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HomeMy WebLinkAbout222-152From:Heusser, Heather A (DNR)
To:Guhl, Meredith D (OGC)
Cc:Morgan, Kirk A (DNR)
Subject:RE: ConocoPhillips Bear 1, Extended Confidentiality?
Date:Wednesday, June 4, 2025 12:07:56 PM
Hi Meredith,
Sean Clifton in the Director’s Office confirmed we have not received an extended confidentiality for
Bear 1.
Heather Ann Heusser
Natural Resource Specialist IV
State of Alaska
Department of Natural Resources
Division of Oil and Gas
550 West 7th Avenue, Suite 1100
Anchorage AK 99501-3560
heather.heusser@alaska.gov
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Friday, May 23, 2025 8:58 AM
To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov>
Cc: Morgan, Kirk A (DNR) <kirk.morgan@alaska.gov>
Subject: ConocoPhillips Bear 1, Extended Confidentiality?
Hi Heather,
Has ConocoPhillips Alaska requested extended confidentiality for Bear 1, an exploration well
drilled and abandoned in 2023, which was due for release after May 3, 2025?
Thank you,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska
Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It
may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such
information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without
first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl
at 907-793-1235 or meredith.guhl@alaska.gov.
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T R A N S M I T T A LL
CONFIDENTIALL DATA
FROM:Sandra D. Lemke TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W.7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE:: Bear 1
Permit: 222-152
DATE: 11/27/2023
Transmitted:
North Slope Exploratory
Bear 1
Via SFTP
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: Bear 1 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 222-152
T38147
11/27/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.11.27
15:04:44 -09'00'
T R A N S M I T T A LL
CONFIDENTIALL DATA
FROM:Sandra D. Lemke TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W.7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska
RE:: Bear 1
Permit: 222-152
DATE: 06/01/2023
Transmitted:
North Slope Exploratory
Bear 1
Via SFTP
Drilling and completions – 89.9 MB
Geochem – 494 MB
LWD – 928 MB
Mudlog – 11.5 MB
Samples – 230 KB
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
CC: Bear 1 - e-transmittal well folder
Receipt: Date:
Alaska/IT-Data Services |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
PTD: 222-152
T37684
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2023.06.02
09:14:29 -08'00'
RECEIVED
APR 2 0 2023
SAMPLE TRANSMITTAL
TKO%PP
333 WEST 7T" SUITE 100
ANCH. AK. 99501
279-1433
OPERATOR: CPAI
SAMPLE TYPE: Dry Cuttings
SAMPLES SENT:
Bear 1
130 - 5523
7 Boxes
SENT BY: M. McCRACKEN
DATE: April 20, 2028
AIR BILL: N/A
CPAI: 2023042001
CHARGE CODE: N/A
NAME: Bear 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:
CONOCOPHILLIPS, ALASKA
700 G ST
ATO-380
ANCHORAGE, AK. 99510
ATTN: MIKE McCRACKEN
Mike.mccracken@conocophillips.com
q(7,017,5 VLT�DW.S
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:9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 75.7 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 (ft MSL)
22. Logs Obtained:
LWD: GR, RES, PWD, D-N, D+I (Surface - TD); Sonic (Production Interval); Mudlog (Surface - TD)
23.
BOTTOM
16 A106 102
9 5/8 L80 1319
7 L80 2441
3 1/2 L80 5508
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.None
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
PACKER SET (MD/TVD)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips
WAG
Gas
4/3/2023 222-152 / 323-165
50-287-20035-00-00
Bear 1
ADL 393519
1,894’ FSL and 226’ FWL of Section 1, T06N-R03E
1,894’ FSL and 226’ FWL of Section 1, T06N-R03E
LONS 22-006
3/2/2023
5523 / 5523
5 ft below tundra
97.07
PO Box 100360 Anchorage, AK 99510-0360
337,359.28 5,815,212.55
1,894’ FSL and 226’ FWL of Section 1, T06N-R03E
CASING WT. PER
FT.GRADE
3/23/2023
CEMENTING RECORD
5,815,214.00
907 / 907
SETTING DEPTH TVD
5,815,213.90
TOP HOLE SIZE AMOUNT
PULLED
337,358.10
337,358.30
TOP
SETTING DEPTH MD
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
BOTTOM
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,
9.3
Surface
2020
1319
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
131 bbls, 11 ppg LiteCRETE6 1/8
26
5508
Surface
2020
TUBING RECORD
Lead: 92.2 bbls, 11 ppg
LiteCRETE
Tail: 22.5 bbls, 12 ppg
LiteCRETE
0
8 1/2 0
19793 1/2
SIZE DEPTH SET (MD)
84 bbls 15.7 ppg AS1
24 0
12 1/4
10 yds
Surface Lead: 174.2 bbls, 11 ppg
DeepCRETE
Tail: 60 bbls, 12 ppg
LiteCRETE
0
165
40
102
Surface 2441
Surface
Surface
Gas-Oil Ratio:
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
Sr Res EngSr Pet GeoSr Pet Eng
Exploratory
none
Oil-Bbl:Water-Bbl:
Water-Bbl:
PRODUCTION TEST
Date of Test:Oil-Bbl:
Flow Tubing
G
s d 1
0 p
d B P
L
s
(att
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
CONFIDENTIALSTATE OF ALASKAATE OF ALASKA
By James Brooks at 4:18 pm, Apr 18, 2023
Abandoned
4/3/2023
JSB
RBDMS JSB 050823
GVTL 5/29/2025 DSR-5/22/23SFD 6/4/2025
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
907 907
Schrader Bluff (Mid) 1415 1415
1594 1594
2402 2402
2977 2977
3935 3935
4515 4515
4991 4991
5060 5060
5206 5206
5523 5523
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Brian Noel
Digital Signature with Date:Contact Email:brian.noel@contractor.cop.com
Contact Phone:907-263-4027
Drilling Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
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
K3
Schrader Bluff (Lower)
K2
Authorized Title:
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.
Base of Bear Interval
TPI (Top of Producing Interval).
Authorized Name and
C30
C10
INSTRUCTIONS
Albian 97
Top of Bear Interval
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.
Formation at TD: Torok
N
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
CONFIDENTIAL
Bear 1
Final P&A Schematic
Surface Casing:
9-5/8" 40# L-80 TXPM
Set @ 1,319’ MD / TVD
Cement to surface 3/5/23
Conductor:
16" 165 ppf Welded Conductor
102' MD / TVD
8-1/2" Intermediate Hole
12-1/4" Surface Hole
Production TD:
5.523' MD / TVD
Last Update: 4/13/23 BDN
Bear Target:
5,060' MD / TVD
Intermediate Casing:
7" 26# L-80 TXPM
Set @ 2,241’ MD / TVD
Cement to surface 3/13/23
6-1/8" Production Hole
Upper Abandonment String/Plug:
3-1/2" 9.3# L-80 EUE
Set @ 1,979’ MD / TVD
Landed Out on Tubing Hanger
Cement Circulated Surface to Surface 3/27/23
Lower Abandonment String/Plug:
3-1/2" 9.3# L-80 EUE
Set @ 5,508’ MD / TVD
BHKA Disconnect Tool @ 2,020' MD / TVD
Cement Circulated TD-above BHKA Tool 3/26/23
Tag plug @ 1,997' MD / TVD
Pressure test to 1600 psi 3/27/23
CONFIDENTIAL
Page 9/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
2/26/2023
12:00
2/27/2023
00:00
12.
00
MIRU, MOVE MOB P Secure bridal lines in the derrick. Pick up
and hang torque tube and install lower tee
bar support. Install link tilt and bails.
Install sensor tee on gooseneck and hang
kelly hose. Continue installing 3rd party
sensors and cameras through out the rig.
Continue rigging up tanks for mud
storage.
2P operations-
4ea rolligon loads out of 2-P Ice pad to
Bear. Highlights: 3 ½ tubing, Super
Sucker, MI pallets, pickup
Back Haul pickup, 5ea cement herc pods.
Olgoonik started their 8th day of
operation.
SAE shipped groceries and 2ea loads fuel
2-P to Bear.
Received the 5ea cement pods back from
SLB refilled with cement.
Received KDTH drum warming Conex,
repaired heater and generator.
2/27/2023
00:00
2/27/2023
06:00
6.0
0
MIRU, MOVE MOB P Continue rigging up TDS service loops,
install shaker screens, install flow line and
air up air boots. Nipple up drilling riser,
install koomey lines on surface stack.
2/27/2023
06:00
2/27/2023
12:00
6.0
0
MIRU, MOVE MOB P Terminate electrical lines on the top drive
and hook up hydraulic lines. Function test
TDS. Function test diverter and surface
annular. Build containment for end of
diverter line.
2/27/2023
12:00
2/27/2023
18:00
6.0
0
MIRU, MOVE MOB P Rig up cellar Gorman Rupp pump, fill rod
wash in mud pumps, continue nipple up
surface riser, function test shakers and
auger in the pits and rock washer. Blow
air through kelly line and cement line.
Route and install SLB pressure
transducer cable on the gooseneck.
Install XT39 saver sub on the top drive
2/27/2023
18:00
2/28/2023
00:00
6.0
0
MIRU, MOVE MOB P Perform rig inspection and diverter test
with AOGCC rep Sean Sullivan. Test gas
alarms, perform diverter test. Accumulator
drawdown test. Test start system pressure
3050 psi, pressure after function - 1800
psi, 200 psi recovery 20 seconds, full
system recovery 95 seconds. Nitrogen
backup 6 bottle average - 2250 psi.
Annular closing time 20 seconds, knife
valve open time 1.5 seconds. Tested PVT
sensors and gain loss alarms.
2/28/2023
00:00
2/28/2023
06:00
6.0
0
MIRU, MOVE MOB P Continue building spud mud, hook up
drain lines to the drip pan and skirt. Load
4" drill pipe in the pipe shed, repair light in
derrick, prep MWD and LWD tools in the
pipe shed. Perform post rig up top drive
inspection and wire tie bolts.
2/28/2023
06:00
2/28/2023
12:00
6.0
0
MIRU, MOVE MOB P Continue loading 4" drill pipe in the shed,
perform derrick inspection, load floor of
BHA and drill pipe handling equipment,
repair 4-way valve on koomey.
2/28/2023
12:00
2/28/2023
18:00
6.0
0
MIRU, MOVE MOB P Install 4" elevators, continue working on
rig acceptance checklist, begin picking up
4" drill pipe and racking back in the
derrick.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 10/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
2/28/2023
18:00
3/1/2023 00:00 6.0
0
MIRU, MOVE MOB P Continue picking up 4" drill pipe and
racking back in the derrick (49 stands
total). Replace head unit on gas sensor.
Load dumb iron in pipe shed, sort 9-5/8"
casing on pad and prep for loading in pipe
shed. Load 9-5/8" landing joint and
hanger in pipe.
3/1/2023 00:00 3/1/2023 01:00 1.0
0
MIRU, MOVE OTHR P Make up 2 stands of drill pipe and tag
TOC at 85.7'MD. Rack back stands in the
derrick.
3/1/2023 01:00 3/1/2023 07:00 6.0
0
MIRU, MOVE OTHR P Slip 82ft drilling line off drum, organize
casing in the yard in preparation to load in
pipe shed. Gather equipment needed for
running communications line to camp.
Load pump liners in the pump room.
perform rig walk through to verify
equipment readiness.
3/1/2023 07:00 3/1/2023 12:00 5.0
0
MIRU, MOVE OTHR P Install 9-5/8" single joint elevators, pick up
9-5/8" landing joint and hanger. perform
dummy run per FMC rep. 22.6 ft to
landing ring. Lay down casing hanger and
landing joint. Begin loading 9-5/8" surface
casing in the pipe shed. Pick up 4 stands
of 4" HWDP and rack back in the derrick.
Transfer 200 bbl's of 10ppg spud mud to
vac trucks to free up space in pits.
Continue building 10 ppg spud mud. (700
bbl's total)
3/1/2023 12:00 3/1/2023 14:00 2.0
0
MIRU, MOVE PULD P Pick up and rack back 4 stands of 5"
HWDP. Function test mud pumps and
check system for leaks.
3/1/2023 14:00 3/1/2023 18:00 4.0
0
MIRU, MOVE PRTS P Fill conductor and circulate back to the
pits, check flow line, drilling riser, and
interconnects for leaks. Close IBOP and
pressure test high pressure mud lines to
4500 psi. Blow down top drive and mud
lines
Simops - cut trench in ice pad and begin
running communications cable for camp
alarm. Build cuttings cell and place
cuttings boxes.
3/1/2023 18:00 3/1/2023 20:00 2.0
0
MIRU, MOVE RURD P Calibrate blocks and drawworks drum
with Totco Rep and SLB.
3/1/2023 20:00 3/1/2023 21:30 1.5
0
SURFAC, DRILL SFTY P Pre job meeting with all parties and
hands. Cover pre-spud, diverter drill, and
make up BHA.
3/1/2023 21:30 3/2/2023 00:00 2.5
0
SURFAC, DRILL BHAH P Load rig floor of BHA components and
thaw connections. Pick up 12-1/4" bit, bit
sub and drill collar. Attempt to make up
the bit. Rig up snatch block to tong pull
line.
3/2/2023 00:00 3/2/2023 02:00 2.0
0
0.0 85.0 SURFAC, DRILL BHAH P Finish rigging up snatch block to tong line,
make up BHA 01 per SLB DD.
3/2/2023 02:00 3/2/2023 02:30 0.5
0
85.0 85.0 SURFAC, DRILL CIRC P Line up pumps and stage circulation up to
450 gpm, 260 psi. Monitor cellar, flow line,
diverter line and verify fluid path.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 11/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/2/2023 02:30 3/2/2023 03:30 1.0
0
85.0 135.0 SURFAC, DRILL DDRL P Drill 12-1/4" surface hole f/ 85' - t/ 135'
MD, 135' TVD, 450 - 500 gpm, 320 psi,
44% f/o, 80 rpm, 1k torque 1-5k wob.
Cuttings composition primarily clay w/
traces of gravel. Jetted flow line as
needed. Clean out the conductor with
thinned out spud mud. Shut down pumps
and swapped over to spud mud at 105'
md.
3/2/2023 03:30 3/2/2023 04:30 1.0
0
135.0 135.0 SURFAC, DRILL RGRP T Observed loss of pressure. Lined up on
pump #2 and attempt to circulate. Stroke
counter on pump #2 not working. Isolate
pump #3 and work on MP #2 stroke
counter. Circulated with pump #1 at 200
gpm.
3/2/2023 04:30 3/2/2023 09:00 4.5
0
135.0 351.0 SURFAC, DRILL DDRL P Drill 12-1/4" surface hole f/ 135' - t/ 351'
MD, 351' TVD. 550 gpm, 740 psi, 56% f/o,
120 rpm, 2k tq, 8k wob.
36k up wt, 33k dn wt, 34k rot wt.
Cuttings composition primarily clay w/
traces of gravel. Jetted flow line as
needed. OWFF on every connection
(static).
3/2/2023 09:00 3/2/2023 11:30 2.5
0
351.0 351.0 SURFAC, DRILL PMPO P Pump out of the hole f/ 351' - t/ 75' MD.
425 gpm, 300 psi, 30 k up wt.
Began packing off the flow line on the last
stand being pulled. Remediated quickly
with jetting the flow line and breaking up
the clay in the riser with water hose.
3/2/2023 11:30 3/2/2023 14:00 2.5
0
351.0 351.0 SURFAC, DRILL BHAH P Blow down top drive, lay down BHA #1
per Slb DD
3/2/2023 14:00 3/2/2023 15:00 1.0
0
351.0 351.0 SURFAC, DRILL CLEN P Clean clear rig floor of BHA #1
components and load the rig floor with
BHA #2 components.
3/2/2023 15:00 3/2/2023 20:00 5.0
0
351.0 351.0 SURFAC, DRILL BHAH P Pick up make up BHA #2 per Slb
DD/MWD. Pre-Job safety meeting, place
barricades and spotters in all areas with
access to cellar or rig floor. Notify
personnel on location of source load
operations. Load source.
3/2/2023 20:00 3/2/2023 21:00 1.0
0
351.0 351.0 SURFAC, DRILL CIRC P Make up top drive, blow air back through
the mud line. Bring on the pumps and
shoot survey. Blow down top drive.
3/2/2023 21:00 3/2/2023 22:00 1.0
0
351.0 351.0 SURFAC, DRILL BHAH T Observed galling on drill collar box and
bottle neck xo threads. Swap drill collar
and xo.
3/2/2023 22:00 3/3/2023 00:00 2.0
0
351.0 351.0 SURFAC, DRILL TRIP P Pre-job safety meeting with all hands on
tripping in the hole operations. Run in 2
stand of 5" HWDP. Change out 5"
handling equipment with 4" handling
equipment. Run in stand of 4" DP.
3/3/2023 00:00 3/3/2023 03:00 3.0
0
351.0 488.0 SURFAC, DRILL DDRL P Dril 12-1/4" surface hole f/351' - t/488'
MD, 488' TVD, 520 gpm, 870 psi, 15k
wob, 120 rpm, 3k tq, 48k up wt, 47k dn
wt, 47k rot wt.
2.2 ADT, 5.76 bit hours
3/3/2023 03:00 3/3/2023 04:30 1.5
0
488.0 488.0 SURFAC, DRILL PMPO P Pump out of the hole f/488' - t/301' MD,
425 gpm, 525 psi, 47k up wt. Blow down
the top drive.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 12/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/3/2023 04:30 3/3/2023 05:30 1.0
0
488.0 488.0 SURFAC, DRILL TRIP P Change elevators to 5", pick up remaining
HWDP and jars, swap elevators to 4" and
RIH to bottom.
3/3/2023 05:30 3/3/2023 06:30 1.0
0
488.0 541.0 SURFAC, DRILL DDRL P Drill 12-1/4" surface hole f/488' - t/ 541'
MD, 541' TVD. 500 gpm, 900 psi, 15k
wob, 3k tq.
Trouble shoot #3 mud pump.
3/3/2023 06:30 3/3/2023 07:00 0.5
0
541.0 514.0 SURFAC, DRILL RGRP P Replace swab on #2 mud pump, rebuild
2" demco bleed line valve on #3 mud
pump.
3/3/2023 07:00 3/3/2023 12:00 5.0
0
514.0 802.0 SURFAC, DRILL DDRL P Drill 12-1/4" suface hole f/ 514' MD - t/802'
MD, 802' TVD, 520 gpm, 1030 psi, 15k
WOB, 120 rpm, 3k tq, 58k up wt, 56k dn
wt, 57k rot wt.
4.24 ADT, 10 total bit hours, 4.83 jar
hours.
3/3/2023 12:00 3/3/2023 22:30 10.
50
802.0 1,323.0 SURFAC, DRILL DDRL P Drill 12-1/4" suface hole f/802' MD -
t/1323' MD, 1323' TVD, 700 gpm, 2350
psi, 10-15k WOB, 120 rpm, 3k tq, 66k up
wt, 63k dn wt, 59k rot wt.
7.68 ADT, 14.12 total bit hours, 12.51 jar
hours.
3/3/2023 22:30 3/3/2023 23:30 1.0
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
CIRC P Cycle pumps for survey, take final torque
and drag, rack back stand in the derrick.
Pump nut plug sweep and circulate out of
the hole while racking back 1 stand to
1,241' MD. 740 gpm, 2460 psi, 120 rpm,
2k tq. 60k up wt while rotating,
3/3/2023 23:30 3/4/2023 00:00 0.5
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
OWFF P Observe well for flow (static)
3/4/2023 00:00 3/4/2023 03:00 3.0
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
BKRM P Back ream out of the hole f/ 1,230' - t/
968' MD, 700 gpm, 2020 psi, 120 rpm, 1-
2k tq.
Observe beginning signs of pack off at
968' MD. Began moving down to get away
from the obstruction. hole began to
unload clay.
3/4/2023 03:00 3/4/2023 06:30 3.5
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
OTHR T Pull bushings and remove clay from
drilling riser, continue to work clay out of
the hole increasing flow rate when
possible. Run in one stand to change
location of circulation. Continue to stage
up pumps and circulate the hole. 180 -
700 gpm, 200 - 2020 psi, 20 - 120 rpms, 1
-2k tq.
3/4/2023 06:30 3/4/2023 07:30 1.0
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
CIRC P Circulate bottoms up while pulling out of
the hole f/ 1,050' - t/ 866' MD, 720 gpm
2050 psi, 120 rpm,
Continue managing clay returns on
surface.
3/4/2023 07:30 3/4/2023 11:30 4.0
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
PMPO P Pump out of the hole f/ 866' - t/ 488' MD,
55k up wt, 55k dn wt.
Continue managing clay returns on
surface.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 13/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/4/2023 11:30 3/4/2023 17:30 6.0
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
BHAH P Change out handling equipment for 5",
pull out of the hole on elevators racking
back 5" HWDP, Lay down BHA per Slb
DD/MWD.
Slight over noticed occationally no more
that 2-5k hookload increases.
3/4/2023 17:30 3/4/2023 20:00 2.5
0
1,323.0 1,323.0 SURFAC,
TRIPCAS
CLEN P Clean and clear the rig floor of BHA tools
and handling equipment, wash the floor,
3/4/2023 20:00 3/5/2023 00:00 4.0
0
1,323.0 1,323.0 SURFAC,
CASING
RURD P Change out saver sub on the top drive to
NC50, rig up volant tool and bail
extentions, pick up casing xo and make
up to TIW valve, bring false bowl, slips
and single joint elevators to the rig floor.
