source:80 P
Outlet from Rig Substructure:86 P
Vent Line(s) Anchored:0 P
Turns Targeted / Long Radius:0 P
Divert Valve(s) Full Opening:0 P
Valve(s) Auto & Simultaneous:
Annular Closed Time:24 P
Knife Valve Open Time:2 P
Diverter Misc:0 NA
Systems Pressure:P3000
Pressure After Closure:P2400
200 psi Recharge Time:P2
Full Recharge Time:P33
Nitrogen Bottles (Number of):P10
Avg. Pressure:P3800
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
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
Matt Nagel
Drilling Engineer
Conoco Phillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK, 99510-0360
Re: Coville River Field, Alpine Oil Pool, CRU Titan-1
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-128
Surface Location: 490’ FSL, 2430’ FEL, Sec 17, T12N, R4E
Bottomhole Location: 4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
Dear Mr. Nagel:
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 _29 day of February 2024.
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.02.29 15:11:32
-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: 21,114 TVD: 7,290
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
3/3/2024
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
4791' to ADL387211
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.5 15. Distance to Nearest Well Open
Surface: x- 355268 y- 5992989 Zone- 4 10 to Same Pool: 3812' to CD5-09
16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90 degrees Downhole: Surface: 3,812
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
24" 20" 154.3 X52 Welded 82 53 53 135 135
13.5" 10.75" 45.5 L-80 TXP 2764 53 53 2817 2423
9.875 x 11" 7.625" 29.7 L-80 HYD563 / TXP 12854 53 53 12907 7238
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: Matt Nagel
Authorized Name: Matt Nagel Contact Email:Matt.B.Nagel@ConocoPhillips.com
Authorized Title: Drilling Engineer Contact Phone:907-263-4747
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
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
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Signature:
Production
Liner
Intermediate
Conductor/Structural
LengthCasing Cement Volume MDSize
Plugs (measured):
(including stage data)
13 yds
1055sx 11 ppg & 275sx 15.8 ppg
18. Casing Program:Top - Setting Depth - BottomSpecifications
4,539
Cement Quantity, c.f. or sacks
Total Depth MD (ft): Total Depth TVD (ft):
59-52-180
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
300sx 15.8 ppg Class G
2385’ FSL, 1063’ FEL, Sec 13, T12N, R3E
4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
LONS 23-002
P.O. Box 100360 Anchorage, Alaska, 99510-0360
ConocoPhillips Alaska, Inc
490’ FSL, 2430’ FEL, Sec 17, T12N, R4E ADL390345, ADL390348, ADL388466,
ADL388463, ASRC-NPR1, ASRC-NPR2
448, 192, 1733, 2276.50, 6091.83, 8838.21
CRU Titan 1
Colville River Unit
Alpine Oil Pool
Commission Use Only
See cover letter for other
requirements.
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Stratigraphic Test
No Mud log req'd: Yes No
No Directional svy req'd: Yes No
cch Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP Sketcch Drhilling Program Time v. Depth Plot Shallow Hazard Analysis
Single Well
Gas Hydrates
No Inclination-only svy req'd: Yes No
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
No
Noo
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 9:18 am, Feb 28, 2024
9:18 am, Feb 28, 2024
X
A.Dewhurst 29FEB24
VTL 02/29/2024
2.2'
Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension
attached
Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT to the AOGCC as soon as available.
Results of Sonic required to verify competent cement behind casing
50-103-20876-00-00
7,283'
58.2'
21,124'
223-128
DSR-2/29/24($8
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.02.29 15:11:03 -09'00'
02/29/24
02/29/24
ZhdŝƚĂŶϭ
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, Alaska 99510-0360
Telephone 907-276-1215
February 27th, 2024
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill Titan 1
Dear Sir or Madam:
ConocoPhillips Alaska, Inc hereby requests to amend an already approved Permit to Drill for the onshore well Titan 1 1. The initial attempt
to set the conductor was unsuccessful and the conductor bore had to be abandoned. A new conductor was drilled approximately 24’ to the
east. The requested revision to the PTD accounts for the new surface hole location
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Kuparuk C sand well from an ice pad. The intended spud date for
this well is March 3rd, 2024. The intended rig used to drill the well is Doyon Rig 26.
Titan 1 is planned to be a Kuparuk C sand pilot well. The 13-1/2” surface hole will TD above the C-30 sand and then 10-3/4” casing will be
set and cemented to surface.
The intermediate section will be drilled with a 9-7/8” x 11” under-reamed steerable drilling assembly and will TD ~10’ TVD above the
Kuparuk C sand. A 7-5/8” casing string will be set and cemented from TD to secure the shoe and cover 250’ TVD (which is greater than 500’
MD) above the shoe.
The production interval will be comprised of a 6-3/4” horizontal hole that will be geo-steered in the Kuparuk C sand. The production hole
will be left unlined and a cement plug will be pumped to isolate the reservoir section.
It is requested that a variance to the blowout prevention equipment test frequency under 10 AAC 25.035(e)(10)(A) be granted for a 21-day
BOPE test schedule per the pilot project that Doyon 26 is currently on.
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. A proposed drilling program
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:
Matt Nagel, (907) 263-4747 & Matt.B.Nagel@conocophillips.com,
or
Chris Brillon, (907) 265-6120 & Chris.l.Brillon@conocophillips.com
Sincerely, cc:
Titan 1 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
Printed: 27-Feb-24
Titan 1
AOGCC Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) .................................................................................... 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ................................................... 2
3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) .......... 2
4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ................................... 3
5. Procedure for Conducting Formation Integrity Tests
(Requirements of 20 AAC 25.005 (c)(5)) ......................................................................................... 4
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ............................. 4
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)).................................... 4
8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .............................................. 5
9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ..... 5
10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .................................................... 6
11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................... 6
12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) .............................................. 6
13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .................................... 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7
(Requirements of 20 AAC 25.005 (c)(14)) ....................................................................................... 8
15. Attachments ............................................................................................................. 8
Attachment 1 Cement Summary
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
Printed: 27-Feb-24
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU Titan 1.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (Titan 1 Slot) 490’ FSL, 2430’ FEL, Sec 17, T12N, R4E
NAD 27
Northings: 5992989
Eastings: 355268
RKB Elevation 64.5’ AMSL
Pad Elevation 10’ AMSL
Location at Productive Horizon (Heel) 2385’ FSL, 1063’ FEL, Sec 13, T12N, R3E
NAD 27
Northings: 5995057
Eastings: 346580
Measured Depth, RKB: 12,953’
Total Vertical Depth, RKB: 7,255’
Total Vertical Depth, SS: 7,190’
Location at Total Depth (Toe) 4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
NAD 27
Northings: 5986969
Eastings: 347544
Measured Depth, RKB: 21,114’
Total Vertical Depth, RKB: 7,290’
Total Vertical Depth, SS: 7,225’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: Titan 1 wp08.1 Directional Plan
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP and diverter schematics on file for Doyon 26.
wp10
58.2'
4.2'
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
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4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4))
The following shows the calculation results of anticipated surface pressure (ASP) while drilling this well:
Casing Size
(in)
Casing Set Depth
MD/TVD (ft)
Fracture
Gradient
(ppg)
Pore
Pressure
(psi)
ASP Drilling
(psi)
20 135 / 135 10.9 50 63
10-3/4 2,817 / 2,423 14.5 1,066 2,533
7-5/8 12,907 / 7,238 14.2 3,257 3,820
Open Hole 21,114 / 7,290 14.2 4,549 N/A
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP 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:
1) ASP = [(FG x 0.052) - 0.1] x D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb/gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.44psi/ft x TVD above HRZ & 0.45psi/ft below HRZ unless otherwise specified
(A) ASP Calculations Per Interval
1. Drilling Below 20” Conductor:
ASP = [(FG x 0.052) – 0.1] x D
= [(10.9x 0.052) – 0.1] x 135 = 63psi
OR
ASP = FPP – (0.1 x D)
= 1,066 – (0.1 x 2,423) = 823 psi
2. Drilling Below 10-3/4” Surface Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(13.5 x 0.052) – 0.1] x 2,423’ = 1,459 psi
OR
ASP = FPP – (0.1 x D)
= 3,257 – (0.1 x 7,238’) = 2,533 psi
AOGCC Application for Permit to Drill, Well Titan 1
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Titan 1 AOGCC APD
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3. Drilling Below 7-5/8” Intermediate Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.5 x 0.052) – 0.1] x 7,238 = 4,733 psi
OR
ASP = FPP – (0.1 x D)
= 4,549 – (0.1 x 7,290) = 3,820 psi
Note: 12.0ppg Kuparuk C Pressure
(B) data on potential gas zones;
The well bore is not expected to penetrate any hydrates nor gas zones.
(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 Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5))
Drill out casing or liner shoe and perform LOT or FIT in accordance with the COP ERD LOT / FIT
procedure that ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing Program: Specifications Top Bottom Cement Quantity, sacks
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
24" 20" 154.3 X52 Welded 82 53 53 135 135 13 yds
13.5" 10.75" 45.5 L-80 TXP 2764 53 53 2817 2423 1055sx 11 ppg & 275sx
15.8 ppg
9.875”
x 11” 7.625" 29.7 L-80 H563/
TXP 12854 53 53 12907 7238
300sx 15.8 ppg Class G
(TOC 250’TVD above
casing shoe)
6.75" N/A N/A N/A N/A 7669 12854 7238 21114 7274 Open Hole
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7))
A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2)
AOGCC Application for Permit to Drill, Well Titan 1
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Titan 1 AOGCC APD
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8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in 13-1/2 9-7/8 x 11 6-3/4
Casing
Size in 10-3/4 7-5/8 N/A
Density ppg 10.5 10.0 - 11.0 10.5 - 12.2
PV cP 9 – 10 10-15 20-30
YP
lb./
100
ft2
45 – 50 25 – 30 30-40
Initial
Gels
lb./
100
ft2
46 15 10
10
Minute
Gels
lb./
100
ft2
48 25 13
API Fluid
Loss
cc/
30
min
< 10 < 10 NA
pH 9.5-10.8 9.5-10 NA
Surface Hole:
The Surface interval will be drilled with a mixed-metal oxide freshwater drilling fluid (DRILPLEX WBM).
Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to
cementing. Maintain mud weight 10.0ppg through the base of Permafrost and increase to 10.5 ppg prior
to TD. Control LGS using solids control system and dilutions where necessary.
Intermediate:
The Intermediate interval will be drilled with a fresh water gel / polymer drilling fluid (FWP WBM). Ensure
good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at 10.0 –
11.0ppg for instability. MPD maybe be used to prevent cycling on the formation. Good filter cake quality,
hole cleaning and maintenance of low gravity drill solids (by diluting as required) will all be important in
maintaining good hole conditions.
Production Hole:
The Production interval will be drilled with an inhibitive mineral oil based drilling fluid (VersaClean).
Maintain mud weight 10.5 – 12.2ppg so that MPD can provide dynamic overbalance of ~12.2ppg EMW
while reducing the risk of lost circulation created by high ECDs. Ensure good hole cleaning by maximizing
fluid annular velocity. Good filter cake quality, hole cleaning, and maintenance of low gravity drill solids
(by diluting as required) will all be important in maintaining good hole conditions.
Please reference pit diagram on file for Doyon 26. All drilling fluid practices will be in accordance with
appropriate regulations stated in 20 AAC 25.033.
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.
AOGCC Application for Permit to Drill, Well Titan 1
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Titan 1 AOGCC APD
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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.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
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13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13))
The proposed drilling program is listed below. Please refer to Completion Schematic.
1. Install landing ring on conductor on existing 20” conductor. Conductor set at 135’ RKB.
2. Move in / rig up Doyon Rig 26 on conductor.
3. Pick up 5-7/8” DP and prepare surface drilling fluid.
4. Spud and directionally drill 13-1/2” hole to casing point at +/-2,817’ MD / 2,423’ TVD as per directional plan.
Run MWD / LWD logging tools (LMWD Program: GR/DIR) in drill string as required for directional
monitoring and formation data gathering.
5. Run and cement new 10-3/4" 45.5# L-80 TXP casing to surface. Adequate excess cement will be pumped to
ensure cement returns to the surface.
6. Install wellhead and test to 1000 psi. Nipple up BOPE with the following equipment/configuration:
a. 18-5/8” Annular / Upper 3-1/2” x 6-5/8” VBR / Blind/Shear Ram / Lower 3-1/2” x 6-5/8” VBR
7. Test BOPE to 250 psi low / 5,000 psi high. Test annular to 250 psi low / 3,500 psi high. (Provide 48 hr.
AOGCC notice)
a. This test pressure meets the requirements for the 21 day pressure testing cycle which requires an
initial pressure test to full working pressure of the BOPE. All subsequent tests will be performed to
250 psi low / 4,000 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi. If the 21
day pressure testing cycle is not granted then the initial pressure test will be performed to 250 psi low /
4,000 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi.
8. Test casing to 3500 psi for 30min.
9. PU 9-7/8” x 11” rotary steerable drilling assembly. Run MWD / LWD logging tools in drill string as required
for directional monitoring and formation data gathering.
10. Drill out cement and 20' new hole. Perform FIT to 13.5 ppg EMW minimum.
11. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 11 ppg
12. Directionally drill 9-7/8” x 11” hole to casing point at +/-12,907’ MD / 7,238’ TVD, landing ~10’ TVD above
the Kuparuk C Sand. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering.
13. Circulate wellbore clean and strip out of the hole to surface.
14. Change upper pipe rams to 7-5/8” solid body and test same to 3,500 psi.
15. Rig up and run new 7-5/8” 29.7# L-80 HYD563/TXP casing.
16. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of
cement to be +/-12,183’ MD / 6,988’ TVD which is 250’ TVD above the intermediate casing shoe.
17. Change upper pipe rams to 3-1/2” x 6-5/8” VBR’s
18. Test BOPE to 250 psi low / 4,000 psi high. Test annular to 250 psi low / 2,500 psi high) (24 hr. AOGCC
notice.)
19. Test casing to 4000 psi for 30min.
20. Pick up 6-3/4” Bit and rotary steerable drilling assembly and RIH and clean out cement to top of float
equipment.
21. Drill out cement and 20' of new hole. Perform FIT to a minimum of 13 ppg EMW. Displace to 11 ppg NAF
drilling fluid.
22. Directionally drill 6-3/4” hole into the Kuparuk C Sand to TD at +/- 21,114’ MD / 7,274’ TVD using MPD as
per directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering. Run Sonic log for 7-5/8” liner TOC
and report to AOGCC once it’s available.
23. Circulate well clean and displace to KW fluid and observe well for flow.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
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24. Strip out of hole and lay down BHA.
25. A sundry will be submitted for on-rig P&A operations.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Drill cuttings and drilling mud form the well will be disposed of by hauling to Alpine injection facility where they
will be disposed by injecting to approved Class I or Class II Disposal wells.
15. Attachments
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Directional Plan
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 27-Feb-24
Titan 1 AOGCC APD
Printed: 27-Feb-24
Attachment 1 – Cement Summary
10-3/4” Surface Casing to 2,817’ MD / 2,423’ TVD
Cement from 2,817’ to 2,317' MD (500’) with 15.8ppg Class G tail and from 2,317' to surface with 11.0ppg
DeepCRETE lead. Assume 250% excess annular volume in Permafrost, 50% excess below the Permafrost, and
no excess within the 20” conductor.
Lead Slurry from 2,248’ MD to Surface with 11.0ppg DeepCRETE
Conductor (135’ – 53’) X 1.364 ft3/ft X 1.0 (0% excess) = 112 ft3
Permafrost to Conductor (1,129’ – 135’) X 0.3639 ft3/ft X 3.5 (250% excess) = 1,266 ft3
Top of Tail to Permafrost (2,317’ – 1,129’) X 0.3639 ft3/ft X 1.5 (50% excess) = 648 ft3
Total Volume = 112 + 1,266 + 648 = 2,026 ft3 => 1055 sx of 11.0ppg DeepCRETE @ 1.92 ft3 /sk
Tail Slurry from 2,817’ MD to 2,317’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (2,817’ – 2,317) X 0.364 ft3/ft X 1.50 (50% excess) = 273 ft3
Shoe Joints (90’) X 0.539 ft3/ft X 1.00 (0% excess) = 49 ft3
Total Volume = 273 + 49 = 322 ft3 => 275 sx of 15.8ppg Class G + additives @ 1.17 ft3/sk
7-5/8” Intermediate Casing to 12,907’ MD / 7,238’ TVD
Cement from 12,907’ to 250’ TVD above the casing shoe with 15.8ppg Class G assuming 40% excess annular
volume.
Tail slurry from 12,907’ MD to 12,183’ MD with 15.8 ppg Class G + additives
11” Hole to Top of Cement (12,797’ – 12,183’) x 0.3431 ft3/ft x 1.4 (40% excess) = 295 ft3
Shoe to top of 9-7/8” Hole (12,907’ – 12,797’) x 0.2148 ft3/ft x 1.4 (40% excess) = 33 ft3
Shoe Track (80’) x 0.2577 ft3/ft x 1.0 (0% excess) = 20 ft3
Total Volume = 295 + 33 + 20 = 348 ft3 => 300 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
6-3/4" Open Hole TD
21,114' MD / 7274' TVD
20" Conductor to 135'
Kuparuk C Sand Top
~12953' MD / ~7247' TVD
Titan, FWK Pilot – Horizontal
Proposed Schematic updated 11/16/23, D26, RKB 54.5 ft, wp08.1
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,817' MD / 2,423' TVD
Kalubik
12558' MD / 7137' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~4000' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
12,907' MD / 7238' TVD @ 77°
C30 Sand Top
2894' MD / 2462' TVD
HRZ Top
12236' MD / 7011' TVD
TOC @ 12,183' MD
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
56 500
500 1000
1000 2000
2000 3000
3000 4000
4000 5000
5000 10000
10000 12000
12000 14000
14000 21125
Titan 1 wp10 Plan Summary
0
3
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
10-3/4" Surface Casing
7-5/8" Intermediate Casing
200.0
200.0
400.0
400.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [400 usft/in]
12281
12232
12187
12148
12112
12080
12051CD2-305 wp19
3750
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
-7000 -6000 -5000 -4000 -3000 -2000 -1000 0
Vertical Section at 140.00°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
1000
2000
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
12000 12750 13500 14250 15000 15750 16500
Measured Depth
DDI
7.170
SURVEY PROGRAM
Date: 2021-02-01T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
56.00 400.00 Titan 1 wp10 (Titan 1) r.5 SDI_URSA1
400.00 21124.45 Titan 1 wp10 (Titan 1) MWD+IFR2+SAG+MS
Ground / 2.20
CASING DETAILS
TVD MD Name
2416.20 2803.55 10-3/4" Surface Casing
7230.20 12915.14 7-5/8" Intermediate Casing7283.01 21124.45 0" Production Open Hole
Mag Model & Date: BGGM2023 15-Mar-24