3/5/2023 00:00 3/5/2023 02:00 2.0
0
1,323.0 1,323.0 SURFAC,
CASING
RURD P Continue rigging up to run 9-5/8" casing,
remove floor mats and bushings, install
false bowl, install tong heads, bring
centralizers to the rig floor.
3/5/2023 02:00 3/5/2023 03:30 1.5
0
1,323.0 1,323.0 SURFAC,
CASING
PUTB P Pre-job safety meeting with all parties on
running 9-5/8" casing. Pick up shoe track
assembly (4jts). Circulate through shoe
track and verify flow path, 4bbls/min, 50
psi.
3/5/2023 03:30 3/5/2023 09:30 6.0
0
1,323.0 1,323.0 SURFAC,
CASING
PUTB P Run 9-5/8", 40#, L80, TXP casing f/ 163' -
t/ 1,233' MD, fill every joint on the fly and
top off every 10 joints. 60k up wt, 56k dn
wt.
Proper displacement during casing run.
3/5/2023 09:30 3/5/2023 10:30 1.0
0
1,323.0 1,323.0 SURFAC,
CASING
HOSO P Make up 14.52' TXP casing pup, 39.91'
Hyd563 by TXP (bxp) crossover joint, 9-
5/8" hanger and landing joint. Land 9-5/8"
casing on hanger at 1319' MD. 60k up wt,
56k dn wt.
3/5/2023 10:30 3/5/2023 12:00 1.5
0
1,323.0 1,323.0 SURFAC,
CEMENT
CIRC P Stage up pumps to 5bbl/min, 100psi.
Circulate and condition mud while
reciprocating 15'. 60k up wt, 56k dn wt.
3/5/2023 12:00 3/5/2023 15:00 3.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
RURD P Blow down CRT and lay down in the pipe
shed. Rig up cement head
3/5/2023 15:00 3/5/2023 20:00 5.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
CIRC P Stage up pumps to 5bbl/min, 100psi.
Circulate and condition mud while
reciprocating 15'. 60k up wt, 56k dn wt.
Simops, build cement contam pills in the
pits and load on vac trucks, rig up line
from pits to cement unit for displacement,
Stage vac trucks in needed areas for
cement job.
Pre-job safety meeting with all parties on
cement job.
3/5/2023 20:00 3/5/2023 21:00 1.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
PRTS P SLB pump 2 bbl's of fresh water, close
valves and pressure test lines to 500 psi
low stall and 3500 psi high stall. Observed
pin hole leak in the 2" cement hose on the
rig floor. Bleed off pressure and rig up
new 2" hose on the manifold. SLB pump 2
bbl's of fresh water and pressure test
cement lines to 500 psi low stall and 3500
psi high stall. (good test)
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 14/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/5/2023 21:00 3/6/2023 00:00 3.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
CMNT P SLB pump 4 bbl's of fresh water and
pressure test lines to 500/3500. Rig
pump 95 bbl's. MudPUSHII with red dye
@ 4.3 bbls/min, 80 PSI, 26% F/O,
Dropped bottom plug. Start batching lead
(Lead wet @ 21:39). Pump 174.2 bbl's of
11.0 ppg DeepCRETE lead cement at 4
bbls/min, 290 PSI, F/O 24%. Land bottom
plug at 97 bbl's away. Batch tail cement
(Tail wet @ 22:54). SLB pump 60 bbl's
12ppg LiteCRETE @ 4 bbls/min, 340 PSI,
F/O 25%. Drop top plug & kick out with
20 bbl's of fresh H2O. SLB displace w/ 10
PPG spud mud @ 5.7 bbls/min, 550 PSI,
F/O 55%. Reduced rate to 3 bbls/min 580
PSI. Bump plug with 1130 PSI (77.4 bbl's
+ 20 bbl's).final circ. PSI 580 Pressure up
to 1130 PSI & hold for 5 minutes. Bleed
off pressure, Check floats good. CIP
23:58 Hrs 3/05/2023. 0 bbl's loss during
cement job. 30 bbl's of contaminated
cement returns to surface, 97 bbl's good
cement to surface (127 bbl's total cement
returns)
3/6/2023 00:00 3/6/2023 02:00 2.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
RURD P Blow down cement lines, rig down cement
head and cementing equipment. Clear rig
floor of cementing equipment.
3/6/2023 02:00 3/6/2023 04:00 2.0
0
1,323.0 1,323.0 SURFAC,
CEMENT
CLEN P Flush surface stack with contam pill, wash
the stack. Begin cleaning pits and flow
line of cement.
3/6/2023 04:00 3/6/2023 14:00 10.
00
1,323.0 1,323.0 SURFAC,
CEMENT
NUND P Remove diverter line from cellar, remove
lines from drilling riser, nipple down
surface annular, diverter tee and adaptor.
Clean up in cellar and prep for wellhead
installation.
3/6/2023 14:00 3/6/2023 18:00 4.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Nipple up Gen 5 wellhead per FMC rep.
Test seals to 1000 psi for 10 min.
Simops, change saver sub to XT39,
continue cleaning in the pits.
Cement at conductor valves (30" below
hanger)
3/6/2023 18:00 3/6/2023 19:30 1.5
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Begin nippling up BOPE, continue
cleaning pits,
3/6/2023 19:30 3/6/2023 21:30 2.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
OTHR P Pull test plugs to the rig floor, run 3-1/2"
test jt with upper test plug and measure
height. Run 7" test joint with lower test
plug and measure height to flange.
3/6/2023 21:30 3/7/2023 00:00 2.5
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Nipple up annular, double gate and mud
cross.
3/7/2023 00:00 3/7/2023 06:00 6.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Continue nipple up BOPE, pick up mud
cross, remove HCR's, roll lower ram body
into place and make up to the mud cross,
lower onto wellhead and begin torquing
bolts.
3/7/2023 06:00 3/7/2023 12:00 6.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Continue nipple up BOPE, install choke
and kill HCR's, 90's and install kill line.
3/7/2023 12:00 3/7/2023 16:00 4.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
NUND P Nipple up riser and choke line. Insulate
external lines. Blow air through choke
manifold. Grease choke manifold and
mud cross valves.
Begin building 10.2 ppg KLAshield mud.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 15/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/7/2023 16:00 3/7/2023 21:00 5.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
RURD P Pick up 4" test joint, make up test plug
and RIH. Fill lines with water a purge air
out of the system. Rig up test lines on test
joint. Shell test BOP's. Test gas alarms.
3/7/2023 21:00 3/7/2023 23:00 2.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
RGRP T Trouble shoot test pump pulsation.
Fabricate dampner and install. Purge
sensator and guage lines.
3/7/2023 23:00 3/8/2023 00:00 1.0
0
1,323.0 1,323.0 SURFAC,
WHDBOP
BOPE P Test annular preventor to 250psi low,
2500 psi high for 5min each test.
3/8/2023 00:00 3/8/2023 08:30 8.5
0
1,323.0 1,323.0 SURFAC,
WHDBOP
BOPE P Initial BOPE test. All tests at 250/5000 psi
for 5 min each test. Test with 4" test joint,
upper and lower pipe rams . Test blind
rams. Test choke valves #1 to #18, top
drive IBOP, test 2ea 4” TIW valves and
1ea dart valve, test mezzanine, HCR and
manual kill valves, test HCR and manual
choke valves, hydraulic and manual
chokes to 2000 psi. and demonstrate
bleed off. Perform accumulator test.
Starting pressure=3050 psi, after
function= 1725 psi, 200 psi attained=24
sec's, full recovery=105 sec. 6 nitrogen
bottles at 1466 psi. Test gas alarms, PVT
and flow show. 2 F/P on H2S sensors on
rig floor and in pits. Replaced sensor on
rig floor and replaced head in pits. Test
witnessed by AOGCC Rep. Adam Earl.
3/8/2023 08:30 3/8/2023 11:30 3.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
RURD P Rig down and blow down testing
euqipment, blow down choke and kill line.
Pull test plug per FMC rep. Install drip pan
on BOP's and skirt.
3/8/2023 11:30 3/8/2023 12:00 0.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
OTHR P Install wear bushing per FMC rep. Wear
bushing Length = 38", ID= 9", OD= 10.8"
3/8/2023 12:00 3/8/2023 15:30 3.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
RURD P Rig up Schlumberger cement unit for 9-
5/8" casing test.
Continue to load 7" casing in the shed.
Continue to build 10.2 ppg KLAshield in
the pits.
3/8/2023 15:30 3/8/2023 16:30 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
PRTS P Pressure test 9-5/8" surface casing to
3000 psi for 30 min (good test). Bleed off
pressure
60 psi loss during 30 min test
3/8/2023 16:30 3/8/2023 17:30 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
RURD P Blow down lines and rig down testing
equipment.
3/8/2023 17:30 3/9/2023 00:00 6.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
OTHR P Cross chain BOP stack and center BOP's.
Install drain lines on the BOP drip pan
and route to cellar box. Hook up cellar
pump. Clean and organize subs, work on
injection pump. Rate test BOP test pump.
Fill cracks around the rig to help hold
heat. Secure outside equipment wind
gusts.
Continue building mud
3/9/2023 00:00 3/9/2023 01:00 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
OTHR P Adjust drip pan on the BOP's, transfer
10.2 ppg KLAshield mud from the pits to
the upright tanks outside.
3/9/2023 01:00 3/9/2023 05:00 4.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
BHAH P Pick up BHA #3 per Slb DD to 461' MD.
3/9/2023 05:00 3/9/2023 07:00 2.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
WASH P Wash in the hole f/ 461' - t/ 1092' MD, 230
gpm, 150 psi, 48k up wt, 50k dn wt.
3/9/2023 07:00 3/9/2023 07:30 0.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
CIRC P Shallow hole test MWD tools at 1092'MD,
500 gpm, 1230 psi, 50 rpm.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 16/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/9/2023 07:30 3/9/2023 12:00 4.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
OTHR P Prepare for surface casing drill out. Test
trip tank pump, test injection pump and
cellar pump.
3/9/2023 12:00 3/9/2023 13:00 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
OTHR P Circulate hole while preping for injection
pump test.
3/9/2023 13:00 3/9/2023 15:30 2.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
SEQP P Blow down top drive, rig up injection
pump on the drillpipe and back side, flood
lines and purge air out of the system.
Close annular preventor, perform mock
LOT/FIT against casing with injection
pump to 250 psi.
3/9/2023 15:30 3/9/2023 18:30 3.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
SFTY P Pre-job safety meeting with rig crew on
upcoming operation. Perform BOP drills
with the rig crew. Blow down mud lines.
3/9/2023 18:30 3/9/2023 20:00 1.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
RURD P Remove radar flow sensor, thaw ice in
tube, install radar sensor, insulate line and
wrap with herculite to keep from freezing.
Calibrate sensor per totco rep.
3/9/2023 20:00 3/9/2023 21:00 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
WASH P Wash in the hole f/1092' - t/ 1225' MD,
230 gpm, 50 psi. Tag TOC 1225'MD.
3/9/2023 21:00 3/9/2023 22:00 1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
DRLG P Drill cement and tag top plug at 1233' MD,
drill out plugs and float collar, 450 gpm,
1020 psi, 67% f/o, 5-15k wob, 40rpm,1-5k
tq. Work through float collar 2 times after
drilling out.
3/9/2023 22:00 3/9/2023 22:30 0.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
DRLG P Drill cement f/ 1236' - t/ 1278' MD, 450
gpm, 1000 psi, 75% flow out, 2-5k WOB,
80 rpm, 2k tq.
3/9/2023 22:30 3/10/2023
00:00
1.5
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
CIRC T Circulate and treat mud returns due to
cement contamination.
3/10/2023
00:00
3/10/2023
01:00
1.0
0
SURFAC,
DRILLOUT
CIRC T Circulate and condition cement
contaminated mud.
3/10/2023
01:00
3/10/2023
01:30
0.5
0
SURFAC,
DRILLOUT
DRLG P Continue drilling cement f/ 1278' - t/1314'
MD. 500 gpm, 1090 psi, 78% f/o, 1-4k
wob, 80 rpm, 2k tq. 55k rot hook load.
3/10/2023
01:30
3/10/2023
03:30
2.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
CIRC T Circulate and weight up mud system from
9.2ppg to 9.9ppg.
3/10/2023
03:30
3/10/2023
04:30
1.0
0
1,323.0 1,323.0 SURFAC,
DRILLOUT
DRLG P Drill out remaining cement, float shoe and
rat hole t/ 1343' MD, 1343' TVD. 575 gpm,
1500 psi, 1-4 k wob, 80-100 rpm, 1-4k tq.
3/10/2023
04:30
3/10/2023
05:00
0.5
0
1,323.0 1,343.0 SURFAC,
DRILLOUT
DDRL P Drill 20 ft of new hole to 1343' MD.
3/10/2023
05:00
3/10/2023
05:30
0.5
0
1,343.0 1,343.0 SURFAC,
DRILLOUT
CIRC P Pump OOH into surface shoe. Circulate
and condition mud to 9.9 ppg in and out.
3/10/2023
05:30
3/10/2023
06:30
1.0
0
1,343.0 1,343.0 SURFAC,
DRILLOUT
RURD P RU to perform FIT. Fluid back lines, close
upper pipe rams.
3/10/2023
06:30
3/10/2023
07:00
0.5
0
1,343.0 1,343.0 SURFAC,
DRILLOUT
FIT P Perform FIT to 13.2 ppg using rigs
injection pump (125-T4 triplex plunger).
Perform test at 50 SPM (0.1077 gal/stk) to
226 psi with 9.9 ppg Spud Mud. Shut-in
pressure fall off was ~2 psi/min
consistently for the entire 10 min duration.
Volume pumped 10.2 gal, valume
returned 0 gal (cannot measure anything
less than ~15 gal due to line volume).
Lithology in 20' of new hole was
characterized by sample collection as silty
claystone with 10-20% sand grains.
Concurfence of good FIT test received
from Drilling Engineer and Exploration
Superintendent.
3/10/2023
07:00
3/10/2023
08:00
1.0
0
1,343.0 1,343.0 SURFAC,
DRILLOUT
RURD P Blow down lines and rig down FIT
equipment.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 17/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/10/2023
08:00
3/10/2023
08:30
0.5
0
1,343.0 1,343.0 INTRM1, DRILL RGRP T Thaw outside lines for upright tanks to rig
fluid transfer.
3/10/2023
08:30
3/10/2023
10:30
2.0
0
1,343.0 1,343.0 INTRM1, DRILL CIRC T Address mud sag in upright tank.
3/10/2023
10:30
3/10/2023
12:00
1.5
0
1,343.0 1,343.0 INTRM1, DRILL DISP P Line up to displace from 9.9 ppg Spud
Mud to 10.2 ppg KLAshield. Lead with 30
bbls high vis spacer. Displace with 367
gpm, 30 rpm and 15' reciprocation.
Spacer returned to surface at 1340 stks,
calculated was 1310 stks - pump had a
hard time pumping the hi vis spacer.
Minimal interface (~5 bbl) was observed
at surface.
3/10/2023
12:00
3/10/2023
16:00
4.0
0
1,343.0 1,343.0 INTRM1, DRILL CIRC P Circulate surface to surface, MW 10+ ppg
out and 10.1+ ppg in. Some barite sag
likely occurred in the fluid transferred from
the 400 bbl upright tanks. Circulate and
condition fluid while weighting up to 10.2
ppg.
3/10/2023
16:00
3/10/2023
16:30
0.5
0
1,343.0 1,343.0 INTRM1, DRILL WASH P Wash to bottom.
3/10/2023
16:30
3/10/2023
18:00
1.5
0
1,343.0 1,402.0 INTRM1, DRILL DDRL P Drill 8.5" intermediate hole f/ 1343' - t/
1402' MD, 1402' TVD. 560 gpm, 980 psi,
75% f/o, 1-2k wob, 1-2k tq. Max gas 16
units.
Control drill at 50fph for 10' cuttings
sample collection.
Flow check every connection (static).
3/10/2023
18:00
3/11/2023
00:00
6.0
0
1,402.0 1,656.0 INTRM1, DRILL DDRL P Drill 8.5" intermediate hole f/ 1402' - t/
1656' MD, 1656' TVD. 580 gpm, 1240 psi,
70% f/o, 2-6k wob, 1-6k tq. Max gas 24
units.
Control drill at 50fph for 10' cuttings
sample collection.
Thin coal bed apparent in samples at
1500' and 1510' MD.
Flow check well on every connection
(static).
3/11/2023
00:00
3/11/2023
06:00
6.0
0
1,656.0 2,136.0 INTRM1, DRILL DDRL P Drill 8.5" intermediate hole f/ 1656' - t/
2136' MD, 2136' TVD. 580 gpm, 120 rpm,
1575 psi, 78% f/o, 5-10k wob, 2-6k tq.
Max gas 24 units.
Increased ROP to 100-150 FPH at 1656'
MD once all tools in string through
potential anomaly zone as per geo.
Flow check well on every connection
(static).
Taking cuttings samples on 30' intervals.
3/11/2023
06:00
3/11/2023
07:30
1.5
0
2,136.0 2,245.0 INTRM1, DRILL DDRL P Drill 8.5" intermediate hole f/ 2136' - t/
2245 MD TD. 2245' TVD.150 fph, 580
gpm, 120 rpm, 1700 psi, 77% f/o, 5-10k
wob, 1-6k tq. Max gas 24 units.
Increased ROP to 100-150 FPH at 1656'
MD once all tools in string through
potential anomaly zone as per geo.
Flow check well on every connection
(static).
Taking cuttings samples on 30' intervals.
3/11/2023
07:30
3/11/2023
08:30
1.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
CIRC P Take final survey and circulate hole clean.
No significant increase in cuttings
observed at surface.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 18/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/11/2023
08:30
3/11/2023
10:30
2.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
BKRM P BROOH f/ 2245' - t/ 2161' MD, 2161'
TVD. 580 gpm, 80 rpm, 1575 psi, 74% f/o,
1-2k tq.
Large quantities of 2-3" claystone cavings
were observed over the shakers.
3/11/2023
10:30
3/11/2023
12:00
1.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
PMPO P Pump OOH f/ 2161' - t/ 2093' MD, 2093'
TVD. 580 gpm, 1560 psi, 74% f/o.
Pump pressure spikes were observed and
the hole began showing signs of packing
off. Decision made to BROOH.
Large quantities of 2-3" claystone cavings
continued to be observed over the
shakers.
3/11/2023
12:00
3/11/2023
14:30
2.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
BKRM P BROOH f/ 2093' - t/ 1719' MD, 1719'
TVD. 300-500 fph, 560 gpm, 50 rpm,
1475 psi, 76% f/o, 1-2k tq.
Large quantities of 2-3" claystone cavings
continued to be observed over the
shakers.
3/11/2023
14:30
3/11/2023
17:00
2.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
PMPO P Pump OOH f/ 1719' - t/ 1391' MD, 1391'
TVD. 580 gpm, 1365 psi, 76% f/o.
Large quantities of 2-3" claystone cavings
continued to be observed over the
shakers.
3/11/2023
17:00
3/11/2023
18:00
1.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
BKRM P BROOH f/ 1391' - t/ 1276' MD, 1276'
TVD. 300-500 fph, 560 gpm, 40 rpm,
1325 psi, 78% f/o, 1-2k tq.
Once inside shoe, TQ and SPP dropped
and smoothed out.
Large quantities of 2-3" clay stone
caving's continued to be observed over
the shakers.
3/11/2023
18:00
3/11/2023
19:00
1.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
CIRC P Circulate bottoms up at the surface shoe.
570 gpm, 1330 psi, 40 rpm, 1k tq.
Send downlink to turn off the pulse
neutron generator.
3/11/2023
19:00
3/11/2023
21:30
2.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
TRIP T Trip in the hole f/ 1276' - t/ 2230' MD,
2230' TVD. 65k up wt, 67k dn wt.
Proper displacement observed during trip.
Did not observe any excessive drag.
3/11/2023
21:30
3/11/2023
23:30
2.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
CIRC T Establish circulation and stage up pumps
to 500 gpm, 1200 psi, ream in the hole f/
2230' - t/ 2245'MD. 60 rpm, 1-4k tq.
Circulated 2 bottoms up, pumped 35 bbl's
hi-vis sweep and circulate hole clean.
Observed minor indications of pack off
while reaming in the hole.
Observed 20% increase in cutting volume
over the shakers from the sweep.
3/11/2023
23:30
3/12/2023
00:00
0.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
PMPO T Pump OOH f/ 2245' - t/ 2097' MD, 2097'
TVD, 183 gpm, 200 psi, 64k up wt, 66k dn
wt.
3/12/2023
00:00
3/12/2023
00:30
0.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
RGRP T Replace die on top drive grabber box.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 19/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/12/2023
00:30
3/12/2023
03:30
3.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
PMPO T Pump OOH f/ 2097' - t/ 1277' MD, 1277'
TVD, 183 gpm, 170 psi, 5% f/o, 52k up
wt.
Proper displacement while pulling out of
the hole.
No indications of excessive drag
observed.
3/12/2023
03:30
3/12/2023
04:15
0.7
5
2,245.0 2,245.0 INTRM1,
TRIPCAS
CIRC P Circulate 2.5 bottoms up, 570 gpm, 1330
psi, 79% f/o, 40 rpm, 1k tq.