Magnetic North is 13.91° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.59° 57128.77nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 56.00 0.00 0.00 56.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 298.00 499.96 1.64 -3.08 1.00 298.00 -3.24 Start Build 2.00
4 700.00 6.00 298.00 699.43 8.19 -15.40 2.00 0.00 -16.17 Start DLS 2.50 TFO -5.07
5 2926.05 61.63 293.24 2477.26 487.52 -1105.05 2.50 -5.07 -1083.78 Start 7288.23 hold at 2926.05 MD
610214.28 61.63 293.24 5940.44 3017.86 -6997.60 0.00 0.00 -6809.78 Start DLS 3.50 TFO -109.64
712296.02 65.00 210.00 7025.20 2489.00 -8522.00 3.50 -109.64 -7384.52 Start DLS 3.50 TFO -61.26
812910.08 76.50 190.70 7229.03 1948.30 -8718.88 3.50 -61.26 -7096.87 Start DLS 6.00 TFO -30.00
913211.24 92.25 181.77 7258.51 1651.57 -8750.98 6.00 -30.00 -6890.20 Start 160.00 hold at 13211.24 MD
1013371.24 92.25 181.77 7252.23 1491.77 -8755.92 0.00 0.00 -6770.96 Start DLS 6.00 TFO -105.95
11 13551.95 89.25 171.35 7249.86 1311.67 -8745.09 6.00 -105.95 -6626.04 Start 1490.00 hold at 13551.95 MD
1215041.95 89.25 171.35 7269.37 -161.25 -8521.02 0.00 0.00 -5353.68 Start Build 6.00
1315087.78 92.00 171.35 7268.87 -206.56 -8514.13 6.00 0.00 -5314.54 Start 210.00 hold at 15087.78 MD
1415297.78 92.00 171.35 7261.54 -414.04 -8482.56 0.00 0.00 -5135.31 Start Drop -6.00
1515381.11 87.00 171.35 7262.26 -496.40 -8470.03 6.00 180.00 -5064.17 Start 250.00 hold at 15381.11 MD
1615631.11 87.00 171.35 7275.35 -743.22 -8432.49 0.00 0.00 -4850.96 Start Build 6.00
1715731.11 93.00 171.35 7275.35 -842.03 -8417.45 6.00 0.00 -4765.60 Start 170.00 hold at 15731.11 MD
1815901.11 93.00 171.35 7266.45 -1009.87 -8391.92 0.00 0.00 -4620.62 Start Drop -6.00
1915954.45 89.80 171.35 7265.15 -1062.57 -8383.90 6.00 180.00 -4575.09 Start 570.00 hold at 15954.45 MD
2016524.45 89.80 171.35 7267.14 -1626.09 -8298.18 0.00 0.00 -4088.31 Start Build 6.00
2116561.11 92.00 171.35 7266.56 -1662.33 -8292.66 6.00 0.00 -4057.00 Start 240.00 hold at 16561.11 MD
2216801.11 92.00 171.35 7258.19 -1899.46 -8256.59 0.00 0.00 -3852.17 Start Drop -6.00
2316884.45 87.00 171.35 7258.91 -1981.81 -8244.06 6.00 180.00 -3781.02 Start 300.00 hold at 16884.45 MD
2417184.45 87.00 171.35 7274.61 -2277.99 -8199.00 0.00 0.00 -3525.17 Start Build 6.00
2517284.45 93.00 171.35 7274.61 -2376.81 -8183.97 6.00 0.00 -3439.81 Start 130.00 hold at 17284.45 MD
2617414.45 93.00 171.35 7267.81 -2505.16 -8164.45 0.00 0.00 -3328.94 Start Drop -6.00
2717451.95 90.75 171.35 7266.58 -2542.21 -8158.81 6.00 180.00 -3296.94 Start 700.00 hold at 17451.95 MD
2818151.95 90.75 171.35 7257.42 -3234.19 -8053.54 0.00 0.00 -2699.18 Start Build 6.00
2918189.45 93.00 171.35 7256.19 -3271.24 -8047.90 6.00 0.00 -2667.18 Start 90.00 hold at 18189.45 MD
3018279.45 93.00 171.35 7251.48 -3360.09 -8034.39 0.00 0.00 -2590.42 Start Drop -6.00
31 18379.45 87.00 171.35 7251.48 -3458.91 -8019.35 6.00 180.00 -2505.06 Start 200.00 hold at 18379.45 MD3218579.45 87.00 171.35 7261.95 -3656.36 -7989.31 0.00 0.00 -2334.50 Start Build 6.00
3318679.45 93.00 171.35 7261.95 -3755.18 -7974.28 6.00 0.00 -2249.13 Start 140.00 hold at 18679.45 MD
3418819.45 93.00 171.35 7254.62 -3893.40 -7953.25 0.00 0.00 -2129.74 Start Drop -6.00
3518890.28 88.75 171.35 7253.54 -3963.40 -7942.60 6.00 180.00 -2069.27 Start 600.00 hold at 18890.28 MD
3619490.28 88.75 171.35 7266.63 -4556.44 -7852.39 0.00 0.00 -1556.98 Start Build 6.00
3719561.11 93.00 171.35 7265.55 -4626.44 -7841.74 6.00 0.00 -1496.51 Start 60.00 hold at 19561.11 MD
3819621.11 93.00 171.35 7262.41 -4685.68 -7832.73 0.00 0.00 -1445.34 Start Drop -6.00
3919721.11 87.00 171.35 7262.41 -4784.49 -7817.69 6.00 180.00 -1359.98 Start 220.00 hold at 19721.11 MD
4019941.11 87.00 171.35 7273.92 -5001.69 -7784.65 0.00 0.00 -1172.36 Start Build 6.00
41 20032.78 92.50 171.35 7274.32 -5092.28 -7770.87 6.00 0.00 -1094.11 Start 150.00 hold at 20032.78 MD
42 20182.78 92.50 171.35 7267.78 -5240.43 -7748.33 0.00 0.00 -966.13 Start Drop -6.00
43 20217.78 90.40 171.35 7266.89 -5275.02 -7743.07 6.00 180.00 -936.25 Start 500.00 hold at 20217.78 MD
4420717.78 90.40 171.35 7263.40 -5769.32 -7667.87 0.00 0.00 -509.26 Start Drop -6.0045 20774.45 87.00 171.35 7264.69 -5825.32 -7659.35 6.00 180.00 -460.88 Start 350.00 hold at 20774.45 MD
4621124.45 87.00 171.35 7283.01 -6170.87 -7606.79 0.00 0.00 -162.39 TD at 21124.45
FORMATION TOP DETAILS
TVDPath Formation
1112.20 Base Frozen Sand
1307.20 Base Permafrost
2204.20 C40
2456.20 C30
2759.20 C20
2973.20 C10
3868.20 K3
4047.20 Top Qannik
4092.20 Base Qannik
4381.20 Albian 97
5047.20 Albian 96
5951.20 Albian 95
7004.20 HRZ FCS
7062.20 HRZ insitu
7130.20 Kalubik
7165.20 K1
7240.20 KupC
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 2.2+2+54 @ 58.20usft (D26)
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0 450 900 1350 1800 2250
Partial Measured Depth
Titan 1 wp10 Ladder View
0
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12000 12750 13500 14250 15000 15750 16500
Measured Depth
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
56.00 400.00 Titan 1 wp10 (Titan 1) r.5 SDI_URSA1
400.00 21124.45 Titan 1 wp10 (Titan 1) MWD+IFR2+SAG+MS
9:03, February 29 2024
CASING DETAILS
TVD MD Name
2416.20 2803.55 10-3/4" Surface Casing
7230.20 12915.14 7-5/8" Intermediate Casing
7283.01 21124.45 0" Production Open Hole
56 500
500 1000
1000 2000
2000 3000
3000 4000
4000 5000
5000 10000
10000 12000
12000 14000
14000 21125
Titan 1 wp10 TC View
100
100
200
200
300
300
400
400
500
500
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [200 usft/in]
12397
12336
12281
12232
12187
12148
12112
12080
12051
12024
CD2-305 wp19
SURVEY PROGRAM
Date: 2021-02-01T00:00:00 Validated: Yes Version:
From To Tool56.00 400.00 r.5 SDI_URSA1
400.00 21124.45 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2416.20 2803.55 10-3/4" Surface Casing
7230.20 12915.14 7-5/8" Intermediate Casing7283.01 21124.45 0" Production Open Hole
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 56.00 0.00 0.00 56.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 298.00 499.96 1.64 -3.08 1.00 298.00 -3.24 Start Build 2.00
4 700.00 6.00 298.00 699.43 8.19 -15.40 2.00 0.00 -16.17 Start DLS 2.50 TFO -5.07
5 2926.05 61.63 293.24 2477.26 487.52 -1105.05 2.50 -5.07 -1083.78 Start 7288.23 hold at 2926.05 MD
610214.28 61.63 293.24 5940.44 3017.86 -6997.60 0.00 0.00 -6809.78 Start DLS 3.50 TFO -109.64712296.02 65.00 210.00 7025.20 2489.00 -8522.00 3.50 -109.64 -7384.52 Start DLS 3.50 TFO -61.26
812910.08 76.50 190.70 7229.03 1948.30 -8718.88 3.50 -61.26 -7096.87 Start DLS 6.00 TFO -30.00
913211.24 92.25 181.77 7258.51 1651.57 -8750.98 6.00 -30.00 -6890.20 Start 160.00 hold at 13211.24 MD
1013371.24 92.25 181.77 7252.23 1491.77 -8755.92 0.00 0.00 -6770.96 Start DLS 6.00 TFO -105.95
11 13551.95 89.25 171.35 7249.86 1311.67 -8745.09 6.00 -105.95 -6626.04 Start 1490.00 hold at 13551.95 MD
1215041.95 89.25 171.35 7269.37 -161.25 -8521.02 0.00 0.00 -5353.68 Start Build 6.00
1315087.78 92.00 171.35 7268.87 -206.56 -8514.13 6.00 0.00 -5314.54 Start 210.00 hold at 15087.78 MD
1415297.78 92.00 171.35 7261.54 -414.04 -8482.56 0.00 0.00 -5135.31 Start Drop -6.00
1515381.11 87.00 171.35 7262.26 -496.40 -8470.03 6.00 180.00 -5064.17 Start 250.00 hold at 15381.11 MD
1615631.11 87.00 171.35 7275.35 -743.22 -8432.49 0.00 0.00 -4850.96 Start Build 6.00
1715731.11 93.00 171.35 7275.35 -842.03 -8417.45 6.00 0.00 -4765.60 Start 170.00 hold at 15731.11 MD
1815901.11 93.00 171.35 7266.45 -1009.87 -8391.92 0.00 0.00 -4620.62 Start Drop -6.00
1915954.45 89.80 171.35 7265.15 -1062.57 -8383.90 6.00 180.00 -4575.09 Start 570.00 hold at 15954.45 MD
2016524.45 89.80 171.35 7267.14 -1626.09 -8298.18 0.00 0.00 -4088.31 Start Build 6.00
2116561.11 92.00 171.35 7266.56 -1662.33 -8292.66 6.00 0.00 -4057.00 Start 240.00 hold at 16561.11 MD
2216801.11 92.00 171.35 7258.19 -1899.46 -8256.59 0.00 0.00 -3852.17 Start Drop -6.00
2316884.45 87.00 171.35 7258.91 -1981.81 -8244.06 6.00 180.00 -3781.02 Start 300.00 hold at 16884.45 MD
2417184.45 87.00 171.35 7274.61 -2277.99 -8199.00 0.00 0.00 -3525.17 Start Build 6.00
2517284.45 93.00 171.35 7274.61 -2376.81 -8183.97 6.00 0.00 -3439.81 Start 130.00 hold at 17284.45 MD
2617414.45 93.00 171.35 7267.81 -2505.16 -8164.45 0.00 0.00 -3328.94 Start Drop -6.00
2717451.95 90.75 171.35 7266.58 -2542.21 -8158.81 6.00 180.00 -3296.94 Start 700.00 hold at 17451.95 MD
2818151.95 90.75 171.35 7257.42 -3234.19 -8053.54 0.00 0.00 -2699.18 Start Build 6.00
2918189.45 93.00 171.35 7256.19 -3271.24 -8047.90 6.00 0.00 -2667.18 Start 90.00 hold at 18189.45 MD
3018279.45 93.00 171.35 7251.48 -3360.09 -8034.39 0.00 0.00 -2590.42 Start Drop -6.00
31 18379.45 87.00 171.35 7251.48 -3458.91 -8019.35 6.00 180.00 -2505.06 Start 200.00 hold at 18379.45 MD
3218579.45 87.00 171.35 7261.95 -3656.36 -7989.31 0.00 0.00 -2334.50 Start Build 6.00
3318679.45 93.00 171.35 7261.95 -3755.18 -7974.28 6.00 0.00 -2249.13 Start 140.00 hold at 18679.45 MD
3418819.45 93.00 171.35 7254.62 -3893.40 -7953.25 0.00 0.00 -2129.74 Start Drop -6.00
3518890.28 88.75 171.35 7253.54 -3963.40 -7942.60 6.00 180.00 -2069.27 Start 600.00 hold at 18890.28 MD
3619490.28 88.75 171.35 7266.63 -4556.44 -7852.39 0.00 0.00 -1556.98 Start Build 6.00
3719561.11 93.00 171.35 7265.55 -4626.44 -7841.74 6.00 0.00 -1496.51 Start 60.00 hold at 19561.11 MD
3819621.11 93.00 171.35 7262.41 -4685.68 -7832.73 0.00 0.00 -1445.34 Start Drop -6.00
3919721.11 87.00 171.35 7262.41 -4784.49 -7817.69 6.00 180.00 -1359.98 Start 220.00 hold at 19721.11 MD
4019941.11 87.00 171.35 7273.92 -5001.69 -7784.65 0.00 0.00 -1172.36 Start Build 6.0041 20032.78 92.50 171.35 7274.32 -5092.28 -7770.87 6.00 0.00 -1094.11 Start 150.00 hold at 20032.78 MD
42 20182.78 92.50 171.35 7267.78 -5240.43 -7748.33 0.00 0.00 -966.13 Start Drop -6.00
43 20217.78 90.40 171.35 7266.89 -5275.02 -7743.07 6.00 180.00 -936.25 Start 500.00 hold at 20217.78 MD
4420717.78 90.40 171.35 7263.40 -5769.32 -7667.87 0.00 0.00 -509.26 Start Drop -6.00
45 20774.45 87.00 171.35 7264.69 -5825.32 -7659.35 6.00 180.00 -460.88 Start 350.00 hold at 20774.45 MD
4621124.45 87.00 171.35 7283.01 -6170.87 -7606.79 0.00 0.00 -162.39 TD at 21124.45
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Titan 1wp10 Surface Location
Titan 1wp10 Surface Location
# Schlumberger-Confidential
Titan 1wp10 Surface Casing
Titan 1wp10 Surface Casing
# Schlumberger-Confidential
Titan 1wp10 Intermediate Csg
Titan 1wp10 Intermediate Csg
# Schlumberger-Confidential
Titan 1wp10 Top Kup C
Titan 1wp10 Top Kup C
# Schlumberger-Confidential
Titan 1wp10 TD
Titan 1wp10 TD
# Schlumberger-Confidential
N
I
G
L
I
Q
C
H
A
N
N
NOTES:
PROJECT
SITE
PHONE : 907-670-4739
1
Dewhurst, Andrew D (OGC)
From:Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent:Thursday, February 29, 2024 11:34
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Loepp, Victoria T (OGC); Guhl, Meredith D (OGC)
Subject:RE: [EXTERNAL]Titan-1 Revised (PTD 223-128)
Attachments:Titan 1 wp10 Permit Report.pdf
Actual ice level is 4.2’ (2.2’ ground elevaƟon + 2’ of ice) and RKB is the 58.2’.
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, February 29, 2024 11:30 AM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]Titan-1 Revised (PTD 223-128)
MaƩ,
OK, just conĮrming KB = 58.2 with GL sƟll = 10’. Would you also please send a copy of the PDF version of the direc Ɵonal
plan (wp10) and I’ll aƩach that to the revised PTD?
Thanks,
Andy
From: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent: Thursday, February 29, 2024 11:09
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: RE: [EXTERNAL]Titan-1 Revised (PTD 223-128)
Yessir. Please see aƩached. Also note this updated plan includes the updated as built ground eleva Ɵon.
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, February 29, 2024 11:06 AM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Guhl,
Meredith D (OGC) <meredith.guhl@alaska.gov>
Subject: [EXTERNAL]Titan-1 Revised (PTD 223-128)
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.
MaƩ,
We are working to expedite the revised Titan PTD. Is there an updated direcƟonal plan for the new SHL?
Andy
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Thursday, February 29, 2024 11:00
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Subject: Titan Well
Victoria,
MaƩ Nagle of CPAI just phoned. FYI: He said they are moving the rig to locaƟon now and they will likely spud on
Monday.
Cheers and Be Well,
Steve D
CONFIDENTIALITY NOTICE: This e-mail message, including any aƩachments, contains informaƟon from the Alaska Oil and Gas ConservaƟon Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain conĮdenƟal and/or privileged informaƟon. The unauthorized review, use
or disclosure of such informaƟon may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without Įrst saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
CRU Titan-1
223-128
X
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36
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8
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.govChris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK, 99510-0360
Re: Coville River Field, Alpine Oil Pool, CRU Titan-1
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-128
Surface Location: 481’ FSL, 2451’ FEL, Sec 17, T12N, R4E
Bottomhole Location: 4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run
must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required by law
from other governmental agencies and does not authorize conducting drilling operations until all other
required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw
the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC
order, or the terms and conditions of this permit may result in the revocation or suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this _ _ day of February 2024.
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2024.02.21 13:23:24
-09'00'
21
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 21,114 TVD: 7,290
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
2/22/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
4791' to ADL387211
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 64.5 15. Distance to Nearest Well Open
Surface: x- 355247 y- 5992980 Zone- 4 10 to Same Pool: 3812' to CD5-09
16. Deviated wells: Kickoff depth: 400 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90 degrees Downhole: Surface: 3,812
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 154.3 X52 Welded 82 53 53 135 135
13.5" 10.75" 45.5 L-80 TXP 2764 53 53 2817 2423
9.875 x 11" 7.625" 29.7 L-80 HYD563 / TXP 12854 53 53 12907 7238
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: Matt Nagel
Authorized Name: Chris Brillon Contact Email:Matt.B.Nagel@ConocoPhillips.com
Authorized Title: Wells Engineering Manager Contact Phone:907-263-4747
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
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
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Signature:
Production
Liner
Intermediate
Conductor/Structural
LengthCasing Cement Volume MDSize
Plugs (measured):
(including stage data)
13 yds
1055sx 11 ppg & 275sx 15.8 ppg
18. Casing Program:Top - Setting Depth - BottomSpecifications
4,539
Cement Quantity, c.f. or sacks
Total Depth MD (ft): Total Depth TVD (ft):
59-52-180
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
300sx 15.8 ppg Class G
2385’ FSL, 1063’ FEL, Sec 13, T12N, R3E
4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
LONS 23-002
P.O. Box 100360 Anchorage, Alaska, 99510-0360
ConocoPhillips Alaska, Inc
481’ FSL, 2451’ FEL, Sec 17, T12N, R4E ADL390345, ADL390348, ADL388466,
ADL388463, ASRC-NPR1, ASRC-NPR2
448, 192, 1733, 2276.50, 6091.83, 8838.21
CRU Titan 1
Colville River Unit
Alpine Oil Pool
Commission Use Only
See cover letter for other
requirements.
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Stratigraphic Test
No Mud log req'd: Yes No
No Directional svy req'd: Yes No
cch Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP Sketcch Drhilling Program Time v. Depth Plot Shallow Hazard Analysis
Single Well
Gas Hydrates
No Inclination-only svy req'd: Yes No
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
No
Noo
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 10:42 am, Dec 22, 2023
DSR-1/26/24
223-128
Separate P&A sundry to be submitted.
VTL 02/20/2024
50-103-20876-00-00
Initial BOP test to 5000 psig; subsequent BOP test to 4000 psig
Annular preventer test to 2500 psig
Waiver for CPAI Rotary Rig BOPE Test Frequency applies according to order OTH-21-018 extension attached
Intermediate I cement evaluation may use SonicScope under the attached Conditions of Approval
Surface casing LOT to the AOGCC as soon as available.
Results of Sonic required to verify competent cement behind casing
A.Dewhurst 31JAN24
X
($8JLC 2/21/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2024.02.21 13:24:13 -09'00'
02/21/24
02/21/24
ZhdŝƚĂŶϭ
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, Alaska 99510-0360
Telephone 907-276-1215
December 20th, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill Titan 1
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Kuparuk C sand well from an ice pad. The intended spud date for
this well is February 22nd, 2023. The intended rig used to drill the well is Doyon Rig 26.
Titan 1 is planned to be a Kuparuk C sand pilot well. The 13-1/2” surface hole will TD above the C-30 sand and then 10-3/4” casing will be
set and cemented to surface.
The intermediate section will be drilled with a 9-7/8” x 11” under-reamed steerable drilling assembly and will TD ~10’ TVD above the
Kuparuk C sand. A 7-5/8” casing string will be set and cemented from TD to secure the shoe and cover 250’ TVD (which is greater than 500’
MD) above the shoe.