3/12/2023
04:15
3/12/2023
06:30
2.2
5
2,245.0 2,245.0 INTRM1,
TRIPCAS
PMPO P Pump OOH f/ 1277' - t/ 458' MD, 458'
TVD, 183 gpm, 170 psi, 5% f/o, 41k up
wt.
3/12/2023
06:30
3/12/2023
07:00
0.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
OWFF P Observe well for flow (static).
3/12/2023
07:00
3/12/2023
07:30
0.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
RGRP T Clean trip tank of old mud and fill with
10.2ppg KLAsheild.
3/12/2023
07:30
3/12/2023
12:00
4.5
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
BHAH P Lay down BHA #3 per Slb DD/MWD.
3/12/2023
12:00
3/12/2023
13:00
1.0
0
2,245.0 2,245.0 INTRM1,
TRIPCAS
CLEN P Clear and clean the rig floor of BHA
components.
3/12/2023
13:00
3/12/2023
14:00
1.0
0
2,245.0 2,245.0 INTRM1,
CASING
WWWH P Make up stack washing tool to the bottom
of 4" drill pipe and wash the stack. Lay
down tool and rack back double. Blow
down top drive.
3/12/2023
14:00
3/12/2023
16:00
2.0
0
2,245.0 2,245.0 INTRM1,
CASING
OTHR P Pull wear bushing and lay down, dummy
run 7" hanger, and install test plug per
FMC rep.
3/12/2023
16:00
3/12/2023
18:30
2.5
0
2,245.0 2,245.0 INTRM1,
CASING
OTHR P Change upper BOP rams to 7".
Simops: change saver sub on top drive to
NC50.
3/12/2023
18:30
3/12/2023
19:00
0.5
0
2,245.0 2,245.0 INTRM1,
CASING
SVRG P Perform derrick inspection, tighten
turnbuckles and back braces on torque
tube.
3/12/2023
19:00
3/12/2023
21:30
2.5
0
2,245.0 2,245.0 INTRM1,
CASING
BOPE P Rig up to test upper pipe rams and
annular preventor with 7" test joint. Purge
air from lines. Test upper pipe rams and
annular preventor with 7" test joint to 250
psi low and 3500 psi high for 5 min each
test. Rig down testing equipment, blow
down lines and pull test plug.
3/12/2023
21:30
3/12/2023
23:00
1.5
0
2,245.0 2,245.0 INTRM1,
CASING
RURD P Pick up the CRT and install the swivel, rig
up to run 7" intermediate casing.
3/13/2023
00:00
3/13/2023
01:30
1.5
0
2,245.0 2,245.0 INTRM1,
CASING
RURD P Continue rigging up to run 7" intermediate
casing.
3/13/2023
01:30
3/13/2023
02:00
0.5
0
2,245.0 2,245.0 INTRM1,
CASING
PUTB P Make up 7" shoe track, pump through
shoe track and confirm floats. (floats
good)
3/13/2023
02:00
3/13/2023
09:00
7.0
0
2,245.0 2,245.0 INTRM1,
CASING
PUTB P Run 7", 26#, L-80, TXP intermediate
casing f/ 165' - t/ 2211' MD, 61k up wt,
63k dn wt.
3/13/2023
09:00
3/13/2023
09:45
0.7
5
2,245.0 2,245.0 INTRM1,
CASING
HOSO P Pick up 7" casing hanger and landing joint
per FMC rep.
3/13/2023
09:45
3/13/2023
14:00
4.2
5
2,245.0 2,245.0 INTRM1,
CASING
WASH P Establish circulation at 4-5 bbls/min, 200-
310 psi, 23% f/o, 63k up wt, 65k dn wt.
Observed signs of fill at 2235' MD.
Pressure fluctuated from 200 psi to 500
psi, work pipe with and with out pumps to
2241' MD. 5-20k set on shoe.
3/13/2023
14:00
3/13/2023
19:00
5.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
CIRC P Circulate and condition mud for cement
job, 6 bbls/min, 240 psi, YP = 22 lbf/100ft²
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 20/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/13/2023
19:00
3/13/2023
20:00
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
RURD P Rig up to pump cement through the volant
tool. Blow down top drive and to Slb
cement unit. Establish circulation through
cement hose.
3/13/2023
20:00
3/13/2023
23:30
3.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
CMNT P SLB pump 5 bbl's of fresh water and
pressure test lines to 500/4000. Drop first
bottom plug, rig pump 41 Bbl's. 10.5 ppg
MudPUSHII with red dye @ 4.3 bbls/min,
75 PSI, 13% F/O, Dropped second
bottom plug. Start batching lead (Lead
wet @ 21:39). Pump 92.2 bbl's of 11 ppg
LiteCRETE w/ D500 lead cement at 4.1
BPM, 210 PSI, F/O 11%. Batch tail
cement (Tail wet @ 22:08). SLB pump
22.5 Bbl's 12 ppg LiteCRETE @ 4 BPM,
390 PSI. Open OA valve and begin taking
returns to the cellar. Drop top plug & kick
out with 20 Bbl's of fresh H2O. SLB
displace w/ 10.2 ppg KlaShield mud @ 4
bbls/min, 490 PSI. Reduced rate to 2
BPM 300 PSI. Pumped 64.2 bbl's of mud
by tank volume, plugs did not bump.
Bleed off pressure, Check floats good.
CIP 23:10 Hrs 3/13/2023. 0 Bbl's loss
during cement job. 27 Bbl's good cement
returns to surface.
3/13/2023
23:30
3/14/2023
00:00
0.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
RURD P Blow down cement lines and begin rigging
down cementing equipment.
3/14/2023
00:00
3/14/2023
01:30
1.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
CLEN P Continue cleaning up surface equipment
post cement job, flush the BOP's and
drain into the cellar. Back out the landing
joint and lay down per FMC rep,
3/14/2023
01:30
3/14/2023
03:00
1.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
RURD P Remove 8' bail extentions, break out and
secure Volant tool in shipping cage. Lay
down casing running equipment and
cementing equipment.
Continue cleaning up cement in cellar.
3/14/2023
03:00
3/14/2023
04:45
1.7
5
2,245.0 2,245.0 INTRM1,
CEMENT
WWSP P Set 7" pack off per FMC rep, test to 5000
psi for ten min (good test). Lay down
running tool
3/14/2023
04:45
3/14/2023
05:45
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
WWWH P Make up stack flushing tool to joint of drill
pipe, run in the hole and attempt to
circulate.
3/14/2023
05:45
3/14/2023
19:00
13.
25
2,245.0 2,245.0 INTRM1,
CEMENT
RGRP T Remove the kelly hose from the derrick,
thaw ice from the kelly hose and stand
pipe. Install kelly hose to top drive and
standpipe.
Simops: Change out saver sub, continue
cleaning cement out of the cellar, load the
pipe shed with 4" drill pipe.
3/14/2023
19:00
3/14/2023
20:00
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
WWWH T Pick up stack flushing tool and flush the
BOP's.
3/14/2023
20:00
3/14/2023
21:30
1.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
OTHR P Change upper rams to 3.5" x 5.5" VBR's.
3/14/2023
21:30
3/14/2023
23:00
1.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
RURD P Continue proccessing 4" drill pipe and HW
drill pipe. Rig up and prep handling
equipment to pick up 4" drill pipe.
3/14/2023
23:00
3/15/2023
00:00
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
OTHR P Install wear bushing per FMC rep. Lay
down running equipment.
3/15/2023
00:00
3/15/2023
06:30
6.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
PULD P Pick up 21 jts of 4" HWDP, 1 Jar & pick up
4" DP & rack in derrick.
3/15/2023
06:30
3/15/2023
07:30
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
OTHR P Pick up test joint. M/U wear bushing
running tool. Retrieve wear bushing &
install test plug in WH.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 21/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/15/2023
07:30
3/15/2023
10:30
3.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
BOPE P R/u BOPE testing equipment. M/u FOSV
& Dart valve. Flush all lines for testing.
3/15/2023
10:30
3/15/2023
19:00
8.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
BOPE P Test BOPE at 250/3500 psi @ 5/5 min.
Test UR, LR, BSR, Annular, Topdrive
IBOPs, floor safety valves, choke
manifold valves on 3.5" & 4" test
mandrels.
Test #1-#5,9,14,18, annular & dart valve
Test #2- Upper pipe rams, TIW #15
Test #3- #1, 4, 8, Upper IBOP, HCR kill
Test #4- #3, 7, 13, Lower IBOP, man kill
Test #5- #2, 6, 12
Test #6- #11
Test #7- LPR w/ 3.5" test jt.
Test #8- HCR, annular w/ 3.5" test jt
Test #9- Man choke, UPR w/ 3.5" test jt,
perform Test #10-koomey test
Test #11- #10
Test Super choke & manual choke to
2000 psi
3/15/2023
19:00
3/15/2023
19:30
0.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
OTHR P Blow down test pump, choke lines &
topdrive.
3/15/2023
19:30
3/15/2023
20:30
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
RURD P Breakdown 3.5" & 4" test mandrels, along
with FOSV & dart valve.
3/15/2023
20:30
3/15/2023
21:00
0.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
OTHR P Install Wearbushing as per FMC rep. WB
-10.38" OD x 6.43" ID.
3/15/2023
21:00
3/15/2023
23:00
2.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
PRTS P R/u to test 7" casing with injection pump.
Sensor installed on IA, chart recorder in
place. Attempt to prime injection pump.
Check fluid end of pump for debris or
mechanical issues, unable to pump.
(Note: SLB reported that they had no bit
breaker for the 6 1/8" bit. Located a
breaker in Deadhorse and transport to 2P
--in progess).
3/15/2023
23:00
3/15/2023
23:30
0.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
PRTS P Prepare SLB cement crew to test casing
with cement pump while continue
troubleshooting injection pump.
3/15/2023
23:30
3/16/2023
00:00
0.5
0
2,245.0 2,245.0 INTRM1,
CEMENT
PRTS P Close Blind Shear rams and pressure test
the 7" casing to 3700 psi recording on
chart recorder. Pumped 2.1 bbls. Hold
pressure for 30 min. Pressure drop of 20
psi in 30 min. Good test.
3/16/2023
00:00
3/16/2023
01:00
1.0
0
2,245.0 2,245.0 INTRM1,
CEMENT
PRTS P Close Blind rams and pressure test the 7"
casing to 3700 psi recording on chart
recorder. Pumped 2.1 bbls. Hold
pressure for 30 min. Pressure drop of 20
psi in 30 min. Good test. Bleed off
casing test psi. Blow down lines.
3/16/2023
01:00
3/16/2023
06:00
5.0
0
2,245.0 2,245.0 INTRM1,
DRILLOUT
BHAH P Hold PJSM on bha handling. P/u 6 1/8"
production interval bha as per SLB DD.
Hold PJSM on loading source and install
same to 904' MD.
3/16/2023
06:00
3/16/2023
08:30
2.5
0
2,245.0 2,245.0 INTRM1,
DRILLOUT
PULD P Pick up 4" DP singles from the pipe shed
f/ 904' to 1560' MD.
3/16/2023
08:30
3/16/2023
09:00
0.5
0
2,245.0 2,245.0 INTRM1,
DRILLOUT
DHEQ P Perform shallow test of SLB bha
components for functionality at 1560' MD.
3/16/2023
09:00
3/16/2023
10:30
1.5
0
2,245.0 2,245.0 INTRM1,
DRILLOUT
PULD P Continue to pick up 4" DP singles f/ 1560'
to 2101', drifting all singles.
3/16/2023
10:30
3/16/2023
12:00
1.5
0
2,245.0 2,245.0 INTRM1,
DRILLOUT
DRLG P Wash down f/ 2101' to 2146' MD. Tag up
on TOC at 2146' MD. Wash/ream to
2154' MD, tag up on FC/plugs. Drill wiper
plugs/float collar f/ 2154' MD with 5-20klbs
WOB, 2-3k TQ, 200 GPM, 950 psi, 40-80
RPMs.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 22/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/16/2023
12:00
3/16/2023
15:30
3.5
0
2,245.0 2,265.0 INTRM1,
DRILLOUT
DRLG P Drlg shoe track f/ 2154' to 2240'. Drill 7"
casing shoe & ream several times. Drill
rat hole to 2245'. Drill new formation to
2265' MD.
3/16/2023
15:30
3/16/2023
16:30
1.0
0
2,265.0 2,265.0 INTRM1,
DRILLOUT
CIRC P Circ hole clean w/ reciprocating pipe.
Mud wt in & out 10.2 ppg.
3/16/2023
16:30
3/16/2023
17:30
1.0
0
2,265.0 2,240.0 INTRM1,
DRILLOUT
TRIP P Pooh 1 std & rack back, placing bit in 7"
casing shoe at 2240'. flow down topdrive
& r/u to perform PIT.
3/16/2023
17:30
3/16/2023
18:30
1.0
0
2,240.0 2,240.0 INTRM1,
DRILLOUT
LOT P Perform FIT at 2240' MD/TVD w/ 10.2 ppg
test mud wt. Close UPR & using the rig
injection pump, pumping 50 spm (.128
bpm), applied 750 psi. Held pressure for
10 min with 20 psi decrease to 730 psi.
Test resulted with a 16.6 ppg EMW.
Bleed off pressure with 1.25 bbls back.
(pumped 2.1 bbls during the test).
3/16/2023
18:30
3/16/2023
20:00
1.5
0
2,240.0 2,240.0 INTRM1,
DRILLOUT
RURD P Blow down kill line, mud line & injection
pump. R/d test equipment w/ Engineering
team reviewing test data. Held PJSM
with Rig crew & all drilling service
contractors on drilling production interval.
3/16/2023
20:00
3/16/2023
20:30
0.5
0
2,240.0 2,265.0 INTRM1,
DRILLOUT
SVRG P Service rig. RIH to 2265' MD.
3/16/2023
20:30
3/17/2023
00:00
3.5
0
2,265.0 2,478.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 2265'
to 2478' MD.
WOB-10-14kft/lbs
RPM-100
P/u-55k
S/o-50k
RW-54k
TQ on-2
TQ off-.5
GPM-255
PSI-1710
ROP-100'/hr
ADT-2.83 hrs
SPR @ 2265 w/ 10.2 ppg
SPM------Pump-------PSI
65------------1------------395
65------------2------------400
65------------3------------300
3/17/2023
00:00
3/17/2023
06:00
6.0
0
2,478.0 2,918.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 2478'
2918' MD.
WOB-5k lbs
RPM-120
P/u-64k
S/o-63k
RW-63k
TQ on-2 to 3k/ftlbs
TQ off-1k
GPM-255
PSI-1750
ROP-100'/hr
ADT-4.5 hrs
ECD-12.0 ppg
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 23/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/17/2023
06:00
3/17/2023
07:30
1.5
0
2,918.0 3,029.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 2918' -
3029' MD. Observed mud losses at 3018'
MD. Initial losses at 148 bbl/hr with ECD
at 11.8 ppg.
WOB-4k lbs
RPM-120
TQ on-2 to 3k/ftlbs
TQ off-1k
GPM-255
PSI-1625
ROP-100'/hr
ADT-1.25 hrs
ECD-12.0 - 12.2 ppg
3/17/2023
07:30
3/17/2023
09:30
2.0
0
3,029.0 3,029.0 PROD1, DRILL CIRC T Monitor well for losses at 3023' MD.
Observed well ballooning back with
pumps down. Circulate b/u at reduced
pump rate to 127 gpm while mixing LCM
pill to ensure no gas due to well
breathing.
Begin adding background concentration
of LCM to the mud system. Only CaCO3
and nut plug.
3/17/2023
09:30
3/17/2023
11:15
1.7
5
3,029.0 3,106.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 3029' -
3106' MD.
WOB-4k lbs
RPM-120
TQ on-2 to 3k/ftlbs
TQ off-1k
P/u-67k
S/o-65k
RW-66k
GPM-255
PSI-2000
ROP-100'/hr
ADT-1.5 hrs
ECD- 11.8 ppg
Losses at 210 bbl/hr while drilling. (Lost
at total of 100 bbls w/ drilling during this
period)
SPR @ 3106' w/ 10.2 ppg
Pump #1-----Pump #2---------Pump #3
SPM65-------SPM-65----------SPM 65
PSI-650------PSI-660----------PSI-425
3/17/2023
11:15
3/17/2023
12:00
0.7
5
3,106.0 3,106.0 PROD1, DRILL CIRC T Circulate at 127 gpm w/ 550 psi while
building volume in the mud pits. Lost a
total of 236 bbl f/ 07:30 hrs to 12:00 hrs.
3/17/2023
12:00
3/17/2023
13:30
1.5
0
3,106.0 3,106.0 PROD1, DRILL CIRC T Continue to circ at 127 gpm w/ 550 psi w/
monitor loss rate and preparing to pump
LCM pill.
3/17/2023
13:30
3/17/2023
14:30
1.0
0
3,106.0 3,106.0 PROD1, DRILL CIRC T Pump & spot 30 bbls LCM pill consisting
of Safe Carb 40 & Walnut Plug at a total
of 30 ppb.
3/17/2023
14:30
3/17/2023
16:45
2.2
5
3,106.0 2,217.0 PROD1, DRILL PMPO T Pump out of hole w/ bha at 127 gpm f/
3106' to 2217' MD. No losses while pooh
(well breathing back 7 bbls) Total losses
250 bbls.
3/17/2023
16:45
3/17/2023
21:00
4.2
5
2,217.0 2,217.0 PROD1, DRILL OWFF T Monitor well at 2217' MD. Well ballooning
back at 2 bbl/hr, slowing down to .4
bbls/hr flow. Simops: building surface
mud volume f/ 355 bbls to 500 bbls.
Transferred 130 bbls of 10.2 ppg mud to
upright tank.
Well flowed back a total of 12.5 bbls.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 24/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/17/2023
21:00
3/17/2023
22:00
1.0
0
2,217.0 2,217.0 PROD1, DRILL CIRC T Circulate at 65 spm-127 gpm w/ 380 psi.
Monitoring well for losses at 2217' MD.
PVT static at 334 bbls.
Continue staging up to 255 gpm w/ 1700
psi. PVT static at 327 bbls (7 bbls
difference due to flow rate change)
ECD-11.6 ppg
3/17/2023
22:00
3/17/2023
23:00
1.0
0
2,217.0 2,809.0 PROD1, DRILL TRIP T TIH slowly f/ 2217' to 2813' MD. Taking
weight (10k down wt) pick up to 2809' and
install topdrive.
3/17/2023
23:00
3/18/2023
00:00
1.0
0
2,809.0 2,809.0 PROD1, DRILL CIRC T Break circ & circulate at 127 gpm w/ 445
psi. PVT static, no losses. Stage pumps
up to 225 gpm w/ 1490 psi. ECD at 11.57
ppg.
Losses started at 90 bph, increasing to
120 bph. Lost 25 bbls to formation. (275
bbls total losses).
Shut down pumps, monitor well on trip
tank while blow down topdrive.
Initially ballooning back at 60 bph, slowing
down to 3 bph after 19 bbls flowed back.
3/18/2023
00:00
3/18/2023
00:30
0.5
0
2,809.0 3,106.0 PROD1, DRILL TRIP T Tih f/ 2809' to 3045', monitoring well on
trip tank. Wash down to 3106' MD w/ 127
gpm-650 psi.
3/18/2023
00:30
3/18/2023
01:15
0.7
5
3,106.0 3,106.0 PROD1, DRILL CIRC T Circ b/u at 65 spm, 127 gpm w/ 650 psi.
At b/u had 50 units of gas, max. Continue
circ until gas units dropped. No losses.
3/18/2023
01:15
3/18/2023
02:00
0.7
5
3,106.0 3,106.0 PROD1, DRILL CIRC T Align pump on 30 bbls of 30 ppb LCM pill
& pump downhole at 127 gpm. Chase
with 30.5 bbls of10.2 ppg mud. Est top of
pill-2282'. No losses while pumping &
displacing pill.
3/18/2023
02:00
3/18/2023
03:00
1.0
0
3,106.0 2,982.0 PROD1, DRILL TRIP T Pooh w/ no pumping, slowly at 250'/hr to
2982'. Well swabbing. M/u topdrive &
attempt to pooh w/ rotation/no pump. Still
having slight swab effect.
3/18/2023
03:00
3/18/2023
05:00
2.0
0
2,982.0 2,982.0 PROD1, DRILL OWFF T Discuss options/go forward plan with
office team. Decision made to mix 60
bbls of LCM pill & lay it out in OH section
w/ pump out of hole. Mixing 60 bbls of 30
ppb LCM pill in pits while monitor well on
trip tank-static. Reciprocating & rotating
pipe @ 20 rpms. Held PJSM on pumping
pill & Pump out of hole.
3/18/2023
05:00
3/18/2023
06:00
1.0
0
3,106.0 2,852.0 PROD1, DRILL PMPO T RIH to 3106' MD. Break circ w/ 10.2 ppg
mud, line up on 30 ppb LCM pill and
pump 30 bbls down drillstring at 127 gpm
w/ 625 psi. Loss rate of 90 bbls/hr while
pumping pill. Continue pumping LCM pill
w/ pump out of hole f/ 3106' to 2852'.
Pump pressure spiked f/ 625 psi to 1200
psi. Shut down pumps and noted a slow
bleed off in pressure. No indications of an
annulus packoff (no overpull, no increase
in TQ). Line up pumps on 10.2 ppg mud.
Attempt to clear obstruction in drillstring-
rocking pumps up to 1200 psi. Pressure
started bleeding off as obstruction/plug
cleared.
3/18/2023
06:00
3/18/2023
08:30
2.5
0
2,852.0 2,222.0 PROD1, DRILL PMPO T Pump out of hole f/ 2852' to 2222' MD at
127 gpm-750 psi, pumping 10.2 ppg mud.
No losses.
3/18/2023
08:30
3/18/2023
09:30
1.0
0
2,222.0 2,222.0 PROD1, DRILL CIRC T Flow Check. Circulate inside the 7"
casing at 2222' MD, staging pumps to 255
gpm w/ 1825 psi. No losses.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 25/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/18/2023
09:30
3/18/2023
10:30
1.0
0
2,222.0 2,222.0 PROD1, DRILL OWFF T Flow check well. Static.
3/18/2023
10:30
3/18/2023
12:00
1.5
0
2,222.0 1,660.0 PROD1, DRILL PMPO T Pump out of hole f/ 2222' to 1660' MD w/
127 gpm-500 psi. P/U-50k. No losses.
3/18/2023
12:00
3/18/2023
14:30
2.5
0
1,660.0 904.0 PROD1, DRILL PMPO T Continue to pump out of hole f/ 1660' to
904' MD w/ 127 gpm-500 psi. No losses.
3/18/2023
14:30
3/18/2023
15:30
1.0
0
904.0 904.0 PROD1, DRILL OWFF T Flow check at bha. Well static, no losses.
3/18/2023
15:30
3/18/2023
16:30
1.0
0
904.0 300.0 PROD1, DRILL TRIP T Pooh on elevators w/ bha. Monitor well
on trip tank. Correct displacement w/
pooh.
3/18/2023
16:30
3/18/2023
19:30
3.0
0
300.0 0.0 PROD1, DRILL BHAH T Hold PJSM w/ SLB DD. L/d 6 1/8" bha
components. (Bit w/ 3x18's, Bit sub BFF,
XO sub, 16 jts of 4" hwdp, jars, 7 jts of 4"
hwdp).
3/18/2023
19:30
3/18/2023
20:30
1.0
0
0.0 0.0 PROD1, DRILL SVRG T Clear & Clean rig floor. Service rig floor.
Submitted notification to AOGCC to
witness BOPE test on 03/20/23.
Confirmation email received.
3/18/2023
20:30
3/18/2023
21:00
0.5
0
0.0 0.0 PROD1, DRILL BHAH T Make up 6 1/8" tricone bit w/ bit sub BFF
on hwdp.
3/18/2023
21:00
3/19/2023
00:00
3.0
0
0.0 1,550.0 PROD1, DRILL TRIP T TIH w/ bha to 1550', filling each std.
Cum losses for this interval: 322 bbls.
3/19/2023
00:00
3/19/2023
01:00
1.0
0
1,550.0 2,180.0 PROD1, DRILL TRIP T Continue to TIH w/ 6 1/8" tricone bit w/
3x18's nozzles w/ dumb iron bha f/ 1550'
to 2180' MD, filling each std. Correct pipe
displacement. (Procore LCM materials
arrived on location at 23:00 hrs) Simops:
Start mixing Procore LCM pill.
3/19/2023
01:00
3/19/2023
01:30
0.5
0
2,180.0 2,180.0 PROD1, DRILL CIRC T Circulate b/u at the casing shoe w/ 127
gpm-300 psi. No losses. Simops:
Continue mixing Procore LCM pill.
3/19/2023
01:30
3/19/2023
02:45
1.2
5
2,180.0 3,106.0 PROD1, DRILL TRIP T Continue to TIH w/ 2180' to 3106' MD,
filling each 4 stds. Correct pipe
displacement, no fill on bottom, no tight
spots in open hole. Simops: Continue
mixing Procore LCM pill.
3/19/2023
02:45
3/19/2023
06:00
3.2
5
3,106.0 3,106.0 PROD1, DRILL CIRC T Circulate at 127 gpm w/ 200 psi. 13 units
of gas at B/u. No losses. Continue to
build Procore LCM pill.
Total mud on surface: 755 bbls.
3/19/2023
06:00
3/19/2023
08:00
2.0
0
3,106.0 3,065.0 PROD1, DRILL PRTS T Rack back 1 std, blow down top drive &
mud lines to the mud pumps. R/u the
high pressure hose f/ SLB to stdpipe.
Send 10.2 ppg mud to SLB cement unit,
pump 10 bbls to fill lines & test lines to
1000 psi.
3/19/2023
08:00
3/19/2023
12:00
4.0
0
3,065.0 1,500.0 PROD1, DRILL DISP T SLB cmt unit pump 31 bbls of 10.2 ppg
Procore LCM pill @ 80 ppb consisting of 5
ppb Protightceal med, 5 ppb SB
Superceal, 70 ppb ProV+ at 3 bpm.
Pump OOH pulling at 2 min/std while cmt
unit is pumping the LCM pill at .3 bpm
placing the top of pill at 1500'.
3/19/2023
12:00
3/19/2023
13:00
1.0
0
1,500.0 1,500.0 PROD1, DRILL CIRC T Circ b/u. Hold PJSM on squeezing LCM
operations. R/u lines, close Annular and
prepare for Procore squeeze.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 26/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/19/2023
13:00
3/19/2023
20:00
7.0
0
1,500.0 1,500.0 PROD1, DRILL OTHR T Perform Procore LCM squeeze ops. 60
bbls of LCM in well f/ TD to 1500'. With
Annular closed, pumping with SLB cmt
unit down the DP building pressure in 50
psi increments. Hesitating 30 min
between each pumping interval,
monitoring the Max psi, Shut psi, & final
pressure each pumping interval. Pumped
a total of 32.3 bbls with a max of 350 psi
dynamic psi, max of 190 psi Final psi.
Total mud on surface: 800 bbls
3/19/2023
20:00
3/19/2023
21:00
1.0
0
1,500.0 1,500.0 PROD1, DRILL OWFF T Blow down all mud lines f/ SLB cement
unit to Rig floor. R/d SLB lines, Bleed off
pressure f/ the annulus, open Annular
preventer. Monitor well on trip tank and
well ballooned back 15 bbls prior to going
static.
3/19/2023
21:00
3/19/2023
21:30
0.5
0
1,500.0 1,500.0 PROD1, DRILL RGRP T Make repairs to topdrive grabber assy.
Sheared bolts/dies in grabber. Simops:
Transferring mud f/ Pit #6 to upright tank
in order to mix 110 bbls of Procore LCM
pill.
3/19/2023
21:30
3/19/2023
22:15
0.7
5
1,500.0 1,500.0 PROD1, DRILL CIRC T Make up topdrive, break circ w/ 127
gpm/200 psi. No losses. Blow down
topdrive.
Simops: Cleaning pit for mixing of
Procore LCM pill.
3/19/2023
22:15
3/19/2023
23:00
0.7
5
1,500.0 2,420.0 PROD1, DRILL TRIP T Tih to 2420 w/ 6 1/8" tricone bit.
Simops: Mixing 110 bbls of Procore LCM
pill at 100 ppb.
3/19/2023
23:00
3/20/2023
00:00
1.0
0
2,420.0 2,420.0 PROD1, DRILL CIRC T Make up topdrive, circulate b/u w/ 127
gpm/200 psi until shakers are clean of
LCM. No losses. Blow down topdrive.
Simops: Continue to prepare Procore
LCM pill.
3/20/2023
00:00
3/20/2023
01:30
1.5
0
2,420.0 2,619.0 PROD1, DRILL TRIP T Tih f/ 2420' to 2619' MD. Break circ &
circulate b/u at 127 gpm w/ 300 psi. No
mud losses.
3/20/2023
01:30
3/20/2023
02:00
0.5
0
2,619.0 3,106.0 PROD1, DRILL TRIP T Tih f/ 2619' to 3106' MD.
3/20/2023
02:00
3/20/2023
04:30
2.5
0
3,106.0 3,106.0 PROD1, DRILL CIRC T Circ b/u at 127 gpm w/ 350 psi. 31 units
max gas at b/u. Circ until shakers clean
up f/ LCM material, then stage pumps up
to 175 gpm w/ 400 psi. No losses. Stage
pumps up to 255 gpm w/ 550 psi. No
losses. Begin pipe rotation-f/ 40 rpms to
120 rpms w/ reciprocating the drill string,
simulating drilling activities. No losses.
Stage pumps up to 302 gpm w/ 800 psi,
120 rpms. No losses.
3/20/2023
04:30
3/20/2023
05:00
0.5
0
3,106.0 3,106.0 PROD1, DRILL OWFF T Flow check well on trip tank. Decision
made to stop preparation of the 2nd
Procore pill prior to barite additions due to
no subsurface mud losses. Make plan to
transfer LCM pill to a Vac truck for
storage.
3/20/2023
05:00
3/20/2023
07:00
2.0
0
3,106.0 2,128.0 PROD1, DRILL PMPO T Pump OOH f/ 3106' to 2128' MD at 127
gpm w/ 325 psi. P/u 63k.
3/20/2023
07:00
3/20/2023
08:00
1.0
0
2,128.0 2,128.0 PROD1, DRILL OWFF T Flowcheck on trip tank at the shoe. Static.
3/20/2023
08:00
3/20/2023
11:30
3.5
0
2,128.0 737.0 PROD1, DRILL PMPO T Pump OOH f/ 2128' to 737' MD w/ 127
gpm at 200 psi.
3/20/2023
11:30
3/20/2023
12:00
0.5
0
737.0 737.0 PROD1, DRILL OWFF T Flowcheck at BHA. Static.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 27/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/20/2023
12:00
3/20/2023
13:30
1.5
0
737.0 0.0 PROD1, DRILL TRIP T Pooh f/ 737' to surface. Break off 6 1/8"
tricone bit. Monitoring well on trip tank-
static.
Tested all gas alarms on the rig.
3/20/2023
13:30
3/20/2023
14:00
0.5
0
0.0 0.0 PROD1, DRILL CLEN T Clear & clean rig floor. Monitor well on
trip tank-static.
3/20/2023
14:00
3/20/2023
14:30
0.5
0
0.0 0.0 PROD1, DRILL MPSP P Retrieve wear bushing. Well static.
3/20/2023
14:30
3/20/2023
16:00
1.5
0
0.0 0.0 PROD1, DRILL RURD P R/u to test BOPE. P/u 3 1/2" test
mandrel, make up head pin, l/d same.
P/u 4" test mandrel. Make up test plug,
FOSV & Inside grey (dart valve). Set test
plug, ensure casing valve is open and
monitored.
3/20/2023
16:00
3/20/2023
22:30
6.5
0
0.0 0.0 PROD1, DRILL BOPE P Pressure tet 11" 5ksi BOP to 250/3500 for
5/5 min.
4" Test mandrel:
Test #1- CMV #5, 9, 14, 18, annular &
dart valve.
Test #2- CMV #1, 4, 8, 15, upper pipe
rams TIW, HCR Kill.
Test #3- Super choke on CM @ 1500 psi.
Test #4- CMV #3, 7, 13, Manual kill valve,
upper ibop.
Test #5- CMV #2, 6, 12, Lower ibop.
Test #6- Manual choke on CM @ 1500
psi.
Test #7- CMV #11
Test #8- Lower pipe rams
3.5" Test Mandrel:
Test #9- Annular preventer, HCR choke
Test #10- Upper pipe rams, manual valve
on mud cross.
Test #11-Koomey test-Witnessed by CPAI
DSV.
Test #12- Lower pipe rams
Test #13-Blind Shear rams
3/20/2023
22:30
3/20/2023
23:30
1.0
0
0.0 0.0 PROD1, DRILL MPSP P R/d test plug, close casing valve. Install
wear bushing and secure with hold down
pins.
3/20/2023
23:30
3/21/2023
00:00
0.5
0
0.0 0.0 PROD1, DRILL RURD P R/d all test equipment, break down test
plug, safety valves from test joints. Clear
floor. Blow down choke/kill lines. Line up
Choke manifold for well control & safety
valves on the rig floor.
3/21/2023
00:00
3/21/2023
04:30
4.5
0
0.0 925.0 PROD1, DRILL BHAH T Hold PJSM, discuss loading RA sources.
P/u Bha #6- 6 1/8" production interval
assy to 925' MD.
3/21/2023
04:30
3/21/2023
06:00
1.5
0
925.0 1,869.0 PROD1, DRILL TRIP T TIH w/ 6 1/8" bha on 4" DP f/ 925' to 1869'
MD. S/O-55k No losses, proper hole fill.
3/21/2023
06:00
3/21/2023
06:45
0.7
5
1,869.0 1,869.0 PROD1, DRILL DHEQ T Shallow test SLB MWD tools. Minimum
rate for tools functionality -215 gpms. No
losses.
3/21/2023
06:45
3/21/2023
08:15
1.5
0
1,869.0 3,106.0 PROD1, DRILL TRIP T Tih f/ 1869' to 3106' MD. No fill on
bottom. S/O-65k. Proper hole fill.
3/21/2023
08:15
3/21/2023
09:00
0.7
5
3,106.0 3,106.0 PROD1, DRILL CIRC T Stage mud pump up to 188 gpm,
monitoring for any losses. 188 gpm-1050
psi, 206 gpm-1200 psi. Flow check.
3/21/2023
09:00
3/21/2023
12:00
3.0
0
3,106.0 3,106.0 PROD1, DRILL CIRC T Circ at 180 gpm w/ 870 psi, rpm-30, TQ
-.8k, reducing mud wt f/ 10.0 ppg to 9.7
ppg.
3/21/2023
12:00
3/21/2023
12:30
0.5
0
3,106.0 3,106.0 PROD1, DRILL OWFF T Flow check well. Static.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 28/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/21/2023
12:30
3/21/2023
18:00
5.5
0
3,106.0 3,355.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 3106'
to 3355' MD. Pumping 30 bbls of 30 ppb
LCM sweeps every other std, initially, then
stopped due to losing sync on MWD tools.
Held Kick w/ drilling Drill-response time-
120 sec.
WOB-6k
RPM-100
TQ-1-4k
SPM-120
GPM-237
PSI-1680
FO-42%
P/U-75
S/O-72
RW-72
ROP av-80'/hr
ADT-4.34 hrs
PVT-318 bbls
BG gas-10
ECD-11.35 ppg
SPR @ 3300' w/ 9.7 ppg
#1-SPM-65, 500 psi, #1-SPM-65, 450 psi,
#3 SPM 65, 500 psi.
3/21/2023
18:00
3/22/2023
00:00
6.0
0
3,355.0 3,692.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 3355'
to 3692' MD.
WOB-5k
RPM-90
TQ-2-4k
SPM-116
GPM-227
PSI-1660
FO-42%
P/U-75
S/O-72
RW-72
ROP av-70'/hr
ADT-4.34 hrs
PVT-315 bbls
BG gas-30
ECD-11.45 ppg
3/22/2023
00:00
3/22/2023
06:00
6.0
0
3,692.0 3,985.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 3692'
to 3985' MD.
WOB-5k
RPM-90-100
TQ-2-6k
SPM-118
GPM-231
PSI-1660
FO-42%
P/U-75
S/O-72
RW-72
ROP av-70'/hr
ADT-4.34 hrs
PVT-307 bbls
BG gas-15
ECD-11.45 ppg
Mud wt-9.7 ppg
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 29/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/22/2023
06:00
3/22/2023
12:00
6.0
0
3,985.0 4,264.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 3985'
to 4264' MD.
WOB-5k
RPM-90-100
TQ-2-6k
SPM-118
GPM-233
PSI-1750
FO-42%
P/U-78
S/O-77
RW-77
ROP av-70'/hr
ADT-4.21 hrs
PVT-307 bbls
BG gas-15
ECD-11.35 ppg
9.7 ppg
SPR @ 3949' MD w/ 9.7 ppg -65 spm-#1-
725 psi, #2-550 psi, #3-500 psi
3/22/2023
12:00
3/22/2023
18:00
6.0
0
4,264.0 4,575.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 4264'
to 4575' MD.
WOB-5-14k
RPM-90-100
TQ-2-6k
SPM-121
GPM-234
PSI-1870
FO-36%
P/U-78
S/O-77
RW-77
ROP av-90'/hr
ADT-4.0 hrs
PVT-330 bbls
BG gas-31
ECD-11.4 ppg
9.75 ppg
SPR @ 4260' MD w/ 9.8 ppg -65 spm-#1-
600 psi, #2-550 psi, #3-500 psi
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 30/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/22/2023
18:00
3/23/2023
00:00
6.0
0
4,575.0 4,892.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 4575' -
4892' MD.
WOB-5-14k
RPM-90-100
TQ-2-6k
SPM-121
GPM-234
PSI-1870
FO-36%
P/U-78
S/O-77
RW-77
ROP av-90'/hr
ADT-4.22 hrs
PVT-330 bbls
BG gas-31
ECD-11.45 ppg
9.85 ppg
SPR @ MD w/ 9.8 ppg -65 spm-#1-600
psi, #2-550 psi, #3-500 psi
Flow checked w/ drilling at 4778' MD
Flow checked w/ drilling at 4818' MD
(gain in active pit each time, mixing pump
issue)
Sent 72 hr notification to AOGCC for
BOPE test on 03/25/2023 depending on
our operations.
3/23/2023
00:00
3/23/2023
06:00
6.0
0
4,892.0 5,096.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 4892'
to 5096' MD.
WOB-7-10k
RPM-90-100
TQ-2-6k
SPM-121
GPM-234
PSI-1870
FO-36%
P/U-95k
S/O-93k
RW-93k
ROP av-50'/hr
ADT-3.9 hrs
PVT-330 bbls
BG gas-31
ECD-11.2 ppg
9.85 ppg
Decrease ROP to 50'/hr at 5032' MD.
Sent 72 hr notification to AOGCC for
BOPE test on 03/22/2023. Updated
communication with AOGCC again on 03-
23-2023
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 31/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/23/2023
06:00
3/23/2023
12:00
6.0
0
5,096.0 5,260.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 5096'
to 5260' MD.
WOB-7-12k
RPM-90-100
TQ-2-6k
SPM-121
GPM-234
PSI-165
FO-36%
P/U-100k
S/O-95k
RW-95k
ROP av-50'/hr
ADT-4.25 hrs
PVT-349 bbls
BG gas-31
ECD-11.2 ppg
9.9 ppg
SPR @ 5260' MD w/ 9.9 ppg -65 spm-#1
-600 psi, #2-550 psi,
3/23/2023
12:00
3/23/2023
18:30
6.5
0
5,260.0 5,523.0 PROD1, DRILL DDRL P Drilling 6 1/8" production interval f/ 5260'
to 5523' MD.
WOB-7-12k
RPM-90-100
TQ-2-6k
SPM-121
GPM-234
PSI-165
FO-36%
P/U-100k
S/O-95k
RW-95k
ROP av-100'/hr
ADT-4.94 hrs
PVT-349 bbls
BG gas-31
ECD-11.2 ppg
9.9 ppg
3/23/2023
18:30
3/23/2023
20:00
1.5
0
5,523.0 5,523.0 PROD1, PLUG CIRC P Circulate hole cleanup cycles at 236 gpm
w/ 1920 psi w/ 100 rpms, reciprocating
the pipe slowly.
Circulated 4 bottoms up. (Simops:
Working with Tesco Topdrive-unable to
rotate)
3/23/2023
20:00
3/23/2023
21:00
1.0
0
5,523.0 5,523.0 PROD1, PLUG OWFF P Flow check well on trip tank.--Static.
3/23/2023
21:00
3/23/2023
21:45
0.7
5
5,523.0 5,462.0 PROD1, PLUG PMPO P Pump OOH @ 227 gpm w/ 1950 psi at
700' fph f/ 5523' to 5462' MD. While
attempt to rack back 1st stand, Topdrive
grabber dies failed. Repair same.
3/23/2023
21:45
3/24/2023
00:00
2.2
5
5,462.0 4,876.0 PROD1, PLUG PMPO P Pump OOH w/ 227 gpm w/ 1950 psi at
700'-1000' fph f/ 5462' to 4876'.
Had slight overpulls at:
5299'-15k
5245'-5k
5174'-6k
Wiped out each interval before continuing
to pull.
Proper pipe displacment on trip out.
3/24/2023
00:00
3/24/2023
09:00
9.0
0
4,876.0 2,240.0 PROD1, PLUG PMPO P Pump OOH w/ 233 gpm w/ 2045 psi at
700'-1000' fph f/ 4876' to 2240' MD. P/U-
92k.
Proper pipe displacment on trip out.
3/24/2023
09:00
3/24/2023
10:00
1.0
0
2,240.0 2,240.0 PROD1, PLUG CIRC P Circ b/u at casing shoe-2240' MD @ 220
gpm w/ 1700 psi.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 32/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/24/2023
10:00
3/24/2023
10:30
0.5
0
2,240.0 2,240.0 PROD1, PLUG OWFF P Flow check well on trip tank-static.
3/24/2023
10:30
3/24/2023
12:00
1.5
0
2,240.0 1,675.0 PROD1, PLUG PMPO P Continue to Pump OOH f/ 2240' to 1675'
MD w/ 220 gpm, 1350 psi. P/U-55k.