The production interval will be comprised of a 6-3/4” horizontal hole that will be geo-steered in the Kuparuk C sand. The production hole
will be left unlined and a cement plug will be pumped to isolate the reservoir section.
It is requested that a variance to the blowout prevention equipment test frequency under 10 AAC 25.035(e)(10)(A) be granted for a 21-day
BOPE test schedule per the pilot project that Doyon 26 is currently on.
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. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
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:
Matt Nagel, (907) 263-4747 & Matt.B.Nagel@conocophillips.com,
or
Chris Brillon, (907) 265-6120 & Chris.l.Brillon@conocophillips.com
Sincerely,cc:
Titan 1 Well File / Jenna Taylor ATO 1560
David Lee ATO 1726
Chris Brillon ATO 1548
Matt Nagel Andy Mack Kuukpik
Drilling Engineer
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
Titan 1
AOGCC Application for Permit to Drill Document
Table of Contents
1.Well Name (Requirements of 20 AAC 25.005 (f)) .................................................................................... 2
2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) ................................................... 2
3.Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) .......... 2
4.Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) ................................... 3
5.Procedure for Conducting Formation Integrity Tests
(Requirements of 20 AAC 25.005 (c)(5)) ......................................................................................... 4
6.Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ............................. 4
7.Diverter System Information (Requirements of 20 AAC 25.005(c)(7)).................................... 4
8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .............................................. 5
9.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ..... 5
10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .................................................... 6
11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ................................... 6
12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) .............................................. 6
13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) .................................... 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7
(Requirements of 20 AAC 25.005 (c)(14)) ....................................................................................... 8
15. Attachments ............................................................................................................. 8
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Property Plat
Attachment 5 Directional Plan
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as CRU Titan 1.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface (Titan 1 Slot) 481’ FSL, 2451’ FEL, Sec 17, T12N, R4E
NAD 27
Northings: 5992980
Eastings: 355247
RKB Elevation 64.5’ AMSL
Pad Elevation 10’ AMSL
Location at Productive Horizon (Heel) 2385’ FSL, 1063’ FEL, Sec 13, T12N, R3E
NAD 27
Northings: 5995057
Eastings: 346580
Measured Depth, RKB: 12,953’
Total Vertical Depth, RKB: 7,255’
Total Vertical Depth, SS: 7,190’
Location at Total Depth (Toe) 4878’ FSL, 4776’ FEL, Sec 30, T12N, R4E
NAD 27
Northings: 5986969
Eastings: 347544
Measured Depth, RKB: 21,114’
Total Vertical Depth, RKB: 7,290’
Total Vertical Depth, SS: 7,225’
Requirements of 20 AAC 25.050(b)
Please see Attachment 5: Titan 1 wp08.1 Directional Plan
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP and diverter schematics on file for Doyon 26.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
4.Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4))
The following shows the calculation results of anticipated surface pressure (ASP) while drilling this well:
Casing Size
(in)
Casing Set Depth
MD/TVD (ft)
Fracture
Gradient
(ppg)
Pore
Pressure
(psi)
ASP Drilling
(psi)
20 135 / 135 10.9 50 63
10-3/4 2,817 / 2,423 14.5 1,066 2,533
7-5/8 12,907 / 7,238 14.2 3,257 3,812
Open Hole 21,114 / 7,274 14.2 4,539 N/A
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP 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:
1) ASP = [(FG x 0.052) - 0.1] x D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb/gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.44psi/ft x TVD above HRZ & 0.45psi/ft below HRZ unless otherwise specified
(A)ASP Calculations Per Interval
1.Drilling Below 20” Conductor:
ASP = [(FG x 0.052) – 0.1] x D
= [(10.9x 0.052) – 0.1] x 135 = 63psi
OR
ASP = FPP – (0.1 x D)
= 1,066 – (0.1 x 2,423) = 823 psi
2.Drilling Below 10-3/4” Surface Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(13.5 x 0.052) – 0.1] x 2,423’ = 1,459 psi
OR
ASP = FPP – (0.1 x D)
= 3,257 – (0.1 x 7,238’) = 2,533 psi
-A.Dewhurst 31JAN24
4,539
7,290'
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
3. Drilling Below 7-5/8” Intermediate Casing
ASP = [(FG x 0.052) – 0.1] x D
= [(14.5 x 0.052) – 0.1] x 7,238 = 4,733 psi
OR
ASP = FPP – (0.1 x D)
= 4,539 – (0.1 x 7,274) = 3,812 psi
Note: 12.0ppg Kuparuk C Pressure
(B) data on potential gas zones;
The well bore is not expected to penetrate any hydrates nor gas zones.
(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 Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 (c)(5))
Drill out casing or liner shoe and perform LOT or FIT in accordance with the COP ERD LOT / FIT
procedure that ConocoPhillips Alaska has on file with the Commission.
6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing Program: Specifications Top Bottom Cement Quantity, sacks
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 154.3 X52 Welded 82 53 53 135 135 13 yds
13.5" 10.75" 45.5 L-80 TXP 2764 53 53 2817 2423 1055sx 11 ppg & 275sx
15.8 ppg
9.875”
x 11” 7.625" 29.7 L-80 H563/
TXP 12854 53 53 12907 7238
300sx 15.8 ppg Class G
(TOC 250’TVD above
casing shoe)
6.75" N/A N/A N/A N/A 7669 12854 7238 21114 7274 Open Hole
7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7))
A diverter will be rigged up while drilling the surface hole as per 20 AAC 25.035 (h)(2)
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in 13-1/2 9-7/8 x 11 6-3/4
Casing
Size in 10-3/4 7-5/8 N/A
Density ppg 10.5 10.0 - 11.0 10.5 - 12.2
PV cP 9 – 10 10-15 20-30
YP
lb./
100
ft2
45 – 50 25 – 30 30-40
Initial
Gels
lb./
100
ft2
46 15 10
10
Minute
Gels
lb./
100
ft2
48 25 13
API Fluid
Loss
cc/
30
min
< 10 < 10 NA
pH 9.5-10.8 9.5-10 NA
Surface Hole:
The Surface interval will be drilled with a mixed-metal oxide freshwater drilling fluid (DRILPLEX WBM).
Keep flow line viscosity at r 200 sec/qt while drilling and running casing. Reduce viscosity prior to
cementing. Maintain mud weight 10.0ppg through the base of Permafrost and increase to 10.5 ppg prior
to TD. Control LGS using solids control system and dilutions where necessary.
Intermediate:
The Intermediate interval will be drilled with a fresh water gel / polymer drilling fluid (FWP WBM). Ensure
good hole cleaning by maximizing fluid annular velocity and rotary speed. Maintain mud weight at 10.0 –
11.0ppg for instability. MPD maybe be used to prevent cycling on the formation. Good filter cake quality,
hole cleaning and maintenance of low gravity drill solids (by diluting as required) will all be important in
maintaining good hole conditions.
Production Hole:
The Production interval will be drilled with an inhibitive mineral oil based drilling fluid (VersaClean).
Maintain mud weight 10.5 – 12.2ppg so that MPD can provide dynamic overbalance of ~12.2ppg EMW
while reducing the risk of lost circulation created by high ECDs. Ensure good hole cleaning by maximizing
fluid annular velocity. Good filter cake quality, hole cleaning, and maintenance of low gravity drill solids
(by diluting as required) will all be important in maintaining good hole conditions.
Please reference pit diagram on file for Doyon 26. All drilling fluid practices will be in accordance with
appropriate regulations stated in 20 AAC 25.033.
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.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
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.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13))
The proposed drilling program is listed below. Please refer to Completion Schematic.
1. Install landing ring on conductor on existing 20” conductor. Conductor set at 135’ RKB.
2. Move in / rig up Doyon Rig 26 on conductor.
3. Pick up 5-7/8” DP and prepare surface drilling fluid.
4. Spud and directionally drill 13-1/2” hole to casing point at +/-2,817’ MD / 2,423’ TVD as per directional plan.
Run MWD / LWD logging tools (LMWD Program: GR/DIR) in drill string as required for directional
monitoring and formation data gathering.
5. Run and cement new 10-3/4" 45.5# L-80 TXP casing to surface. Adequate excess cement will be pumped to
ensure cement returns to the surface.
6. Install wellhead and test to 1000 psi. Nipple up BOPE with the following equipment/configuration:
a. 18-5/8” Annular / Upper 3-1/2” x 6-5/8” VBR / Blind/Shear Ram / Lower 3-1/2” x 6-5/8” VBR
7. Test BOPE to 250 psi low / 5,000 psi high. Test annular to 250 psi low / 3,500 psi high. (Provide 48 hr.
AOGCC notice)
a. This test pressure meets the requirements for the 21 day pressure testing cycle which requires an
initial pressure test to full working pressure of the BOPE. All subsequent tests will be performed to
250 psi low / 4,000 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi. If the 21
day pressure testing cycle is not granted then the initial pressure test will be performed to 250 psi low /
4,000 psi for the BOPE and the annular will be tested to 250 psi low / 2,500 psi.
8. Test casing to 3500 psi for 30min.
9. PU 9-7/8” x 11” rotary steerable drilling assembly. Run MWD / LWD logging tools in drill string as required
for directional monitoring and formation data gathering.
10. Drill out cement and 20' new hole. Perform FIT to 13.5 ppg EMW minimum.
11. Install Managed Pressure Drilling (MPD) bearing assembly and displace to 11 ppg
12. Directionally drill 9-7/8” x 11” hole to casing point at +/-12,907’ MD / 7,238’ TVD, landing ~10’ TVD above
the Kuparuk C Sand. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering.
13. Circulate wellbore clean and strip out of the hole to surface.
14. Change upper pipe rams to 7-5/8” solid body and test same to 3,500 psi.
15. Rig up and run new 7-5/8” 29.7# L-80 HYD563/TXP casing.
16. Rig up and pump cement as per program. Displace cement with mud, check floats upon bumping plug. Top of
cement to be +/-12,183’ MD / 6,988’ TVD which is 250’ TVD above the intermediate casing shoe.