3/24/2023
12:00
3/24/2023
14:00
2.0
0
1,675.0 925.0 PROD1, PLUG PMPO P Continue to Pump OOH f/ 1675' to 925'
MD w/ 220 gpm, 1200 psi. P/U 40k.
3/24/2023
14:00
3/24/2023
18:00
4.0
0
925.0 282.0 PROD1, PLUG PMPO P Continue to Pump OOH f/ 925' to 282'
MD, laying down 4" HWDP w/ 220 gpm,
1000 psi. P/u 30K
3/24/2023
18:00
3/24/2023
21:15
3.2
5
282.0 0.0 PROD1, PLUG BHAH P POOH l/d 6 1/8" bha, laying down all
components. Hold PJSM for removing
RA Source f/ bha.
3/24/2023
21:15
3/24/2023
22:30
1.2
5
0.0 0.0 PROD1, PLUG RURD P Clear & clean rig floor of SLB bha subs.
Clear skate in pipe shed. Hold PJSM.
Monitoring well on trip tank-static.
3/24/2023
22:30
3/24/2023
23:30
1.0
0
0.0 0.0 PROD1, PLUG OTHR P P/u Halliburton plug launching manifold,
remove ACME sub, load BHKA dart,
witnessed by CPAI DSV. M/u & torque
NC50 handling sub on plug launcher. L/d
same to pipe shed.
3/24/2023
23:30
3/25/2023
00:00
0.5
0
0.0 0.0 PROD1, PLUG RURD P R/u Doyon casing tools to run 3.5" 9.3# L-
80 EUE 8rd tubing. Monitor well on trip
tank. XO 3.5" EUE pin X XT39 made up
to FOSV and ready on rig floor.
Simops ongoing: Pump out dilution fluid
f/ Pit #6. Transfer LCM f/ pill pit to #6 pit.
Cleaning Pill pit for mixing Mud Push
Spacer for SLB cementer. Prepare
chemicals for mixing of Blackwater pill for
upcoming cement job. Prepare to pump
remaining ProCore pill & mud f/ upright
tank and circ around system after cement
plug job.
3/25/2023
00:00
3/25/2023
01:00
1.0
0
0.0 0.0 PROD1, PLUG RURD P R/u Doyon casing tools to run 3.5" 9.3# L-
80 EUE 8rd tubing. Monitor well on trip
tank. XO 3.5" EUE pin X XT39 made up
to FOSV and ready on rig floor.
Simops ongoing: Pump out dilution fluid
f/ Pit #6. Transfer LCM f/ pill pit to #6 pit.
Cleaning Pill pit for mixing Mud Push
Spacer for SLB cementer. Prepare
chemicals for mixing of Blackwater pill for
upcoming cement job. Prepare to pump
remaining ProCore pill & mud f/ upright
tank and circ around system after cement
plug job.
3/25/2023
01:00
3/25/2023
07:30
6.5
0
0.0 3,501.0 PROD1, PLUG PUTB P P/u singles & rih w/ 3.5" 9.3# L-80 EUE 8
rd tubing to 3501' MD. Monitoring
displacement on triptank.
Simops: Mixing SLB Mud Push spacer at
10.5 ppg.
3/25/2023
07:30
3/25/2023
09:00
1.5
0
3,501.0 3,501.0 PROD1, PLUG PUTB P P/u & Halliburton BHKA tool w/ DP
adaptor sub w/ 6" Stub ACME pin XO &
EUE pin X XT39 XO. Change out
elevators f/ 3.5" to 4".
3/25/2023
09:00
3/25/2023
12:00
3.0
0
3,501.0 5,522.0 PROD1, PLUG TRIP P TIH w/ 32 stds of 4" 14# XT39 drillpipe f/
3501' to 5522' MD and tagged up w/ 15k.
3/25/2023
12:00
3/25/2023
13:30
1.5
0
5,522.0 5,522.0 PROD1, PLUG RURD P P/u Halliburton dart launching/cement
head. M/u XO & FOSV beneath it. R/u
lines.
3/25/2023
13:30
3/25/2023
18:30
5.0
0
5,522.0 5,522.0 PROD1, PLUG CIRC P Hold PJSM, circ 2 b/u w/ 208 gpm-425
psi. Pump LCM sweeps out of Pit #6 and
NES truck. Mix water was at 100 deg.
Bring in more water to cool it down to 90
deg.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 33/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/25/2023
18:30
3/25/2023
19:30
1.0
0
5,522.0 5,522.0 PROD1, PLUG CIRC P Continue circ w/ 208 gpm-420 psi, while
mixing Contaminated Pill-100 bbls in Pit
#6 & weight up Mud Push spacer to 10.5
ppg. NES preparing cutting boxes at
rockwasher for cement job.
3/25/2023
19:30
3/25/2023
20:00
0.5
0
5,522.0 5,522.0 PROD1, PLUG CIRC P Hold PJSM with all personnel for cement
job. Blow down low psi mud lines down f/
rig to SLB cement unit to ensure still clear.
Pumped 37 bbls of 10.5 ppg Mud Push w/
rig pump at 198 gpm w/ 382 psi.
3/25/2023
20:00
3/25/2023
21:00
1.0
0
5,522.0 5,522.0 PROD1, PLUG PRTS P Blow down rig lines back to mud pumps,
blow down SLB hard line f/ rig to pump to
confirm clear. Break circ with SLB
Cement unit and test lines at 500/3500
psi.
3/25/2023
21:00
3/25/2023
22:00
1.0
0
5,522.0 2,020.0 PROD1, PLUG CMNT P Mix & pump 131 bbls of 11.0 ppg Litecrete
slurry at 4.6 bpm w/ 860 psi. Drop the
Halliburton BHKA dart f/ plug launcher,
good indication of dart launching with flag.
SLB displaced with 9.9 ppg mud @ 4 bpm
for 17 bbls, then slowed to 3 bpm and
latched plug at 21 bbls away w/ 2500 psi.
Good indication of BHKA disconnect w/
Weight indicator change f/ 65k lbs to 46k
lbs. BHKA disconnect at 2020' MD. No
mud losses during cement operations.
Cement in place at 21:45 hrs.
3/25/2023
22:00
3/25/2023
23:00
1.0
0
2,020.0 1,959.0 PROD1, PLUG WOC P Remove Haliburton Dart launching head
and pick up 60' above BHKA at 1959' MD.
Drop foam ball & circ 2-bottoms up at 200
gpm w/ 250 psi, slowing to 150 gpm w/
150 psi. Observed mud push spacer and
a trace of cement over shakers.
3/25/2023
23:00
3/26/2023
00:00
1.0
0
1,959.0 1,920.0 PROD1, PLUG WOC P L/d single DP w/ FOSV & 2 ea 4" pup jts.
M/u TD & circ 1500 stks at 150 gpm w/
150 psi while clearing rig floor. Shut down
pump & flowcheck.
3/26/2023
00:00
3/26/2023
00:30
0.5
0
1,920.0 1,920.0 PROD1, PLUG WOC P Finished l/d single of 4" DP w/ pup jts &
FOSV. OWFF w/ tour changing at 1920'
MD. FOSV on rig floor w/ WOC.
3/26/2023
00:30
3/26/2023
05:30
5.0
0
1,920.0 0.0 PROD1, PLUG WOC P Pooh w/ BHKA running tool, laying down
4" 14# S-135 XT39 DP. Monitor fillups on
trip tank. Lay down 64 jts total. Break off
the Halliburton BHKA tool & DP adaptor
sub w/ ACME conn & 3.5" EUE 8rd X
XT39 box crossover sub. P/u single f/
pipe shed and break down pup jts &
FOSV w/ WOC.
3/26/2023
05:30
3/26/2023
06:00
0.5
0
0.0 0.0 PROD1, PLUG WOC P Service rig w/ monitor well on trip tank w/
WOC.
3/26/2023
06:00
3/26/2023
08:30
2.5
0
0.0 0.0 PROD1, PLUG WOC P RIH w/ 15 stds of 4" XT39 DP f/ the
derrick to 931'. Pooh & l/d same to the
pipe shed. Loading all 4" DP to pipe tubs
(48 jts per tub). Monitoring well on trip
tank, WOC.
3/26/2023
08:30
3/26/2023
11:00
2.5
0
0.0 0.0 PROD1, PLUG WOC P RIH w/ 15 stds of 4" XT39 DP f/ the
derrick to 931'. Pooh & l/d same to the
pipe shed. Loading all 4" DP to pipe tubs
(48 jts per tub). Monitoring well on trip
tank w/ WOC.
3/26/2023
11:00
3/26/2023
13:30
2.5
0
0.0 0.0 PROD1, PLUG WOC P RIH w/ 15 stds of 4" XT39 DP f/ the
derrick to 931'. Pooh & l/d same to the
pipe shed. Loading all 4" DP to pipe tubs
(48 jts per tub). Monitoring well on trip
tank w/ WOC.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 34/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/26/2023
13:30
3/26/2023
15:00
1.5
0
0.0 1,054.0 PROD1, PLUG WOC P Tih open ended w/ 4" XT39 DP f/ derrick
to 1054'. Monitoring well on trip tank w/
WOC.
3/26/2023
15:00
3/26/2023
15:30
0.5
0
1,054.0 1,054.0 PROD1, PLUG WOC P R/d SLB sensors f/ standpipe &
drawworks w/ WOC.
3/26/2023
15:30
3/26/2023
17:30
2.0
0
1,054.0 0.0 PROD1, PLUG WOC P Pooh l/d 4" XT39 DP f/ 1054'. Monitoring
well on trip tank w/ WOC.
3/26/2023
17:30
3/26/2023
18:00
0.5
0
0.0 0.0 PROD1, PLUG WOC P Retrieve wear bushing.
3/26/2023
18:00
3/26/2023
20:00
2.0
0
0.0 0.0 PROD1, PLUG WOC P Fill pit#6 w/ water. M/u jet tool and wash
Bops. L/d BOP jet tool & 1 jts of 4" DP.
3/26/2023
20:00
3/26/2023
21:30
1.5
0
0.0 0.0 PROD1, PLUG RURD P Hold PJSM. P/u 4" test jt & make up
FOSV, inside BOP and set test plug. R/u
to test BOPE.
3/26/2023
21:30
3/27/2023
00:00
2.5
0
0.0 PROD1, PLUG BOPE P Test 11" 5k psi BOPE on 4" & 3.5" test
joints at 250/3500 psi for 5/5 min.
#1 Test-CMV #5,9,14,18, annular, dart
valve--250/3500 psi
#2 Test-CMV #1,4,8,15, UPR, FOSV--
250/3500 psi
#3 Test-Superchoke-1500 psi
#4 Test-CMV 3,7,13, Manual Kill valve,
Upper IBOP-250/3500 psi
3/27/2023
00:00
3/27/2023
07:00
7.0
0
0.0 0.0 PROD1, PLUG BOPE P Test 11" 5k psi BOPE on 4" & 3.5" test
joints at 250/3500 psi for 5/5 min.
Continue to test BOPE.
Test #5-CMV #2,6,12, Lower IBOP
Test #6-Manual choke on CM, 1500 psi
Test #7- CMV #11
Test #8-Lower Pipe Rams
C/O test jt f/ 4" mandrel to 3.5" test
mandrel
Test #9-Annular, HCR choke
Test #10-UR, manual choke
Test #11-LR
Test #12-BSR, CMV #10
Simops: R/d SLB MWD/DD units &
equipment.
3/27/2023
07:00
3/27/2023
09:00
2.0
0
0.0 0.0 PROD1, PLUG RURD P Retrieve test plug, close casing valve. L/d
test plug & test jt. L/d handling
equipment. P/u 4.5" landing jt w/ 4.5" IBT
& m/u crossovers. L/d same. Clear &
clean rig floor. Blow down choke & kill
lines.
3/27/2023
09:00
3/27/2023
12:00
3.0
0
0.0 508.0 PROD1, PLUG PUTB P R/u Doyon casing tong & run 3.5" 9.3# L-
80 EUE 8rd tubing to 508' MD. Change
out tubing tongs. XO & FOSV on rig floor.
3/27/2023
12:00
3/27/2023
14:30
2.5
0
508.0 1,997.0 PROD1, PLUG PUTB P Hold PJSM, continue to run 3.5" tubing f/
508' to 1997'. Tagged up w/ 10k wt down.
Witnessed by AOGCC rep Adam Earl.
3/27/2023
14:30
3/27/2023
16:30
2.0
0
1,997.0 1,997.0 PROD1, PLUG PRTS P R/u lines & attempt to test the lower P&A
plug with the Doyon injection pump.
Pump failed. R/u lines to SLB unit.
Pressure test the lower P&A plug at 1997'
MD w/ 1610 psi for 30 min. Good test.
AOGCC rep departed location.
3/27/2023
16:30
3/27/2023
17:30
1.0
0
1,997.0 1,994.6 PROD1, PLUG CIRC P Circ & cond mud @ 65 spm w/ 200 psi.
Simops: Start r/d of Geolog mudlogging
equipment.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 35/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/27/2023
17:30
3/27/2023
19:30
2.0
0
1,994.6 1,994.6 PROD1, PLUG RURD P Blow down mud lines. R/d test valves.
L/d 1 jt of 3.5" tubing (jt #63). Change
elevator f/ 3.5" to 4.5". P/u the 4.5"
landing jt & make up the XT39 X 1502
Weco & torque same. L/d same. Change
elevators back to 3.5", p/u 3.5" tubing jt
#63, XO 3.5" EUE 8rd x 4.5" IBT box, 4.5"
IBT pup jt & FMC hanger (10.8" OD).
With BOPs drained, lower the hanger and
land at 18.19 RKB. EOT at 1994.6' MD.
3/27/2023
19:30
3/27/2023
20:30
1.0
0
1,994.6 1,994.6 PROD1, PLUG WWSP P Run in FMC hanger hold down pins w/ in
simops: rig up SLB cement lines, pump
out BOP cellar, install 90 deg on IA casing
valve, stage NES vac trucks at cellar w/
contaminated pill in each truck.
3/27/2023
20:30
3/27/2023
21:30
1.0
0
1,994.6 1,994.6 PROD1, PLUG CIRC P Hold PJSM w/ all personnel for cementing
operations. Break circ w/ SLB cement
unit. Test lines at 2400 psi. Pump 30
bbls of 10.5 ppg Mud Push w/ rig pump.
3/27/2023
21:30
3/27/2023
22:00
0.5
0
1,994.6 1,994.6 PROD1, PLUG CMNT P Mix & pump 84 bbls of 15.7 ppg ASI
cement as per SLB, taking returns via IA
casing valve into the cellar. Observed the
Mud Push returns to surface, followed
with cement returns at surface after 74
bbls of 15.7 ppg cement pumped away.
Weighting cement returns to confirm
along with PH meter and chemically
checking. Confirmed with 15.7 ppg
cement returns. Continue pumping 8
more bbls to devoid the cement mixing
tub on unit. Displace w/ 3.5 bbls of water.
NES vacuum truck pumping
mud/pill/cement from cellar in simops.
CIP at 22:00 hrs.
3/27/2023
22:00
3/27/2023
22:30
0.5
0
1,994.6 1,994.6 PROD1, PLUG WOC P While WOC, Bleed off psi, monitor well to
ensure balanced. Blow down SLB lines.
3/27/2023
22:30
3/27/2023
23:00
0.5
0
1,994.6 0.0 PROD1, PLUG WOC P While WOC, Back out the 4.5" landing jt
from the FMC tubing hanger. Pump
blackwater through all lines and landing jt.
L/d same. Simops: Start r/d SLB MI
Swaco mud lab. Put 20 bbls of
blackwater in rockwasher.
3/27/2023
23:00
3/28/2023
00:00
1.0
0
0.0 0.0 PROD1, PLUG WOC P While WOC, P/u jet tool & jt of 4" XT39
DP. Circ w/ blackwater, jetting the 11" 5M
BOP. Pump thru choke/kill lines. L/d DP.
Blow down mud lines & cement lines.
Note: Will allow SLB cement team to rest
and start their r/d of equipment tomorrow.
3/28/2023
00:00
3/28/2023
01:30
1.5
0
0.0 0.0 PROD1, PLUG WOC P WOC on the upper P&A cement job to
surface. Simops: Blow down choke
manifold. Pump blackwater through all
pumps, flush w/ fresh water & blow down
same. Pull suction screeens, freeze
protect test pump.
3/28/2023
01:30
3/28/2023
04:30
3.0
0
0.0 0.0 PROD1, PLUG WOC P P/u 4.5" landing jt & remove crossover
subs. Break down subs f/ Halliburton dart
launcher. L/d handling equip f/ rig floor.
Psi washing BOPs, cleaning pill pit & trip
tank.
3/28/2023
04:30
3/28/2023
07:00
2.5
0
0.0 0.0 PROD1, PLUG NUND P Remove fluids f/ BOPs w/ supersucker,
remove drip pan & BOP turnbuckles. N/d
flow riser & outside choke/kill lines.
3/28/2023
07:00
3/28/2023
14:00
7.0
0
0.0 0.0 PROD1, PLUG NUND P Bleed down accumulator pressure. N/d
Bop riser. Remove accumulator control
lines. N/d 11" 5M BOPE & Annular
preventer.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 36/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/28/2023
14:00
3/28/2023
17:00
3.0
0
0.0 0.0 PROD1, PLUG NUND P Clean off wellhead. String check TOC in
3.5" tubing-TOC at 249'. Install FMC
adaptor spool & 5M dry hole tree.
Simops: Pumping fluid f/ mud pits,
cleaning mud pits. R/d all service
contractor units-MWD, Mudlogger, Mud
Lab, Cement unit. Staging all third party
rental tools for loadout and transport off
location (tubulars, landing jts, PESI tools,
KDTH equip, Hallib, SLB)
3/28/2023
17:00
3/28/2023
18:00
1.0
0
0.0 0.0 DEMOB, MOVE DMOB P Break off BOP handling tool, XT39 x
NC50 XO. L/d handling joint.
3/28/2023
18:00
3/29/2023
00:00
6.0
0
0.0 0.0 DEMOB, MOVE DMOB P Clean cellar box. R/d cement manifold,
standpipe, elevators, bale links. Breakout
saver sub & IBOP. Pull seats, liners &
pistons on mud pumps 2 & 3. Grease
pump modules & freeze protect same.
Offloading mud from pits and rockwasher.
Continue cleaning mud pits. Pressure
washing rig floor windwalls & derrick.
3/29/2023
00:00
3/29/2023
06:00
6.0
0
0.0 0.0 DEMOB, MOVE RURD P Hold PJSM. Continue to rig down Rig
components. R/d mud pumps & freeze
protect, power washing wind walls.
Cleaning mud pits. R/d Koomey unit &
store lines. R/d service umbilical for
topdrive. Disconnect topdrive mud hose.
L/d topdrive torque tube f/ derrick to pipe
shed. R/d auto driller & rig floor camera
system.
3/29/2023
06:00
3/29/2023
12:00
6.0
0
0.0 0.0 DEMOB, MOVE RURD P Lay down Block assy link tilt. L/d lower
section of torque tube. Continue cleaning
mud pits. Finished rigging down mud
pumps. Blow down mud gas separator.
Prepare pipe shed for transporting.
Crane fly the topdrive cradle to the rig
floor & secure topdrive in transport cradle.
Remove centrifuge & MGS for transport.
Troubleshooting hydraulics on reel house.
Remove external mud lines & choke
hose.
3/29/2023
12:00
3/29/2023
18:00
6.0
0
0.0 0.0 DEMOB, MOVE RURD P Hold PJSM.
* Spool up topdrive service loop w/ crane.
Remove washpipe f/ topdrive. Prepare
derrick mast for telescoping down: Unplug
lights, r/d drk board, install bridle lines
back in sheaves, turn standpipe & r/d
crownsaver.
* Break interconnects between mud pits.
* R/d flowline.
* Drain mixing pumps & desilter pump.
* Remove stairs and landing from
rockwasher pit.
* R/d mud pits, remove auger.
Release Rig at 18:00 hrs.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 37/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/29/2023
18:00
3/30/2023
00:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Hold PJSM.
* Remove topdrive f/ rig floor w/ crane.
* Remove windwall doors above the cattle
shoot.
* Install bridle becket in blocks & bridle
up.
* Adjust SLB sensor at stdpipe gooseneck
to clear drk board.
* Secure topdrive kelly hose and cement
line to stdpipe.
* Telescope top section of derrick mast
down.
* Hang blocks on torque tube.
* Hang kelly hose & cement line in
derrick.
* R/d geronimo line.
* R/d rig floor dog house.
3/30/2023
00:00
3/30/2023
06:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Hold PJSM.
* Secure block assy, derrick, clean out
flow line, cellar hoses.
* Disconnect PRV's, high pressure lines at
mud pumps.
* Vacuum fluid from rock washer & cellar
box.
* R/d Doyon shop for transport.
* Transporting in: MI Swaco pallet
materials, Brice heaters, 200 bbls of
drilling fluids. SLB MWD unit, MI Mud lab.
3/30/2023
06:00
3/30/2023
12:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P * Blow down sub steam heaters.
* Move the C-18 & VFD control room out
and stage for transport.
* Continue to rig down the shop, pits &
pipe shed.
* Continue cleaning the rock washer pits.
3/30/2023
12:00
3/30/2023
18:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Hold PJSM.