17. Change upper pipe rams to 3-1/2” x 6-5/8” VBR’s
18. Test BOPE to 250 psi low / 4,000 psi high. Test annular to 250 psi low / 2,500 psi high) (24 hr. AOGCC
notice.)
19. Test casing to 4000 psi for 30min.
20. Pick up 6-3/4” Bit and rotary steerable drilling assembly and RIH and clean out cement to top of float
equipment.
21. Drill out cement and 20' of new hole. Perform FIT to a minimum of 13 ppg EMW. Displace to 11 ppg NAF
drilling fluid.
22. Directionally drill 6-3/4” hole into the Kuparuk C Sand to TD at +/- 21,114’ MD / 7,274’ TVD using MPD as
per directional plan. Run MWD/LWD logging tools (LMWD Program: GR/RES/DEN/NEU/SON/DIR) in drill
string as required for directional monitoring and formation data gathering. Run Sonic log for 7-5/8” liner TOC
and report to AOGCC once it’s available.
23. Circulate well clean and displace to KW fluid and observe well for flow.
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
24. Strip out of hole and lay down BHA.
25. A sundry will be submitted for on-rig P&A operations.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Drill cuttings and drilling mud form the well will be disposed of by hauling to Alpine injection facility where they
will be disposed by injecting to approved Class I or Class II Disposal wells.
15. Attachments
Attachment 1 Cement Summary
Attachment 2 Drilling Hazards Summary
Attachment 3 Completion Schematic
Attachment 4 Directional Plan
AOGCC Application for Permit to Drill, Well Titan 1
Saved: 19-Dec-23
Titan 1 AOGCC APD
Printed: 19-Dec-23
Attachment 1 – Cement Summary
10-3/4” Surface Casing to 2,817’ MD / 2,423’ TVD
Cement from 2,817’ to 2,317' MD (500’) with 15.8ppg Class G tail and from 2,317' to surface with 11.0ppg
DeepCRETE lead. Assume 250% excess annular volume in Permafrost, 50% excess below the Permafrost, and
no excess within the 20” conductor.
Lead Slurry from 2,248’ MD to Surface with 11.0ppg DeepCRETE
Conductor (135’ – 53’) X 1.364 ft3/ft X 1.0 (0% excess) = 112 ft3
Permafrost to Conductor (1,129’ – 135’) X 0.3639 ft3/ft X 3.5 (250% excess) = 1,266 ft3
Top of Tail to Permafrost (2,317’ – 1,129’) X 0.3639 ft3/ft X 1.5 (50% excess) = 648 ft3
Total Volume = 112 + 1,266 + 648 = 2,026 ft3 => 1055 sx of 11.0ppg DeepCRETE @ 1.92 ft3 /sk
Tail Slurry from 2,817’ MD to 2,317’ MD with 15.8ppg Class G + additives
Shoe to Top of Tail (2,817’ – 2,317) X 0.364 ft3/ft X 1.50 (50% excess) = 273 ft3
Shoe Joints (90’) X 0.539 ft3/ft X 1.00 (0% excess) = 49 ft3
Total Volume = 273 + 49 = 322 ft3 => 275 sx of 15.8ppg Class G + additives @ 1.17 ft3/sk
7-5/8” Intermediate Casing to 12,907’ MD / 7,238’ TVD
Cement from 12,907’ to 250’ TVD above the casing shoe with 15.8ppg Class G assuming 40% excess annular
volume.
Tail slurry from 12,907’ MD to 12,183’ MD with 15.8 ppg Class G + additives
11” Hole to Top of Cement (12,797’ – 12,183’) x 0.3431 ft3/ft x 1.4 (40% excess) = 295 ft3
Shoe to top of 9-7/8” Hole (12,907’ – 12,797’) x 0.2148 ft3/ft x 1.4 (40% excess) = 33 ft3
Shoe Track (80’) x 0.2577 ft3/ft x 1.0 (0% excess) = 20 ft3
Total Volume = 295 + 33 + 20 = 348 ft3 => 300 sx of 15.8ppg Class G + additives @ 1.16 ft3/sk
Attachment 2 Titan Drilling Hazards
Summary
13-1/2" Hole / 10-3/4” Casing Interval
Event Risk Level Mitigation Strategy
Gas Hydrates Low
Diverter drills and if observed – control drill, reduce pump
rates and circulating time, reduce mud temperatures. Shallow
hazard study noted minimal risk on ice pad.
Abnormal Pressure in Surface
Formations Low Diverter drills, increased mud weight. Shallow hazard study
noted minimal risk on ice pad
Abnormal Pressure in C-30
(CD2 Annular Injection) Low
Top-set C-30 formation. No annular injection performed in the
area nor abnormal pressure encountered in C-30 on CD2-162
/ CD2-310/ CD2-361
Clay Balling High Maintain planned mud parameters and flow rates. Use
proactive anti-balling sweeps and mud product additions.
9-7/8” x 11” Hole / 7-5/8” Casing Interval
Event Risk Level Mitigation Strategy
Lost Circulation High
Reduce pump rates, reduce trip speeds, real time ECD
monitoring, mud rheology, add lost circulation material as
needed. Use MPD to reduce ECDs.
Swabbing on Trips Medium
Reduce trip speeds, condition mud properties, proper hole
filling, pump out of hole, real time ECD monitoring, & use MPD
if possible.
Abnormal Reservoir Pressure High
Well control drills, flow check during connections, use MPD to
fingerprint / provide dynamic overbalance, increase mud
weight as needed to maintain overbalance during tripping
activities.
Wellbore Instability High
Employ CD2-162 and CD2-310 instability mitigations
(underreamer, proper EMW to prevent shear failure, MPD),
monitor real-time drilling data. Use CPAI Lower Shale
instability mitigation drilling best practices.
6-3/4” Open Hole Production Interval
Event Risk Level Mitigation Strategy
Lost Circulation Medium
Reduce pump rates, reduce trip speeds, real time ECD
monitoring, mud rheology, add lost circulation material as
needed. Use MPD to reduce ECDs.
Swabbing on Trips Medium
Reduce trip speeds, condition mud properties, proper hole
filling, pump out of hole, real time ECD monitoring, & use MPD
if possible.
Abnormal Reservoir Pressure High
Well control drills, flow check during connections, use MPD to
fingerprint / provide dynamic overbalance, increase mud
weight as needed to maintain overbalance during tripping
activities.
Wellbore Instability High
Employ CD2-162 and CD2-310 instability mitigations (proper
EMW to prevent shear failure, MPD, & inhibited fluid), monitor
real-time drilling data. Use CPAI Lower Shale instability
mitigation drilling best practices.
6-3/4" Open Hole TD
21,114' MD / 7274' TVD
20" Conductor to 135'
Kuparuk C Sand Top
~12953' MD / ~7247' TVD
Titan, FWK Pilot – Horizontal
Proposed Schematic updated 11/16/23, D26, RKB 54.5 ft, wp08.1
13-1/2" Open Hole with
10-3/4" 45.5 ppf L-80 TXP
2,817' MD / 2,423' TVD
Kalubik
12558' MD / 7137' TVD
9-7/8" X 11" Underreamed Openhole with
Top Set Casing
~4000' 7-5/8" 29.7 ppf L-80 HYD563
7-5/8" 29.7 ppf L-80 TXP
12,907' MD / 7238' TVD @ 77°
C30 Sand Top
2894' MD / 2462' TVD
HRZ Top
12236' MD / 7011' TVD
TOC @ 12,183' MD
10.5 PPG DRILPLEX
11.0 PPG FWP
11 PPG NAF
ADL388466
ADL380095
ADL390344
ASRC-NPR2
ADL390350
ADL388463
ASRC-NPR1
ADL390348
ADL388465
ADL388904
ADL387211
ADL390345
ADL
14
24
28
11
18
32
29
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35
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1
7 8
17
26
20
33
21
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19
5 4
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31
6
CHAR 1 TEMPTATION 1
TEMPTATION
1A
IAPETUS 2
C
D
2
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5
9
C
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2
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1
CD
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0
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1
8
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2
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9
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CD2-7
3
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1
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2
1
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1
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0
7
C
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1
0
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C
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-
0
3
C
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2
-
7
4
C
D
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-
9
2
C
D
5
-
0
2
A
C
D
2
-
0
2
C
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-
1
2
C
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-
7
2
C
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3
6
1
C
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5
-
2
2
C
D
5
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0
9
CD
2
-
7
3
C
D
5
-
2
3
C
D
2
-
3
1
0
k11/13/2023
010.5
Miles
Titan 1
PTD Map
Open Interval
Well Trajectory
Existing Well
Exploration Well BHL
Unit Boundary
CPAI Lease
Tita
n
1
CD5 CD2
PIKKA
UNIT
COLVILLE
RIVER UNIT
GREATER
MOOSES
TOOTH UNIT
QUOKKA
UNIT
56 500
500 1000
1000 1500
1500 2000
2000 3000
3000 5000
5000 10000
10000 12000
12000 14000
14000 21115
Titan 1 wp08.1 Plan Summary
0
3
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0 3000 6000 9000 12000 15000 18000 21000
Measured Depth
10-3/4" Surface Casing
7-5/8" Intermediate Casing
200.0
200.0
400.0