* String down block & crown. Install
string up line.
* Move out and stage pipe shed heater.
* Continue to r/d shop, pits, rock washer &
pipe shed.
* Blow down steam & water.
* Crane lifts: fly roof caps & poles behind
the drk.
* Move out and stage pipe shed and cattle
shoot.
* Fly windwalls, roof caps, rafters &
trappers cabin off of drawworks skid.
* Continue to pump out rockwasher.
* Shipped 180 bbls of drilling fluids.
* Transport MI pallet material to 2P.
* Transport 2- 4" DP tubs.
3/30/2023
18:00
3/31/2023
00:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Hold PJSM.
* Disconnect lines from doghouse.
* Secure tugger lines & geronimo line in
derrick.
* Lay derrick horizontal.
* Disconnect mast cylinders & hyd lines.
* Rig down & lower doghouse into water
tank.
* Move out water tank to staging area.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 38/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
3/31/2023
00:00
3/31/2023
06:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Demobilization of the Arctic Fox f/ Bear 1
location. PJSM
* Removing windwalls from sub base,
stack up and secure for loadout.
* Stowe remaining fuel lines & electrical
cables.
* R/d interconnecting pit doors.
* L/d sub base doors and secure same.
* Stage down boilers to cool.
* Position crane and rig up for lift.
Backload for transport to 2P:
* 2 tubs of 4" DP.
* 120 bbls of drilling fluids.
3/31/2023
06:00
3/31/2023
12:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P Continue rig down of Arctic Fox. PJSM.
* Remove derrick mast f/ rig sub base &
load out on Rolligon trailer. Secure same.
* R/d drawworks skid & coolant lines.
* Position crane to lift drawworks skid.
* Allowing boiler to continue to cool down.
Transport to 2P:
* 16 rig mats.
3/31/2023
12:00
3/31/2023
18:00
6.0
0
0.0 0.0 DEMOB, MOVE MOB P PJSM. Rigging down rig components.
* Crane lift drawworks kid off of sub &
move to staging area.
* Crane lift sub base f/ well, stage to truck
and load out on haul trailer.
* Remove shaker tank & stage.
* Remove shale shaker baskets w/ loader.
* Move out & stage suction tank.
* Move out & stage mud pumps #1, #2, &
#3.
3/31/2023
18:00
4/1/2023 00:00 6.0
0
0.0 0.0 DEMOB, MOVE MOB P Hold PJSM. Rigging down rig
components.
* Break up ice on rig matting.
* Pick up rig mats with loader.
* Load out mats on haul trailer for
transport to 2P.
* Organize & secure conexs for transport.
* Stack up and secure w/ banding
material misc items to pallets.
* Secure misc loose items on mud tanks
& pump room.
* Vacuum melted ice from herculite in
proximity of conductor perimeter.
* Transport 120 bbls of drilling fluids to 2P
& rig matting.
4/1/2023 00:00 4/1/2023 06:00 6.0
0
0.0 0.0 DEMOB, MOVE MOB P Demobilization of the Arctic Fox f/ Bear 1
location. PJSM
* Remove herculite between Gen#1
complex and well head.
* Pull 40 bbls of water to flush Vac truck.
* Load BOP skid, rig matting, windwalls &
drwwks skid on Rolligon flatbeds.
* Secure cover on topdrive.
* Inspecting Demco valves in pump room.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 39/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
4/1/2023 06:00 4/1/2023 18:00 12.
00
0.0 0.0 DEMOB, MOVE MOB P Continue demobilization of the Arctic Fox
f/ Bear 1 location.
* KDTH crew prepare to perform final
P&A.
* Install barricades & emergency rescue
device. Check cellar with gas detector,
Drill 1/4" hole in 16" conductor w/ pnuem
drill. Check with gas detector.
* Cut window in 16" conductor to access
the 9 5/8" csg. Welded fitting to surface
casing and m/u nipple & needle valve.
Drill 1/4" hole in surface csg and check
with gas detector. Cut window in 9 5/8"
surface csg to access the 7" casing.
* Weld fitting to 7" inter casing & m/u
nipple & needle valve assy. Drilled 1/4"
hole in 7" csg. Check w/ gas detector.
Cut window in 7" csg to access the 3.5"
tbg.
* Weld fitting to 3.5" tbg & m/u nipple and
needle valve assy. Drill 1/4" hole in 3.5"
tbg. Check w/ gas detector.
Cut the 3.5" tubing, 7" intermediate
casing, 9 5/8" surface casing & 16"
conductor. Pull casing head & tree out of
cellar w/ crane. Dress tops of casing &
tubing.
* Mix 42 gals of cement and fill voids in
casing/tubing. Install heater trunk lines
& cover with rig matting, allowing cement
to harden.
* Blow down boilers back to hot well.
* NES pumping and flushing water f/
hotwell as needed to flush lines.
* Continue to service Demco valves in
pump room.
Transported to 2P:
* 120 bbls of drill fluids.
* Doghouse & HPU.
* Water tank
* Mud pits
* KDTH conex w/ Polydyke, misc shaker
screens for D142.
* Chemical van w/ SLB cement
chemicals, 3 ea shale shakers.
4/1/2023 18:00 4/2/2023 00:00 6.0
0
0.0 DEMOB, MOVE MOB P Continue demobilization of the Arctic Fox
f/ Bear 1 location.
*Load Rolligons: 53' sewer van, 2 mud
tanks w/ 60 bbls of drilling fluid ea, pallet
materials.
* Performing maintenance on rig equip
while all rig modules are staged for
transport to 2P.
*Finish offloading boiler hotwell.
* Maintenance on Demco valves in pump
room.
* Shut down generators & disconnect
same.
* Disconnect Air compressor, boiler room
& motorman's complexes. Stage for
loadout. Split shop & stage for loadout.
* Load out shaker complex & shaker
baskets.
* Continue to load out misc Doyon tools &
equip in pipe bunks.
* Pick up rig mats & herculite. Continue
to organize pad for equipment to be
loaded on to rolligon flat beds.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 40/44
BEAR 1
Report Printed: 4/17/2023
Time Log & Summary Report AOGCC
Job type: DRILLING ORIGINAL
Time Log
Start Time End Time
Dur
(hr)
Start Depth
(ftKB)
End Depth
(ftKB) Phase Phase Op Code Activity Code
Time
P-T-X Operation
4/2/2023 00:00 4/2/2023 12:00 12.
00
0.0 0.0 DEMOB, MOVE MOB P Demobilization of the Doyon Arctic Fox f/
Bear 1 location. 6 Rolligons transporting
staged equipment f/ Bear 1 to 2P.
• Checked cement at 08:30, firm.
• Bob Noble, AOGC, inspected cement
and abandoment I.D. plate and approved
both.
• NES welder welded on the
abandonment plate.
• Pulled grating f/ cellar.
• Vacuumed mud and cuttings with vac
truck.
• Bob Noble left 2P for Bear 1 on rolligon
at 08:00.
• Shipped two rolligons with 62.5 bbl. mud
each and one rolligon with vac truck
loaded with 75 bbl. mud to 2P
* Doyon crew departed location for
Deadhorse to reassemble the Arctic Fox.
(11 crew )
4/2/2023 12:00 4/3/2023 00:00 12.
00
0.0 0.0 DEMOB, MOVE MOB P Continue the demobilization of the Doyon
Arctic Fox f/ Bear 1 location w/ 6 rolligons
running 24 hrs/day transporting staged
equipment f/ Bear 1 to 2P.
*Cut out weld between conductor and
cellar box floor by 19:00 hrs.
• Secured cellar and placed heater trunks
to warm up cellar in preparation for pulling
cellar.
• ~40 bbl. of mud, cuttings and water from
cellar clean up on vac truck. All other
wellbore fluids are gone.
* Photo crew departed location on
Rolligons.
• Shipped Mud Pump #1, Generator #1, 5
rig mats and various windwalls to 2P via
rolligons.
• Shipped Mud Pump #2, Generator #2, 4
rig mats, gas buster and windwalls for the
drawworks
4/3/2023 00:00 4/3/2023 12:00 12.
00
0.0 0.0 DEMOB, MOVE MOB P Demobilization of the Doyon Arctic Fox f/
Bear 1 location. 6 Rolligons transporting
staged equipment f/ Bear 1 to 2P. NES
trucking all equipment f/ 2P to Deadhorse.
Bear 1 Final Abandonment:
* Pulled cellar box with crane.
* Cut-off is 5' below tundra level.
* Backfilled cellar hole
Loaded on rolligons for delivery to 2P.
* Mud pump #3
* Top drive house and toolpusher's shack
* Rig mats and miscellaneous windwalls
* NES welding truck
* Boiler
* C-18
* Motorman's shed w/ fuel tank
* Rockwasher
* Top drive
Doyon staff at Deadhorse rigging up
Arctic Fox rig modules.
Rig Name: DOYON ARCTIC FOX
Rig Accept : 2/28/2023
Rig Release : 3/28/2023
Well Name: BEAR 1
CONFIDENTIALCONFIDENTIALCONFIDENTIALTi L & S R t AOGCC
Page 1/1
BEAR 1
Report Printed: 4/17/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
3/5/2023 21:00
Cementing End Date
3/5/2023 23:58
Wellbore Name
BEAR 1
Comment
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
22.9
Bottom Depth (ftKB)
1,319.0
Full Return?
Yes
Vol Cement …
127.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
580.0
P Plug Bump (psi)
1,130.0
Recip?
Yes
Stroke (ft)
15.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
SLB pump 4 bbl's of fresh water and pressure test lines to 500/3500. Rig pump 95 bbl's. MudPUSHII with red dye @ 4.3 bbls/min, 80 PSI, 26% F/O, Dropped
bottom plug. Start batching lead (Lead wet @ 21:39). Pump 174.2 bbl's of 11.0 ppg DeepCRETE lead cement at 4 bbls/min, 290 PSI, F/O 24%. Land bottom plug
at 97 bbl's away. Batch tail cement (Tail wet @ 22:54). SLB pump 60 bbl's 12ppg LiteCRETE @ 4 bbls/min, 340 PSI, F/O 25%. Drop top plug & kick out with 20
bbl's of fresh H2O. SLB displace w/ 10 PPG spud mud @ 5.7 bbls/min, 550 PSI, F/O 55%. Reduced rate to 3 bbls/min 580 PSI. Bump plug with 1130 PSI (77.4
bbl's + 20 bbl's).final circ. PSI 580 Pressure up to 1130 PSI & hold for 5 minutes. Bleed off pressure, Check floats good. CIP 23:58 Hrs 3/05/2023. 0 bbl's loss
during cement job. 30 bbl's of contaminated cement returns to surface, 97 bbl's good cement to surface (127 bbl's total cement returns)
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
22.9
Est Btm (ftKB)
819.0
Amount (sacks)
515
Class
Blend
Volume Pumped (bbl)
174.2
Yield (ft³/sack)
1.90
Mix H20 Ratio (gal/sack)
6.71
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
66.0
Thickening Time (hr)
4.92
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
819.0
Est Btm (ftKB)
1,319.0
Amount (sacks)
203
Class
Blend
Volume Pumped (bbl)
60.0
Yield (ft³/sack)
1.66
Mix H20 Ratio (gal/sack)
5.60
Free Water (%) Density (lb/gal)
12.00
Plastic Viscosity (cP)
81.0
Thickening Time (hr)
2.82
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
CONFIDENTIALCONFIDENTIALCONFIDENTIALCt
Page 1/1
BEAR 1
Report Printed: 4/17/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
3/13/2023 20:50
Cementing End Date
3/13/2023 23:10
Wellbore Name
BEAR 1
Comment
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
22.8
Bottom Depth (ftKB)
2,240.8
Full Return?
Yes
Vol Cement …
27.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
4
P Pump Final (psi)
300.0
P Plug Bump (psi) Recip?
Yes
Stroke (ft)
15.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
SLB pump 5 bbls of fresh water and pressure test lines to 500/4000. Drop first bottom plug, rig pump 41 Bbls. 10.5 ppg MudPUSHII with red dye @ 4.3 bbls/min,
75 PSI, 13% F/O, Dropped second bottom plug. Start batching lead (Lead wet @ 21:39). Pump 92.2 bbls of 11 ppg LiteCRETE w/ D500 lead cement at 4.1
BPM, 210 PSI, F/O 11%. Batch tail cement (Tail wet @ 22:08). SLB pump 22.5 Bbls 12 ppg LiteCRETE @ 4 BPM, 390 PSI. Open OA valve and begin taking
returns to the cellar. Drop top plug & kick out with 20 Bbls of fresh H2O. SLB displace w/ 10.2 pp KlaShield mud @ 4 bbls/min, 490 PSI. Reduced rate to 2 BPM
300 PSI. Pumped 64.2 bbls of mud by tank volume, plugs did not bump. Bleed off pressure, Check floats good. CIP 23:10 Hrs 3/13/2023. 0 Bbls loss during
cement job. 27 Bbls good cement returns to surface.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
22.8
Est Btm (ftKB)
1,741.0
Amount (sacks)
269
Class
Blend
Volume Pumped (bbl)
92.2
Yield (ft³/sack)
1.93
Mix H20 Ratio (gal/sack)
5.95
Free Water (%) Density (lb/gal)
11.00
Plastic Viscosity (cP)
103.0
Thickening Time (hr)
3.43
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
1,741.0
Est Btm (ftKB)
2,241.0
Amount (sacks)
76
Class
Blend
Volume Pumped (bbl)
22.5
Yield (ft³/sack)
1.66
Mix H20 Ratio (gal/sack)
5.42
Free Water (%) Density (lb/gal)
12.00
Plastic Viscosity (cP)
197.0
Thickening Time (hr)
4.22
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
CONFIDENTIALCONFIDENTIALCONFIDENTIALCt
Page 1/1
BEAR 1
Report Printed: 4/17/2023
Cement
Cement Details
Description
Production String 1 Cement
Cementing Start Date
3/25/2023 21:00
Cementing End Date
3/25/2023 22:00
Wellbore Name
BEAR 1
Comment
Good tag & Test.
Cement Stages
Stage # 1
Description
Plug – Plug Back /
Abandonment Plug
Objective
Plug and abandon
production section
Top Depth (ftKB)
1,997.6
Bottom Depth (ftKB)
5,523.0
Full Return?
Yes
Vol Cement …Top Plug?
Yes
Btm Plug?
No
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…P Pump Final (psi)
860.0
P Plug Bump (psi)
2,500.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
1,997.6
Tag Method
Tubing
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 37 bbls 10.5 ppg MudPush II. Mix & pump 131 bbls of 11.0 ppg Litecrete slurry at 4.6 bpm w/ 860 psi. Drop the Halliburton BHKA dart f/ plug launcher, good
indication of dart launching with flag. SLB displaced with 9.9 ppg mud @ 4 bpm for 17 bbls, then slowed to 3 bpm and latched plug at 21 bbls away w/ 2500 psi.
Good indication of BHKA disconnect w/ Weight indicator change f/ 65k lbs to 46k lbs. BHKA disconnect at 2020' MD. No mud losses during cement operations.
Cement in place at 21:45 hrs. ~2 bbls cement (~50' in casing) on top of dart. After pulling 60' above top of BHKA mud push and trace cement were obvserved at
surface while circulating.
Cement Fluids & Additives
Fluid
Fluid Type
Abandonment
Cement
Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
130.0
Yield (ft³/sack)
1.91
Mix H20 Ratio (gal/sack)
5.70
Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Production String 1 Cement
CONFIDENTIALCONFIDENTIALCONFIDENTIALCt
Page 1/1
BEAR 1
Report Printed: 4/17/2023
Cement
Cement Details
Description
Production String 2 Cement
Cementing Start Date
3/27/2023 21:30
Cementing End Date
3/27/2023 22:00
Wellbore Name
BEAR 1
Comment
Cement Stages
Stage # 1
Description
Plug – Plug Back /
Abandonment Plug
Objective
Upper P&A
Top Depth (ftKB)
18.2
Bottom Depth (ftKB)
1,994.0
Full Return?
Yes
Vol Cement …
12.0
Top Plug?
No
Btm Plug?
No
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
2
Q Pump Avg (bbl/…
3
P Pump Final (psi)
150.0
P Plug Bump (psi) Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 30 bbls 10.5 ppg MudPush II. Mix & pump 84 bbls of 15.7 ppg ASI cement as per SLB, taking returns via IA casing valve into the cellar. Observed the Mud
Push returns to surface, followed with cement returns at surface after 74 bbls of 15.7 ppg cement pumped away. Weighting
cement returns to confirm along with PH meter and chemically checking. Confirmed with 15.7 ppg cement returns. Continue pumping 8 more bbls to devoid the
cement mixing tub on unit. Displace w/ 3.5 bbls of water. NES vacuum truck pumping mud/pill/cement from cellar in simops. CIP at 22:00 hrs.
Cement Fluids & Additives
Fluid
Fluid Type
Abandonment
Cement
Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl)
Yield (ft³/sack)
0.93
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
Production String 2 Cement
CONFIDENTIALCONFIDENTIALCONFIDENTIALCt
! "
Digitally signed by Vincent Osara
DN: C=US, OU=Schlumberger, O=Schlumberger,
CN=Vincent Osara, E=vosara@slb.com
Reason: I am the author of this document
Location: your signing location here
Date: 2023.03.28 17:25:33-08'00'
Foxit PhantomPDF Version: 10.1.4
Vincent
Osara
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CONFIDENTIAL
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April 2, 2023 #1
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April 2, 2023 #4
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Bear 1 ExploraƟon Well API 50-287-20035-00-00 PTD 222-152, Sundry 323-165 P&A Pictures
April 3, 2023 #5
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Bear 1 ExploraƟon Well API 50-287-20035-00-00 PTD 222-152, Sundry 323-165 P&A Pictures
April 3, 2023 #6
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Bear 1 ExploraƟon Well API 50-287-20035-00-00 PTD 222-152, Sundry 323-165 P&A Pictures
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Bear 1 ExploraƟon Well API 50-287-20035-00-00 PTD 222-152, Sundry 323-165 P&A Pictures
April 3, 2023 #8
CONFIDENTIALnWell API50Well API 50--2877--200350-000--00 PTD 22200 PTD 222-152 Sundry 32352 Sundry 3 -165 P165 P
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Monday, April 10, 2023 1:47 PM
To:Arctic Fox Rig 1
Cc:Regg, James B (OGC)
Subject:RE: Emailing: 3-27-23 Bear 1
Attachments:Doyon 1 03-15-23 Revised.xlsx; Doyon 1 03-20-23 Revised.xlsx; Doyon 1 03-27-23 Revised.xlsx
Kelly,
Attached are revised reports for 03/15/23, 03/20/23, & 03/27/23. All reports were missing the low test pressure (250
that was included in the remarks) from the Test Pressure fields and the number of Nitgn. Bottles (6 was included on the
previous report). The Choke Ln. Valves quantity was listed as 0 therefore the test result should be "NA". Please review
these changes and the corrected formatting and update your copies.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907‐793‐1242
CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil
and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may
contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may
violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or
forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907‐793‐
1242 or phoebe.brooks@alaska.gov.
‐‐‐‐‐Original Message‐‐‐‐‐
From: Arctic Fox Rig 1 <arcticfox@doyondrilling.com>
Sent: Monday, March 27, 2023 10:58 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>;
Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Cc: Company Man Arctic Fox (dafcm@conocophillips.com) <dafcm@conocophillips.com>
Subject: Emailing: 3‐27‐23 Bear 1
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.
Kelly Haug
Arctic fox 1
arcticfox@doyondrilling.com>
1‐907‐355‐5834
Bear 1PTD 2221520
2023-0402_Surface_Abandon_Bear-1_bn
Page 1 of 2
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 4/5/2023
P. I. Supervisor
FROM: Bob Noble SUBJECT: Surface Abandonment
Petroleum Inspector Bear 1
ConocoPhillips Alaska Inc.
PTD 2221520; Sundry 323-165
4/2/2023: I traveled to CPAI’s Bear 1 location on a roll-a-gon. CPAI representative
Guy Whitlock met me upon arrival, and we went right to the well. I found the cutoff depth
to be 5 feet below tundra level. All strings of pipe were found to be full of good hard
cement. I inspected the 16-inch x ¼-inch marker plate – it had all the required
information. I allowed them to weld the plate on and back fill the hole.
Attachments: Photos (2)
2023-0402_Surface_Abandon_Bear-1_bn
Page 2 of 2
Surface Abandonment – Bear #1 (PTD 2221520)
Photos by AOGCC Inspector B. Noble
4/2/2023
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:1 Township:6N Range:3E Meridian:Umiat
Drilling Rig:Doyon 1 Rig Elevation:22 ft Total Depth:6600 ft MD Lease No.:ADL 393519
Operator Rep:Suspend:P&A:X
Conductor:16"O.D. Shoe@ 102 Feet Csg Cut@ Feet
Surface:9 5/8"O.D. Shoe@ 1319 Feet Csg Cut@ Feet
Intermediate:7"O.D. Shoe@ 2241 Feet Csg Cut@ Feet
Production:O.D. Shoe@ Feet Csg Cut@ Feet
Liner:O.D. Shoe@ Feet Csg Cut@ Feet
Tubing:O.D. Tail@ Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Open Hole Bottom 6600 ft 1997 ft 10.2 ppg Drillpipe tag
Initial 15 min 30 min 45 min Result
Tubing 1610 1590 1590
IA
OA
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Guy Whitlock
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
I traveled out to Bear 1 to witness a tag and pressure test of the reservoir isolation plug. Guy Whitlock was the CPA Company
Man. They tagged top of cement @ 1,997 ft MD via 3.5-inch tubing string with an orange peeled bullnose. Set 7.5K lbs on the
plug. 30-minute pressure test followed with passing results shown in the chart above.