400.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [400 usft/in]
122981227112245122211219912177121571213812119121001208612070
12055
12041 CD2-305 wp19
3750
Tr
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-7000 -6000 -5000 -4000 -3000 -2000 -1000 0
Vertical Section at 140.00°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
-100
0
100
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-83 -55 -28 0 28 55 83
Measured Depth
DDI
7.222
SURVEY PROGRAM
Date: 2021-02-01T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
55.50 400.00 Titan 1 wp08.1 (Titan 1) SDI_URSA1_I4
400.00 2810.00 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
2810.00 12900.00 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
12900.00 21113.98 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
Ground / 10.00
CASING DETAILS
TVD MD Name
2423.50 2817.66 10-3/4" Surface Casing
7237.50 12904.67 7-5/8" Intermediate Casing
7290.31 21113.98 0" Production Open Hole
Mag Model & Date: BGGM2023 01-Mar-24
Magnetic North is 13.93° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.59° 57130.05nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 55.50 0.00 0.00 55.50 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 298.00 499.96 1.64 -3.08 1.00 298.00 -3.24 Start Build 2.00
4 700.00 6.00 298.00 699.43 8.19 -15.40 2.00 0.00 -16.17 Start DLS 2.50 TFO -4.93
5 2922.39 61.54 293.38 2475.49 488.57 -1101.10 2.50 -4.93 -1082.04 Start 7279.04 hold at 2922.39 MD
610201.43 61.54 293.38 5944.40 3027.68 -6975.11 0.00 0.00 -6802.85 Start DLS 3.50 TFO -109.67
712285.55 65.00 210.00 7032.50 2500.00 -8500.00 3.50 -109.67-7378.81 Start DLS 3.50 TFO -61.26
812899.61 76.50 190.70 7236.33 1959.30 -8696.88 3.50 -61.26 -7091.15 Start DLS 6.00 TFO -30.00
913200.77 92.25 181.77 7265.81 1662.57 -8728.98 6.00 -30.00 -6884.49 Start 160.00 hold at 13200.77 MD
1013360.77 92.25 181.77 7259.53 1502.77 -8733.92 0.00 0.00 -6765.25 Start DLS 6.00 TFO -105.95
11 13541.48 89.25 171.35 7257.16 1322.67 -8723.09 6.00 -105.95 -6620.32 Start 1490.00 hold at 13541.48 MD
1215031.48 89.25 171.35 7276.67 -150.25 -8499.02 0.00 0.00 -5347.96 Start Build 6.00
1315077.31 92.00 171.35 7276.17 -195.56 -8492.13 6.00 0.00 -5308.83 Start 210.00 hold at 15077.31 MD
1415287.31 92.00 171.35 7268.84 -403.04 -8460.56 0.00 0.00 -5129.60 Start Drop -6.00
1515370.65 87.00 171.35 7269.56 -485.40 -8448.03 6.00 180.00 -5058.45 Start 250.00 hold at 15370.65 MD
1615620.65 87.00 171.35 7282.65 -732.22 -8410.49 0.00 0.00 -4845.25 Start Build 6.00
1715720.65 93.00 171.35 7282.65 -831.03 -8395.45 6.00 0.00 -4759.88 Start 170.00 hold at 15720.65 MD
1815890.65 93.00 171.35 7273.75 -998.87 -8369.92 0.00 0.00 -4614.90 Start Drop -6.00
1915943.98 89.80 171.35 7272.45 -1051.57 -8361.90 6.00 180.00 -4569.37 Start 570.00 hold at 15943.98 MD
2016513.98 89.80 171.35 7274.44 -1615.09 -8276.18 0.00 0.00 -4082.59 Start Build 6.00
21 16550.65 92.00 171.35 7273.86 -1651.33 -8270.66 6.00 0.00 -4051.29 Start 240.00 hold at 16550.65 MD
2216790.65 92.00 171.35 7265.49 -1888.46 -8234.59 0.00 0.00 -3846.45 Start Drop -6.00
2316873.98 87.00 171.35 7266.21 -1970.81 -8222.06 6.00 180.00 -3775.31 Start 300.00 hold at 16873.98 MD
2417173.98 87.00 171.35 7281.91 -2266.99 -8177.00 0.00 0.00 -3519.46 Start Build 6.00
2517273.98 93.00 171.35 7281.91 -2365.81 -8161.97 6.00 0.00 -3434.10 Start 130.00 hold at 17273.98 MD
2617403.98 93.00 171.35 7275.11 -2494.16 -8142.45 0.00 0.00 -3323.23 Start Drop -6.00
2717441.48 90.75 171.35 7273.88 -2531.21 -8136.81 6.00 180.00 -3291.22 Start 700.00 hold at 17441.48 MD
2818141.48 90.75 171.35 7264.72 -3223.19 -8031.54 0.00 0.00 -2693.47 Start Build 6.00
2918178.98 93.00 171.35 7263.49 -3260.24 -8025.90 6.00 0.00 -2661.46 Start 90.00 hold at 18178.98 MD
3018268.98 93.00 171.35 7258.78 -3349.09 -8012.39 0.00 0.00 -2584.71 Start Drop -6.00
31 18368.98 87.00 171.35 7258.78 -3447.91 -7997.35 6.00 180.00 -2499.35 Start 200.00 hold at 18368.98 MD3218568.98 87.00 171.35 7269.25 -3645.36 -7967.31 0.00 0.00 -2328.78 Start Build 6.00
3318668.98 93.00 171.35 7269.25 -3744.18 -7952.28 6.00 0.00 -2243.42 Start 140.00 hold at 18668.98 MD
3418808.98 93.00 171.35 7261.92 -3882.40 -7931.25 0.00 0.00 -2124.02 Start Drop -6.00
3518879.81 88.75 171.35 7260.84 -3952.40 -7920.60 6.00 180.00 -2063.55 Start 600.00 hold at 18879.81 MD
3619479.81 88.75 171.35 7273.93 -4545.44 -7830.39 0.00 0.00 -1551.27 Start Build 6.00
3719550.65 93.00 171.35 7272.85 -4615.44 -7819.74 6.00 0.00 -1490.80 Start 60.00 hold at 19550.65 MD
3819610.65 93.00 171.35 7269.71 -4674.68 -7810.73 0.00 0.00 -1439.63 Start Drop -6.00
3919710.65 87.00 171.35 7269.71 -4773.49 -7795.69 6.00 180.00 -1354.27 Start 220.00 hold at 19710.65 MD
4019930.65 87.00 171.35 7281.22 -4990.69 -7762.65 0.00 0.00 -1166.64 Start Build 6.00
4120022.31 92.50 171.35 7281.62 -5081.28 -7748.87 6.00 0.00 -1088.39 Start 150.00 hold at 20022.31 MD
4220172.31 92.50 171.35 7275.08 -5229.43 -7726.33 0.00 0.00 -960.41 Start Drop -6.00
4320207.31 90.40 171.35 7274.19 -5264.02 -7721.07 6.00 180.00 -930.53 Start 500.00 hold at 20207.31 MD
4420707.31 90.40 171.35 7270.70 -5758.32 -7645.87 0.00 0.00 -503.54 Start Drop -6.004520763.98 87.00 171.35 7271.99 -5814.32 -7637.35 6.00 180.00 -455.17 Start 350.00 hold at 20763.98 MD
4621113.98 87.00 171.35 7290.31 -6159.87 -7584.79 0.00 0.00 -156.67 TD at 21113.98
FORMATION TOP DETAILS
TVDPath Formation
1119.50 Base Frozen Sand
1314.50 Base Permafrost
2211.50 C40
2463.50 C30
2766.50 C20
2980.50 C10
3875.50 K3
4054.50 Top Qannik
4099.50 Base Qannik
4388.50 Albian 97
5054.50 Albian 96
5958.50 Albian 95
7011.50 HRZ FCS
7069.50 HRZ insitu
7137.50 Kalubik
7172.50 K1
7247.50 KupC
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 10+1.5+54 @ 65.50usft (D26)
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0°
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62°
90°
89°
92 °
87°
90°92°
87°
91°
87°
89°
87°
90°
87°
Titan 1wp08.1
Ba
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0450900135018002250
Partial Measured Depth
Titan 1 wp08.1 Ladder View
0
150
300
Ce
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12000 12750 13500 14250 15000 15750 16500
Measured Depth
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
55.50 400.00 Titan 1 wp08.1 (Titan 1) SDI_URSA1_I4
400.00 2810.00 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
2810.00 12900.00 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
12900.00 21113.98 Titan 1 wp08.1 (Titan 1) MWD+IFR2+SAG+MS
11:50, November 07 2023
CASING DETAILS
TVD MD Name
2423.50 2817.66 10-3/4" Surface Casing
7237.50 12904.67 7-5/8" Intermediate Casing
7290.31 21113.98 0" Production Open Hole
56 500
500 1000
1000 1500
1500 2000
2000 3000
3000 5000
5000 10000
10000 12000
12000 14000
14000 21115
Titan 1 wp08.1 TC View
75
75
150
150
225
225
300
300
375
375
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [150 usft/in]
12298
12271
12245
12221
12199
12177
12157
12138
12119
12100
12086
12070
12055CD2-305 wp19
SURVEY PROGRAM
Date: 2021-02-01T00:00:00 Validated: Yes Version:
From To Tool
55.50 400.00 SDI_URSA1_I4
400.00 2810.00 MWD+IFR2+SAG+MS
2810.00 12900.00 MWD+IFR2+SAG+MS
12900.00 21113.98 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
2423.50 2817.66 10-3/4" Surface Casing
7237.50 12904.67 7-5/8" Intermediate Casing
7290.31 21113.98 0" Production Open Hole
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 55.50 0.00 0.00 55.50 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.00
3 500.00 2.00 298.00 499.96 1.64 -3.08 1.00 298.00 -3.24 Start Build 2.00
4 700.00 6.00 298.00 699.43 8.19 -15.40 2.00 0.00 -16.17 Start DLS 2.50 TFO -4.93
5 2922.39 61.54 293.38 2475.49 488.57 -1101.10 2.50 -4.93 -1082.04 Start 7279.04 hold at 2922.39 MD
610201.43 61.54 293.38 5944.40 3027.68 -6975.11 0.00 0.00 -6802.85 Start DLS 3.50 TFO -109.67
712285.55 65.00 210.00 7032.50 2500.00 -8500.00 3.50 -109.67-7378.81 Start DLS 3.50 TFO -61.26
812899.61 76.50 190.70 7236.33 1959.30 -8696.88 3.50 -61.26 -7091.15 Start DLS 6.00 TFO -30.00
913200.77 92.25 181.77 7265.81 1662.57 -8728.98 6.00 -30.00 -6884.49 Start 160.00 hold at 13200.77 MD
1013360.77 92.25 181.77 7259.53 1502.77 -8733.92 0.00 0.00 -6765.25 Start DLS 6.00 TFO -105.95
11 13541.48 89.25 171.35 7257.16 1322.67 -8723.09 6.00 -105.95 -6620.32 Start 1490.00 hold at 13541.48 MD
1215031.48 89.25 171.35 7276.67 -150.25 -8499.02 0.00 0.00 -5347.96 Start Build 6.00
1315077.31 92.00 171.35 7276.17 -195.56 -8492.13 6.00 0.00 -5308.83 Start 210.00 hold at 15077.31 MD
1415287.31 92.00 171.35 7268.84 -403.04 -8460.56 0.00 0.00 -5129.60 Start Drop -6.00