March 27, 2023
Adam Earl
Well Bore Plug & Abandonment
Bear 1
ConocoPhillips Alaska
PTD 2221520; Sundry 323-165
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2023-0327_Plug_Verification_Bear-1_ae
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:1 DATE:3/15/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221520 Sundry #
Operation:Drilling:Workover:Explor.:x
Test:Initial:Weekly:x Bi-Weekly:Other:
Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2326
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 11" 5K P Pit Level Indicators P P
#1 Rams 1 3.5 X 5.5 VBR'S P Flow Indicator P P
#2 Rams 1 Blind/Shears P Meth Gas Detector P P
#3 Rams 1 3.5 X 5.5 VBR'S P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 0 NA Time/Pressure Test Result
HCR Valves 2 3-1/16 P System Pressure (psi)3075 P
Kill Line Valves 2 3-1/16 P Pressure After Closure (psi)1650 P
Check Valve 0 NA 200 psi Attained (sec)12 P
BOP Misc 1 3-1/16 / kill line P Full Pressure Attained (sec)88 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):6@2150 P
No. Valves 15 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 1 FP Annular Preventer 20 P
#1 Rams 4 P
Coiled Tubing Only:#2 Rams 5 P
Inside Reel valves 0 NA #3 Rams 4 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:8.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3-12-23/18:00
Waived By
Test Start Date/Time:3/15/2023 10:30
(date)(time)Witness
Test Finish Date/Time:3/15/2023 19:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Doyon
Test all BOPE componets 250/3500psi 5 mins each, Test the Annular 250/3500psi 5mins each / All with 4" & 3.5" test joints.
During test #2a the bleeder valve on the test manifold was leaking passed, Durning test 2b the choke hose developed a leak at
the Oteco hub, Test 2c was operator error "insufficient test pressure of 3200psi" Test 2d was a final good test on the bope
componets " Upper 3.5" x 5.5" VBR's, FOSV, CMV #15 "
Kelly Haug / Benjamin Rogers
Conoco Phillips
Fred Herbert / James Wise
Bear 1
Test Pressure (psi):
arcticfox@doyondrilling.com
dafcm@concophillips.com
Form 10-424 (Revised 08/2022)2023-0315_BOP_Doyon1_Bear-1
J. Regg
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:1 DATE:3/20/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221520 Sundry #
Operation:Drilling:Workover:Explor.:x
Test:Initial:Weekly:x Bi-Weekly:Other:
Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2326
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 11" 5K P Pit Level Indicators P P
#1 Rams 1 3.5 X 5.5 VBR'S P Flow Indicator P P
#2 Rams 1 Blind/Shears P Meth Gas Detector P P
#3 Rams 1 3.5 X 5.5 VBR'S P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 0 P Time/Pressure Test Result
HCR Valves 2 3-1/16 P System Pressure (psi)3050 P
Kill Line Valves 2 3-1/16 P Pressure After Closure (psi)1650 P
Check Valve 0 NA 200 psi Attained (sec)12 P
BOP Misc 1 3-1/16 / kill line P Full Pressure Attained (sec)92 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):6@2150 P
No. Valves 15 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 17 P
#1 Rams 4 P
Coiled Tubing Only:#2 Rams 4 P
Inside Reel valves 0 NA #3 Rams 4 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3-20-23/19:30
Waived By
Test Start Date/Time:3/20/2023 16:30
(date)(time)Witness
Test Finish Date/Time:3/20/2023 23:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Doyon
Test all BOPE componets 250/3500psi 5 mins each, Test the Annular 250/3500psi 5mins each / All with 4" & 3.5" test joints.
Kelly Haug / Benjamin Rogers
Conoco Phillips
Fred Herbert / James Wise
Bear 1
Test Pressure (psi):
arcticfox@doyondrilling.com
dafcm@concophillips.com
Form 10-424 (Revised 08/2022)2023-0320_BOP_Doyon1_Bear-1
===NA
J. Regg
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:1 DATE:3/27/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221520 Sundry #
Operation:Drilling:Workover:Explor.:x
Test:Initial:Weekly:x Bi-Weekly:Other:
Rams:250/3500 Annular:2503500 Valves:250/3500 MASP:2326
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1 P
Permit On Location P Hazard Sec.P Lower Kelly 1 P
Standing Order Posted P Misc.NA Ball Type 1 P
Test Fluid Water Inside BOP 1 P
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0 NA Trip Tank P P
Annular Preventer 1 11" 5K P Pit Level Indicators P P
#1 Rams 1 3.5 X 5.5 VBR'S P Flow Indicator P P
#2 Rams 1 Blind/Shears P Meth Gas Detector P P
#3 Rams 1 3.5 X 5.5 VBR'S P H2S Gas Detector P P
#4 Rams 0 NA MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 0 NA Time/Pressure Test Result
HCR Valves 2 3-1/16 P System Pressure (psi)3050 P
Kill Line Valves 2 3-1/16 P Pressure After Closure (psi)1650 P
Check Valve 0 NA 200 psi Attained (sec)14 P
BOP Misc 1 3-1/16 / kill line P Full Pressure Attained (sec)128 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:1000 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):2150 P
No. Valves 15 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc Annular Preventer 18 P
#1 Rams 3 P
Coiled Tubing Only:#2 Rams 4 P
Inside Reel valves 0 NA #3 Rams 4 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:9.5 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3-25-23 10:00
Waived By
Test Start Date/Time:3/26/2023 21:30
(date)(time)Witness
Test Finish Date/Time:3/27/2023 7:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Doyon
Test all BOPE componets 250/3500psi 5 mins each, Test the Annular 250/3500psi 5mins each / All with 4" & 3.5" test joints. No
re-tests due to bope eq. re-test #1 due to insuffient pressure, re-test #5 due to leaking valve on test eq, re-test #8 due to leak on
the test hose, re-test #9 due to pressure sensor failure on test pump.
Kelly Haug / Benjamin Rogers
Conoco Phillips
Fred Herbert / James Wise
Bear 1
Test Pressure (psi):
arcticfox@doyondrilling.com
dafcm@concophillips.com
Form 10-424 (Revised 08/2022)2023-0327_BOP_Doyon1_Bear-1
J. Regg
/
6@
TT RR AA NN SS MM II TT TT AA LL
FROM: Sandra D. Lemke TO: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 333 W. 7th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: Bear 1
Permit: 222-152
DATE: 04/05/2023
Transmitted:
North Slope Exploratory
Bear 1
Via SFTP
____ Schlumberger Final directional Survey
Transmittal instructions: please promptly sign, scan, and e-mail to
CC: Bear 1 - e-transmittal well folder
Receipt: Date:
| |
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?Bear 1
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field:Current Pools:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
None None
Casing Collapse
Structural
Conductor
Surface 3090
Intermediate 5410
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:Brian Noel
Contact Email:
brian.noel@contractor.cop.com
Contact Phone: 907-263-4027
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:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
6-1/8" open hole
16"
9-5/8"
80
1296
Perforation Depth MD (ft):
7"2220
MD
7240
5750
102
1319
2241
102
1319
66006600
2241
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 393519
222-152
PO Box 100360 Anchorage, AK 99510-0360 50-287-20035-00-00
ConocoPhillips
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size:
3/23/2023
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:
AOGCC USE ONLY
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
g g
perator Name:erator Name:
3. Address:Add
perforating:perforating:
Regulation or Conservation Order gegulation or Conservation Order
ed perforations require a spacing exorations require a spac
signation (Lease Number):ation (Lease Number)
al Depth TVD (ft):TVD (f Effective DepthEffective Dept
Packers and SSSV MD (ackers and SSSV MD
13. Well Class after proposed wWell Class after proposed
xploratoryplorat Stratigraphatigrap
Well Status after proposed work:ell Status after proposed wor
WINJNJ
WAGWAG GSG
GINJG Op ShutdowOp Shutdo
Contact Name:Contac Brian Noelrian Noel
ntact Email:ail:
brian.noel@conbrian.noel@c
t Phone:hone:907-263-402727
Number:mber:
1/8" open holeole
16"
9-5/8"9-5/8
8080
7"
666
gth Sizee
PR
PO Box 100360 Anchorage, AK 99O Box 100360 Anchora
onocoPhillipsnocoP
Tubing Size:ng Size
deviated from without prior writted from without prior writt
with PTD 10-407
Provide field copies of well logs to AOGCC for review prior to P&A cementing operations. SFD
BOP test to 3500 psig
Annular preventer test to 2500 psig
Applicable conditions of approval on original PTD apply.
AOGCC inspection required after cutoff and before remedial cementing. Photo documentation required.
X
X
VTL 3/23/23 SFD 3/20/2023
Exploratory Exploratory SFD 3/20/2023
DSR-3/20/23GCW 03/24/23JLC 3/24/2023
3/24/23
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.24 12:07:24
-08'00'
RBDMS JSB 033023
Post Office Box 100360
Anchorage, Alaska 99510-0360
March 16, 2023
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Sundry Application to Plug & Abandon Bear 1 Exploration Well
Dear Commissioners:
ConocoPhillips Alaska, Inc hereby applies for sundry approval to permanently abandon Bear 1
(PTD 222-152).
This vertical well will soon reach total depth with wireline logging planned. After logs are obtained
the Arctic Fox will be used for the plug and abandon operations. Once the rig has moved off
location, the wellhead will be cut off below ground level and a marker plate will be welded on in
accordance with the regulations.
The estimated start for Bear 1 P&A operations is March 23, 2023.
Please find attached:
Form 10-403 Application
Proposed P&A program
Proposed P&A well schematic
If you have any questions or require further information, please contact me at (907) 263-4027.
Sincerely,
Brian Noel
Drilling Engineer
March Mar 16
Commissioneommissione
Alaska Oil and GAlaska Oil and
333 West 733th AvenuAv
Anchorage, Alaska 99Anchorage, Alaska 99
RE:RE:Sundry ApplicatioSundry Appli
Commmismisssionersers:
llips Alaska, Inc hereby applaska, Inc hereby ap
2).
ill soonsoon reachch tototal depth pth ww
usued for thee plug and abanand
ill be cut off below ground lbelow ground
ations.
P&A&oopperations era is Mararchc 23
on, please contacton, please contact me att (9(9
Bear 1 proposed P&A steps after POOH with wireline:
1. Test BOPE.
2. Rig up and run new 3-1/2 9.2# L-80 EUE from TD to 200 inside the 7 shoe.
Centralize tubing with 1
hydrocarbon bearing zones.
3. Pick up BHKA disconnect tool, RIH with 4 drill pipe and tag bottom.
4. Circulate bottoms up to condition mud, pump cement, drop disconnect dart
and displace with mud.
5. Release from BHKA, pick up and circulate out residual cement, POOH.
6. Rig up and RIH with 3-9.2# L-80 EUE. Tag TOC and pressure test
casing/plug to 1500 psi. Notify AOGCC to witness.
7. Circulate bottoms up, space out, land tubing hanger and RILDS.
8. Pump cement down tubing to surface taking returns from the annulus valves.
9. Once good cement back to surface, shut in and rig down cementers.
10.After WOC, ND BOP and install dry hole tree (master valve and tree cap).
11.After the rig moves from location, cut off the wellhead and tubulars
ground level. Weld a marker plate with the well name/number, PTD number,
and API number to cover all casing strings.
12.Remove cellar box and backfill. AOGCC to witness final P&A operations.
1.91 ft^3/sk
117.7 bbls
5.3 bbls
39.6 bbls
162.6 bbls or 913 ft^3 or 478 sks
22.1 bbls
6-1/8" Production Lower Abandonment Cement Calculations
Design: Run 3-1/2" EUE sacrificial tubing string and cement in place with 11 ppg LiteCRETE cement
to 200' TVD inside intermediate shoe. Open hole volume based on wireline caliper + 10% excess
Lead Cement yield =
11 ppg LiteCRETE Slurry
6-1/8" OH x 3-1/2" Annulus = (6600' - 2241') x 0.0245 bbl/ft x 1.1 (10% excess)
7" CSG x 3-1/2" Annulus = (2241' - 2041') x 0.0264 bbl/ft x 1 (0% excess)
3-1/2" Tubing = (6600' - 2041') x 0.0087 bbl/ft x 1 (0% excess)
Total Lead Cement =
Displacement = 2041' x 0.0108 bbl/ft =
0.93 ft^3/sk
53.8 bbls
17.7 bbls
71.6 bbls or 401.8 ft^3 or 432 sks
6-1/8" Production Upper Abandonment Cement Calculations
Lead Cement yield =
Design: Run 3-1/2" EUE sacrificial tubing string and cement to surface with 15.7 ppg AS1.
Total Lead Cement =
15.7 ppg AS1 Slurry
7" x 3-1/2" Annulus = 2041 x 0.0264 bbl/ft x 1 (0% excess)
3-1/2" Tubing = (2041' - 0') x 0.0087 bbl/ft x 1 (0% excess)
22
C
hyd
3.Pick upPick up
4.4.Circulate bate
and displace pla
5.5.Release from BHase from B
RRigig upu anandd RIHRIH with
asing/plung/pl g to 1500 psito 1500 p
ulate bottoms up, spacelate bottoms up, space
emement nt down tubing own tubing to sto s
cementmen back to surfaack to surfacec
BOP and install dry honstall dry ho
fromm location, location, cut c off off tht
marker marker plate with tplate with thehe w
all casing stringsall casing strings .
fill. fill. AOGCC to witnessAOGCC to witnes
117.7 b
3 bb
6 bbls
22
ndonment Cemen
cement in place with
ume based on wireline cali
.1 (10%
1 (0% excess)
excess
culations
Provide field copies of well logs to
AOGCC for review prior to P&A
cementing operations. SFD 3/20/2023
Check regulations for info to go on marker plate.
Bear 1
Proposed P&A Schematic
Surface Casing:
9-5/8" 40# L-80 TXPM
8.835" ID / 8.679" Drift
3,090 psi Collapse / 5,750 psi Burst
Set @ MD / TVD
Cement to surface 3/5/23
Conductor:
16" Welded Conductor
102' MD / TVD
8-1/2" Intermediate Hole
KLA SHIELD
10.2 PPG
Spud Mud
10 PPG
12-1/4" Surface Hole
FMC MBS WELLHEAD
Production TD:
6,600' +/- MD / TVD
Last Update: 3/15/23 BDN
Bear Target:
5,250' +/- MD / TVD
Intermediate Casing:
7" 26# L-80 TXPM
6.276" ID / 6.151" Drift
5,410 psi Collapse / 7,240 psi Burst
Set @ MD / TVD
Cement to surface 3/13/23
6-1/8" Production Hole
KLA SHIELD
10.2 PPG
Upper Abandonment String/Plug:
3-1/2" 9.2# L-80 EUE
2.992" ID / 2.867" Drift
10,540 psi Collapse / 10,160 psi Burst
200' Inside Intermediate Shoe to Surface
Landed Out on Tubing Hanger
With Cement Circulated Surface to Surface
Lower Abandonment String/Plug:
3-1/2" 9.2# L-80 EUE
2.992" ID / 2.867" Drift
10,540 psi Collapse / 10,160 psi Burst
TD to 200' Inside Intermediate Shoe
Set with BHKA Disconnect Tool
With Cement Circulated TD-top BHKA Tool
IntermediIn
7" 26# L7" 26# L--80 T80
6.276" ID / 6.156" ID / 6.15
5,410 psi Collapse /410 psi Collapse
Set @ Set @ MD / TVMD / TV
Cement to surface 3/13/Cement to surface 3/13
6-1/8" Pr1/8" P
Spud Mudud
10 PPGG
tring/Plug:
Burst
urface
cee
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________BEAR 1
JBR 04/17/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
H2S sensors in pits and on rig floor F/P
Test Results
TEST DATA
Rig Rep:Haug/RogersOperator:ConocoPhillips Alaska, Inc.Operator Rep:Herbert/Tucker
Rig Owner/Rig No.:Doyon 1 PTD#:2221520 DATE:3/8/2023
Type Operation:EXPL Annular:
250/2500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopAGE230322112329
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 10.5
MASP:
2326
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 11 P
#1 Rams 1 3 1/2 X 5 1/2 P
#2 Rams 1 Blind/shear P
#3 Rams 1 3 1/2 X 5 1/2 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 0 NA
HCR Valves 2 3 1/16 P
Kill Line Valves 2 3 1/16 P
Check Valve 0 NA
BOP Misc 1 3 1/16 P
System Pressure P3050
Pressure After Closure P1725
200 PSI Attained P24
Full Pressure Attained P105
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@ 1466
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P FPH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P17
#1 Rams P5
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9
99999
9
9
9H2S sensors in pits
FP
2023-0127_Rig_Doyon1_Bear-1_ss
Page 1 of 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 3/3/2023
P. I. Supervisor
FROM: Sully Sullivan SUBJECT: Rig Inspection – Doyon 1
Petroleum Inspector Bear #1
CPAI
PTD 2221520
2/27/2023: I traveled by way of Casa flight from Kuparuk to Bear 1 exploration well
being drilled by CPAI to witness the diverter test and perform a rig inspection. Once
there I met with Doyon Drilling’s Safety Man for orientation. Immediately after
orientation I began the rig inspection prior to the witnessing the diverter test. Pusher
Ben Rogers and Company Man Mike Tucker were of great help in answering all
questions and providing all current documentation. The mast was recently damaged,
triggering an API 4G mast inspection and repairs (see attached). No issues identified
during the rig inspector nor during the diverter test. Doyon 1 (Arctic Fox) was in good
condition, well heated, and ready for the exploratory drilling program.
I departed location traveling back to KRU 2P pad by way of rolligon, then hitched a ride
to Kuparuk where the State pickup was parked.
Attachments: Rig Inspection Report Form – 2023-0227
Rig Inspection Photos
Mast Inspection and Repair Report – 2023-0220
Mast Certification – 2023-0224
P.I. Supv
Comm:
Rig Coil Tubing Unit?No
Rig Contractor Rig Representative
Operator Operator Representative
Well Permit to Drill #2221520 Sundry Approval #n/a
Operation Inspection Location
Working Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure P
P Flow Rate Sensor P Operating Pressure P
P Mud Gas Separator P Fluid Level/Condition P
NA Degasser P Pressure Gauges P
NA Separator Bypass P Sufficient Valves P
NA Gas Detectors P Regulator Bypass P
P Alarms Separate/Distinct P Actuators (4-way valves)P
NA Choke/Kill Line Connections P Blind Ram Handle Cover P
NA Reserve Pits P Control Panel, Driller P
NA Trip Tank P Control Panel, Remote P
P Firewall P
NA 2 or More Pumps P
P Kelly or TD Valves P Independent Power Supply P
P Floor Safety Valves P N2 Backup P
P Driller's Console P Condition of Equipment P
P Flow Monitor P
Flow Rate Indicator P
Pit Level Indicators P Valves P
PPE P Gauges P Remote Hydraulic Choke P
Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P
Housekeeping P Hydraulic Control Panel P Targeted Turns P
Well Control Plan P Kill Sheet Current P Bypass Line P
FAILURES:0 CORRECT BY:
COMMENTS
Rig is on diverter. I inspected BOP stack in storage. Rig mast was repaired and inspected prior to start of well - inspection report
attached. Photos attached.
CHOKE MANIFOLD
Bear Exploration (Ice pad)
MUD SYSTEM
Bear 1
Drilling
CLOSING UNIT
ALASKA OIL AND GAS CONSERVATION COMMISSION
RIG INSPECTION REPORT
HCR Valve(s)
Manual Valves
Annular Preventer
Working Pressure, BOP Stack
Stack Anchored
Choke Line
Kill Line
Targeted Turns
Pipe Rams
Blind Rams
Guy Witlock
Ben Rogers
Locking Devices, Rams
BOP STACK
Sean Sullivan
2/27/2023INSPECT DATE
AOGCC INSPECTOR
Doyon 1 (Arctic Fox)
Doyon
CPAI
MISCELLANEOUS
Flange/Hub Connections
Drilling Spool Outlets
Flow Nipple
Control Lines
RIG FLOOR
2023-0227_Rig_Doyon1_Bear-1_ss rev. 4-19-2023
JBR; 3/29/2023
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 1 of 7
Rig Inspection – Doyon 1
Bear #1 (PTD 2221520)
Photos by AOGCC Inspector S. Sullivan
2/27/2023
Bear 1 Drilling Location – Doyon 1
Diverter vent line
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 2 of 7
Diverter vent line
-anchored
Annular Preventer
and knife valve
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 3 of 7
Annular Preventer
Choke Manifold
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 4 of 7
Accumulator
pressure gauges
Accumulator
charge bottles
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 5 of 7
Nitrogen backup
system charge
bottles
BOPE control lines
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 6 of 7
Rig floor
Drillers station
2023-0227_Rig_Doyon1_Bear-1_photos_ss
Page 7 of 7
Weight indicator Load line sensor
File No:Date:
Location:Inspector:
Customer:Rig No:
Company No:Nameplate on Mast:YES
Serial No:QF-2352-05-57 Nameplate Correct:YES
Model No:RIG MASTER MODEL MT106-9.5-4006 Mast Position:Standing
Clear Height:106ft Lying Down
Base Width:9'-6" ✓Assembled
SHL Rating:6 LINES - 350,000 lbs ✓Disassembled
SHL Rating:8 LINES - 400,000 lbs Date of Man:Aug-05
Wind Speed Ratings:WITH SETBACK - 70 knots Manufacturer:Quality Fab, Edmonton, AB
Wind Speed Ratings:NO SETBACK - 93 knots
Mast Type:Telescoping
Mast Description:TELE DOUBLE
Manufacturer's Drawings Available at Inspection:Presentation Drawings
√ - indicates item ok N/A - not applicable NIC - not included in certification
Doyon Drilling
4. New bolts have been procured for the crown.
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Mast Inspection Form
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
N1657
NES Shop, Prudhoe Bay, AK
2023_02_16
Blair Nelsen
F-577-1
Notes from inspection - 2023_02 - 16
1. Strongback bent at bunk closest to crown (boom location) - HSS 6x4x3/16". Buckled and bent from severe
impact. Strongback was cut so the top section could be removed. The deflection in the strongback was forcing the
shims in the bottom section tight to the top section. Must replace strongback. After cutting the strongback the
dimensions between the rear main legs of the bottom section is 107 5/8". OEM spec is 108" between the main legs.