15 15370.65 87.00 171.35 7269.56 -485.40 -8448.03 6.00 180.00 -5058.45 Start 250.00 hold at 15370.65 MD
1615620.65 87.00 171.35 7282.65 -732.22 -8410.49 0.00 0.00 -4845.25 Start Build 6.00
1715720.65 93.00 171.35 7282.65 -831.03 -8395.45 6.00 0.00 -4759.88 Start 170.00 hold at 15720.65 MD
1815890.65 93.00 171.35 7273.75 -998.87 -8369.92 0.00 0.00 -4614.90 Start Drop -6.00
1915943.98 89.80 171.35 7272.45 -1051.57 -8361.90 6.00 180.00 -4569.37 Start 570.00 hold at 15943.98 MD
2016513.98 89.80 171.35 7274.44 -1615.09 -8276.18 0.00 0.00 -4082.59 Start Build 6.00
21 16550.65 92.00 171.35 7273.86 -1651.33 -8270.66 6.00 0.00 -4051.29 Start 240.00 hold at 16550.65 MD
2216790.65 92.00 171.35 7265.49 -1888.46 -8234.59 0.00 0.00 -3846.45 Start Drop -6.00
2316873.98 87.00 171.35 7266.21 -1970.81 -8222.06 6.00 180.00 -3775.31 Start 300.00 hold at 16873.98 MD
2417173.98 87.00 171.35 7281.91 -2266.99 -8177.00 0.00 0.00 -3519.46 Start Build 6.00
2517273.98 93.00 171.35 7281.91 -2365.81 -8161.97 6.00 0.00 -3434.10 Start 130.00 hold at 17273.98 MD
2617403.98 93.00 171.35 7275.11 -2494.16 -8142.45 0.00 0.00 -3323.23 Start Drop -6.00
2717441.48 90.75 171.35 7273.88 -2531.21 -8136.81 6.00 180.00 -3291.22 Start 700.00 hold at 17441.48 MD
2818141.48 90.75 171.35 7264.72 -3223.19 -8031.54 0.00 0.00 -2693.47 Start Build 6.00
2918178.98 93.00 171.35 7263.49 -3260.24 -8025.90 6.00 0.00 -2661.46 Start 90.00 hold at 18178.98 MD3018268.98 93.00 171.35 7258.78 -3349.09 -8012.39 0.00 0.00 -2584.71 Start Drop -6.00
31 18368.98 87.00 171.35 7258.78 -3447.91 -7997.35 6.00 180.00 -2499.35 Start 200.00 hold at 18368.98 MD
3218568.98 87.00 171.35 7269.25 -3645.36 -7967.31 0.00 0.00 -2328.78 Start Build 6.00
3318668.98 93.00 171.35 7269.25 -3744.18 -7952.28 6.00 0.00 -2243.42 Start 140.00 hold at 18668.98 MD
3418808.98 93.00 171.35 7261.92 -3882.40 -7931.25 0.00 0.00 -2124.02 Start Drop -6.00
3518879.81 88.75 171.35 7260.84 -3952.40 -7920.60 6.00 180.00 -2063.55 Start 600.00 hold at 18879.81 MD
3619479.81 88.75 171.35 7273.93 -4545.44 -7830.39 0.00 0.00 -1551.27 Start Build 6.00
3719550.65 93.00 171.35 7272.85 -4615.44 -7819.74 6.00 0.00 -1490.80 Start 60.00 hold at 19550.65 MD
3819610.65 93.00 171.35 7269.71 -4674.68 -7810.73 0.00 0.00 -1439.63 Start Drop -6.00
3919710.65 87.00 171.35 7269.71 -4773.49 -7795.69 6.00 180.00 -1354.27 Start 220.00 hold at 19710.65 MD
4019930.65 87.00 171.35 7281.22 -4990.69 -7762.65 0.00 0.00 -1166.64 Start Build 6.00
4120022.31 92.50 171.35 7281.62 -5081.28 -7748.87 6.00 0.00 -1088.39 Start 150.00 hold at 20022.31 MD
4220172.31 92.50 171.35 7275.08 -5229.43 -7726.33 0.00 0.00 -960.41 Start Drop -6.004320207.31 90.40 171.35 7274.19 -5264.02 -7721.07 6.00 180.00 -930.53 Start 500.00 hold at 20207.31 MD
4420707.31 90.40 171.35 7270.70 -5758.32 -7645.87 0.00 0.00 -503.54 Start Drop -6.00
4520763.98 87.00 171.35 7271.99 -5814.32 -7637.35 6.00 180.00 -455.17 Start 350.00 hold at 20763.98 MD
4621113.98 87.00 171.35 7290.31 -6159.87 -7584.79 0.00 0.00 -156.67 TD at 21113.98
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Titan 1wp08.1 Surface Location
Titan 1wp08.1 Surface Location
# Schlumberger-Confidential
Titan 1wp08.1 Surface Casing
Titan 1wp08.1 Surface Casing
# Schlumberger-Confidential
Titan 1wp08.1 Intermediate Csg
Titan 1wp08.1 Intermediate Csg
# Schlumberger-Confidential
Titan 1wp08.1 Top Kup C
Titan 1wp08.1 Top Kup C
# Schlumberger-Confidential
Titan 1wp08.1 TD
Titan 1wp08.1 TD
# Schlumberger-Confidential
1
Dewhurst, Andrew D (OGC)
From:Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Sent:Wednesday, January 31, 2024 13:14
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Roby, David S (OGC); Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]CRU Titan-1 (PTD 223-128) - Questions
Follow Up Flag:Follow up
Flag Status:Completed
Hi Andy,
Please see my notes in red below.
Thank you
Matt Nagel
Drilling Engineer
ConocoPhillips Alaska
Office: 907-263-4747
Cell: 281-615-3922
Matt.B.Nagel@ConocoPhillips.com
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, January 31, 2024 11:05 AM
To: Nagel, Matt B <Matt.B.Nagel@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby,
David S (OGC) <dave.roby@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Subject: [EXTERNAL]CRU Titan-1 (PTD 223-128) - Questions
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.
MaƩ,
I am compleƟng the review of the CRU Titan-1 PTD and have a few quesƟons:
x This PTD is classiĮed as a development well, but it is described as a pilot hole. Would you explain why this would
not be an exploratory well? Is the purpose of the well to delineate the pool?
Titan 1 is targeƟng a known and producing reservoir with the intent to reduce uncertainty on reservoir
thickness and quality in order to ascertain if further economic development is available.
x Would you conĮrm the TVD of 7,290’ at TD; I believe there is a typo in secƟon 4:
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2
You’re correct. TVD is 7,290’
x Would you please conĮrm the anƟcipated pore pressure in the Kuparuk C target of 12 ppg EMW?
Correct. AnƟcipated pore pressure in the Kuparuk C is 12.0 ppg EMW.
x Do you anƟcipate H2S at this locaƟon? Would you please provide informaƟon on the nearest/most relevant
locaƟons that have (or have not) encountered H2S? And would you conĮrm that the operaƟon will meets the
requirements under 20AAC 25.065(c)?
No, we do not anƟcipate H2S at this locaƟon. Closest oīset wells are Char 1, Iapetus 2, TemptaƟon 1
and 1A. There was no H2S observed while drilling any of those wells. Yes, we will meet all the
requirements under 20AAC 25.065(c).
x Would you conĮrm the KB elevaƟon? There is a minor discrepancy between what is listed on the 10-401 and the
direcƟonal plan.
Ground level is anƟcipated to be 10’ with an esƟmated ice thickness of 1.5’ which is causing the
discrepancy. RKB will be updated once an as built is survey is available upon comple Ɵon of the ice pad.
x And just a reminder that an “as-built” survey will need to be provided before well compleƟon or abandonment
as per 20 AAC 25.070(2).
Yessir. An as-built will be provided.
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
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
223-128
ALPINE OIL POOLCOLVILLE RIVER
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AD
L
3
8
8
4
6
6
,
A
D
L
3
8
8
4
6
3
,
A
S
R
C
-
N
P
R
1
,
a
n
d
AS
R
C
-
N
P
R
2
2
Le
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
Un
i
q
u
e
w
e
l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
CO
L
V
I
L
L
E
R
I
V
E
R
,
A
L
P
I
N
E
O
I
L
-
1
2
0
1
0
0
-
g
o
v
e
r
n
e
d
b
y
4
4
3
D
4
We
l
l
l
o
c
a
t
e
d
i
n
a
d
e
f
i
n
e
d
p
o
o
l
Ye
s
5
We
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
We
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
Su
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
If
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
Op
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
10
Op
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
11
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
Ca
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
NA
14
We
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
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
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
82
'
c
o
n
d
u
c
t
o
r
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
2
8
1
7
'
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
12
9
%
e
x
c
e
s
s
p
l
a
n
n
e
d
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
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
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
4
5
3
9
p
s
i
g
(
1
2
.
0
p
p
g
E
M
W
)
;
w
i
l
l
d
r
i
l
l
w
/
1
0
/
5
-
1
2
.
2
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
3
8
1
2
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
4
0
0
0
p
s
i
g
s
u
b
s
u
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
a
n
t
i
c
i
p
a
t
e
d
.
O
p
e
r
a
t
i
o
n
w
i
l
l
m
e
e
t
a
l
l
H
2
S
r
e
q
u
i
r
e
m
e
n
t
s
i
n
r
e
g
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
Re
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
a
n
t
i
c
i
p
a
t
e
d
t
o
b
e
1
2
p
p
g
E
M
W
.
M
P
D
t
o
b
e
e
m
p
l
o
y
e
d
i
n
i
n
t
e
r
m
e
d
i
a
t
e
a
n
d
p
r
o
d
u
c
t
i
o
n
h
o
l
e
.
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/
3
1
/
2
0
2
4
Ap
p
r
VT
L
Da
t
e
2/
2
0
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
1/
3
1
/
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
2
/
2
1
/
2
0
2
4