2. HSS 4x4 diagonals attached to the bent strongback did not spring back to straight. The ends are approximately 1-
1/2" up from the OEM location. Remove and replace.
3. GAP between mast bottom section shims and top section is acceptable for mast top section removal. Will
reassess when top section is removed.
4. Replace bridal lines as they were pinched between sections.
5. Remove crown and assess bearings from impact.
6. Remove TOP SECTION and assess main legs where impact occurred between sections. Top or bottom section
rear legs could have damage that is not visible until the top section is removed.
1. New Bridal Lines have been ordered.
2. Two (2) Tugger Air Hoist Cables ordered
3. Bearings for the crown sheaves have been ordered.
7. The second bunk also took some impact as evidence from the damage wood on the bunk. The bunk needs to be
moved and further investigation. The width at the rear legs at this point is 107 7/8" but the width at the front legs of
the bottom section is 109". OEM spec is 108". This strong back may be deflected as well. Further investigation
required.
ACTION ITEM LIST - DOYON PERSONNEL MANAGING
Numbered items 1,2,3… see reference on attached report.
Mast Nameplate Info
DOYON ARCTIC FOX-RIG 1
1 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
4. New Bridal Lines were ordered.
5. All Crown Sheave bearings and Seals were replaced by Doyon Personnel.
6. Top Section was removed and inspected. No damage was found to the main legs of the top section or bottom
section. The dropping impact did not damage the main legs of the mast.
ACTION ITEM LIST - DOYON PERSONNEL MANAGING
1. New Bridal Lines have been ordered.
2. Two (2) Tugger Air Hoist Cables ordered
3. Bearings for the crown sheaves replaced.
4. New bolts have been procured for the crown.
7. The strongback at the second bunk was within OEM specifications and was not replaced.
8. All applicable welds were wire wheeled to bare metal and inpsected by Kakivik Asset Management with magnetic
particle methods. A few minor cracks were found and were repaired and reinspected.
Final Notes - 2023_02_20
1. Buckled HSS 6x4X3/16" strongback was replaced with HSS 6x4x1/4" to OEM dimensions.
2. Damaged HSS 4x4 diagonals were replaced with HSS 4x4x1/4" tubing to OEM dimensions.
3. GAP between mast bottom section shims and top section was measured and found to be acceptable to OEM
specifications after repairs.
2 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
Date:File No:N1657
Location:Inspector:
Customer:Rig No:
1 2
3 4
Closer view of bent strongback - HSS 6 x 4 x 3/16"Force of impact buckled strongback tubes near the main
legs both sides of mast.
Report Pages
2023_02_16
View of mast in NES Shop on 2023_02_16.View of damaged strongback above bunk closest to
crown end of mast.
Picture -
Prudhoe Bay, AK
Doyon Drilling
Blair Nelsen
Picture - Picture -
DOYON ARCTIC FOX-RIG1
Picture -
3 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
5 6
7 8
View of the amount the strongback moved after cutting
free.
Picture - Picture -
View of bent strongback after bunk removed. View of bent strongback after bunk removed -
approximately 4" of deflection. Member will be
replaced.
HSS 6x4x3/16" strongback was cut and sprung back 2".
Camber in the strongback was holding the shims tight
against the top section. Strongback had to be cut to get top
section removed.
Picture - Picture -
4 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
9 10
11 12
Width at section is 107 5/8" after strongback was cut. OEM
dimension is 108". May need to use a porta power to widen
when installing new strongback.
HSS 4x4 diagonals that are attached to the HSS 6x4x3/16" are
still bent up about 1-1/2" after strongback was cut. HSS 4x4
diagonal should be replaced.
Picture - Picture -
Picture - Picture -
View of 2nd bunk on the trailer. Still trying to assess if the
impact was critical at this point. Width at back legs - 107-
7/8". Width at front legs - 109".
Bridal lines are pinched between top and bottom section of mast -
both sides of mast. Replace.
5 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
13 14
15 16
Picture - Picture -
View of other side of bunk. 109" width at front legs at this section.
View of width at back legs at bunk - 107 7/8"View of shims in mast near top section. There was no
space at all in this location before strongback was cut.
Picture - Picture -
6 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
17 18
View of shim. View of shims in mast near top section. There was no
space at all in this location before strongback was cut.
Picture - Picture -
7 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
19 20
21 22
Notes and dimensions from mast inspection.
Picture - Picture -
Picture - Picture -
View of mast with crown removed. Crown removed from mast.
Pictures from February 17 & 18, 2023
View of Shim.
8 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
23 24
25 26
Picture -
View of crown cluster. Bearings to be replaced. View of typical space between sheaves - gaps between
seals are inconsistent - seals are jammed into
themselves and rubbing while turning.
Picture - Picture -
Bent Strongback removed from mast. Top section of mast removed from bottom section.
Picture -
9 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
27 28
29 30
View of mast top section - bridal line marks.Bridal line marks were bridal line was stuck between
top and bottom section. Typical both sides of mast.
Picture - Picture -
View of diagonals removed from mast.View of diagonals removed from mast.
Picture - Picture -
10 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
31 32
33 34
Picture - Picture -
View of top section on blocks for inspection. New HSS 6x4x1/4" strongback added into mast.
Distance between back legs at strongback verified to be
108".
Picture - Picture -
View of MPI inspecton in progress. Damaged material removed from mast.
11 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
35 36
37 38
View of crown with sheaves removed. MPI inspection to
be completed on crown.
Welding to begin on strongback. Temporary brace
clamped in at front legs of bottom section.
Picture - Picture -
View of all new member tacked in mast bottom section. Dimensions verified before welding.
Picture - Picture -
12 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
39 40
41 42
View of welding completed on new members in bottom
section of mast.
MPI completed on all new members welded into mast
bottom section. Welds passed MPI.
Picture - Picture -
Pictures from February 19, 2023
View of new members welded in mast bottom section. View of magnetic particle inspection of crown frame.
All welds passed.
Picture - Picture -
13 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
43 44
45 46
Top section of mast being installed into bottom section.
Picture - Picture -
Top Section installed in bottom section of mast. View from other direction of top section installed in
bottom section.
Picture - Picture -
View of top section of mast. Magnetic particle inspection
complete. Welds repainted and ready to install into bottom
section.
14 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
47 48
49 50
View of shims and spacing of top section in mast. Shims
within acceptable tolerances.
View of shim tolerances.
Picture - Picture -
View of mast reassembled. Waiting on crown. View of crown end of mast. New bearings to be
installed in crown on February 20, 2023 before crown
frame is reinstalled on mast top section.
Picture - Picture -
15 of 16
2019-Sep-01 0
Document Number:
Approved by:
Dhruv Diwanji Dhruv Diwanji
Date:Revision Number:
Created by:
RIG INSPECTION FORM
API RP 4G Category III / IV
F-577-1
51 52
53 54
View of outside races in cluster sheaves. Bearing races had impact marks from the tapered rollers
contact caused from the mast dropping. MUST replace
all crown bearings. Replacement was completed by
Doyon Personnel on Feb. 20, 2023.
Picture - Picture -
View of disassembled Bridal Line Sheave. Suggest replacing bushing at next Level 3 interval.
Sheaves are safe to use for telescoping. Bushing is
starting to wear as per design.
Picture - Picture -
16 of 16
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________BEAR 1
JBR 04/05/2023
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:The Arctic Fox was in well kept condition with all Diverter functions operating smoothly.
TEST DATA
Rig Rep:Ben RogersOperator:ConocoPhillips Alaska, Inc.Operator Rep:Guy Witlock
Contractor/Rig No.:Doyon 1 PTD#:2221520 DATE:2/27/2023
Well Class:EXP Inspection No:divSTS230226185257
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
Test Time:3
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:NA NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:20 P
Hole Size:12.25 P
Vent Line(s) Size:16 P
Vent Line(s) Length:140 P
Closest Ignition Source:90 P
Outlet from Rig Substructure:106 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:P
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:20 P
Knife Valve Open Time:2 P
Diverter Misc:0 NA
Systems Pressure:P3050
Pressure After Closure:P1800
200 psi Recharge Time:P20
Full Recharge Time:P95
Nitrogen Bottles (Number of):P6
Avg. Pressure:P2250
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
NA NAMud System Misc:
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Marty Marti
Wells Planning Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Exploratory Field, Exploratory Pool, Bear 1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 222-152
Surface Location: 3385’ FNL, 5053’ FEL, Sec. 1, T6N, R3E
Bottomhole Location: 3385’ FNL, 5053’ FEL, Sec. 1, T6N, R3E
Dear Mr. Marti:
Enclosed is the approved application for the permit to drill the above referenced well.
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.
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, 2023. 9
Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.02.09 10:54:14 -09'00'
12/02/2022
SFD
SFD 1/31/2023
Review LOT w/ AOGCC as soon as available.
SC shoe LOT min required is 12.5 ppg EMW; w/ mitigations(attached Conditions of Approval), 12.0 ppg EMW
will be accepted. Int shoe LOT required is 13.5 ppg EMW w/ mitigations(attached Conditions of Approval)
3-1/2
VTL 2/6/2023
Initial BOP test to 5000 psig
Subsequent BOP tests to 3500 psig
Initial rig inspection required
Annular preventer test to 2500 psig
BOP test frequency is 1 week
Separate sundry to be submitted for P&A operations.
6-1/8
6-1/8 3-1/2
DSR-12/5/22
5952180 SFD
222-152 50-287-20035-00-00
X
100'
SFD
GCW 02/08/23JLC 2/9/2023
2/9/23
2/9/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.02.09 15:12:58 -09'00'
BEAR 1 PERMIT TO DRILL (PTD 222-152)
CONDITIONS OF APPROVAL
Mitigations measures required for prevention and early detection of kicks:
1.) Communication:
x Ensure all personnel understand the risks associated with the shallow anomaly and the
shallow shoe location
x Ensure all personnel have had the opportunity to review the influx mitigation plan
x Risks/Mitigations in place during daily operations should be discussed at every pre-tour and
pre-job meeting
2.) If in doubt, space out and shut the well in on the upper pipe rams
3.) Flow check well during all connections
4.) Minimize Potential for Swab
x Overbalance at the shallow anomaly will be ~50 psi and ~190 psi at intermediate TD
x Overbalance at production hole target will be ~273 psi
x Always pump out of the hole
x Monitor the hole volumes on the smallest active system possible
x Minimize pipe movement without the pumps engaged – if pipe is required to be moved
without pumps on, ensure to use minimal acceleration
5.) Frequent drills
x Perform kick drills with ALL crews daily
x Ensure all personnel know what their job is when executing a well kill operation – with the
shallow depth of this section, execution of the well kill operation in a timely manner is of
importance
x Shallow gas drill should be conducted before drilling out the surface shoe
x Kick while drilling and kick while tripping drills should be performed with each crew with
importance put on bringing the well under control as fast as possible to minimize influx
volume
x Perform rig evacuation drill with each crew
6.) Keep the hole full
x Monitor hole on trip tank – verify displacement frequently
x Fill pipe every stand while tripping drill pipe in the hole
x Fill casing every joint while tripping in the hole
7.) Utilize Mudloggers to Monitor Gas Trends
x Monitor background gas and connection gas profiles
x If something changes – notify the company representative
8.) Monitor parameters while on bottom drilling ahead
x Pit volume increase – alarms set tight (5 bbls)
x Flow out increase – alarms should be set tight (10%)
x Drilling breaks – if encountered for more than 5’, pick up off bottom and OWFF
x Connection gas / background gas
x Cuttings behavior
x Drilling parameters: Increase in ROP, pump pressure decrease, pump stroke increase, string
weight change, and cut mud weights are possible warning signs of a kick
9.) Minimize active volume while on bottom drilling ahead
x All fluid transfers require approval prior to execution
x All pits transfers should be announced and noted on the Totco monitors
x Pits should be lined up to minimize active system
10.) Fluid volume accounting
x Minimize use of water hose on rig floor
x Set up pipe wiper and mud bucket configuration to capture as much fluid as possible
x Define clear/consistent method to measure fluid volume in the cellar
11.) Minimum contingency fluid and materials on site:
x Weighting material to weight entire active system up by 1 ppg on site
x Materials on site to build planned section volume (OH volume * DR + 500 bbl surface
volume) plus 10%
x While drilling intermediate and production, an additional 400 bbls of fluid (either from
previous section or fluid ready for disposal) should be kept on site as a contingency
12.) Lost circulation contingencies
x LCM materials quantities noted in the approved mud program should be on site
x LCM decision tree should be reviewed prior to each section
x Cementing equipment and contingency cement materials should be on site at all times as a
last resort contingency should losses not be able to be healed by conventional methods
(2693 psi at 5250' TVD =
0.513 psi/ft ~ 9.9 ppg EMW)
SFD 1/30/2023
VTL 2/1/2023
.
w/ mitigation measures: see Conditions of approval
Separate sundry
required for
P&A operations
XXX Review LOT w/ AOGCC as soon as available
12.5 ppg(12.0 ppg w/ mitigation measures)see Conditions of approval
VTL 2/1/2023
VTL 2/1/2023
Review LOT w/ AOGCC as soon as available
oq
70°5'0"N70°0'0"N69°55'0"N69°50'0"No
Bear 1WP02 Surface Location
Bear 1WP02 Surface Location
Schlumberger Confidential
ation
Assessment of Shallow Conditions at Proposed Bear-1 Well •
Boar:t R1,d7739300k BBBr-,
At the proposed Bear-1 well,
seismic amplitude response within
Sequence 1 is consistent with
background values and provides
no evidence of existing hazards or
constraints (Figs. 19, 20, and 21).
No issues are expected while
drilling through this Sequence,
although instances of variable ROP
and vibration may be experienced.
Within Sequence 2, mitigation
measures should be implemented
to address the potential for low
saturation gas. The presence of
prominent amplitude anomalies
updip from the well location, within
an interpreted sand layer, supports
this recommendation (Figs. 19 and
No issues are expected while drilling through Sequences 3, 4 and 5. In Sequence 6, based on expected lithologic variabilities and the presence of
migrating clinoforms, close monitoring of drilling parameters is advised to possibly anticipate issues related with borehole instability, swelling clays
and/or free gas (Fig. 19)_ Increased gas content is expected within Sequences 7 and 8 (Figs_ 19, 20, and 21) as recorded at offset wells but proper
mitigation, including efforts to reduce swabbing, are expected to successfully address potential gas shows.
24 www.ikonscienre.com I www.fugro.com
C I
Assessment of Shallow Conditions at Proposed Bear-1 Well - •
Bear-1 X 1471399 ooa Bear-1
Fig.20 Portion of inline 10704 and crossfrne 10913 displaying the sweetness attribute over a pseudo relief
. E www.ikonscience.corn I www.fugro.com
Integrated Tophole Prognosis Chart Proposed Bear -1 •
Pm DcRAd L,,cauen SERF -1
X.1,427,)99.00r•6,614,96a.00
P.. W1.11 a10721
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__ www.ikonscience.com I www-fugro.com
Arctic Fox
5
INSTRUMENTATION
1 ea. - LEL detector at the shaker possum belly, cellar, rig floor, and drillers console.
1 ea. - H2S detector in pit area, cellar, rig floor, and drillers console.
1 ea. - trip tank volume indicator
WELL CONTROL EQUIPMENT
BOP Equipment
1 ea. - Hydril diverter annular BOP, model MSP, 21 1/4” x 2000 psi, flanged, NACE trim
1 ea. - BOP products annular, series 800, 11” x 5000 psi, stud x flanged, NACE trim.
1 ea. - BOP Products double gate, series 700, manual, 11” x 5000 psi, stud x stud, NACE trim
1 ea. - BOP Products single gate, series 700, manual, 11” x 5000 psi, stud x stud, NACE trim
2 ea. - BOP Products shear bonnet, series 700, tandem boosters, 5000 psi
BOP Rams
2 ea. - BOP Products variable bore rams, series 700, 3-1/2" x 5-1/2"
1 ea. - BOP Products blind shear ram
Spools and Valves
1 ea. - mud cross, 11” x 11” x 5000 psi with 2 ea.- 3 1/8" x 5000 psi side outlets, NACE trim
2 ea. - 3 1/8” x 5000 psi, hydraulically operated gate valves, NACE trim
2 ea. - 3 1/8” x 5000 psi manual valve , NACE trim
Choke Manifold
1 ea. - 2 1/16” x 5000 psi, manual gate valve, NACE trim
13 ea. - 3 1/8” x 5000 psi, manual gate valves, NACE trim
1 ea. - 3 1/8” x 5000 psi, manual choke
1 ea. - 3 1/8” x 5,000 psi, remote operated hydraulic choke
All valves have NACE trim and color coded handles for sequencing.
The remote choke control panel is located on the drill floor
- trip tan trip tan
LLL CONTROLCONTROL EQUIPEQUIPQ
mentnt
diverter annular BOP, mdiverter annular BOP,
cts annularcts annular, series 800,series 800
double gateuble gate, series 700, series 700,
e gate, series 700, manugate, series 700, man
net, series 700, tandem s 700, tandem
es 700, 3-1/2" x 5-1/2"s 700, 3-1/2" x 5-1/2"
00 psi side outlets, NApsi side outlets, NA
E trim
6
BOP Closing Unit
1 ea. - Oilco, 6 station, 3000 psi, 180 gallon accumulator unit, with a remote control panel in the doghouse.
Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary back-up is
an air pump, and tertiary emergency pressure is provided by bottled nitrogen
BOP Test Pump
1 ea. – 5000 psi, triplex pump with dedicated test fluid tank.
Drillstring Valves
1 ea. - 5,000 psi. , 6 5/8 upper kelly cock
2 ea. - 5,000 psi., 4 ½ XH lower kelly cock
1 ea. - 5,000 psi , 4 ½ XH , IBOP valve
pum
OP Test Pump
1 ea.–5000 psi, triplex
Valves
psi. , 6 5/8 upper kell
4 ½ XH lower kelly c
XH , IBOP valve
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.
BEAR 1
EXPLORATORYEXPLORATORY
Mud logging equipment and crew will be fully functional during all drilling operations from spud to
total depth of this well.
222-152
WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:BEAR 1Initial Class/TypeEXP / PENDGeoArea890Unit On/Off ShoreOnProgramEXPField & PoolWell bore segAnnular DisposalPTD#:2221520NA1 Permit fee attachedYes Entire Well lies within ADL0393519.2 Lease number appropriateYes3 Unique well name and numberNA Exploratory well4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitNA Vertical well8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes 80 ft - 16"63# H40 welded conductor pipe run18 Conductor string providedYes19 Surface casing protects all known USDWsYes 172% excess cement planned20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgNo Productive interval will be drilled, tested and plugged22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes Cuttings temporarily stored in ice-bermed drilling storage cell before hauling to approved disposal facility24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes Exploration well; no nearby wellbores26 Adequate wellbore separation proposedYes Diverter line route/straight line meets regulation27 If diverter required, does it meet regulationsYes Max formation pressure is 2986 psig(8.7 to 9.2 ppg EMW); will drill w/ 10.2 ppg EMW28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP is 2326 psig; will test BOPs to 3500 psig30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No H2S measures are required as this is a remote exploratory well.35 Permit can be issued w/o hydrogen sulfide measuresYes Normal pressure gradient expected except for potential overpressure up to 9.9 ppg in "Bear" target sands.36 Data presented on potential overpressure zonesYes Shallow gas (low potential) and gas hydrates (moderate potential from 750' to 1700' MD. Mitigation37 Seismic analysis of shallow gas zonesNA discussed on p. 35. Abnormal pressure and wellbore instability mitigation discussed on p. 36.38 Seabed condition survey (if off-shore)Yes Aaron Donat 907-265-108939 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate1/31/2023ApprVTLDate1/9/2023ApprSFDDate1/31/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateEntire well will be mud logged and pressure-while-drilling tools will be utilized to monitor equivalent circulating density (ECD) of the mud during drilling operations. Operator's planned mud program conforms to those used in nearest wells and appears adequate to maintain wellbore stability and mitigate expected pressures. SFDJLC 2/9/2023
